Text

Response to Request for Additional Information Regarding License Amendment Request to Adopt TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B
	ML101450001
Person / Time
Site:	Clinton
Issue date:	05/21/2010
From:	Hansen J L; Exelon Generation Co, Exelon Nuclear
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	RS-10-093, TAC ME3332
	Download: ML101450001 (217)
	v • d • e

Exelon Generation www.exeloncorp.com 4300 Winfield Road Nuclear Warrenville, 11 60555 RS- 1 0-093 10 CFR 50.90 May 21,201 0 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Clinton Power Station, Units 1 Facility Operating License No. NPF-62 NRC Docket No. 50-461

Subject:

Response to Request for Additional Information Regarding License Amendment Request to Adopt TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 58," (TAC No. ME3332)

References:

1. Letter from J. L. Hansen (Exelon Generation Company, LLC) to U. S. NRC, "Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)," dated February 15, 2010 2. Letter from U. S. NRC to Mr. C. G. Pardee (Exelon Generation Company, LLC), " Request for Additional Information Regarding License Amendment Request to Adopt TSTF-425, Revision 3, 'Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 58,' (ME3332)," dated April 22,2010 In Reference 1, Exelon Generation Company, LLC (EGC) requested an amendment to Appendix A, Technical Specifications (TS), of Facility Operating License No. NPF-62 for Clinton Power Station, Unit 1 (CPS). The proposed change modifies the TS by implementing the guidance found in Technical Specifications Task Force (TSTF) Traveler TSTF-425, "Relocate Surveillance Frequencies to Licensee Control - RITSTF lnitiative 5B," Revision 3. In Reference 2, the NRC requested that EGC provide additional information in support of their review of Reference

1. The NRC's request for additional information and the specific EGC responses are provided in Attachment 1 to this letter. Attachment 2 provides an updated version of the TS Bases markups associated with the proposed change for information only, as discussed in Attachment

1.

May 21,2009 U. S. Nuclear Regulatory Commission Page 2 There are no regulatory commitments contained within this letter.

If you have any questions concerning this letter, please contact Mr. Mitchel A. Mathews at (630) 657-281 9. I declare under penalty of perjury that the foregoing is true and correct. Executed on the 21 st day of May, 201 0. ~6na-Sef - Licensing and Regulatory Affairs Exelon Generation Company, LLC Attachments:

1. Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)

2. Revised Markup of Proposed Technical Specifications Bases Pages ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Request No 1. On license amendment request Attachment 1, page 3 of 5, 2.2 "Optional Changes and Variations," item number 3, CPS provided the following information regarding a variation from TSTF-425:

The insert provided in TSTF-425 to replace text describing the basis for each Frequency relocated to the Surveillance Frequency Control Program has been revised from, "The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program," to read

'The Frequency may be based on factors such as operating experience, equipment reliability, or plant risk, and is controlled under the

Surveillance Frequency Control Program." This deviation is necessary to reflect the CPS basis for frequencies which do not, in all cases, base Frequency on operating experience, equipment reliability, and plant risk.

While the above TSTF-425 deviation from the TSTF-425 Technical Specification Bases statement addresses Surveillance Frequencies

relocated to, but not changed under, the Surveillance Frequency Control Program (SFCP), it does not specifically exclude Surveillance Frequencies changes made in accordance with the SFCP and is, therefore, not consistent with SFCP requirements. Please provide additional clarification explaining how CPS intends to ensure that all

Surveillance Frequencies relocated to the SFCP, with or without subsequent Frequency change, will maintain: 1) Bases for unchanged Surveillance Frequencies and, 2) compliance with proposed CPS TS 5.5.16, "Surveillance Frequency Control Program" requirements. Request No. 1 Response:The proposed change described in Reference 1 requests NRC approval to relocate Surveillance Frequencies to the Surveillance Frequency Control Program (SFCP). Upon implementation of the proposed change, Exelon Generation Company, LLC (EGC) plans to relocate the existing Technical Specifications (TS) Bases information describing the basis for the Surveillance Frequencies to the SFCP. This will ensure that the information describing the bases for unchanged Surveillance Frequencies is maintained. As discussed in Reference 1, EGC proposed a variation from TSTF-425 that replaced text describing the basis for each Frequency relocated to the SFCP. This variation was necessary because, independent of whether Surveillance Frequencies have been changed under the SFCP, the Surveillance Frequencies are not, in all cases, based on operating experience, equipment reliability, and plant risk. As required by proposed TS Section 5.5.16, "Surveillance Frequency Control Program," subsequent changes to the Frequencies listed in the SFCP will be made in accordance with the NRC-endorsed methodology described in Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1. NEI 04-10 provides Page 1 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) the methodology to identify, assess, implement, and monitor proposed changes to Surveillance Frequencies. NEI 04-10 identifies the need to address both quantitative and qualitative considerations when changing Surveillance Frequencies. As discussed in Section 4.0, Step 7, qualitative considerations include vendor-specified maintenance frequency, test intervals specified in applicable industry codes and standards, impact on defense-in-depth protection, and the existence of alternate testing of structures, systems, and components (SSCs) affected by the change. These qualitative considerations provide

examples of instances where Surveillance Frequencies changed under the SFCP may not be based upon operating experience, equipment reliability, or plant risk. As a result, EGC's proposed variation from TSTF-425 provides wording that more accurately reflects the methodology described in NEI 04-10. However, in order to avoid future confusion regarding this issue, EGC plans to replace the Bases text insert proposed in Reference 1 (i.e., "The Frequency may be based on factors such as operating experience, equipment reliability, or plant risk, and is controlled under the Surveillance Frequency Control Program") with a revised insert that reads "The Surveillance Frequency is controlled under the Surveillance Frequency Control Program." A revised TS Bases markup showing this revision is provided in Attachment 2 for information only and does not require NRC

approval.Request No 2. In Table A.2-1 of Attachment 2 of the submittal, the peer review element identified as TH-8 states that additional room heatup calculations are

needed to support modeling assumptions for room cooling requirements. The impact is identified as "primarily a documentation issue," and further that "the PRA already makes appropriate

assumptions regarding the need for room cooling in the appropriate

areas." There is insufficient information for the staff to reach a

conclusion on the disposition of this peer review item. Specifically, for any areas for which room cooling is assumed to not be required where there is not a documented room heatup analysis to support the assumption, the licensee should identify room cooling assumptions and their bases. Note that there are similar concerns with Table A.2-2 of , gap #2, which should also be addressed in the response. Request No. 2 Response:Key Clinton Power Station (CPS) systems or areas for which the CPS Probabilistic Risk Assessment (PRA) assumes room cooling is not required for the PRA mission time and for which a specific loss of room cooling calculation does not exist are summarized in Table 1 below. The modeling approach used is reasonable given the plant design and would be consistent with approaches used in typical industry PRA models.

Page 2 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)

Table 1:

SUMMARY

OF SYSTEMS OR AREAS NOT REQUIRING ROOM COOLING IN CPS PRA AND WHERE NO SPECIFIC ROOM COOLING CALCULATION EXISTS System or Area Room Cooling Required in PRA?Mission Time (hr.) Bases/Assumptions Control Rod Drive (CRD) pumps No24 hrs The CRD pumps are located in the basement of the turbine building in a

large open area. The PRA does not require room cooling for the CRD pumps because the areas are sufficiently large that room temperature is expected to be

adequate over the PRA 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months mission

time.The CRD pumps and oil coolers are cooled by the Turbine Building Closed Cooling Water (TBCCW) system. This dependency is modeled in the PRA.

Feedwater/Condensate

Booster/CondensateNo24 hrs The Feedwater (FW), Condensate Booster (CB) and Condensate (CD) system pumps are located in different areas of the turbine building. The PRA

does not require room cooling for FW/CB/CD operation over the PRA 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months mission time. This is a common

industry PRA assumption.

These systems run continuously and room cooling is not a limiting

consideration for their operation. The FW/CB/CD pumps lube oil cooling is provided by TBCCW. This dependency

is modeled in the PRA.

Page 3 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)

Table 1:

SUMMARY

OF SYSTEMS OR AREAS NOT REQUIRING ROOM COOLING IN CPS PRA AND WHERE NO SPECIFIC ROOM COOLING CALCULATION EXISTS System or Area Room Cooling Required in PRA?Mission Time (hr.) Bases/Assumptions Battery Rooms No4 hrs Batteries are used in the PRA for short-term operation (e.g., bus switching, station blackout (SBO) scenarios).

Battery room heatup rates are modest even without room ventilation and would not impact operation of the batteries during their four-hour mission time. The PRA does not credit the batteries in long

term accident scenarios (i.e., greater than four hours). Battery room ventilation is also used to prevent reaching hydrogen concentration limits in the rooms. This is a longer term issue not significant to the PRA and not required in the PRA.

Page 4 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)

Table 1:

SUMMARY

OF SYSTEMS OR AREAS NOT REQUIRING ROOM COOLING IN CPS PRA AND WHERE NO SPECIFIC ROOM COOLING CALCULATION EXISTS System or Area Room Cooling Required in PRA?Mission Time (hr.) Bases/Assumptions Essential Switchgear

RoomsNo24 hrs At some plants, loss of cooling to electrical switchgear rooms is a concern.

At CPS, however, essential switchgear, including chargers in switchgear rooms, is located in large areas. These areas are normally supplied with ventilation and specific area coolers. Extended loss of ventilation could result in a controlled unit shutdown due to equipment qualification concerns. But the concerns would not be expected to

lead to a reactor scram.

The refrigeration and fans are not required in the CPS PRA for the switchgear rooms because they are sufficiently large that temperature related equipment failures are not expected to

occur over the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months mission. Main Control Room No24 The Main Control Room is normally cooled by the one of two subsystems of heating, ventilation, and air conditioning (HVAC). If the operating subsystem

fails, a redundant standby HVAC subsystem will be available for the cooling loads in these two areas.

Room heat-up is a slowly developing event. Complete loss of room cooling can be addressed by opening doors and use of temporary fans, as necessary.These actions are proceduralized and the equipment is pre-staged. The CPS PRA does not model or require control room ventilation.

Page 5 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)

Table 1:

SUMMARY

OF SYSTEMS OR AREAS NOT REQUIRING ROOM COOLING IN CPS PRA AND WHERE NO SPECIFIC ROOM COOLING CALCULATION EXISTS System or Area Room Cooling Required in PRA?Mission Time (hr.) Bases/Assumptions Plant Service Water No24 hrs The Plant Service Water (WS) Pumps are located within a large open area of

the Screenhouse that does not have

coolers. Consistent with this open design the PRA does not model Screenhouse ventilation for the WS

System.Service Air/Instrument

AirNo24 hrs.The Service Air (SA) Compressors (which also supply the Instrument Air System) are located in an open area of the Radwaste Building. It is assumed in the PRA that separate room ventilation is not required because of the large areas.The SA compressors require cooling water from the Component Cooling

Water System (CCW). This cooing dependency is modeled in the PRA.

Emergency Core Cooling System and Reactor Core Isolation Cooling Pump Rooms Yes24 hrs Room cooling for Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) is provided though the ECCS room cooling

system (VY). The VY coolers are

modeled in the PRA as dependencies

for the ECCS and RCIC systems for mission time operation. Alternately the model considers room cooling success for ECCS and RCIC rooms if operators open the Pump room doors connecting the ECCS and RCIC room doors with

the much larger Auxiliary or Fuel Building air volumes.

Page 6 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) Request No 3. In Table A.2-2 of Attachment 2 of the submittal, gap #3 regarding the process for developing pre-initiator human error events identifies four

specific deficiencies of the analysis. The importance is stated as "primarily a documentation issue." No adequate basis is provided for this statement. In fact, the status of the item implies that the

requirements are not actual but only "inferred" and states without a

basis that "other BWRs" which attempted to rigorously follow the standard model fewer pre-initiator events. The licensee needs to provide a more rigorous basis for why its method for identification of pre-initiator human error events actually conforms to the requirements of

the standard and that the deficiency is only a matter of documentation. Request No. 3 Response:As noted in the discussion of gap #3, the pre-initiator human error event approach is believed to meet the intent of the identified supporting requirements. There is no deficiency with regard to technical adequacy of the CPS PRA. The CPS PRA systems analysis-based approach to identification of pre-initiator human failure events (HFEs) is that the HFEs of interest should be those associated with the functions, systems or components that are significant contributors to the PRA results. The

CPS PRA identifies potential misalignment and miscalibration pre-initiator errors based on systems analysis methods (e.g., identifying which equipment can be misaligned and fail a train (or trains), which instrumentation could be postulated to be miscalibrated and fail a train (or trains), etc.) which is an accepted industry approach used in performing PRAs.

Although it is not an exhaustive review of procedures, as might be implied by the supporting

requirements under high-level requirement (HLR) HR-A, the results of the assessment are

consistent with the assessment conducted for the supporting requirements under HLR SY-A. This process is sufficiently systematic to provide a high degree of confidence that the relevant HFEs have been identified. The fact that the CPS PRA explicitly includes 107 pre-initiator operator actions, many more than typically modeled in Boiling Water Reactor (BWR)

PRAs, is evidence of the breadth of consideration of pre-initiator human actions. This approach is also consistent with the general knowledge, from nuclear plant PRA experience, that "misalignment" or "miscalibration" activities that do not result in common cause impacts are rarely significant contributors to PRA results. Thus, it is not appropriate to devote substantial PRA development resources to an exhaustive search for all possible pre-initiator human errors, as would be implied by a literal reading of Supporting Requirements HR-A1, HR-A2, and HR-A3. The CPS PRA pre-initiator action identification approach is a systems analysis based approach, and leads to the identification of an appropriate set of pre-initiator HEPs for inclusion in the PRA, as evidenced by the set of 107 such actions included in the model. Given the difference in the method used to achieve the results required by HLR HR-C of the PRA Standard, a rigorous comparison for how the CPS PRA pre-initiator identification process conforms to the full set of supporting requirements under HLR-A, -B, and -C is difficult to create. Hence, this gap has been identified as a documentation issue.

Page 7 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) This difference in approach is not a deficiency with the CPS PRA, but rather results from a prescription of method in these specific supporting requirements. As such, an inquiry has already been submitted to the ASME Committee on Nuclear Risk Management (CNRM) in this regard, and that Committee is considering a change to the Standard related to these supporting requirements. Request No 4. In Table A.2-2 of Attachment 2 of the submittal, gap #5 regarding failure data and unavailability data development is "...judged to have a non-significant impact...," "...judged to have a minimal impact...," and that the model is "reasonably consistent with data from the plant MR

database, which is adequate for future applications." No basis is provided for how these judgments have been reached given the identified gaps to the probabilistic risk assessment standard requirements. The licensee should more rigorously address the specific

impact of the deficiency on the failure data to justify the stated non-

significance for this application." Request No. 4 Response:Gap # 5 in Table A.2-2 relates to Supporting Requirement DA-C10. Capability Category II of Supporting Requirement DA-C10 states: When using surveillance test data, REVIEW the test procedure to determine whether a test should be credited for each possible failure

mode.COUNT only completed tests or unplanned operational demands as success for component operation. If the component failure mode is decomposed into sub-elements (or causes) that are fully tested, then USEtests that exercise specific sub-elements in their evaluation. Thus, one sub-element sometimes has many more successes than another.

[Example: a diesel generator is tested more frequently than the load sequencer.

IF the sequencer were to be included in the diesel generator boundary, the number of valid test would be significantly decreased.]The plant experience inputs used in the CPS PRA plant-specific component failure rate calculations are based on actual plant events, equipment rotations and run times, and

completed surveillance test information. The CPS PRA conforms to the intent of this supporting requirement to ensure that appropriate failure and exposure counts are used in the plant-specific component failure rate calculations.

Surveillance tests and actual system demands are the sources of the failures and successes and demands and exposure hours used in PRA plant-specific component failure estimates. The purpose of Supporting Requirement DA-C10 is to ensure that the identified failures and demands and exposure hours used in the PRA plant-specific component failure rate estimates do not under-estimate failure rates due to crediting test demands that do not fully test the failure modes in question.

Page 8 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) The level of detail implied by Supporting Requirement DA-C10 would not significantly impact the CPS PRA component failure rate calculations. The CPS PRA self-assessment identified this supporting requirement as a potential area of documentation enhancement. This enhancement would provide a detailed accounting of the CPS failure data gathering by test procedure, and assess how that approach compares against the current CPS PRA approach that utilizes the Mitigating System Performance Index (MSPI) and system engineer data. The CPS PRA performs Bayesian update statistical calculations for 66 component failure modes. Typical of industry practices, these calculations are performed using an industry generic prior distribution (e.g., NUREG-1715, "Component Performance Studies," data), or

posterior from previous revision of the PRA, and updated with plant specific failures and demand or exposure data. The CPS plant specific data for these Bayesian updated component failure rate calculations are obtained from CPS MSPI data if available, else from system engineers. This data is reasonable and appropriate. The numbers of identified failures for use in the PRA failure rate calculations are not expected to significantly change due to a test-by-test review versus PRA modeled failure modes. The denominator (i.e., demands and hourly exposure) estimates obtained from MSPI and system engineers can be postulated to change slightly if the method employed was to perform the test-by-test accounting. However, performing a documented accounting

of the failure and demand and exposure data against procedures is expected to result in non-significant changes to the Bayesian updated component failure rate calculations. Three illustrative component failure calculation examples are provided below. The essential service water system (SX) pumps are key components in the CPS risk profile.

The Bayesian updated component failure to run (i.e., per hour) rate for these pumps used an identified 0 failures in 660.6 run hours of plant specific experience, resulting in a posterior failure rate mean of 3.08E-5/hour. If it is conservatively postulated here that the hourly exposure period obtained from MSPI is 20% too high for this component failure mode, the Bayesian update calculation would result in 3.09E-5/hour. Such a small change in this one Bayesian updated failure rate has a negligible impact on core damage frequency (CDF) and large early release frequency (LERF) (i.e., CDF and LERF each change by <0.1%).

percent).Similarly, the Bayesian updated component failure to start (i.e., per demand) rate for the SX pumps used an identified 0 failures in 81 demands of plant specific experience, resulting in a posterior failure rate mean of 3.24E-3/demand. If it is conservatively postulated that the number of demands obtained from MSPI is 20% too high for this component failure mode, the Bayesian update calculation would result in 3.27E-3/demand. Such a small change in this one Bayesian updated failure rate has a negligible impact on CDF and LERF (i.e., CDF and LERF each change by <0.1%).

Page 9 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3) As another example, Supporting Requirement DA-C10 provides an example of an emergency diesel generator (EDG) tested separately from the load sequencer and at different testing frequencies. Given this example in the supporting requirement, an alternative modeling approach to the data gathering for the CPS EDGs could be devised to develop separate failure events in the PRA for "EDG Fails to Start/Load (not including sequencer)" and for "EDG Fails to Start/Load (due to sequencer)". However, such an approach is not necessary to obtain reasonable estimates for use in the PRA. Further information in this regard is provided below:

Review of NUREG/CR-5500, "Reliability Study: Emergency Diesel Generator Power System, 1987-1993," shows that sequencer failures have been assessed generically in the past at approximately 4% of EDG start failures.

No EDG failures have occurred in the data period of the current CPS PRA update. The Bayesian updated component failure to start (i.e., per demand) rate for the EDGs in the CPS PRA uses an identified no failures in 156 demands of plant specific experience, resulting in a posterior failure rate mean of 7.95E-3/demand.

If the NUREG/CR-5500 information is used to reduce the CPS PRA EDG prior distribution mean by 4% (i.e., 0.96 x the CPS EDG failure to start (FTS) prior mean) for use in a Bayesian update calculation of "EDG FTS (not including sequencer)" and using the 156 demands, the Bayesian updated posterior would be 7.73E-3/demand.

If the NUREG/CR-5500 information is used to estimate a prior distribution for EDG FTS due to sequencer failure (i.e., 0.04 x the CPS EDG FTS prior mean) and then Bayesian updated using 0 failures in six EDG sequencer surveillance tests (i.e., EDG sequencers assumed here only to receive valid test for data analysis during refueling outages (RFOs); two RFOs during the data analysis period of the current CPS PRA update and three EDGs), the Bayesian updated posterior value for "EDG Fails to Start/Load (due to sequencer)" would be 4.36E-4/demand.

The sum of these two results (i.e., 7.73E-3/demand "EDG FTS (not including sequencer)" + 4.36E-4/demand "EDG Fails to Start/Load (due to sequencer)" = 8.17E-3/demand) differs by less than 3% from the 7.95E-3/demand used in the current CPS PRA for EDG FTS.The above are examples of individual component failure rate calculations. The impact on CDF and LERF of variability in calculated component failure rates across the full PRA model can be investigated by a Monte Carlo sampling process of the entire model and component failure rate distributions. The CPS PRA base CDF and LERF results were processed through a Monte Carlo correlated sampling process (i.e., using the EPRI R&R Workstation UNCERT software, Version 2.3a) to test the variability in the mean CDF and LERF due to variability in component failure rates. To address the correlated sampling, 146 component failure rates covering both the plant specific calculations and other generic failure rates are included in the PRA "type code" database with failure rate distributions and linked to the appropriate component failure basic events. The Monte Carlo analysis then sampled from the "type code" database to ensure correlated sampling of the failure data. The review Page 10 of 11 ATTACHMENT 1 Additional Information Supporting the Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (Adoption of TSTF-425, Revision 3)

Page 11 of 11 included the performance of 100,000 Monte Carlo samples. The result of this uncertainty analysis showed that the propagated uncertainty mean of CDF and LERF each increased by less than 1% over the point-estimate values obtained from the base PRA quantification runs. In addition, the 95% percentiles of CDF and LERF remained well below regulatory thresholds (i.e., by approximately an order of magnitude).

ATTACHMENT 2 Revised Markup of Proposed Technical Specifications Bases Pages Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 REVISED MARKUP OF PROPOSED TECHNICAL SPECIFICATIONS BASES PAGES(Note: TS Bases pages are provided for information only.) B 3.1-19 B 3.3-59 B 3.3-214 B 3.5-26 B 3.6-124 B 3.8-47 B 3.1-26 B 3.3-63 B 3.3-219 B 3.6-14 B 3.6-127 B 3.8-48 B 3.1-32 B 3.3-64 B 3.3-220 B 3.6-22b B 3.6-131 B 3.8-56 B 3.1-36 B 3.3-72 B 3.3-221 B 3.6-26 B 3.6-132 B 3.8-57 B 3.1-40 B 3.3-73 B 3.3-228 B 3.6-28a B 3.7-6 B 3.8-68 B 3.1-41 B 3.3-74 B 3.3-229 B 3.6-31 B 3.7-6a B 3.8-68a B 3.1-42 B 3.3-82 B 3.3-235 B 3.6-34 B 3.7-9 B 3.8-68b B 3.1-43 B 3.3-83 B 3.3-236 B 3.6-37a B 3.7-16a B 3.8-73 B 3.1-47 B 3.3-84 B 3.4-7 B 3.6-42 B 3.7-16b B 3.8-77 B 3.1-48 B 3.3-119 B 3.4-11 B 3.6-43 B 3.7-21 B 3.8-87 B 3.2-4 B 3.3-120 B 3.4-16 B 3.6-47c B 3.7-24 B 3.8-92 B 3.2-8 B 3.3-120a B 3.4-21 B 3.6-52 B 3.7-24a B 3.8-96 B 3.2-11 B 3.3-120b B 3.4-22 B 3.6-55 B 3.7-27 B 3.8-97 B 3.3.23 B 3.3-121 B 3.4-27 B 3.6-58a B 3.7-29 B 3.9-4 B 3.3.24 B 3.3-132 B 3.4-27a B 3.6-63 B 3.8-13b B 3.9-7 B 3.3-25 B 3.3-133 B 3.4-35 B 3.6-64 B 3.8-14 B 3.9-11 B 3.3-26 B 3.3-134 B 3.4-38 B 3.6-65 B 3.8-15 B 3.9-18 B 3.3-27 B 3.3-170 B 3.4-42 B 3.6-76 B 3.8-16 B 3.9-21 B 3.3-27a B 3.3-171 B 3.4-47 B 3.6-77 B 3.8-17 B 3.9-24 B 3.3-28 B 3.3-172 B 3.4-52 B 3.6-81 B 3.8-18 B 3.9-28 B 3.3-29 B 3.3-173 B 3.4-58 B 3.6-82 B 3.8-19 B 3.9-32 B 3.3-30 B 3.3-182 B 3.4-60 B 3.6-88 B 3.8-19b B 3.10-9 B 3.3-30a B 3.3-183 B 3.4-61 B 3.6-88b B 3.8-21 B 3.10-10 B 3.3-36 B 3.3-184 B 3.4-63 B 3.6-94 B 3.8-22 B 3.10-14 B 3.3-37 B 3.3-185 B 3.5-10 B 3.6-95 B 3.8-23 B 3.10-15 B 3.3-38 B 3.3-194 B 3.5-11 B 3.6-101 B 3.8-24 B 3.10-20 B 3.3-39f B 3.3-195 B 3.5-12 B 3.6-101a B 3.8-25 B 3.10-25 B 3.3-39g B 3.3-196 B 3.5-13 B 3.6-105 B 3.8-26 B 3.10-28 B 3.3-39h B 3.3-205 B 3.5-14 B 3.6-105a B 3.8-28 B 3.10-37 B 3.3-39i B 3.3-206 B 3.5-14a B 3.6-105b B 3.8-29 B 3.10-38 B 3.3-46 B 3.3-207 B 3.5-20 B 3.6-111 B 3.8-30 B 3.10-41 B 3.3-47 B 3.3-212 B 3.5-20a B 3.6-118 B 3.8-31 B 3.10-45 B 3.3-48 B 3.3-213a B 3.5-24 B 3.6-119 B 3.8-32 B 3.10-46 B 3.3-58 B 3.3-213b B 3.5-25 B 3.6-121 B 3.8-45 Control Rod OPERABILITY B 3.1.3 CLINTON B 3.1-19 Revision No. 13-1 BASES (continued)

SURVEILLANCE SR 3.1.3.1 REQUIREMENTS The position of each control rod must be determined, to ensure adequate information on control rod position is available to the operator for determining control rod OPERABILITY and controlling rod patterns. Control rod

position may be determined by the use of OPERABLE position indicators, by moving control rods to a position with an OPERABLE indicator, or by the use of other appropriate methods. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this SR is based on

operating experience related to expected changes in control

rod position and the availability of control rod position indications in the control room.

SR 3.1.3.2 Deleted SR 3.1.3.3

Control rod insertion capability is demonstrated by inserting each partially or fully withdrawn control rod at

least one notch and observing that the control rod moves.

The control rod may then be returned to its original

position. This ensures the control rod is not stuck and is

free to insert on a scram signal. This Surveillance is modified by a note identifying that the Surveillance is not required to be performed when THERMAL POWER is less than or equal to the actual LPSP of the RPCS since the notch insertions may not be compatible with the requirements of

BPWS (LCO 3.1.6) and the RPCS (LCO 3.3.2.1). This note also provides a time allowance (i.e., the associated SR Frequency plus the extension allowed by SR 3.0.2) such that the

Surveillance is not required to be performed until the next scheduled control rod testing. This note provides this allowance to prevent unnecessary perturbations in reactor

operation to perform this testing on a control rod. The 31 day Frequency takes into account operating experience

related to changes in CRD performance. At any time, if a

control rod is (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Rod Scram Times B 3.1.4 CLINTON B 3.1-26 Revision No. 11-7 BASES SURVEILLANCE SR 3.1.4.2 REQUIREMENTS Additional testing of a sample of control rods is required to verify the continued performance of the scram function during the cycle. A representative sample contains at least 10% of the control rods. The sample remains "representative" if no more than 7.5% of the control rods in the tested sample are determined to be "slow." If more than

7.5% of the sample is declared to be "slow" per the criteria in Table 3.1.4-1, additional control rods are tested until

this 7.5% criterion (i.e., 7.5% of the entire sample size) is satisfied, or until the total number of "slow" control

rods throughout the core, from all surveillances) exceed the

LCO limit. For planned testing, the control rods selected

for the sample should be different for each test. Data from

inadvertent scrams should be used whenever possible to avoid

unnecessary testing at power, even if the control rods with

data were previously tested in a sample. The 200 day Frequency is based on operating experience that has shown

control rod scram times do not significantly change over an

operating cycle. This Frequency is also reasonable, based

on the additional Surveillances done on the CRDs at more

frequent intervals in accordance with LCO 3.1.3 and

LCO 3.1.5, "Control Rod Scram Accumulators."

With regard to scram time values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 8).

SR 3.1.4.3

When work that could affect the scram insertion time is performed on a control rod or the CRD System, testing must

be done to demonstrate that each affected control rod

retains adequate scram performance over the range of

applicable reactor pressures from zero to the maximum

permissible pressure. The scram testing must be performed once before declaring the control rod OPERABLE. The required scram time testing must demonstrate that the

affected control rod is still within acceptable limits by demonstrating an acceptable scram insertion time to notch

position 13. The scram time acceptance criteria for this

alternate test shall be determined by linear interpolation

between 0.95 seconds at a reactor coolant pressure of 0 psig

and 1.40 seconds at 950 psig. The limits for reactor

pressures < 950 psig are established based on a high

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Rod Scram Accumulators B 3.1.5 CLINTON B 3.1-32 Revision No. 5-9 BASES ACTIONS D.1 (continued) The reactor mode switch must be immediately placed in the shutdown position if either Required Action and associated Completion Time associated with the loss of the CRD pump (Required Actions B.1 and C.1) cannot be met. This ensures

that all insertable control rods are inserted and that the reactor is in a condition that does not require the active function (i.e., scram) of the control rods. This Required Action is modified by a Note stating that the Required

Action is not applicable if all control rods associated with

the inoperable scram accumulators are fully inserted, since the function of the control rods has been performed.

SURVEILLANCE SR 3.1.5.1 REQUIREMENTS SR 3.1.5.1 requires that the accumulator pressure be checked every 7 days to ensure adequate accumulator pressure exists to provide sufficient scram force. The primary indicator of accumulator OPERABILITY is the accumulator pressure. A minimum accumulator pressure is specified, below which the

capability of the accumulator to perform its intended

function becomes degraded and the accumulator is considered inoperable. The minimum accumulator pressure of 1520 psig

is well below the expected pressure of 1750 psig (Ref. 2).

Declaring the accumulator inoperable when the minimum pressure is not maintained ensures that significant degradation in scram times does not occur. The 7 day

Frequency has been shown to be acceptable through operating

experience and takes into account indications available in the control room.

With regard to accumulator pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value

with respect to instrument uncertainties. This requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in the associated plant procedures (Ref. 6).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

periodically Control Rod Pattern B 3.1.6 CLINTON B 3.1-36 Revision No. 7-5 BASES ACTIONS B.1 and B.2 (continued) withdrawals have. Required Action B.1 is modified by a Note that allows the affected control rods to be bypassed in RACS in accordance with SR 3.3.2.1.9 to allow insertion only.

With nine or more OPERABLE control rods not in compliance with BPWS, the reactor mode switch must be placed in the shutdown position within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . With the reactor mode switch in Shutdown, the reactor is shut down, and therefore

does not meet the applicability requirements of this LCO.

The allowed Completion Time of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is reasonable to allow insertion of control rods to restore compliance, and is

appropriate relative to the low probability of a CRDA occurring with the control rods out of sequence.

SURVEILLANCE SR 3.1.6.1 REQUIREMENTS The control rod pattern is verified to be in compliance with the BPWS at a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency, ensuring the assumptions of

the CRDA analyses are met. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this

Surveillance was developed considering that the primary

check of the control rod pattern compliance with the BPWS is

performed by the RPC (LCO 3.3.2.1). The RPC provides

control rod blocks to enforce the required control rod

sequence and is required to be OPERABLE when operating at

< 16.7% RTP.

REFERENCES 1. USAR, Section 15.0

2. USAR, Section 15.4.9.

3. NUREG-0979, "NRC Safety Evaluation Report Related to the Final Design Approval of the GESSAR II BWR/6 Nuclear Island Design, Docket No. 50-447," Section 4.2.1.3.2, April 1983.

4. NUREG-0800, "Standard Review Plan," Section 15.4.9, "Radiological Consequences of Control Rod Drop Accident (BWR)," Revision 2, July 1981.

5. 10 CFR 100.11, "Determination of Exclusion Area, Low Population Zone, and Population Center Distance." (continued) periodicallyTheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SLC System B 3.1.7 CLINTON B 3.1-40 Revision No. 10-5 BASES

ACTIONS A.1 (continued) remaining OPERABLE subsystem could result in reduced SLC System shutdown capability. The 7 day Completion Time is based on the availability of an OPERABLE subsystem capable

of performing the intended SLC System function and the low

probability of a Design Basis Accident (DBA) or severe

transient occurring concurrent with the failure of the

Control Rod Drive System to shut down the plant.

B.1 If both SLC subsystems are inoperable, at least one subsystem must be restored to OPERABLE status within

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . The allowed Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is

considered acceptable, given the low probability of a DBA or

transient occurring concurrent with the failure of the

control rods to shut down the reactor.

C.1 and C.2

If any Required Action and associated Completion Time is not met, the plant must be brought to a MODE in which the LCO

does not apply. To achieve this status, the plant must be

brought to MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and MODE 4 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 3.1.7.1, SR 3.1.7.2, and SR 3.1.7.3 REQUIREMENTS SR 3.1.7.1 through SR 3.1.7.3 are 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Surveillances, verifying certain characteristics of the SLC System (i.e., the volume and temperature of the borated solution in the

storage tank, and temperature of the pump suction piping),

thereby ensuring the SLC System OPERABILITY without disturbing normal plant operation. These Surveillances

ensure the proper borated solution and temperature, including the temperature of the pump suction piping, are maintained. Maintaining a minimum specified borated solution temperature is important in ensuring that the boron

remains in solution and does not precipitate out in the (continued)

SLC System B 3.1.7 CLINTON B 3.1-41 Revision No. 4-6 BASES SURVEILLANCE SR 3.1.7.1, SR 3.1.7.2, and SR 3.1.7.3 (continued)

REQUIREMENTS storage tank or in the pump suction piping. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of these SRs is based on operating experience that has shown there are relatively slow variations in the measured parameters of volume and temperature.

With regard to volume and temperature values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Refs. 3, 4, 5).

SR 3.1.7.4 and SR 3.1.7.6

SR 3.1.7.4 verifies the continuity of the explosive charges in the injection valves to ensure proper operation will

occur if required. Other administrative controls, such as

those that limit the shelf life of the explosive charges, must be followed. The 31 day Frequency is based on

operating experience that has demonstrated the reliability

of the explosive charge continuity.

SR 3.1.7.6 verifies each valve in the system is in its correct position, but does not apply to the squib (i.e.,

explosive) valves. Verifying the correct alignment for

manual, power operated, and automatic valves in the SLC

System flow path ensures that the proper flow paths will

exist for system operation. A valve is also allowed to be

in the nonaccident position, provided it can be aligned to

the accident position from the control room. This is

acceptable since the SLC System is a manually initiated system. This Surveillance does not apply to valves that are locked, sealed, or otherwise secured in position, since they were verified to be in the correct position prior to locking, sealing, or securing. This verification of valve alignment does not apply to valves that cannot be inadvertently misaligned, such as check valves. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being

mispositioned are in the correct positions. The 31 day

Frequency is based on engineering judgment and is consistent

with the procedural controls governing valve operation that

ensure correct valve positions.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

SLC System B 3.1.7 CLINTON B 3.1-42 Revision No. 4-6 BASES SURVEILLANCE SR 3.1.7.5 REQUIREMENTS (continued) This Surveillance requires an examination of the sodium pentaborate solution by using chemical analysis to ensure the proper concentration of boron exists in the storage tank. SR 3.1.7.5 must be performed anytime boron or water

is added to the storage tank solution to establish that the boron solution concentration is within the specified limits.

This Surveillance must be performed anytime the solution temperature is restored to >

70°F, to ensure no significant boron precipitation occurred. The 31 day Frequency of this Surveillance is appropriate because of the relatively slow variation of boron concentration between surveillances.

With regard to boron concentration values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 6).

SR 3.1.7.7

Demonstrating each SLC System pump develops a flow rate

> 41.2 gpm at a discharge pressure >

1220 psig ensures that pump performance has not degraded during the fuel cycle.

This minimum pump flow rate requirement ensures that, when

combined with the sodium pentaborate solution concentration

requirements, the rate of negative reactivity insertion from the SLC System will adequately compensate for the positive

reactivity effects encountered during power reduction, cooldown of the moderator, and xenon decay. This test confirms one point on the pump design curve, and is indicative of overall performance. Such inservice

inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this Surveillance is

in accordance with the Inservice Testing Program.

Values obtained for flow rate and discharge pressure pursuant to this SR, as read from plant indication instrumentation, are considered to be nominal values and therefore do not require compensation for instrument indication uncertainties (Ref. 7).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SLC System B 3.1.7 CLINTON B 3.1-43 Revision No. 10-7 BASES SURVEILLANCE SR 3.1.7.8 and SR 3.1.7.9 REQUIREMENTS These Surveillances ensure that there is a functioning flow path from the boron solution storage tank to the RPV, including the firing of an explosive valve. The replacement charge for the explosive valve shall be from the same

manufactured batch as the one fired or from another batch that has been certified by having one of that batch successfully fired. The pump and explosive valve tested should be alternated such that both complete flow paths are

tested every 48 months, at alternating 24 month intervals.

The Surveillance may be performed in separate steps to prevent injecting boron into the RPV. An acceptable method

for verifying flow from the pump to the RPV is to pump

demineralized water from a test tank through one SLC subsystem and into the RPV. The 24 month Frequency is based on the need to perform this Surveillance under the

conditions that apply during a plant outage and the

potential for an unplanned transient if the Surveillance

were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance test; therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

Demonstrating that all piping between the boron solution storage tank and the suction inlet to the injection pumps is

unblocked ensures that there is a functioning flow path for

injecting the sodium pentaborate solution. An acceptable

method for verifying that the suction piping is unblocked is

to pump from the storage tank to the test tank. Following

this test, the piping will be drained and flushed with

demineralized water. The 24 month Frequency is acceptable since there is a low probability that the subject piping

will be blocked due to precipitation of the boron from

solution in the piping. This is especially true in light of

the daily temperature verification of this piping required

by SR 3.1.7.3. However, if, in performing SR 3.1.7.3, it is

determined that the temperature of this piping has fallen

below the specified minimum, SR 3.1.7.9 must be performed

once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after the piping temperature is

restored to >

70°F. (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.TheSurveillanceFrequencyis controlledundertheSurveillance FrequencyControlProgram.

SDV Vent and Drain Valves B 3.1.8 CLINTON B 3.1-47 Revision No. 10-7 BASES (continued)

SURVEILLANCE SR 3.1.8.1 REQUIREMENTS During normal operation, the SDV vent and drain valves should be in the open position (except when performing SR 3.1.8.2) to allow for drainage of the SDV piping.

Verifying that each valve is in the open position ensures

that the SDV vent and drain valves will perform their intended function during normal operation. This SR does not require any testing or valve manipulation; rather, it involves verification that the valves are in the correct

position. The 31 day Frequency is based on engineering

judgment and is consistent with the procedural controls governing valve operation, which ensure correct valve

positions. Improper valve position (closed) would not affect the isolation function.

SR 3.1.8.2

During a scram, the SDV vent and drain valves should close to contain the reactor water discharged to the SDV piping.

Cycling each valve through its complete range of motion (closed and open) ensures that the valve will function

properly during a scram. The 92 day Frequency is based on

operating experience and takes into account the level of

redundancy in the system design.

SR 3.1.8.3 SR 3.1.8.3 is an integrated test of the SDV vent and drain valves to verify total system performance. After receipt of

a simulated or actual scram signal, the closure of the SDV

vent and drain valves is verified. The closure time of

30 seconds after a receipt of a scram signal is based on the

bounding leakage case evaluated in the accident analysis.

Similarly, after receipt of a simulated or actual scram

reset signal, the opening of the SDV vent and drain valves

is verified. The LOGIC SYSTEM FUNCTIONAL TEST in

LCO 3.3.1.1 and the scram time testing of control rods in

LCO 3.1.3, "Control Rod OPERABILITY," overlap this

Surveillance to provide complete testing of the assumed

safety function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that

apply during a plant outage and the potential for an

unplanned transient if the Surveillance were performed with (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

SDV Vent and Drain Valves B 3.1.8 CLINTON B 3.1-48 Revision No. 10-7 BASES SURVEILLANCE SR 3.1.8.3 (continued)

REQUIREMENTS the reactor at power. Operating experience has shown these components usually pass the Surveillance; therefore, the Frequency was concluded to be acceptable from a reliability

standpoint.

With regard to SDV vent and drain valve closing time values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 4).

REFERENCES 1. USAR, Section 4.6.1.1.2.4.2.5.

2. 10 CFR 100.

3. NUREG-0803, "Generic Safety Evaluation Report Regarding Integrity of BWR Scram System Piping," August 1981.

4. Calculation IP-0-0017.

APLHGR B 3.2.1 CLINTON B 3.2-4 Revision No. 9-3 BASES

ACTIONS B.1 (continued)

POWER must be reduced to < 21.

6% RTP within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The allowed Completion Time is reasonable, based on operating

experience, to reduce THERMAL POWER to < 21.

6% RTP in an orderly manner and without challenging plant systems.

______________________________________________________________________________

SURVEILLANCE SR 3.2.1.1 REQUIREMENTS APLHGRs are required to be initially calculated within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is 21.6% RTP and then every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter. They are compared to the specified

limits in the COLR to ensure that the reactor is operating

within the assumptions of the safety analysis. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is based on both engineering judgment and recognition of the slowness of changes in power distribution under normal conditions. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowance after THERMAL POWER 21.6% RTP is achieved is acceptable given the large inherent margin to operating limits at low power levels.

With regard to APLHGR values obtained pursuant to this SR, as determined from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref.

6).

(continued) periodicallyTheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

MCPR B 3.2.2 CLINTON B 3.2-8 Revision No.

8-7 BASES

SURVEILLANCE SR 3.2.2.1 REQUIREMENTS The MCPR is required to be initially calculated within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is 21.6% RTP and then every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter. It is compared to the specified limits in the COLR to ensure that the reactor is operating within

the assumptions of the safety analysis. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

Frequency is based on both engineering judgment and recognition of the slowness of changes in power distribution during normal operation. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowance after THERMAL POWER reaches 21.6% RTP is acceptable given the large inherent margin to operating limits at low power

levels.

With regard to MCPR values obtained pursuant to this SR, as determined from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 9).

SR 3.2.2.2

Because the transient analyses may take credit for conservatism in the control rod scram speed performance, it

must be demonstrated that the specific scram speed

distribution is consistent with that used in the transient

analyses. SR 3.2.2.2 determines the actual scram speed

distribution and compares it with the assumed distribution.

The MCPR operating limit is then determined based either on

the applicable limit associated with scram times of LCO

3.1.4, "Control Rod Scram Times," or the realistic scram

times. The scram time dependent MCPR limits are contained

in the COLR. This determination must be preformed and any

necessary changes must be implemented with in 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after

each set of control rod scram time tests required by SR

3.1.4.1, SR 3.1.4,2, and SR 3.1.4.4 because the effective

scram speed distribution may change during the cycle or

after maintenance that could affect scram times. The 72

hour Completion Time is acceptable due to the relatively

minor changes in the actual control rod scram speed

distribution expected during the fuel cycle.

(continued) periodicallyTheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

LHGR B 3.2.3 CLINTON B 3.2-11 Revision No. 9-3 BASES ______________________________________________________________________________

LCO With only one recirculation loop in operation, in (continued) conformance with the requirements of LCO 3.4.1, "Recirculation Loops Operating," the limit is determined by multiplying the exposure dependent LHGR limit by the smaller of either LHGRFAC f, LHGRFAC p, and the LHGR single loop operation multiplier, where the single loop operation multiplier has been determined by a specific single recirculation loop analysis (Refs.

6 and 7). APPLICABILITY The LHGR limits are derived from fuel design analysis that is limiting at high power level conditions. At core thermal power levels < 21.

6% RTP, the reactor is operating with a substantial margin to the LHGR limits and, therefore, the Specification is only required when the reactor is operating at 21.6% RTP. ACTIONS A.1

If any LHGR exceeds its required limit, an assumption regarding an initial condition of the fuel design analysis is not met. Therefore, prompt action should be taken to restore the LHGR(s) to within its required limit(s) such

that the plant is operating within analyzed conditions and

within the design limits of the fuel rods. The 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

Completion Time is normally sufficient to restore the

LHGR(s) to within its limit and is acceptable based on the low probability of a transient occurring simultaneously with the LHGR out of specification.

B.1 If the LHGR cannot be restored to within its required limit within the associated Completion Time, the plant must be

brought to a MODE or other specified condition in which the

LCO does not apply. To achieve this status, THERMAL POWER

must be reduced to < 21.

6% RTP within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The allowed Completion Time is reasonable, based on operating experience, to reduce THERMAL POWER to < 21.

6% RTP in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.2.3.1 REQUIREMENTS The LHGRs are required to be initially calculated within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is 21.6% RTP and then every 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter. They are compared with the specified

limits in the COLR to ensure that the reactor is operating within the assumptions of the safety analysis. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is based on both engineering judgment and recognition of the slowness of changes in power distribution

during normal conditions. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowance after THERMAL POWER 21.6% RTP is achieved is acceptable given the large inherent margin to operating limits at lower power levels. ___________________________________________________________________(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

periodically RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-23 Revision No. 7-5 BASES ______________________________________________________________________________

SURVEILLANCE analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does REQUIREMENTS not significantly reduce the probability that the RPS will (continued) trip when necessary.

SR 3.3.1.1.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read

approximately the same value. Significant deviations

between the instrument channels could be an indication of

excessive instrument drift on one of the channels or

something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is

outside the criteria, it may be an indication that the

instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK

supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO.

SR 3.3.1.1.2

To ensure that the APRMs are accurately indicating the true core average power, the APRMs are calibrated to the reactor power calculated from a heat balance. The Frequency of once per 7 days is based on minor changes in LPRM sensitivity, which could affect the APRM reading between performances of

SR 3.3.1.1.8.

A restriction to satisfying this SR when < 21.6% RTP is provided that requires the SR to be met only at >

21.6% RTP because it is difficult to accurately maintain APRM

indication of core THERMAL POWER consistent with a heat

balance when < 21.6% RTP. At low power levels, a high degree (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fr eque ncyCo n t r olPr og r a m.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-24 Revision No. 7-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.2 (continued)

REQUIREMENTS of accuracy is unnecessary because of the large inherent margin to thermal limits (MCPR and APLHGR). At >

21.6% RTP, the Surveillance is required to have been satisfactorily

performed within the last 7 days in accordance with SR

3.0.2. A Note is provided which allows an increase in

THERMAL POWER above 21.6% if the 7 day Frequency is not met per SR 3.0.2. In this event, the SR must be performed

within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching or exceeding 21.6% RTP.

Twelve hours is based on operating experience and in

consideration of providing a reasonable time in which to

complete the SR.

With regard to core thermal power values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument

indication uncertainties (Ref. 11).

SR 3.3.1.1.3 The Average Power Range Monitor Flow Biased Simulated Thermal Power-High Function uses the recirculation loop

drive flows to vary the trip setpoint. This SR ensures that

the APRM Function accurately reflects the required setpoint

as a function of flow.

The Frequency of 7 days is based on engineering judgment, operating experience, and the reliability of this

instrumentation.

SR 3.3.1.1.4 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the

intended function. A successful test of the required

contact(s) of a channel relay may be performed by the

verification of the change of state of a single contact of

the relay. This clarifies what is an acceptable CHANNEL

FUNCTIONAL TEST of a relay. This is acceptable because all

of the other required contacts of the relay are verified by

other Technical Specifications and non-Technical

Specifications tests at least once per refueling interval

with applicable extensions.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

As noted, SR 3.3.1.1.4 is not required to be performed when entering MODE 2 from MODE 1 since testing of the MODE 2

required IRM and APRM Functions cannot be performed in

MODE 1 without utilizing jumpers, lifted leads, or movable (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-25 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.4 (continued)

REQUIREMENTS links. This allows entry into MODE 2 if the 7 day Frequency is not met per SR 3.0.2. In this event, the SR must be

performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2 from MODE 1.

Twelve hours is based on operating experience and in

consideration of providing a reasonable time in which to

complete the SR.

A Frequency of 7 days provides an acceptable level of system average availability over the Frequency interval and is based on reliability analysis (Ref. 9).

SR 3.3.1.1.5 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended Function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. A Frequency of 7 days provides an acceptable level of system average availability over the Frequency and is based on the reliability analysis of Reference 9.

SR 3.3.1.1.6 and SR 3.3.1.1.7

These Surveillances are established to ensure that no gaps in neutron flux indication exist from subcritical to power operation for monitoring core reactivity status.

The overlap between SRMs and IRMs is required to be demonstrated to ensure that reactor power will not be increased into a region without adequate neutron flux indication. This is required prior to withdrawing SRMs from

the fully inserted position since indication is being transitioned from the SRMs to the IRMs.

The overlap between IRMs and APRMs is of concern when reducing power into the IRM range. On power increases, the

system design will prevent further increases (initiate a rod

block) if adequate overlap is not maintained.

Overlap between IRMs and APRMs exists when sufficient IRMs and APRMs concurrently have onscale readings such that the transition between MODE 1 and MODE 2 can be made without either an APRM downscale rod block or an IRM upscale rod (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-26 Revision No. 12-4 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.6 and SR 3.3.1.1.7 (continued)

REQUIREMENTS block. Overlap between SRMs and IRMs similarly exists when, prior to withdrawing the SRMs from the fully inserted

position, IRMs are above the downscale value of 5 and

increasing as neutron flux increases, prior to the SRMs

indication reaching their upscale limit.

As noted, SR 3.3.1.1.7 is only required to be met during entry into MODE 2 from MODE 1. That is, after the overlap requirement has been met and indication has transitioned to the IRMs, maintaining overlap is not required (APRMs may be reading downscale once in MODE 2).

If overlap for a group of channels is not demonstrated (e.g., IRM/APRM overlap), the reason for the failure of the

Surveillance should be determined and the appropriate

channel(s) declared inoperable. Only those appropriate

channel(s) that are required in the current MODE or

condition should be declared inoperable.

A Frequency of 7 days is reasonable based on engineering judgment and the reliability of the IRMs and APRMs.

SR 3.3.1.1.8 LPRM gain settings are determined from the local flux profiles measured by the Traversing Incore Probe (TIP)

System. This establishes the relative local flux profile

for appropriate representative input to the APRM System.

The 2000 MWD/T Frequency is based on operating experience with LPRM sensitivity changes and the NRC Safety Evaluation documenting approval of License Amendment 181 (Reference 14).

SR 3.3.1.1.9 and SR 3.3.1.1.12 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the

intended function. A successful test of the required

contact(s) of a channel relay may be performed by the

verification of the change of state of a single contact of

the relay. This clarifies what is an acceptable CHANNEL

FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Any setpoint adjustment shall

be consistent with the assumptions of the current plant

specific setpoint methodology. The 92 day Frequency of SR

3.3.1.1.9 is based on the reliability analysis of

Reference 9.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-27 Revision No. 12-2 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.9 and SR 3.3.1.1.12 (continued)

REQUIREMENTS The 24 month Frequency for the Reactor Mode Switch -

Shutdown Position function is based on the need to perform this Surveillance under the conditions that apply during a

plant outage and the potential for an unplanned transient if

the Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually pass the Surveillance.

The 24-month Frequency for the Scram Discharge Volume float switch channel functional test is based on a plant-specific risk analysis documented in Reference 13. This analysis demonstrated that a surveillance test interval of 24 months resulted in a very small increase in core damage frequency and large early release frequency. In addition, this frequency supports optimizing radiological exposures as low as reasonably achievable.

SR 3.3.1.1.10 The calibration of analog trip modules provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less

conservative than the Allowable Value specified in

Table 3.3.1.1-1. If the trip setting is discovered to be

less conservative than accounted for in the appropriate

setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more

conservative than accounted for in the appropriate setpoint

methodology.

The Frequency of 92 days for SR 3.3.1.1.10 is based on the reliability analysis of Reference 9.

SR 3.3.1.1.11 and SR 3.3.1.1.13 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The SR 3.3.1.1.13 calibration for selected Functions is modified by a Note as identified in Table 3.3.1.1-1. This Note, which applies only to those Functions identified in

Table 3.3.1.1-1, is divided into three parts. Part 1 of the Note requires evaluation of instrument performance for the condition where the as-found setting for these instrument

channels is outside its As-Found Tolerance (AFT) but

conservative with respect to the Allowable Value.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-27a Revision No. 12-4 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.11 and SR 3.3.1.1.13 (continued)

REQUIREMENTS Evaluation of instrument performance will verify that the instrument will continue to behave in accordance with design-basis assumptions. The purpose of the assessment is to ensure confidence in the instrument performance prior to

returning the instrument to service. Initial evaluation will be performed by the technician performing the surveillance who will evaluate the instrument's ability to maintain a stable setpoint within the As-Left Tolerance (ALT). The technician's evaluation will be reviewed by on-

shift operations personnel during the approval of the surveillance data. Subsequent to returning the instrument

to service, the deviation is entered into the Corrective Action Program. In accordance with procedures, entry into the Corrective Action Program will require review and documentation of the condition for operability by on-shift operations personnel. Additional evaluation and potential corrective actions as necessary will ensure that any as-

found setting found outside the AFT is evaluated for long-

term operability trends. If the as-found channel setpoint is not conservative with respect to the Allowable Value, the

channel shall be declared inoperable. Part 2 of the Note requires that the instrument channel setpoint shall be reset to within the ALT of the Actual Trip Setpoint (ATSP). The ATSP is equivalent to or more conservative than the Nominal

Trip Setpoint (NTSP). The NTSP is the limiting value of the

sensed process variable at which a trip may be set in

accordance with the methodology documented in the ORM.

Therefore, the NTSP is equivalent to the Limiting Safety System Setting (LSSS) required by 10 CFR 50.36, "Technical

specifications." The Actual Trip Setpoint is also

calculated in accordance with the plant-specific setpoint

methodology as documented in the CPS ORM and may include additional margin. The ATSP will ensure that sufficient margin to the safety and/or analytical limit is maintained.

If the as-left instrument channel setpoint cannot be returned to within the ALT of the Actual Trip Setpoint, then

the channel shall be declared inoperable. Part 3 of the

Note indicates that the Nominal Trip Setpoint and the

methodology used to determine the Nominal Trip Setpoint, the As-Found Tolerance and the As-Left Tolerance bands are specified in the ORM.

Note 1 states that neutron detectors are excluded from CHANNEL CALIBRATION because of the difficulty of simulating a meaningful signal. Changes in neutron detector

sensitivity are compensated for by performing the 7 day calorimetric calibration (SR 3.3.1.1.2) and the 2000 MWD/T LPRM calibration against the TIPs (SR 3.3.1.1.8). A second Note is provided that requires the APRM and the IRM SRs to be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of entering MODE 2 from MODE 1.

(continued)

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-28 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.11 and SR 3.3.1.1.13 (continued)

REQUIREMENTS Testing of the MODE 2 APRM and IRM Functions cannot be performed in MODE 1 without utilizing jumpers, lifted leads, or movable links. This Note allows entry into MODE 2 from

MODE 1 if the associated Frequency is not met per SR 3.0.2.

Twelve hours is based on operating experience and in

consideration of providing a reasonable time in which to

complete the SR. The Frequency of SR 3.3.1.1.11 and SR

3.3.1.1.13 is based upon the assumption of the magnitude

of equipment drift in the setpoint analysis.

SR 3.3.1.1.14

The Average Power Range Monitor Flow Biased Simulated Thermal Power-High Function uses an electronic filter circuit to generate a signal proportional to the core THERMAL POWER from the APRM neutron flux signal. This filter circuit is representative of the fuel heat transfer dynamics that produce the relationship between the neutron

flux and the core THERMAL POWER. The filter time constant

is specified in the COLR and must be verified to ensure that

the channel is accurately reflecting the desired parameter.

The Frequency of 24 months is based on engineering judgment and reliability of the components.

With regard to filter time constant values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 11).

SR 3.3.1.1.15

The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific

channel. The functional testing of control rods, in

LCO 3.1.3, "Control Rod OPERABILITY," and SDV vent and drain

valves, in LCO 3.1.8, "Scram Discharge Volume (SDV) Vent and

Drain Valves," overlaps this Surveillance to provide

complete testing of the assumed safety function.

(continued)

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RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-29 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.15 (continued)

REQUIREMENTS The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by

the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the

components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the Surveillance.

SR 3.3.1.1.16

This SR ensures that scrams initiated from the Turbine Stop Valve Closure and Turbine Control Valve Fast Closure, Trip

Oil Pressure-Low Functions will not be inadvertently

bypassed when THERMAL POWER is >

33.3% RTP. This involves calibration of the bypass channels. Adequate margins for the instrument setpoint methodology are incorporated into the actual setpoint.

If any bypass channel setpoint is nonconservative such that the Functions are bypassed at >

33.3% RTP (e.g., due to open main steam line drain(s), main turbine bypass valve(s) or

other reasons), then the affected Turbine Stop Valve Closure

and Turbine Control Valve Fast Closure, Trip Oil

Pressure-Low Functions are considered inoperable.

Alternatively, the bypass channel can be placed in the

conservative condition (nonbypass). If placed in the

nonbypass condition, this SR is met and the channel is

considered OPERABLE.

The Frequency of 24 months is based on engineering judgment and reliability of the components.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillanceFrequencyControlProgram.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-30 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.1.17 REQUIREMENTS (continued) This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the

accident analysis. The RPS RESPONSE TIME acceptance

criteria are included in plant Surveillance procedures.

As noted, neutron detectors are excluded from RPS RESPONSE TIME testing because the principles of detector operation

virtually ensure an instantaneous response time. In

addition, for Functions 3, 4, and 5, the associated sensors

are not required to be response time tested. For these

Functions, response time testing for the remaining channel

components, including the ATMs, is required. This allowance

is supported by Reference 10. RPS RESPONSE TIME tests are

conducted on a 24 month STAGGERED TEST BASIS. Note 3 of SR 3.3.1.1.17 requires STAGGERED TEST BASIS Frequency for each

Function to be determined separately based on the four

channels as specified in Table 3.3.1.1-1. This Frequency is

based on the logic interrelationships of the various channels required to produce an RPS scram signal.

Therefore, staggered testing results in response time verification of these devices every 24 months. This Frequency is consistent with the typical industry refueling

cycle and is based upon plant operating experience, which shows that random failures of instrumentation components causing serious time degradation, but not channel failure, are infrequent.

With regard to RPS RESPONSE TIME values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and

therefore does not require compensation for instrument indication uncertainties (Ref. 12).

______________________________________________________________________________ (continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RPS Instrumentation B 3.3.1.1 CLINTON B 3.3-30a Revision No. 12-4 BASES ______________________________________________________________________________

REFERENCES 1. USAR, Section 7.2.

2. USAR, Section 5.2.2.

3. USAR, Section 6.3.3.

4. USAR, Chapter 15.

5. USAR, Section 15.4.1.2.

6. NEDO-23842, "Continuous Control Rod Withdrawal in the Startup Range," April 18, 1978.

7. USAR, Section 15.4.9.

8. Letter, P. Check (NRC) to G. Lainas (NRC), "BWR Scram Discharge System Safety Evaluation," December 1, 1980, as attached to NRC Generic Letter dated December 9, 1980. 9. NEDO-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System,"

March 1988.

10. NEDO-32291-A, "System Analyses for Elimination of Selected Response Time Testing Requirements," January 1994.

11. Calculation IP-0-0002.

12. Calculation IP-0-0024.

13. Risk Management Document No. 1073, "Scram Discharge Volume Level Instrument Surveillance Interval Extension Risk Assessment," dated November 17, 2006.

14. Letter from U. S. NRC to C. Pardee (AmerGen Energy Company, LLC), "Clinton Power Station (CPS), Unit No. 1

- Issuance of Amendment Re: License Amendment Request to Increase the Interval Between Local Power Range Monitor Calibrations from 1000 Megawatt-Days/Ton (MWD/T) to 2000 MWD/T as Required in CPS Technical Specification Surveillance Requirement 3.3.1.1.8 and 3.3.1.3.2 (TAC No. MD3795)," dated September 12, 2008.

SRM Instrumentation B 3.3.1.2 CLINTON B 3.3-36 Revision No. 0 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.2.1 and SR 3.3.1.2.3 (continued)

REQUIREMENTS The Frequency of once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for SR 3.3.1.2.1 is based on operating experience that demonstrates channel

failure is rare. While in MODES 3 and 4, reactivity changes

are not expected; therefore, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is

relaxed to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for SR 3.3.1.2.3. The CHANNEL CHECK

supplements less formal, but more frequent, checks of

channels during normal operational use of the displays

associated with the channels required by the LCO.

SR 3.3.1.2.2

To provide adequate coverage of potential reactivity changes in the core, one SRM is required to be OPERABLE in the

quadrant where CORE ALTERATIONS are being performed, and the

other OPERABLE SRM must be in an adjacent quadrant

containing fuel. Note 1 states that this SR is required to

be met only during CORE ALTERATIONS. It is not required to

be met at other times in MODE 5 since core reactivity

changes are not occurring. This Surveillance consists of a

review of plant logs to ensure that SRMs required to be

OPERABLE for given CORE ALTERATIONS are, in fact, OPERABLE.

In the event that only one SRM is required to be OPERABLE, per Table 3.3.1.2-1, footnote (b), only the a. portion of

this SR is required. Note 2 clarifies that more than one of

the three requirements can be met by the same OPERABLE SRM.

The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is based upon operating experience and

supplements operational controls over refueling activities, which include steps to ensure that the SRMs required by the

LCO are in the proper quadrant.

SR 3.3.1.2.4

This Surveillance consists of a verification of the SRM instrument readout to ensure that the SRM reading is greater than a specified minimum count rate. This ensures that the detectors are indicating count rates indicative of neutron flux levels within the core. Verification of the signal to

noise ratio also ensures that the detectors are inserted to

a normal operating level. In a fully withdrawn condition, the detectors are sufficiently removed from the fueled

(continued)

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SRM Instrumentation B 3.3.1.2 CLINTON B 3.3-37 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.2.4 (continued)

REQUIREMENTS region of the core to essentially eliminate neutrons from reaching the detector. Any count rate obtained while fully

withdrawn is assumed to be "noise" only. With few fuel

assemblies loaded, the SRMs will not have a high enough

count rate to satisfy the SR. Therefore, allowances are

made for loading sufficient "source" material, in the form

of irradiated fuel assemblies, to establish the minimum

count rate.

To accomplish this, the SR is modified by a Note that states that the count rate is not required to be met on an SRM that

has less than or equal to four fuel assemblies adjacent to

the SRM and no other fuel assemblies are in the associated

core quadrant. With four or less fuel assemblies loaded

around each SRM and no other fuel assemblies in the

associated quadrant, even with a control rod withdrawn the

configuration will not be critical.

The Frequency is based upon channel redundancy and other information available in the control room, and ensures that

the required channels are frequently monitored while core

reactivity changes are occurring. When no reactivity

changes are in progress, the Frequency is relaxed from

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

With regard to count rate values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 1).

SR 3.3.1.2.5 Performance of a CHANNEL FUNCTIONAL TEST demonstrates the associated channel will function properly. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The 31 day Frequency is based on operating experience and on other

Surveillances (such as CHANNEL CHECK) that ensure proper

functioning between CHANNEL FUNCTIONAL TESTS.

(continued)

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SRM Instrumentation B 3.3.1.2 CLINTON B 3.3-38 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.1.2.5 (continued)

REQUIREMENTS The Note to the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the

Applicability. The SR must be performed in MODE 2 within

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of entering MODE 2 with IRMs on Range 2 or below.

The allowance to enter the Applicability with the 31 day Frequency not met is reasonable, based on the limited time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowed after entering the Applicability and the

inability to perform the Surveillance while at higher power

levels. Although the Surveillance could be performed while

on IRM Range 3, the plant would not be expected to maintain

steady state operation at this power level. In this event, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is reasonable, based on the SRMs being

otherwise verified to be OPERABLE (i.e., satisfactorily

performing the CHANNEL CHECK) and the time required to

perform the Surveillances.

SR 3.3.1.2.6

Performance of a CHANNEL CALIBRATION verifies the performance of the SRM detectors and associated circuitry.

The Frequency considers the plant conditions required to

perform the test, the ease of performing the test, and the

likelihood of a change in the system or component status.

The neutron detectors are excluded from the CHANNEL

CALIBRATION because they cannot readily be adjusted. The

detectors are fission chambers that are designed to have a

relatively constant sensitivity over the range, and with an

accuracy specified for a fixed useful life.

The Note to the Surveillance allows the Surveillance to be delayed until entry into the specified condition of the Applicability. The SR must be performed in MODE 2 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of entering MODE 2 with IRMs on Range 2 or below. The allowance to enter the Applicability with the 24 month Frequency not met is reasonable, based on the limited time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months allowed after entering the Applicability and the inability to perform the Surveillance while at higher power levels. Although the Surveillance could be performed while on IRM Range 3, the plant would not be expected to maintain steady state operation at this power level. In this event, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is reasonable, based on the SRMs being otherwise verified to be OPERABLE (i.e., satisfactorily (continued TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

OPRM Instrumentation B 3.3.1.3 CLINTON B 3.3-39f Revision No. 12-4 BASES SURVEILLANCE For the following OPRM instrumentation Surveillances, REQUIREMENTS both OPRM modules are tested, although only one is required (continued) to satisfy the Surveillance Requirement. SR 3.3.1.3.1 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the channel will perform the intended

function. A Frequency of 184 days provides an acceptable level of system average unavailability over the Frequency

interval and is based on the reliability of the channel (Reference 7).

SR 3.3.1.3.2 LPRM gain settings are determined from the local flux profiles measured by the Traversing Incore Probe (TIP)

System. This establishes the relative local flux profile for

appropriate representative input to the APRM System. The

2000 MWD/T Frequency is based on operating experience with LPRM sensitivity changes and the NRC Safety Evaluation documenting approval of License Amendment 181 (Reference 12).

SR 3.3.1.3.3 The CHANNEL CALIBRATION is a complete check of the instrument loop. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to

account for instrument drifts between successive

calibrations, consistent with the plant specific setpoint

methodology. Calibration of the channel provides a check of

the internal reference voltage and the internal processor

clock frequency. It also compares the desired trip setpoint

with those in the processor memory. Since the OPRM is a

digital system, the internal reference voltage and processor clock frequency are, in turn, used to automatically calibrate the internal analog to digital converters. The nominal setpoints for the period based detection algorithm are

specified in the Core Operating Limits Report (COLR). As

noted, neutron detectors are excluded from CHANNEL

CALIBRATION because of the difficulty of simulating a

meaningful signal. Changes in neutron detector sensitivity are compensated for by performing the 2000 MWD/T LPRM calibration against the TIPs (SR 3.3.1.1.8). SR 3.3.1.1.8

thus also ensures the operability of the OPRM instrumentation.

The nominal setpoints for the OPRM trip function for the period based detection algorithm (PBDA) are specified in the

COLR. The PBDA trip setpoints are the number of confirmation

counts required to permit a trip signal and the peak to

average amplitude required to generate a trip signal.

The Frequency of 24 months is based upon the assumption of the magnitude of equipment drift provided by the equipment supplier (Reference 7).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

OPRM Instrumentation B 3.3.1.3 CLINTON B 3.3-39g Revision No. 11-1 BASES SURVEILLANCE SR 3.3.1.3.4 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific channel. The functional testing of control rods in LCO 3.1.3, "Control Rod OPRABILITY," and scram discharge volume (SDV) vent and drain valves in LCO 3.1.8, "Scram Discharge Volume (SDV) Vent and Drain Valves," overlaps this Surveillance to provide complete testing of the assumed safety function. The OPRM self-test function may be utilized to perform this testing for those components that it is designed to monitor.

The 24 month Frequency is based on engineering judgement and reliability of the components. Operating experience has shown these components usually pass the surveillance when performed at the 24 month Frequency.

SR 3.3.1.3.5 This SR ensures that trips initiated from the OPRM System will not be inadvertently bypassed when THERMAL POWER is 25% RTP and recirculation drive flow is the value corresponding to 60% of rated core flow. This normally involves calibration of the bypass channels. The 25% RTP value is the plant specific value for the enable region, as described in Reference 10.

These values have been conservatively selected so that specific, additional uncertainty allowances need not be applied. Specifically, for the THERMAL POWER, the Average Power Range Monitor (APRM) establishes the reference signal to enable the OPRM System at 25% RTP. Thus, the nominal setpoints corresponding to the values listed above (25% RTP and the value corresponding to 60% of rated core flow) will be used to establish the enabled region of the OPRM System trips. (References 1, 2, 6, 10, and 11)

The Frequency of 24 months is based on engineering judgement, high reliability of the components, and operating experience.

SR 3.3.1.3.6 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis (Reference 6). The OPRM self-test function may be utilized to perform this testing for those components it is designed to monitor. The RPS RESPONSE TIME acceptance criteria are included in plant Surveillance procedures.

As noted, neutron detectors are excluded from RPS RESPONSE TIME testing because the principles of detector operation (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

OPRM Instrumentation B 3.3.1.3 CLINTON B 3.3-39h Revision No. 12-4 BASES SURVEILLANCE SR 3.3.1.3.6 (continued)

REQUIREMENTS virtually ensure an instantaneous response time. RPS RESPONSE TIME tests are conducted on an 24 month STAGGERED TEST BASIS. This Frequency is consistent with the refueling cycle and is based upon operating experience, which shows that random failures of instrumentation components causing serious time degradation, but not channel failure, are infrequent.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Rod Block Instrumentation B 3.3.2.1 CLINTON B 3.3-39i Revision No. 12-4 BASES (continued)

REFERENCES 1. NEDO-31960, "BWR Owners' Group Long-Term Stability Solutions Licensing Methodology," June 1991.

2. NEDO-31960, "BWR Owners' Group Long-Term Stability Solutions Licensing Methodology," Supplement 1, March 1992. 3. NRC Letter, A. Thadani to L. A. England, "Acceptance for Referencing of Topical Reports NEDO-31960, Supplement 1, 'BWR Owners' Group Long-Term Stability Solutions Licensing Methodology'," July 12, 1994.

4. Generic Letter 94-02, "Long-Term Solutions and Upgrade of Interim Operating Recommendations for Thermal-Hydraulic Instabilities in Boiling Water Reactors,"

July 11, 1994.

5. BWROG Letter BWROG-94079, "Guidelines for Stability Interim Corrective Action," June 6, 1994.

6. NEDO-32465-A, "BWR Owners' Group Reactor Stability Detect and Suppress Solution Licensing Basis Methodology and reload Application," August 1996.

7. CENPD-400-P, Rev. 01, "Generic Topical Report for the ABB Option III Oscillation Power Range Monitor (OPRM),"

May 1995.

8. NRC Letter, B. Boger to R. Pinelli, "Acceptance of Licensing Topical Report CENPD-400-P, 'Generic Topical Report for the ABB Option III Oscillation Power Range Monitor (OPRM)'," August 16, 1995.

9. NEDO-30851-P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System," March 1988. 10. NEDC-32989P, "Safety Analysis Report for Clinton Power Station Extended Power Uprate," dated June 2001.

11. Letter from K. P. Donovan (BWR Owners' Group) to U. S.

NRC, "Guidelines for Stability Option III 'Enabled Region'," dated September 17, 1996.

12. Letter from U. S. NRC to C. Pardee (AmerGen Energy Company, LLC), "Clinton Power Station (CPS), Unit No. 1

- Issuance of Amendment Re: License Amendment Request to Increase the Interval Between Local Power Range Monitor Calibrations from 1000 Megawatt-Days/Ton (MWD/T) to 2000 MWD/T as Required in CPS Technical Specification Surveillance Requirement 3.3.1.1.8 and 3.3.1.3.2 (TAC No. MD3795)," dated September 12, 2008.

Control Rod Block Instrumentation B 3.3.2.1 CLINTON B 3.3-46 Revision No. 7-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.2.1.1, SR 3.3.2.1.2, SR 3.3.2.1.3, and REQUIREMENTS SR 3.3.2.1.4 (continued)

The CHANNEL FUNCTIONAL TESTS for the RPC and RWL are performed by attempting to withdraw a control rod not in compliance with the prescribed sequence and verifying that a

control rod block occurs. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL

FUNCTIONAL TEST of a relay. This is acceptable because all

of the other required contacts of the relay are verified by other Technical Specifications and non-Technical

Specifications tests at least once per refueling interval with applicable extensions. SR 3.3.2.1.1 verifies proper operation of the two-notch withdrawal limit of the RWL and SR 3.3.2.1.2 verifies proper operation of the four-notch withdrawal limit of the RWL. SR 3.3.2.1.3 and SR 3.3.2.1.4 verify proper operation of the RPC. Any setpoint adjustment

shall be consistent with the assumptions of the current

plant specific setpoint methodology. As noted, the SRs are not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after specified

conditions are met (e.g., after any control rod is withdrawn in MODE 2). This allows entry into the appropriate conditions needed to perform the required SRs. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months allowance is based on operating experience and in

consideration of providing a reasonable time in which to

complete the SRs. The Frequencies are based on reliability

analysis (Ref. 6).

SR 3.3.2.1.5 The LPSP is the point at which the RPCS makes the transition between the function of the RPC and the RWL. This transition point is automatically varied as a function of

power. This power level is inferred from the first stage

turbine pressure (one channel to each trip system). These power setpoints must be verified periodically to be within the Allowable Values.

If any LPSP is nonconservative such that the RPC is bypassed at 16.7% RTP, then the RPC is considered inoperable.

Similarly, if the LPSP is nonconservative such that the RWL low power Function is bypassed at > 29.2% RTP, (e.g., due to open main steam line drain(s), main turbine bypass valve(s),

or other reasons), then the RWL is considered inoperable.

Since this channel has both upper and lower required limits, it is not allowed to be placed in a condition to enable

either the RPC or RWL Function.

The Frequency of 92 days is based on the setpoint methodology utilized for these channels.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Rod Block Instrumentation B 3.3.2.1 CLINTON B 3.3-47 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.2.1.6 REQUIREMENTS (continued) This SR ensures the high power function of the RWL is not bypassed when power is > 70% RTP. The power level is

inferred from turbine first stage pressure signals.

Periodic testing of the HPSP channels is required to verify the HPSP to be less than or equal to the limit. This involves calibration of the HPSP. Adequate margins in

accordance with setpoint methodologies are included.

If the HPSP is nonconservative such that the RWL high power Function is bypassed at > 70% RTP, (e.g., due to open main

steam line drain(s), main turbine bypass valve(s), or other

reasons), then the RWL is considered inoperable.

Alternatively, the HPSP can be placed in the conservative

condition (nonbypass). If placed in the nonbypassed

condition, the SR is met and the RWL would not be considered

inoperable.

The Frequency of 92 days is based on the setpoint methodology utilized for these channels.

SR 3.3.2.1.7

A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint

methodology.

The Frequency is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.2.1.8 The CHANNEL FUNCTIONAL TEST for the Reactor Mode Switch-Shutdown Position Function is performed by attempting to withdraw any control rod with the reactor mode switch in the shutdown position and verifying a control rod block occurs.

A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.

As noted in the SR, the Surveillance is not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after the reactor mode switch is in (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Control Rod Block Instrumentation B 3.3.2.1 CLINTON B 3.3-48 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.2.1.8 (continued)

REQUIREMENTS the shutdown position, since testing of this interlock with the reactor mode switch in any other position cannot be

performed without using jumpers, lifted leads, or movable

limits. This allows entry into MODES 3 and 4 if the

24 month Frequency is not met per SR 3.0.2. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months allowance is based on operating experience and in

consideration of providing a reasonable time in which to

complete the SRs.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the Surveillance.

SR 3.3.2.1.9

LCO 3.1.3 and LCO 3.1.6 may require individual control rods to be bypassed in RACS to allow insertion of an inoperable

control rod or correction of a control rod pattern not in

compliance with BPWS. With the control rods bypassed in the

RACS, the RPC will not control the movement of these

bypassed control rods. Individual control rods may also be

required to be bypassed to allow continuous withdrawal for

determining the location of leaking fuel assemblies or

adjustment of control rod speed. To ensure the proper

bypassing and movement of those affected control rods, a

second licensed operator or other qualified member of the

technical staff must verify the bypassing and movement of

these control rods is in conformance with applicable

analyses. Compliance with this SR allows the RPC and RWL to

be OPERABLE with these control rods bypassed.

REFERENCES 1. USAR, Section 7.6.1.7.

2. USAR, Section 15.4.2.

3. NEDE-24011-P-A, "General Electric Standard Application for Reload Fuel" (latest approved revision).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

PAM Instrumentation B 3.3.3.1 CLINTON B 3.3-58 Revision No. 4-1 BASES ______________________________________________________________________________

ACTIONS F.1 (continued) installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the

normal PAM channels. The Special Report shall be submitted

in accordance with 10 CFR 50.4 within 14 days of entering Condition F.

SURVEILLANCE The following SRs apply to each PAM instrumentation Function REQUIREMENTS in Table 3.3.3.1-1, except as noted below.

SR 3.3.3.1.1

Performance of the CHANNEL CHECK once every 31 days ensures that a gross instrumentation failure has not occurred. A

CHANNEL CHECK is normally a comparison of the parameter

indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of

excessive instrument drift in one of the channels or of

something even more serious. CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION. The high radiation instrumentation should be compared to similar plant instruments located throughout the plant.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including isolation, indication, and readability. If a

channel is outside the criteria, it may be an indication

that the sensor or the signal processing equipment has

drifted outside its limit.

The Frequency of 31 days is based upon plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of

a given function in any 31 day interval is rare. The

CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of those

displays associated with the required channels of this LCO.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

PAM Instrumentation B 3.3.3.1 CLINTON B 3.3-59 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.3.1.2 (Deleted)

REQUIREMENTS (continued) SR 3.3.3.1.3

For all Functions a CHANNEL CALIBRATION is performed every 24 months, or approximately at every refueling. CHANNEL CALIBRATION is a complete check of the instrument loop

including the sensor. The test verifies that the channel

responds to the measured parameter with the necessary range

and accuracy. The Frequency is based on operating

experience and consistency with the typical industry

refueling cycles.

The CHANNEL CALIBRATION of the Primary Containment and Drywell Area Radiation Functions consists of an electronic calibration of the channel, not including the detector, for

range decades above 10 R per hour and a one point

calibration check of the detector below 10 R per hour with

an installed or portable gamma source.

REFERENCES 1. Regulatory Guide 1.97, "Instrumentation for Light-Water Cooled Nuclear Power Plants to Assess

Plant and Environs Conditions During and Following an

Accident," Revision 3, May 1983.

2. SSER 5, Section 7.5.3.1.

3. USAR, Table 7.1-13.

4. USAR Section 7.5.1.4.2.4.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Remote Shutdown System B 3.3.3.2 CLINTON B 3.3-63 Revision No. 0 BASES ACTIONS A.1 (continued)

Condition A addresses the situation where one or more required Functions of the Remote Shutdown System is inoperable. This includes the control and transfer switches for any required Function.

The Required Action is to restore the Function (both divisions, if applicable) to OPERABLE status within 30 days.

The Completion Time is based on operating experience and the

low probability of an event that would require evacuation of

the control room.

B.1 If the Required Action and associated Completion Time of Condition A are not met, the plant must be brought to a MODE

in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Time is reasonable, based

on operating experience, to reach the required MODE from

full power conditions in an orderly manner and without

challenging plant systems.

SURVEILLANCE SR 3.3.3.2.1 REQUIREMENTS Performance of the CHANNEL CHECK once every 31 days ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter

indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read

approximately the same value. Significant deviations

between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is (continued)

Remote Shutdown System B 3.3.3.2 CLINTON B 3.3-64 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.3.2.1 (continued)

REQUIREMENTS outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted

outside its limit. As specified in the Surveillance, a

CHANNEL CHECK is only required for those channels that are normally energized.

The Frequency is based upon plant operating experience that demonstrates channel failure is rare.

SR 3.3.3.2.2 SR 3.3.3.2.2 verifies each required Remote Shutdown System transfer switch and control circuit performs the intended

function. This verification is performed from the remote

shutdown panel and locally, as appropriate. Operation of

the equipment from the remote shutdown panel and the local

control stations are not necessary. The Surveillance can be

satisfied by performance of a continuity check. This will

ensure that if the control room becomes inaccessible, the

plant can be placed and maintained in MODE 3 from the remote

shutdown panel and the local control stations. However, this Surveillance is not required to be performed only

during a plant outage. Operating experience demonstrates

that Remote Shutdown System control channels usually pass

the Surveillance.

SR 3.3.3.2.3

CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. The test verifies the channel responds to measured parameter values with the necessary range and accuracy.

The 24 month Frequency is based upon operating experience and is consistent with the typical industry refueling cycle.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 19.

2. Operational Requirements Manual, Attachment 1.

3. NUREG-0853, "Safety Evaluation Report Related to the Operation of Clinton Power Station, Unit No. 1,"

Supplement No. 6, July 1986, Section 7.4.3.1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

EOC-RPT Instrumentation B 3.3.4.1 CLINTON B 3.3-72 Revision No. 5-5 BASES (continued)

______________________________________________________________________________

SURVEILLANCE The Surveillances are modified by a Note to indicate that REQUIREMENTS when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated

Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains EOC-RPT trip capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be

returned to OPERABLE status or the applicable Condition entered and Required Actions taken. This Note is based on the reliability analysis (Ref. 6) assumption of the average

time required to perform channel surveillance. That

analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does

not significantly reduce the probability that the

recirculation pumps will trip when necessary.

SR 3.3.4.1.1

A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Any setpoint adjustment shall be consistent with the assumptions of the current plant

specific setpoint methodology.

The Frequency of 92 days is based on reliability analysis (Ref. 6).

SR 3.3.4.1.2

CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel

responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The Frequency is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

EOC-RPT Instrumentation B 3.3.4.1 CLINTON B 3.3-73 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.4.1.3 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific

channel. The system functional test of the pump breakers is

included as a part of this test, overlapping the LOGIC SYSTEM FUNCTIONAL TEST, to provide complete testing of the

associated safety function. Therefore, if a breaker is incapable of operating, the associated instrument channels would also be inoperable.

The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self Test System may be tested at the frequency recommended by the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass the Surveillance test.

SR 3.3.4.1.4

This SR ensures that an EOC-RPT initiated from the TSV Closure and TCV Fast Closure, Trip Oil Pressure-Low

Functions will not be inadvertently bypassed when THERMAL

POWER is >

33.3% RTP. This involves calibration of the bypass channels. Adequate margins for the instrument setpoint methodologies are incorporated into the actual

setpoint. If any bypass channel's setpoint is

nonconservative such that the Functions are bypassed at 33.3% RTP (e.g., due to open main steam line drain(s), main turbine bypass valve(s) or other reasons), the affected TSV Closure and TCV Fast Closure, Trip Oil Pressure-Low Functions are considered

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

EOC-RPT Instrumentation B 3.3.4.1 CLINTON B 3.3-74 Revision No. 12-3 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.4.1.4 (continued)

REQUIREMENTS inoperable. Alternatively, the bypass channel can be placed in the conservative condition (nonbypass). If placed in the

nonbypass condition, this SR is met and the channel

considered OPERABLE.

The Frequency of 24 months has shown that channel bypass failures between successive tests are rare.

SR 3.3.4.1.5

This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the accident analysis. The EOC-RPT SYSTEM RESPONSE TIME acceptance criteria are included in applicable plant procedures and include an assumed RPT breaker interruption time of 80 milliseconds. This assumed RPT breaker

interruption time is validated by the performance of

periodic mechanical timing checks, contact wipe and erosion

checks, and high potential tests on each breaker in

accordance with plant procedures at least once per 48 months. The acceptance criterion for the RPT breaker mechanical timing check shall be 41 milliseconds (for trip coil TC2).

EOC-RPT SYSTEM RESPONSE TIME tests are conducted on an 24 month STAGGERED TEST BASIS. The Note requires STAGGERED

TEST BASIS Frequency to be determined on a per Function

basis. This is accomplished by testing all channels of one

Function every 24 months on an alternating basis such that

both Functions are tested every 48 months. This Frequency

is based on the logic interrelationships of the various

channels required to produce an EOC-RPT signal. Response

times cannot be determined at power because operation of

final actuated devices is required. Therefore, this

Frequency is consistent with the typical industry refueling

cycle and is based upon plant operating experience, which

shows that random failures of instrumentation components

that cause serious response time degradation, but not

channel failure, are infrequent occurrences.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

ATWS-RPT Instrumentation B 3.3.4.2 CLINTON B 3.3-82 Revision No. 8-1 BASES (continued)

______________________________________________________________________________

SURVEILLANCE REQUIREMENTS SR 3.3.4.2.1

Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that gross failure of instrumentation has not occurred. A

CHANNEL CHECK is normally a comparison of the parameter

indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read

approximately the same value. Significant deviations

between the instrument channels could be an indication of

excessive instrument drift in one of the channels or

something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying that the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays

associated with the required channels of this LCO.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ATWS-RPT Instrumentation B 3.3.4.2 CLINTON B 3.3-83 Revision No. 8-1 BASES_________________________________________________________________________

SURVEILLANCE SR 3.3.4.2.2 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the

intended function. A successful test of the required

contact(s) of a channel relay may be performed by the

verification of the change of state of a single contact of

the relay. This clarifies what is an acceptable CHANNEL

FUNCTIONAL TEST of a relay. This is acceptable because all

of the other required contacts of the relay are verified by

other Technical Specifications and non-Technical

Specifications tests at least once per refueling interval

with applicable extensions.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint

methodology.

SR 3.3.4.2.3

Calibration of trip units provides a check of the actual trip setpoints. The channel must be declared inoperable if

the trip setting is discovered to be less conservative than

the Allowable Value specified in SR 3.3.4.2.4. If the trip

setting is discovered to be less conservative than the

setting accounted for in the appropriate setpoint

methodology, but is not beyond the Allowable Value, the

channel performance is still within the requirements of the

plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.

SR 3.3.4.2.4

A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint methodology.

The Frequency is based upon the assumption of the magnitude of equipment drift in the setpoint analysis.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ATWS-RPT Instrumentation B 3.3.4.2 CLINTON B 3.3-84 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.4.2.5 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required trip logic for a specific

channel. The system functional test of the pump breakers, included as part of this Surveillance, overlaps the LOGIC SYSTEM FUNCTIONAL TEST to provide complete testing of the

assumed safety function. Therefore, if a breaker is

incapable of operating, the associated instrument channel(s)

would be inoperable.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the Surveillance.

REFERENCES 1. USAR, Section 7.7.1.25.2

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCS Instrumentation B 3.3.5.1 CLINTON B 3.3-119 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE taken. This Note is based on the reliability analysis REQUIREMENTS (Ref. 4) assumption of the average time required to perform (continued) channel Surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does not significantly reduce the

probability that the ECCS will initiate when necessary.

SR 3.3.5.1.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A

CHANNEL CHECK is normally a comparison of the parameter

indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read

approximately the same value. Significant deviations

between the instrument channels could be an indication of

excessive instrument drift in one of the channels or

something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is

outside the criteria, it may be an indication that the

instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of

channels during normal operational use of the displays

associated with the channels required by the LCO.

SR 3.3.5.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. For series Functions, a separate CHANNEL FUNCTIONAL TEST is not required for each Function, provided each Function is tested. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCS Instrumentation B 3.3.5.1 CLINTON B 3.3-120 Revision No. 10-6 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.5.1.2 (continued)

REQUIREMENTS Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint

methodology.

The Frequency of 92 days is based on the reliability analyses of Reference 4.

SR 3.3.5.1.3 The calibration of ATMs provides a check of the actual trip setpoints. The channel must be declared inoperable if the

trip setting is discovered to be not within its required

Allowable Value specified in Table 3.3.5.1-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not

beyond the Allowable Value, the channel performance is still

within the requirements of the plant safety analyses. Under

these conditions, the setpoint must be readjusted to be

equal to or more conservative than the setting accounted for

in the appropriate setpoint methodology.

The SR 3.3.5.1.3 calibration for selected Functions is modified by a Note as identified in Table 3.3.5.1-1. This Note, which applies only to those Functions identified in Table 3.3.5.1-1, is divided into three parts. Part 1 of the Note requires evaluation of instrument performance for the condition where the as-found setting for these instrument channels is outside its As-Found Tolerance (AFT) but conservative with respect to the Allowable Value.

Evaluation of instrument performance will verify that the instrument will continue to behave in accordance with design-basis assumptions. The purpose of the assessment is to ensure confidence in the instrument performance prior to returning the instrument to service. Initial evaluation will be performed by the technician performing the surveillance who will evaluate the instrument's ability to maintain a stable setpoint within the As-Left Tolerance (ALT). The technician's evaluation will be reviewed by on-shift operations personnel during the approval of the surveillance data. Subsequent to returning the instrument to service, the deviation is entered into the Corrective Action Program. In accordance with procedures, entry into the Corrective Action Program will require review and documentation of the condition for operability by on-shift operations personnel. Additional evaluation and potential corrective actions as necessary will ensure that any as-found setting found outside the AFT is evaluated for long-term operability trends. If the as-found channel setpoint is not conservative with respect to the Allowable Value, the (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

ECCS Instrumentation B 3.3.5.1 CLINTON B 3.3-120a Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.5.1.3 (continued)

REQUIREMENTS channel shall be declared inoperable. Part 2 of the Note requires that the instrument channel setpoint shall be reset

to within the ALT of the Actual Trip Setpoint (ATSP). The

ATSP is equivalent to or more conservative than the Nominal Trip Setpoint (NTSP). The NTSP is the limiting value of the

sensed process variable at which a trip may be set in

accordance with the methodology documented in the ORM.

Therefore, the NTSP is equivalent to the Limiting Safety

System Setting (LSSS) required by 10 CFR 50.36, "Technical

specifications." The Actual Trip Setpoint is also calculated in accordance with the plant-specific setpoint

methodology as documented in the CPS ORM and may include additional margin. The ATSP will ensure that sufficient margin to the safety and/or analytical limit is maintained.

If the as-left instrument channel setpoint cannot be

returned to within the ALT of the Actual Trip Setpoint, then the channel shall be declared inoperable. Part 3 of the

Note indicates that the Nominal Trip Setpoint and the

methodology used to determine the Nominal Trip Setpoint, the As-Found Tolerance and the As-Left Tolerance bands are

specified in the ORM.

The Frequency of 92 days is based on the reliability analysis of Reference 4.

SR 3.3.5.1.4 and SR 3.3.5.1.6

A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel

responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The SR 3.3.5.1.4 and SR 3.3.5.1.6 calibrations for selected Functions are modified by a Note as identified in Table 3.3.5.1-1. This Note, which applies only to those Functions identified in Table 3.3.5.1-1, is divided into three parts.

Part 1 of the Note requires evaluation of instrument

performance for the condition where the as-found setting for

these instrument channels is outside its As-Found Tolerance (AFT) but conservative with respect to the Allowable Value.

Evaluation of instrument performance will verify that the instrument will continue to behave in accordance with

design-basis assumptions. The purpose of the assessment is to ensure confidence in the instrument performance prior to returning the instrument to service. Initial evaluation

will be performed by the technician performing the

surveillance who will evaluate the instrument's ability to

maintain a stable setpoint within the As-Left Tolerance (ALT). The technician's evaluation will be reviewed by on-

shift operations personnel during the approval of the (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCS Instrumentation B 3.3.5.1 CLINTON B 3.3-120b Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.5.1.4 and SR 3.3.5.1.6 (continued)

REQUIREMENTS surveillance data. Subsequent to returning the instrument to service, the deviation is entered into the Corrective Action Program. In accordance with procedures, entry into the Corrective Action Program will require review and

documentation of the condition for operability by on-shift operations personnel. Additional evaluation and potential corrective actions as necessary will ensure that any as-found setting found outside the AFT is evaluated for long-term operability trends. If the as-found channel setpoint is not conservative with respect to the Allowable Value, the

channel shall be declared inoperable. Part 2 of the Note

requires that the instrument channel setpoint shall be reset

to within the ALT of the Actual Trip Setpoint (ATSP). The ATSP is equivalent to or more conservative than the Nominal

Trip Setpoint (NTSP). The NTSP is the limiting value of the

sensed process variable at which a trip may be set in

accordance with the methodology documented in the ORM.

Therefore, the NTSP is equivalent to the Limiting Safety System Setting (LSSS) required by 10 CFR 50.36, "Technical

specifications." The Actual Trip Setpoint is also calculated in accordance with the plant-specific setpoint

methodology as documented in the CPS ORM and may include

additional margin. The ATSP will ensure that sufficient

margin to the safety and/or analytical limit is maintained.

If the as-left instrument channel setpoint cannot be

returned to within the ALT of the Actual Trip Setpoint, then

the channel shall be declared inoperable. Part 3 of the Note indicates that the Nominal Trip Setpoint and the

methodology used to determine the Nominal Trip Setpoint, the As-Found Tolerance and the As-Left Tolerance bands are specified in the ORM.

The Frequencies are based upon the assumption of the magnitude of equipment drift in the setpoint analysis.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCS Instrumentation B 3.3.5.1 CLINTON B 3.3-121 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.5.1.5 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.1, LCO 3.5.2, LCO 3.7.2, LCO 3.8.1, and LCO 3.8.2

overlaps this Surveillance to provide complete testing of

the assumed safety function.

The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for unplanned transients if the

Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the Surveillance.

REFERENCES 1. USAR, Section 5.2.2.

2. USAR, Section 6.3.

3. USAR, Chapter 15.

4. NEDC-30936-P-A, "BWR Owners' Group Technical Specification Improvement Analyses for ECCS Actuation

Instrumentation, Part 2," December 1988.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RCIC System Instrumentation B 3.3.5.2 CLINTON B 3.3-132 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 2 and 5; and (b) for up REQUIREMENTS to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 3, and 4 provided the associated (continued) Function maintains trip capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the

channel must be returned to OPERABLE status or the

applicable Condition entered and Required Actions taken.

This Note is based on the reliability analysis (Ref. 2)

assumption of the average time required to perform channel

Surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

testing allowance does not significantly reduce the

probability that the RCIC will initiate when necessary.

SR 3.3.5.2.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read

approximately the same value. Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying that the

instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK

supplements less formal, but more frequent, checks of

channel status during normal operational use of the displays

associated with the channels required by the LCO.

SR 3.3.5.2.2

A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Any setpoint adjustment shall (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RCIC System Instrumentation B 3.3.5.2 CLINTON B 3.3-133 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.5.2.2 (continued)

REQUIREMENTS be consistent with the assumptions of the current plant specific setpoint methodology.

The Frequency of 92 days is based on the reliability analysis of Reference 2.

SR 3.3.5.2.3

The calibration of analog trip modules provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in

Table 3.3.5.2-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of

the plant safety analysis. Under these conditions, the

setpoint must be re-adjusted to be equal to or more

conservative than accounted for in the appropriate setpoint

methodology.

The Frequency of 92 days is based on the reliability analysis of Reference 2.

SR 3.3.5.2.4 and SR 3.3.5.2.6

CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel

responds to the measured parameter with the necessary range

and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The Frequencies are based on the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.5.2.5

The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific channel. The system functional testing performed in LCO 3.5.3 overlaps this Surveillance to provide complete

testing of the safety function.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RCIC System Instrumentation B 3.3.5.2 CLINTON B 3.3-134 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.5.2.5 (continued)

REQUIREMENTS The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer are based on mean time between failure analysis for the components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the Surveillance.

REFERENCES 1. USAR, Section 15.4.9.

2. NEDE-770-06-2, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical

Specifications," February 1991.

3. USAR, Section 5.4.6. TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 CLINTON B 3.3-170 Revision No. 5-2 BASES (continued)

______________________________________________________________________________

SURVEILLANCE As noted at the beginning of the SRs, the SRs for each REQUIREMENTS Primary Containment and Drywell Isolation Instrumentation Function are found in the SRs column of Table 3.3.6.1-1.

The Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed

for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains

isolation capability. Isolation capability may be maintained by ensuring that a sufficient number or arrangement of channels is maintained OPERABLE to effect the trip function, or by maintaining the affected primary containment and drywell isolation valves closed during performance of the surveillance. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the

channel must be returned to OPERABLE status or the

applicable Condition entered and Required Actions taken.

This Note is based on the reliability analysis (Refs. 5 and

6) assumption of the average time required to perform

channel Surveillance. That analysis demonstrated that the 6

hour testing allowance does not significantly reduce the

probability that the isolation valves will isolate the

penetration flow path(s) when necessary.

SR 3.3.6.1.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A

CHANNEL CHECK is normally a comparison of the parameter

indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read approximately the same value. Significant deviations between the instrument channels could be an indication of

excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit.

The Frequency is based on operating experience that demonstrates channel failure is rare.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 CLINTON B 3.3-171 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.1.1 (continued)

REQUIREMENTS The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use

of the displays associated with the channels required by the

LCO.

SR 3.3.6.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. For series Functions, a separate CHANNEL

FUNCTIONAL TEST is not required for each Function, provided

each Function is tested. A successful test of the required

contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

The Frequency is based on reliability analysis described in References 5 and 6.

SR 3.3.6.1.3 The calibration of analog trip modules consists of a test to provide a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value

specified in Table 3.3.6.1-1. If the trip setting is

discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the

requirements of the plant safety analysis. Under these

conditions, the setpoint must be readjusted to be equal to

or more conservative than accounted for in the appropriate

setpoint methodology.

The Frequency of 92 days is based on the reliability analysis of References 5 and 6.

SR 3.3.6.1.4, SR 3.3.6.1.5, and SR 3.3.6.1.8

CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 CLINTON B 3.3-172 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.1.4, SR 3.3.6.1.5, and SR 3.3.6.1.8 (continued)

REQUIREMENTS responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint

methodology.

The Frequencies of SR 3.3.6.1.4, SR 3.3.6.1.5, and SR 3.3.6.1.8 are based on the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.6.1.6

The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific

channel. The system functional testing performed on PCIVs

in LCO 3.6.1.3 and on drywell isolation valves in LCO

3.6.5.3 overlaps this Surveillance to provide complete

testing of the assumed safety function. (Likewise, system functional testing performed pursuant to LCO 3.7.1 overlaps this Surveillance to provide complete testing for verifying

automatic actuation capability for the Division 1 and 2 SX

subsystems.) The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply

during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance.

The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by

the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer are based on mean time between failure analysis for the components in the associated circuits.

SR 3.3.6.1.7 This SR ensures that the individual channel response times are less than or equal to the maximum values assumed in the

accident analysis. Testing is performed only on channels

where the assumed response time does not correspond to the

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 CLINTON B 3.3-173 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.1.7 (continued)

REQUIREMENTS diesel generator (DG) start time. For channels assumed to respond within the DG start time, sufficient margin exists

in the 12 second start time when compared to the typical

channel response time (milliseconds) so as to assure adequate response without a specific measurement test. The

instrument response times must be added to the MSIV closure

times to obtain the ISOLATION SYSTEM RESPONSE TIME.

ISOLATION SYSTEM RESPONSE TIME acceptance criteria are

included in applicable plant procedures.

As noted, the associated sensors are not required to be response time tested. Response time testing for the remaining channel components, including the ATMs, is required. This is supported by Reference 7.

Note 2 to SR 3.3.6.1.7 requires the STAGGERED TEST BASIS Frequency for each Function to be determined seperately

based on the number of channels as specified on Table 3.3.6.1-1. This Frequency is based on the logic interrelationships of the various channels required to

produce an isolation signal.

ISOLATION SYSTEM RESPONSE TIME tests are conducted on an 24 month STAGGERED TEST BASIS. This Frequency is consistent with the typical industry refueling cycle and is based upon plant operating experience that shows that random failures of instrumentation components causing serious response time

degradation, but not channel failure, are infrequent.

With regard to ISOLATION SYSTEM RESPONSE TIME values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 8).

REFERENCES 1. USAR, Section 6.2.

2. USAR, Chapter 15.

3. NEDO-31466, "Technical Specification Screening Criteria Application and Risk Assessment,"

November 1987.

4. USAR, Section 9.3.5.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Secondary Containment Isolation Instrumentation B 3.3.6.2 CLINTON B 3.3-182 Revision No. 0 BASES ______________________________________________________________________________

ACTIONS C.1.1, C.1.2, C.2.1, and C.2.2 (continued)

Alternatively, declaring the associated SCID(s) or SGT subsystem inoperable (Required Actions C.1.2 and C.2.2) is

also acceptable since the Required Actions of the respective

LCOs (LCO 3.6.4.2 and LCO 3.6.4.3) provide appropriate actions for the inoperable components.

One hour is sufficient for plant operations personnel to establish required plant conditions or to declare the

associated components inoperable without challenging plant

systems.

SURVEILLANCE As noted at the beginning of the SRs, the SRs for each REQUIREMENTS Secondary Containment Isolation instrumentation Function are located in the SRs column of Table 3.3.6.2-1.

The Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely

for performance of required Surveillances, entry into

associated Conditions and Required Actions may be delayed

for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function

maintains secondary containment isolation capability. Upon

completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

allowance, the channel must be returned to OPERABLE status

or the applicable Condition entered and Required Action(s)

taken. This Note is based on the reliability analysis (Refs. 3 and 4) assumption of the average time required to

perform channel Surveillance. That analysis demonstrated

that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does not significantly

reduce the probability that the SCIDs will isolate the

associated penetration flow paths and the SGT System will

initiate when necessary.

SR 3.3.6.2.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the indicated parameter for one instrument channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should

read approximately the same value. Significant deviations between the instrument channels could be an indication of

(continued)

Secondary Containment Isolation Instrumentation B 3.3.6.2 CLINTON B 3.3-183 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.2.1 (continued)

REQUIREMENTS excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is

outside the criteria, it may be an indication that the instrument has drifted outside its limit.

The Frequency is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK

supplements less formal, but more frequent, checks of

channels during normal operational use of the displays associated with the channels required by the LCO.

SR 3.3.6.2.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

The Frequency of 92 days is based upon the reliability analysis of References 3 and 4.

SR 3.3.6.2.3

Calibration of analog trip modules provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in

Table 3.3.6.2-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology, but is not beyond the Allowable Value, performance is still within the requirements of the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Secondary Containment Isolation Instrumentation B 3.3.6.2 CLINTON B 3.3-184 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.2.3 (continued)

REQUIREMENTS The Frequency of 92 days is based on the reliability analysis of References 3 and 4.

SR 3.3.6.2.4 and SR 3.3.6.2.6

CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel

responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The Frequencies are based upon the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.6.2.5

The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required isolation logic for a specific

channel. The system functional testing, performed on SCIDs

and the SGT System in LCO 3.6.4.2 and LCO 3.6.4.3, respectively, overlaps this Surveillance to provide complete

testing of the assumed safety function.

The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by

the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the

components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Secondary Containment Isolation Instrumentation B 3.3.6.2 CLINTON B 3.3-185 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.2.5 (continued)

REQUIREMENTS Operating experience has shown these components usually pass the Surveillance.

______________________________________________________________________________

REFERENCES 1. USAR, Section 6.2.3.

2. USAR, Chapter 15.

3. NEDO-31677-P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation," July 1990.

4. NEDC-30851-P-A Supplement 2, "Technical Specifications Improvement Analysis for BWR Isolation Instrumentations Common to RPS and ECCS

Instrumentation," March 1989.

5. USAR, Section 7.3.1.1.2.

6. USAR, Section 7.1.2.1.11.

7. USAR, Section 7.3.1.1.9.2.

8. USAR, Section 7.6.1.2.

RHR Containment Spray System Instrumentation B 3.3.6.3 CLINTON B 3.3-194 Revision No. 0 BASES ______________________________________________________________________________

SURVEILLANCE associated Conditions and Required Actions may be delayed REQUIREMENTS for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function (continued) maintains RHR containment spray initiation capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required Actions

taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the

6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does not significantly reduce the

probability that the RHR containment spray will initiate

when necessary.

SR 3.3.6.3.1

Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read

approximately the same value. Significant deviations

between the instrument channels could be an indication of

excessive instrument drift in one of the channels or

something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is

outside the criteria, it may be an indication that the instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK

supplements less formal, but more frequent, checks of

channels during normal operational use of the displays

associated with the channels required by the LCO.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RHR Containment Spray System Instrumentation B 3.3.6.3 CLINTON B 3.3-195 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.3.2 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure the entire channel will perform the

intended function. For Series Functions, a separate CHANNEL

FUNCTIONAL TEST is not required for each Function, provided

each Function is tested. A successful test of the required

contact(s) of a channel relay may be performed by the

verification of the change of state of a single contact of

the relay. This clarifies what is an acceptable CHANNEL

FUNCTIONAL TEST of a relay. This is acceptable because all

of the other required contacts of the relay are verified by

other Technical Specifications and non-Technical

Specifications tests at least once per refueling interval

with applicable extensions.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint

methodology.

The Frequency of 92 days is based upon the reliability analysis of Reference 3.

SR 3.3.6.3.3

The calibration of analog trip modules provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is discovered to be less conservative than the Allowable Value specified in Table 3.3.6.3-1. If the trip setting is discovered to be

less conservative than accounted for in the appropriate

setpoint methodology, but is not beyond the Allowable Value, the channel performance is still within the requirements of

the plant safety analysis. Under these conditions, the setpoint must be readjusted to be equal to or more

conservative than accounted for in the appropriate setpoint

methodology.

The Frequency of 92 days is based upon the reliability analysis of Reference 3.

SR 3.3.6.3.4 and SR 3.3.6.3.6

A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint methodology.

The Frequencies are based on the assumption of the magnitude of equipment drift in the setpoint analysis.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RHR Containment Spray System Instrumentation B 3.3.6.3 CLINTON B 3.3-196 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.3.5 REQUIREMENTS (continued) The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required initiation logic for a specific

channel. The system functional testing performed in

LCO 3.6.1.7, "Residual Heat Removal (RHR) Containment

Spray," overlaps this Surveillance to provide complete

testing of the assumed safety function.

The Self Test System may be utilized to perform this testing for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by

the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the

components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the Surveillance.

REFERENCES 1. USAR, Section 7.3.1.1.4.

2. USAR, Section 6.2.1.1.5.

3. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for

Selected Instrumentation Technical Specifications,"

February 1991.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SPMU System Instrumentation B 3.3.6.4 CLINTON B 3.3-205 Revision No. 0 BASES (continued)

______________________________________________________________________________

SURVEILLANCE As noted at the beginning of the SRs, the SRs for each SPMU REQUIREMENTS System Function are located in the SRs column of Table 3.3.6.4-1.

The Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely

for performance of required Surveillances, entry into

associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function

maintains suppression pool makeup initiation capability.

Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable Condition entered and Required

Actions taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does not significantly reduce the probability that the SPMU will initiate when

necessary.

SR 3.3.6.4.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures

that a gross failure of instrumentation has not occurred. A

CHANNEL CHECK is normally a comparison of the parameter

indicated on one channel to a similar parameter on other

channels. It is based on the assumption that instrument

channels monitoring the same parameter should read

approximately the same value. Significant deviations

between the instrument channels could be an indication of

excessive instrument drift in one of the channels or

something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is

outside the criteria, it may be an indication that the

instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the required channels of the LCO.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SPMU System Instrumentation B 3.3.6.4 CLINTON B 3.3-206 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.4.2 REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure the entire channel will perform the

intended function. For Series Functions, a separate CHANNEL

FUNCTIONAL TEST is not required for each Function, provided each Function is tested. A successful test of the required contact(s) of a channel relay may be performed by the

verification of the change of state of a single contact of

the relay. This clarifies what is an acceptable CHANNEL

FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical

Specifications tests at least once per refueling interval with applicable extensions.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

The Frequency of 92 days is based on the reliability

analysis of Reference 3.

SR 3.3.6.4.3 and SR 3.3.6.4.4 The calibration of analog trip modules and analog comparator units provides a check of the actual trip setpoints. The channel must be declared inoperable if the trip setting is

discovered to be less conservative than the Allowable Value

specified in Table 3.3.6.4-1. If the trip setting is discovered to be less conservative than accounted for in the appropriate setpoint methodology but is not beyond the

Allowable Value, the channel performance is still within the

requirements of the plant safety analysis. Under these

conditions, the setpoint must be readjusted to be equal to or more conservative than accounted for in the appropriate setpoint methodology.

The Frequency of 92 days is based on the reliability

analysis of Reference 3.

SR 3.3.6.4.5, SR 3.3.6.4.6, and SR 3.3.6.4.8 A CHANNEL CALIBRATION is a complete check of the instrument

loop and the sensor. This test verifies that the channel

responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

SPMU System Instrumentation B 3.3.6.4 CLINTON B 3.3-207 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.4.5, SR 3.3.6.4.6, and SR 3.3.6.4.8 (continued)

REQUIREMENTS The Frequencies are based on the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.6.4.7 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the

OPERABILITY of the required initiation logic for a specific

channel. The system functional testing performed in

LCO 3.6.2.4, "Suppression Pool Makeup (SPMU) System,"

overlaps this Surveillance to provide complete testing of

the assumed safety function.

The Self Test System may be utilized to perform this testing

for those components that it is designed to monitor. Those

portions of the solid-state logic not monitored by the Self

Test System may be tested at the frequency recommended by

the manufacturer, rather than at the specified 24-month Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the

components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the Surveillance.

______________________________________________________________________________

REFERENCES 1. USAR, Section 7.3.1.1.10

2. USAR, Section 6.2.7.

3. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for

Selected Instrumentation Technical Specifications,"

February 1991.

______________________________________________________________________________

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Relief and LLS Instrumentation B 3.3.6.5 CLINTON B 3.3-212 Revision No. 5-5 BASES ______________________________________________________________________________

ACTIONS B.1 and B.2 (continued)

If the inoperable trip system is not restored to OPERABLE

status within 7 days, per Condition A, or if two trip

systems are inoperable, 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

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 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 The Surveillances are modified by a Note to indicate that REQUIREMENTS when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains relief or LLS initiation capability, as applicable. Upon

completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

allowance, the channel must be returned to OPERABLE status

or the applicable Condition entered and Required Actions

taken. This Note is based on the reliability analysis (Ref. 3) assumption of the average time required to perform

channel surveillance. That analysis demonstrated the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months

testing allowance does not significantly reduce the

probability that the relief and LLS valves will initiate

when necessary.

SR 3.3.6.5.1 A CHANNEL FUNCTIONAL TEST is performed on each required

channel to ensure that the entire channel will perform the

intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Any setpoint adjustment shall be consistent with the assumptions of the current plant

specific setpoint methodology.

The Frequency of 92 days is based on the reliability

analysis of Reference 3.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Relief and LLS Instrumentation B 3.3.6.5 CLINTON B 3.3-213a Revision No. 10-6 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.5.2 (continued)

REQUIREMENTS If the as-left instrument channel setpoint cannot be returned to within the ALT of the Actual Trip Setpoint, then the channel shall be declared inoperable. Part 3 of the Note indicates that the Nominal Trip Setpoint and the methodology used to determine the Nominal Trip Setpoint, the As-Found Tolerance and the As-Left Tolerance bands are specified in the ORM.

The Frequency of 92 days is based on the reliability analysis of Reference 3.

SR 3.3.6.5.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The SR 3.3.6.5.3 calibration is modified by a Note. This Note is divided into three parts. Part 1 of the Note requires evaluation of instrument performance for the condition where the as-found setting for these instrument channels is outside its As-Found Tolerance (AFT) but conservative with respect to the Allowable Value.

Evaluation of instrument performance will verify that the instrument will continue to behave in accordance with design-basis assumptions. The purpose of the assessment is to ensure confidence in the instrument performance prior to returning the instrument to service. Initial evaluation will be performed by the technician performing the surveillance who will evaluate the instrument's ability to maintain a stable setpoint within the As-Left Tolerance (ALT). The technician's evaluation will be reviewed by on-shift operations personnel during the approval of the surveillance data. Subsequent to returning the instrument to service, the deviation is entered into the Corrective Action Program. In accordance with procedures, entry into the Corrective Action Program will require review and documentation of the condition for operability by on-shift operations personnel. Additional evaluation and potential corrective actions as necessary will ensure that any as-found setting found outside the AFT is evaluated for long-term operability trends. If the as-found channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable. Part 2 of the Note requires that the instrument channel setpoint shall be reset to within the ALT of the Actual Trip Setpoint (ATSP). The ATSP is equivalent to or more conservative than the Nominal

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Relief and LLS Instrumentation B 3.3.6.5 CLINTON B 3.3-213b Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.5.3 (continued)

REQUIREMENTS Trip Setpoint (NTSP). The NTSP is the limiting value of the sensed process variable at which a trip may be set in

accordance with the methodology documented in the ORM.

Therefore, the NTSP is equivalent to the Limiting Safety

System Setting (LSSS) required by 10 CFR 50.36, "Technical

specifications." The Actual Trip Setpoint is also

calculated in accordance with the plant-specific setpoint

methodology as documented in the CPS ORM and may include

additional margin. The ATSP will ensure that sufficient

margin to the safety and/or analytical limit is maintained.

If the as-left instrument channel setpoint cannot be

returned to within the ALT of the Actual Trip Setpoint, then

the channel shall be declared inoperable. Part 3 of the

Note indicates that the Nominal Trip Setpoint and the

methodology used to determine the Nominal Trip Setpoint, the

As-Found Tolerance and the As-Left Tolerance bands are

specified in the ORM.

The Frequency is based upon the assumption of the magnitude

of equipment drift in the setpoint analysis.

SR 3.3.6.5.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific channel. The system functional testing performed for S/RVs

in LCO 3.4.4 and LCO 3.6.1.6 overlaps this Surveillance to

provide complete testing of the assumed safety function.

The Self Test System may be utilized to perform this testing

for those components that it is designed to monitor. Those portions of the solid-state logic not monitored by the Self Test System may be tested at the frequency recommended by

the manufacturer, rather than at the specified 24-month (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Relief and LLS Instrumentation B 3.3.6.5 CLINTON B 3.3-214 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.6.5.4 (continued)

REQUIREMENTS Frequency. The frequencies recommended by the manufacturer

are based on mean time between failure analysis for the

components in the associated circuits.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass the Surveillance.

______________________________________________________________________________

REFERENCES 1. USAR, Section 5.2.2.

2. USAR, Section 7.3.1.1.1.4.2.

3. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for

Selected Instrumentation Technical Specifications,"

February 1991.

______________________________________________________________________________

CRV System Instrumentation B 3.3.7.1 CLINTON B 3.3-219 Revision No. 0 BASES ______________________________________________________________________________

ACTIONS B.1 and B.2 (continued)

With any Required Action and associated Completion Time not met, one CRV subsystem must be placed in the high radiation

mode of operation (Required Action B.1) to ensure that

control room personnel will be protected in the event of a

Design Basis Accident. The method used to place the CRV

subsystem in operation must provide for automatically

reinitiating the subsystem upon restoration of power

following a loss of power to the CRV subsystem(s).

Alternately, if it is not desired to start the subsystem in

the high radiation mode, the CRV subsystem associated with

inoperable, untripped channels must be declared inoperable

within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time is intended to allow the operator time to place the CRV subsystem in operation. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time is acceptable because it minimizes risk while allowing time for restoration or tripping of channels, or for placing the associated CRV subsystem in operation.

SURVEILLANCE As noted at the beginning of the SRs, the SRs for each CRV REQUIREMENTS System Instrumentation Function are located in the SRs column of Table 3.3.7.1-1.

The Surveillances are also modified by a Note to indicate that when a channel is placed in an inoperable status solely

for performance of required Surveillances, entry into

associated Conditions and Required Actions may be delayed

for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function

maintains CRV System high radiation mode initiation

capability. Upon completion of the Surveillance, or

expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be

returned to OPERABLE status or the applicable Condition

entered and Required Actions taken. This Note is based on

the reliability analysis (Refs. 4 and 5) assumption of the

average time required to perform channel surveillance. That

analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months testing allowance does

not significantly reduce the probability that the CRV System will initiate when necessary.

SR 3.3.7.1.1 Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A

(continued)

CRV System Instrumentation B 3.3.7.1 CLINTON B 3.3-220 Revision No. 5-5 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.7.1.1 (continued)

REQUIREMENTS CHANNEL CHECK is normally a comparison of the indicated parameter for one instrument channel to a similar parameter

on other channels. It is based on the assumption that

instrument channels monitoring the same parameter should

read approximately the same value. Significant deviations

between the instrument channels could be an indication of

excessive instrument drift in one of the channels or

something even more serious. A CHANNEL CHECK will detect

gross channel failure; thus, it is key to verifying the

instrumentation continues to operate properly between each

CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is

outside the criteria, it may be an indication that the

instrument has drifted outside its limit.

The Frequency is based upon operating experience that demonstrates channel failure is rare. The CHANNEL CHECK

supplements less formal, but more frequent, checks of

channel status during normal operational use of the displays

associated with channels required by the LCO.

SR 3.3.7.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Any setpoint adjustment shall be consistent with the assumptions of the current plant

specific setpoint methodology.

The Frequency of 92 days is based on the reliability analyses of References 4, 5, and 6.

SR 3.3.7.1.3 A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

CRV System Instrumentation B 3.3.7.1 CLINTON B 3.3-221 Revision No. 1-1 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.7.1.3 (continued)

REQUIREMENTS adjusted to account for instrument drifts between successive calibrations consistent with the plant specific setpoint

methodology.

The Frequency is based on the assumption of the magnitude of equipment drift in the setpoint analysis.

______________________________________________________________________________

REFERENCES 1. USAR, Section 7.3.1.1.6.

2. USAR, Section 6.4.

3. USAR, Chapter 15.

4. GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications," February 1991.

5. NEDC-31677P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation,"

July 1990.

6. USAR, Section 7.6.1.2.5.

7. USAR, Section 7.6.2.2.5.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

LOP Instrumentation B 3.3.8.1 CLINTON B 3.3-228 Revision No. 5-5 BASES ______________________________________________________________________________

ACTIONS B.1 (continued) If any Required Action and associated Completion Time is not met, the associated Function may not be capable of

performing the intended function. Therefore, the associated

DG(s) are declared inoperable immediately. This requires entry into applicable Conditions and Required Actions of

LCO 3.8.1 and LCO 3.8.2, which provide appropriate actions

for the inoperable DG(s).

______________________________________________________________________________

SURVEILLANCE As noted at the beginning of the SRs, the SRs for each LOP REQUIREMENTS Instrumentation Function are located in the SRs column of Table 3.3.8.1-1.

The Surveillances are modified by a Note to indicate that when a channel is placed in an inoperable status solely for

performance of required Surveillances, entry into associated

Conditions and Required Actions may be delayed for up to

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months provided the associated Function maintains DG

initiation capability. Upon completion of the Surveillance, or expiration of the 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months allowance, the channel must be

returned to OPERABLE status or the applicable Condition entered and Required Actions taken.

SR 3.3.8.1.1 This SR has been deleted.

SR 3.3.8.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the

intended function. For series Functions, i.e., for the

degraded voltage relays in series with their associated

delay timers, a separate CHANNEL FUNCTIONAL TEST is not

required for each Function, provided each Function is tested. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

The Frequency of 31 days is based on plant operating experience with regard to channel OPERABILITY that demonstrates that failure in any 31 day interval is rare.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

LOP Instrumentation B 3.3.8.1 CLINTON B 3.3-229 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.3.8.1.3 REQUIREMENTS (continued) A CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies the channel

responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The Frequency is based on the assumption of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.8.1.4 The LOGIC SYSTEM FUNCTIONAL TEST demonstrates the OPERABILITY of the required actuation logic for a specific

channel. The system functional testing performed in

LCO 3.8.1 and LCO 3.8.2 overlaps this Surveillance to

provide complete testing of the assumed safety functions.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the Surveillance.

REFERENCES 1. USAR, Section 8.3.1.1.2.

2. USAR, Section 5.2.2.

3. USAR, Section 6.3.3.

4. USAR, Chapter 15.

5. IP Calculation 19-AN-19.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RPS Electric Power Monitoring B 3.3.8.2 CLINTON B 3.3-235 Revision No. 13-2 BASES

______________________________________________________________________________

SURVEILLANCE SR 3.3.8.2.1 (continued)

REQUIREMENTS This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at

least once per refueling interval with applicable extensions. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

As noted in the Surveillance, the CHANNEL FUNCTIONAL TEST is only required to be performed while the plant is in a

condition in which the loss of the RPS bus will not jeopardize steady state power operation (the design of the system is such that the power source must be removed from service to conduct the Surveillance). The 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is intended to indicate an outage of sufficient duration to allow for scheduling and proper performance of the

Surveillance. The 184 day Frequency and the Note in the

Surveillance are based on guidance provided in Generic Letter 91-09 (Ref. 3).

SR 3.3.8.2.2 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. This test verifies that the channel

responds to the measured parameter within the necessary

range and accuracy. CHANNEL CALIBRATION leaves the channel

adjusted to account for instrument drifts between successive

calibrations consistent with the plant specific setpoint

methodology.

The Frequency is based upon the assumption of a 24 month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.

SR 3.3.8.2.3

Performance of a system functional test demonstrates a required system actuation (simulated or actual) signal. The

logic of the system will automatically trip open the

associated power monitoring assembly circuit breaker. Only

one signal per power monitoring assembly is required to be

tested. This Surveillance overlaps with the CHANNEL

CALIBRATION to provide complete testing of the safety

function. The system functional test of the Class 1E

circuit breakers is included as part of this test to provide

complete testing of the safety function. If the breakers

are incapable of operating, the associated electric power

monitoring assembly would be inoperable.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.is RPS Electric Power Monitoring B 3.3.8.2 CLINTON B 3.3-236 Revision No. 13-2 BASES

______________________________________________________________________________

SURVEILLANCE SR 3.3.8.2.3 (continued)

REQUIREMENTS The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the Surveillance.

REFERENCES 1. USAR, Section 8.3.1.1.3.1.

2. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

3 NRC Generic Letter 91-09, "Modification of Surveillance Interval for the Electric Protective Assemblies in Power Supplies for the Reactor

Protection System."

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fr eque ncyCo n t r olPr og r a m.

CLINTON B 3.4-7 Revision No. 11-1 Recirculation Loops Operating B 3.4.1 BASES ACTIONS D.1 (continued)

With no recirculation loops in operation, or the Required Action and associated Completion Time of Conditions A, B, or C not met, the unit is required to be brought to a MODE in which the LCO does not apply. The plant is required to be placed in MODE 3 in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . In this condition, the recirculation loops are not required to be operating because

of the reduced severity of DBAs and minimal dependence on

the recirculation loop coastdown characteristics. The

allowed Completion Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-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 3.4.1.1 REQUIREMENTS This SR ensures the recirculation loop flows are within the allowable limits for mismatch. At low core flow (i.e.,

< 70% of rated core flow), the MCPR requirements provide

larger margins to the fuel cladding integrity Safety Limit

such that the potential adverse effect of early boiling

transition during a LOCA is reduced. A larger flow mismatch

can therefore be allowed when core flow is < 70% of rated

core flow. The recirculation loop jet pump flow, as used in

this Surveillance, is the summation of the flows from all of

the jet pumps associated with a single recirculation loop.

The mismatch is measured in terms of percent of rated core flow. This SR is not required when both loops are not in

operation since the mismatch limits are meaningless during

single loop or natural circulation operation. The

Surveillance must be performed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both

loops are in operation. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is consistent with the Frequency for jet pump OPERABILITY verification and has been shown by operating experience to be adequate to

detect off normal jet pump loop flows in a timely manner.

With regard to recirculation loop flow values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 4).

(continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

FCVs B 3.4.2 CLINTON B 3.4-11 Revision No. 10-7 BASES ______________________________________________________________________________

ACTIONS B.1 (continued) If the FCVs are not deactivated, (locked up) and cannot be restored to OPERABLE status within the associated Completion Time, the unit must be brought to a MODE in which the LCO

does not apply. To achieve this status, the unit must be

brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . This brings the unit to a condition where the flow coastdown characteristics

of the recirculation loop are not important. The allowed

Completion Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is reasonable, based on

operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging unit

systems. ______________________________________________________________________________

SURVEILLANCE SR 3.4.2.1 REQUIREMENTS Hydraulic power unit pilot operated isolation valves located between the servo valves and the common "open" and "close" lines are required to close in the event of a loss of

hydraulic pressure. When closed, these valves inhibit FCV

motion by blocking hydraulic pressure from the servo valve

to the common open and close lines as well as to the

alternate subloop. This Surveillance verifies FCV lockup on

a loss of hydraulic pressure as assumed in the design basis

LOCA analyses.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass the SR. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Jet Pumps B 3.4.3 CLINTON B 3.4-1 6 Revision No. 7-5 BASES SURVEILLANCE SR 3.4.3.1 (continued)

REQUIREMENTS Individual jet pumps in a recirculation loop typically do not have the same flow. The unequal flow is due to the

drive flow manifold, which does not distribute flow equally

to all risers. The flow (or jet pump diffuser to lower

plenum differential pressure) pattern or relationship of one

jet pump to the loop average is repeatable. An appreciable

change in this relationship is an indication that increased (or reduced) resistance has occurred in one of the jet

pumps. This may be indicated by an increase in the relative

flow for a jet pump that has experienced beam cracks.

The deviations from normal are considered indicative of a potential problem in the recirculation drive flow or jet

pump system (Ref. 2). Normal flow ranges and established

jet pump flow and differential pressure patterns are established by plotting historical data as discussed in Reference 2.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency has been shown by operating experience to be adequate to verify jet pump OPERABILITY and is

consistent with the Frequency for recirculation loop

OPERABILITY verification.

This SR is modified by two Notes. Note 1 allows this Surveillance not to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the associated recirculation loop is in operation, since these checks can only be performed during jet pump operation. The 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is an acceptable time to establish conditions

appropriate for data collection and evaluation.

Note 2 allows this SR not to be performed when THERMAL POWER is 21.6% RTP. During low flow conditions, jet pump noise approaches the threshold response of the associated flow instrumentation and precludes the collection of repeatable and meaningful data.

With regard to drive flow and differential pressure values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 4).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

S/RVs B 3.4.4 CLINTON B 3.4-21 Revision No. 10-7 BASES SURVEILLANCE SR 3.4.4.2 (continued)

REQUIREMENTS The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the SR. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

This SR is modified by a Note that excludes valve actuation.

This prevents an RPV pressure blowdown.

SR 3.4.4.3

A manual actuation of each required S/RV (those valves removed and replaced to satisfy SR 3.4.4.1) is performed to verify that the valve is functioning properly. This SR can be demonstrated by one of two methods. If performed by Method 1, plant startup is allowed prior to performing this test because valve OPERABILITY and the setpoints for overpressure protection are verified, per ASME requirements (Ref. 6), prior to valve installation. Therefore, this SR is modified by a Note that states 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 reactor steam

pressure and flow are adequate to perform the test. The 12

hours allowed for manual actuation after the required

pressure is reached is sufficient to achieve stable

conditions for testing and provides a reasonable time to

complete the SR. If performed by Method 2, valve

OPERABILITY has been demonstrated for all installed S/RVs

based upon the successful operation of a test sample of

S/RVs.

1. Manual actuation of the S/RV with verification of the response of the turbine control valves or bypass

valves, by a change in the measured steam flow, or any

other method suitable to verify steam flow (e.g.,

tailpipe temperature or acoustic monitoring).

Adequate reactor steam pressure must be available to

perform this test to avoid damaging the valve. Also, adequate flow must be passing through the main turbine

or turbine bypass valves to continue to control

reactor pressure when the S/RVs divert steam flow upon

opening. Sufficient time is therefore allowed after

the required pressure and flow are achieved to perform

this test. Adequate pressure at which this test is to

be performed is consistent with the pressure

recommended by the valve manufacturer.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

S/RVs B 3.4.4 CLINTON B 3.4-22 Revision No. 10-7 BASES SURVEILLANCE SR 3.4.4.3 (continued)

REQUIREMENTS

2. The sample population of S/RVs tested to satisfy SR 3.4.4.1 will also be stroked in the relief mode during

"as-found" testing to verify proper operation of the

S/RV. The successful performance of the test sample

of S/RVs provides reasonable assurance that the

remaining installed S/RVs will perform in a similar

fashion. After the S/RVs are replaced, the relief-

mode actuator of the newly-installed S/RVs will be

uncoupled from the S/RV stem, and cycled to ensure

that no damage has occurred to the S/RV during

transportation and installation. Following cycling, the relief-mode actuator is recoupled and the proper

positioning of the stem nut is independently verified.

This verifies that each replaced S/RV will properly perform its intended function. If the valve fails to actuate due only to the failure of the solenoid but is capable of opening on overpressure, the safety function of the S/RV is considered OPERABLE.

The 24 month Frequency was developed based on the S/RV tests required by the ASME Boiler and Pressure Vessel Code,Section XI (Ref. 1). Operating experience has shown that

these components usually pass the Surveillance. Therefore, the Frequency was concluded to be acceptable from a

reliability standpoint.

REFERENCES 1. ASME, Boiler and Pressure Vessel Code,Section III and XI. 2. USAR, Section 5.2.2.

3. USAR, Section 15.

4. NEDC-32202P, "SRV Setpoint Tolerance and Out-of-Service Analysis for Clinton Power Station, "August

1993."

5. Calculation IP-0-0032.

6. ASME/ANSI OM-19 8 7, Operation and Maintenance of Nuclear Power Plants, Part 1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

BASES

______________________________________________________________________________

CLINTON B 3.4-27 Revision No. 4-6 RCS Operational LEAKAGE B 3.4.5ACTIONS C.1 and C.2 (continued)

brought to MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 within 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-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 3.4.5.1 REQUIREMENTS The RCS LEAKAGE is monitored by a variety of instruments designed to quantify the various types of LEAKAGE. Leakage detection instrumentation is discussed in more detail in the Bases for LCO 3.4.7, "RCS Leakage Detection Instrumentation." Sump level and flow rate are typically monitored to determine actual LEAKAGE rates. However, any

method may be used to quantify LEAKAGE within the guidelines

of Reference 7. In conjunction with alarms and other

administrative controls, a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency for this

Surveillance is appropriate for identifying changes in

LEAKAGE and for tracking required trends (Ref.

8).

With regard to LEAKAGE values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 9).

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

8

BASES

______________________________________________________________________________

CLINTON B 3.4-27a Revision No. 4-6 RCS Operational LEAKAGE B 3.

4.5REFERENCES

1. 10 CFR 50.2.

2. 10 CFR 50.55a(c).

3. 10 CFR 50, Appendix A, GDC 55.

4. GEAP-5 6 20, "Failure Behavior in ASTM A10 6 B Pipes Containing Axial ThroughWall Flaws," April 19

68. 5. NUREG-75/0 6 7, "Investigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of

Boiling Water Reactor Plants," October 1975.

6. USAR, Section 5.2.5.5.3.

7. Regulatory Guide 1.45, May 1973.

8. Generic Letter 88-01, Supplement 1, "NRC Position on IGSCC in BWR Austenitic Stainless Steel Piping,"

February 1992.

9. Calculation IP-0-0033.

RCS Leakage Detection Instrumentation B 3.4.7 CLINTON B 3.4-35 Revision No. 3-1 BASES APPLICABLE and 5). Each of the leakage detection systems inside the SAFETY ANALYSES drywell is designed with the capability of detecting LEAKAGE (continued) less than the established LEAKAGE rate limits.

Identification of the LEAKAGE allows the operators to evaluate the significance of the indicated LEAKAGE and, if necessary, shut down the reactor for further investigation and corrective action. The allowed LEAKAGE rates are well

below the rates predicted for critical crack sizes (Ref.

6). Therefore, these actions provide adequate response before a significant break in the RCPB can occur.

RCS leakage detection instrumentation satisfies Criterion 1 of the NRC Policy Statement.

LCO The drywell floor drain sump flow monitoring system is required to quantify the unidentified LEAKAGE from the RCS.

Thus, for the system to be considered OPERABLE, either the sump level rate of change, or the sump pump discharge flow monitoring portion of the system must be OPERABLE. The

other monitoring systems provide qualitative indication to the operators so closer examination of other detection systems will be made to determine the extent of any corrective action that may be required. With the leakage

detection systems inoperable, monitoring for LEAKAGE in the

RCPB is degraded.

APPLICABILITY In MODES 1, 2, and 3, leakage detection systems are required to be OPERABLE to support LCO 3.4.5. This Applicability is consistent with that for LCO 3.4.5.

ACTIONS A.1

With both drywell floor drain sump flow monitoring systems inoperable, no other form of sampling can provide the

equivalent information to quantify leakage. However, the

drywell atmospheric activity monitor and the drywell air

cooler condensate flow rate monitor will provide indications

of changes in leakage.

With both drywell floor drain sump monitoring systems inoperable, but with RCS unidentified and total LEAKAGE

being determined every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (SR 3.4.5.1), operation may (continued)

BASES

______________________________________________________________________________

CLINTON B 3.4-3 8 Revision No. 10-7 RCS Leakage Detection Instrumentation B 3.4.7SURVEILLANCE SR 3.4.7.1 (continued)

REQUIREMENTS gives reasonable confidence that the channel is operating properly. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is based on instrument

reliability and is reasonable for detecting off normal

conditions.

SR 3.4.7.2

This SR requires the performance of a CHANNEL FUNCTIONAL TEST of the required RCS leakage detection instrumentation. The test ensures that the monitors can perform their function in

the desired manner. The test also verifies the relative accuracy of the instrumentation. A successful test of the required contact(s) of a channel relay may be performed by

the verification of the change of state of a single contact

of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The Frequency of 31 days

considers instrument reliability, and operating experience has shown it proper for detecting degradation.

SR 3.4.7.3

This SR requires the performance of a CHANNEL CALIBRATION of the required RCS leakage detection instrumentation channels.

The calibration verifies the accuracy of the instrumentation, including the instruments located inside the drywell. The

Frequency of 24 months is a typical refueling cycle and considers channel reliability. Operating experience has

proven this Frequency is acceptable.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 30.

2. Regulatory Guide 1.45.

3. USAR, Section 5.2.5.2.2.

4. GEAP-5 6 20, "Failure Behavior in ASTM A10 6 B Pipes Containing Axial ThroughWall Flaws," April 19

68.

5. NUREG-75/0 6 7, "Investigation and Evaluation of Cracking in Austenitic Stainless Steel Piping of Boiling Water Reactor Plants," October 1975.

6. USAR, Section 5.2.5.5.3.

7. USAR, Section 5.2.5.9.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

RCS Specific Activity B 3.4.

8 CLINTON B 3.4-42 Revision No. 4-6 BASES (continued)

SURVEILLANCE SR 3.4.

8.1 REQUIREMENTS This Surveillance is performed to ensure iodine remains within limit during normal operation. The 7 day Frequency

is adequate to trend changes in the iodine activity level.

This SR is modified by a Note that requires this Surveillance to be performed only in MODE 1 because the

level of fission products generated in other MODES is much

less.

With regard to specific activity values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

REFERENCES 1. 10 CFR 100.11.

2. USAR, Section 15.

6.4.

3. Calculation IP-0-0035.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RHR Shutdown Cooling SystemHot Shutdown B 3.4.9 CLINTON B 3.4-47 Revision No. 1-1 BASES ACTIONS B.1, B.2, and B.3 (continued)

During the period when the reactor coolant is being circulated by an alternate method (other than by the required RHR shutdown cooling subsystem or recirculation pump), the reactor coolant temperature and pressure must be

periodically monitored to ensure proper function of the alternate method. The once per hour Completion Time is

deemed appropriate.

SURVEILLANCE SR 3.4.9.1 REQUIREMENTS This Surveillance verifies that one RHR shutdown cooling subsystem or recirculation pump is in operation and

circulating reactor coolant. The required flow rate is

determined by the flow rate necessary to provide sufficient

decay heat removal capability. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is

sufficient in view of other visual and audible indications

available to the operator for monitoring the RHR subsystem

in the control room.

This Surveillance is modified by a Note allowing sufficient time to align the RHR System for shutdown cooling operation after clearing the pressure interlock that isolates the

system, or for placing a recirculation pump in operation.

The Note takes exception to the requirements of the Surveillance being met (i.e., forced coolant circulation is not required for this initial 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months period), which also

allows entry into the Applicability of this Specification in

accordance with SR 3.0.4 since the Surveillance will not be "not met" at the time of entry into the Applicability.

REFERENCES 1. USAR, Section 5.4.7.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RHR Shutdown Cooling SystemCold Shutdown B 3.4.10 CLINTON B 3.4-52 Revision No. 1-1 BASES SURVEILLANCE SR 3.4.10.1 (continued)

REQUIREMENTS decay heat removal capability. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient in view of other visual and audible indications available to the operator for monitoring the RHR subsystem in the control room.

REFERENCES 1. USAR, Section 5.4.7.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RCS P/T Limits B 3.4.11 CLINTON B 3.4-5 8 Revision No. 9-1 BASES

ACTIONS C.1 and C.2 (continued) Operation outside the P/T limits in other than MODES 1, 2, and 3 (including defueled conditions) must be corrected so that the RCPB is returned to a condition that has been

verified by stress analyses. The Required Action must be

initiated without delay and continued until the limits are restored.

Besides restoring the P/T limit parameters to within limits, an evaluation is required to determine if RCS operation is allowed. This evaluation must verify that the RCPB

integrity is acceptable and must be completed before approaching criticality or heating up to > 200

°F. Several methods may be used, including comparison with pre-analyzed

transients, new analyses, or inspection of the components.

ASME Section XI, Appendix E (Ref.

6), may be used to support the evaluation; however, its use is restricted to evaluation of the beltline.

SURVEILLANCE SR 3.4.11.1 REQUIREMENTS Verification that operation is within limits is required every 30 minutes when RCS pressure and temperature

conditions are undergoing planned changes. This Frequency

is considered reasonable in view of the control room indication available to monitor RCS status. Also, since temperature rate of change limits are specified in hourly

increments, 30 minutes permits assessment and correction of

minor deviations.

Surveillance for heatup, cooldown, or inservice leakage and hydrostatic testing may be discontinued when the criteria

given in the relevant plant procedure for ending the

activity are satisfied.

This SR has been modified by a Note that requires this Surveillance to be performed only during system heatup and

cooldown operations and inservice leakage and hydrostatic

testing. (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

periodically RCS P/T Limits B 3.4.11 CLINTON B 3.4-60 Revision No. 4-6 BASES

SURVEILLANCE SR 3.4.11.3 and SR 3.4.11.4 (continued)

REQUIREMENTS (continued) An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.11.4 is to compare the temperatures of the operating recirculation loop and the idle loop.

SR 3.4.11.3 and SR 3.4.11.4 have been modified by a Note that requires the Surveillance to be met only in MODES 1, 2, 3, and 4 during recirculation pump start. In MODE 5, the

overall stress on limiting components is lower; therefore, T limits are not required.

With regard to temperature difference values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Refs. 13, 14).

SR 3.4.11.5, SR 3.4.11.

6 , and SR 3.4.11.7 Limits on the reactor vessel flange and head flange temperatures are generally bounded by the other P/T limits during system heatup and cooldown. However, operations approaching MODE 4 from MODE 5 and in MODE 4 with RCS

temperature less than or equal to certain specified values

require assurance that these temperatures meet the LCO

limits.

The flange temperatures must be verified to be above the limits 30 minutes before and while tensioning the vessel

head bolting studs to ensure that once the head is tensioned

the limits are satisfied. SR 3.4.11.5 allows up to 10% of

the reactor vessel head bolting studs to be fully tensioned with flange temperatures < 70

°F. This allows the closure flange O-rings to be sealed to support raising reactor water level to assist in warming the flanges. When in MODE 4 with RCS temperature 8 0°F, 30 minute checks of the flange temperatures are required because of the reduced margin to the limits. When in MODE 4 with RCS temperature 90°F, monitoring of the flange temperature is required every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to ensure the temperatures are within limits.

(continued)

RCS P/T Limits B 3.4.11 CLINTON B 3.4-61 Revision No. 7-5 BASES SURVEILLANCE SR 3.4.11.5, SR 3.4.11.

6 , and SR 3.4.11.7 (continued)

REQUIREMENTS The 30 minute Frequency reflects the urgency of maintaining the temperatures within limits, and also limits the time that the temperature limits could be exceeded. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

Frequency is reasonable based on the rate of temperature

change possible at these temperatures.

With regard to reactor vessel flange and head flange temperature values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not

require compensation for instrument indication uncertainties (Ref. 15).

SR 3.4.11.

8 and SR 3.4.11.9

Differential temperatures within the applicable limits ensure that thermal stresses resulting from increases in THERMAL POWER or recirculation loop flow during single recirculation loop operation will not exceed design allowances. Performing the Surveillance within 15 minutes before beginning such an increase in power or flow rate provides adequate assurance that the limits will not be

exceeded between the time of the Surveillance and the time

of the change in operation.

An acceptable means of demonstrating compliance with the temperature differential requirement in SR 3.4.11.9 is to

compare the temperatures of the operating recirculation loop

and the idle loop.

Plant specific test data has determined that the bottom head is not subject to temperature stratification with natural circulation at power levels as low as 25% of RTP and with any single loop flow rate greater than or equal to 30% of

rated loop flow. Therefore, SR 3.4.11.

8 and SR 3.4.11.9 have been modified by a Note that requires the Surveillance

to be met only when THERMAL POWER or loop flow is being

increased when the above conditions are not met. The Note

for SR 3.4.11.9 further limits the requirement for this

Surveillance to exclude comparison of the idle loop temperature if the idle loop is isolated from the RPV since

the water in the loop cannot be introduced into the remainder of the Reactor Coolant System.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Reactor Steam Dome Pressure B 3.4.12 CLINTON B 3.4-63 Revision No. 4-6 BASES APPLICABILITY In MODES 3, 4, and 5, the limit is not applicable because (continued) the reactor is shut down. In these MODES, the reactor pressure is well below the required limit, and no anticipated events will challenge the overpressure limits.

ACTIONS A.1

With the reactor steam dome pressure greater than the limit, prompt action should be taken to reduce pressure to below the limit and return the reactor to operation within the

bounds of the analyses. The 15 minute Completion Time is reasonable considering the importance of maintaining the pressure within limits. This Completion Time also ensures

that the probability of an accident while pressure is

greater than the limit is minimal.

B.1 If the reactor steam dome pressure cannot be restored to within the limit within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not

apply. To achieve this status, the plant must be brought to

at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion

Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-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 3.4.12.1 REQUIREMENTS Verification that reactor steam dome pressure is 1045 psig ensures that the initial conditions of the vessel overpressure protection analysis are met. Operating

experience has shown the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency to be sufficient for identifying trends and verifying operation within safety analyses assumptions.

With regard to reactor steam dome pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

ECCSOperating B 3.5.1 CLINTON B 3.5-10 Revision No. 13-2 BASES (continued)

SURVEILLANCE SR 3.5.1.1 REQUIREMENTS The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge lines of the HPCS System, LPCS System, and LPCI subsystems full of water ensures that the systems will perform properly, injecting their full capacity into the RCS upon

demand. This will also prevent a water hammer following an ECCS initiation signal. One acceptable method of ensuring the lines are full is to vent at the high points. The 31 day Frequency is based on operating experience, on the procedural controls governing system operation, and on the

gradual nature of void buildup in the ECCS piping.

SR 3.5.1.2 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides

assurance that the proper flow paths will exist for ECCS

operation. This SR does not apply to valves that are

locked, sealed, or otherwise secured in position since these

valves were verified to be in the correct position prior to

locking, sealing, or securing. A valve that receives an

initiation signal is allowed to be in a nonaccident position

provided the valve will automatically reposition in the

proper stroke time. This SR does not require any testing or

valve manipulation; rather, it involves verification that

those valves potentially capable of being mispositioned are

in the correct position. This SR does not apply to valves

that cannot be inadvertently misaligned, such as check

valves.

The 31 day Frequency of this SR was derived from the Inservice Testing Program requirements for performing valve

testing at least once every 92 days. The Frequency of 31

days is further justified because the valves are operated

under procedural control and because improper valve

alignment would only affect a single subsystem. This

Frequency has been shown to be acceptable through operating

experience.

This SR is modified by a Note that allows LPCI subsystems to be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the RHR cut in permissive pressure in MODE 3, if

capable of being manually realigned (remote or local) to the LPCI mode and not otherwise inoperable. This allows operation in the RHR shutdown cooling mode during MODE 3 if

necessary.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

ECCSOperating B 3.5.1 CLINTON B 3.5-11 Revision No. 13-2 BASES SURVEILLANCE SR 3.5.1.3 REQUIREMENTS (continued) Verification every 31 days that ADS accumulator supply pressure is 140 psig assures adequate air pressure for reliable ADS operation. The accumulator on each ADS valve provides pneumatic pressure for valve actuation. The designed pneumatic supply pressure requirements for the

accumulator are such that, following a failure of the

pneumatic supply to the accumulator, at least two valve actuations can occur with the drywell at 70% of design

pressure (Ref. 15). The ECCS safety analysis assumes only one actuation to achieve the depressurization required for

operation of the low pressure ECCS. This minimum required pressure of 140 psig is provided by the Instrument Air System. The 31 day Frequency takes into consideration administrative control over operation of the Instrument Air System and alarms for low air pressure.

With regard to ADS accumulator supply pressure values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is not considered to be

a nominal value with respect to instrument uncertainties.

This requires additional margin to be added to the limit to

compensate for instrument uncertainties, for implementation

in the associated plant procedures (Ref. 17).

SR 3.5.1.4 The performance requirements of the ECCS pumps are determined through application of the 10 CFR 50, Appendix K, criteria (Ref. 8). This periodic Surveillance is performed (in accordance with the ASME Code,Section XI, requirements for the ECCS pumps) to verify that the ECCS pumps will develop the flow rates required by the respective analyses.

The ECCS pump flow rates ensure that adequate core cooling

is provided to satisfy the acceptance criteria of 10 CFR 50.46 (Ref. 10).

The pump flow rates are verified with a pump differential pressure that is sufficient to overcome the RPV pressure expected during a LOCA. The pump outlet pressure is

adequate to overcome the elevation head pressure between the

pump suction and the vessel discharge, the piping friction

losses, and RPV pressure present during LOCAs. These values

may be established during pre-operational testing. The

Frequency for this Surveillance is in accordance with the Inservice Testing Program requirements.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCSOperating B 3.5.1 CLINTON B 3.5-12 Revision No. 13-2 BASES SURVEILLANCE SR 3.5.1.4 (continued)

REQUIREMENTS With regard to pump flow rates and differential pressures values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Refs. 18, 19, 20).

SR 3.5.1.5

The ECCS subsystems are required to actuate automatically to perform their design functions. This Surveillance test

verifies that, with a required system initiation signal (actual or simulated), the automatic initiation logic of

HPCS, LPCS, and LPCI will cause the systems or subsystems to

operate as designed, including actuation of the system

throughout its emergency operating sequence, automatic pump

startup, and actuation of all automatic valves to their

required positions. This Surveillance also ensures that the

HPCS System will automatically restart on an RPV low water

level (Level 2) signal received subsequent to an RPV high

water level (Level 8) trip and that the suction is

automatically transferred from the RCIC storage tank to the

suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST

performed in LCO 3.3.5.1, "Emergency Core Cooling System (ECCS) Instrumentation," overlaps this Surveillance to

provide complete testing of the assumed safety function.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually pass the SR, which is based on the refueling cycle.

Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCSOperating B 3.5.1 CLINTON B 3.5-13 Revision No. 13-2 BASES SURVEILLANCE SR 3.5.1.5 (continued)

REQUIREMENTS

This SR is modified by a Note that excludes vessel injection/spray during the Surveillance. Since all active

components are testable and full flow can be demonstrated by

recirculation through the test line, coolant injection into

the RPV is not required during the Surveillance.

SR 3.5.1.6 The ADS designated S/RVs are required to actuate automatically upon receipt of specific initiation signals.

A system functional test is performed to demonstrate that the mechanical portions of the ADS function (i.e., solenoids) operate as designed when initiated either by an

actual or simulated initiation signal, causing proper

actuation of all the required components. SR 3.5.1.7 and

the LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.1

overlap this Surveillance to provide complete testing of the

assumed safety function.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually pass the SR, which is based on the refueling cycle.

Therefore, the Frequency was concluded to be acceptable from

a reliability standpoint.

This SR is modified by a Note that excludes valve actuation.

This prevents an RPV pressure blowdown.

SR 3.5.1.7 A manual actuation of each required ADS valve (those valves removed and replaced to satisfy SR 3.4.4.1) is performed to

verify that the valve is functioning properly. This SR can

be demonstrated by one of two methods. If performed by

Method 1, plant startup is allowed prior to performing this

test because valve OPERABILITY and the setpoints for

overpressure protection are verified, per ASME requirements (Ref. 22), prior to valve installation. Therefore, this SR is modified by a Note that states 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 reactor steam

pressure and flow are adequate to perform the test. The 12

hours allowed for manual actuation after the required

pressure is reached is sufficient to achieve stable

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCSOperating B 3.5.1 CLINTON B 3.5-14 Revision No. 13-2 BASES SURVEILLANCE SR 3.5.1.7 (continued)

REQUIREMENTS Conditions for testing and provides a reasonable time to complete the SR. If performed by Method 2, valve

OPERABILITY has been demonstrated for all installed ADS

valves based upon the successful operations of a test sample

of S/RVs.

1. Manual actuation of the ADS valve, with verification of the response of the turbine control valves or bypass

valves, by a change in the measured steam flow, or any

other method suitable to verify steam flow (e.g.,

tailpipe temperature or acoustic monitoring). Adequate

reactor steam pressure must be available to perform

this test to avoid damaging the valve. Also, adequate

steam flow must be passing through the main turbine or

turbine bypass valves to continue to control reactor

pressure when the ADS valves divert steam flow upon

opening. Sufficient time is therefore allowed after

the required pressure and flow are achieved to perform

this test. Adequate pressure at which this test is to

be performed is consistent with the pressure

recommended by the valve manufacturer.

2. The sample population of S/RVs tested to satisfy SR 3.4.4.1 will also be stroked in the relief mode during "as-found" testing to verify proper operation of the S/RV. The successful performance of the test sample of

S/RVs provides reasonable assurance that all ADS valves

will perform in a similar fashion. After the S/RVs are

replaced, the relief-mode actuator of the newly-

installed S/RVs will be uncoupled from the S/RV stem, and cycled to ensure that no damage has occurred to the

S/RV during transportation and installation. Following

cycling, the relief-mode actuator is recoupled and the proper positioning of the stem nut is independently verified. This verifies that each replaced S/RV will

properly perform its intended function.

SR 3.5.1.6 and the LOGIC SYSTEM FUNCTIONAL TEST performed in

LCO 3.3.5.1 overlap this Surveillance to provide complete

testing of the assumed safety function. The STAGGERED TEST

BASIS Frequency ensures that both solenoids for each ADS valve relief-mode actuator are alternately tested. The

Frequency of the required relief-mode actuator testing is

based on the tests required by ASME OM, Part 1, (Ref. 22) as implemented by the Inservice Testing Program of Specification 5.5.6. The testing Frequency required by the Inservice Testing Program is based on operating experience and valve performance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCSOperating B 3.5.1 CLINTON B 3.5-14a Revision No. 13-2 BASES SURVEILLANCE SR 3.5.1.8 REQUIREMENTS (continued) This SR ensures that the ECCS RESPONSE TIMES are within limits for each of the ECCS injection and spray subsystems.

The response time limits (i.e., <

42 seconds for the LPCI subsystems, <

41 seconds for the LPCS subsystem, and <

27 seconds for the HPCS system) are specified in applicable

surveillance test procedures. This SR is modified by a Note

which identifies that the associated ECCS actuation

instrumentation is not required to be response time tested.

This is supported by Reference 16.

Response time testing of the remaining subsystem components is required. However, of the remaining subsystem components, the time for each ECCS pump to reach rated speed is not directly measured in the response time tests. The time(s) for the ECCS pumps to reach rated speed is bounded, in all cases, by the time(s) for the ECCS injection valve(s)

to reach the full-open position. Plant-specific

calculations show that all ECCS motor start times at rated

voltage are less than two seconds. In addition, these

calculations show that under degraded voltage conditions, the time to rated speed is less than five seconds.

ECCS RESPONSE TIME tests are conducted every 24 months. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the SR, which is based on the refueling cycle.

Therefore, the Frequency was concluded to be acceptable from

a reliability standpoint.

With regard to ECCS RESPONSE TIME values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 21).

______________________________________________________________________________ (continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCSShutdown B 3.5.2 CLINTON B 3.5-20 Revision No. 4-6 BASES SURVEILLANCE SR 3.5.2.1 and SR 3.5.2.2 (continued)

REQUIREMENTS With regard to RCIC storage tank water level values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 2).

The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency of these SRs was developed considering operating experience related to suppression pool and RCIC

storage tank water level variations during the applicable

MODES. Furthermore, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is considered

adequate in view of other indications in the control room, including alarms, to alert the operator to an abnormal

suppression pool or RCIC storage tank water level condition.

SR 3.5.2.3, SR 3.5.2.5, and SR 3.5.2.6

The Bases provided for SR 3.5.1.1, SR 3.5.1.4, and SR 3.5.1.5 are applicable to SR 3.5.2.3, SR 3.5.2.5, and SR 3.5.2.6, respectively.

With regard to pump flow rates and differential pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3, 4, 5).

SR 3.5.2.4

Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS

operation. This SR does not apply to valves that are

locked, sealed, or otherwise secured in position since these

valves were verified to be in the correct position prior to

locking, sealing, or securing. A valve that receives an

initiation signal is allowed to be in a nonaccident position provided the valve will automatically reposition in the proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are

______________________________________________________________________________ (continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

ECCSShutdown B 3.5.2 CLINTON B 3.5-20a Revision No. 4-6 BASES SURVEILLANCE SR 3.5.2.4 (continued)

REQUIREMENTS in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check

valves. The 31 day Frequency is appropriate because the

valves are operated under procedural control and the

probability of their being mispositioned during this time

period is low.

In MODES 4 and 5, the RHR System may operate in the shutdown cooling mode to remove decay heat and sensible heat from the

reactor. Therefore, RHR valves that are required for LPCI

subsystem operation may be aligned for decay heat removal.

This SR is modified by a Note that allows one LPCI subsystem

of the RHR System to be considered OPERABLE for the ECCS

function if all the required valves in the LPCI flow path

can be manually realigned (remote or local) to allow

injection into the RPV and the system is not otherwise

inoperable. This will ensure adequate core cooling if an

inadvertent vessel draindown should occur.

REFERENCES 1. USAR, Section 6.3.3.

2. Calculation IP-0-0049.

3. Calculations 01HP09/10/11 and IP-C-0042.

4. Calculations 01LP08/11/14 and IP-C-0043.

5. Calculations 01RH19/20/22/24/25 and IP-C-0041.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RCIC System B 3.5.3 CLINTON B 3.5-24 Revision No. 0 BASES (continued)

SURVEILLANCE SR 3.5.3.1 REQUIREMENTS The flow path piping has the potential to develop voids and pockets of entrained air. Maintaining the pump discharge

line of the RCIC System full of water ensures that the

system will perform properly, injecting its full capacity

into the Reactor Coolant System upon demand. This will also

prevent a water hammer following an initiation signal. One

acceptable method of ensuring the line is full is to vent at

the high points. The 31 day Frequency is based on the

gradual nature of void buildup in the RCIC piping, the

procedural controls governing system operation, and

operating experience.

SR 3.5.3.2

Verifying the correct alignment for manual, power operated, and automatic valves in the RCIC flow path provides assurance that the proper flow path will exist for RCIC operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position since these were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an

initiation signal is allowed to be in a nonaccident position

provided the valve will automatically reposition in the

proper stroke time. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of potentially being mispositioned are

in the correct position. This SR does not apply to valves

that cannot be inadvertently misaligned, such as check

valves. For the RCIC System, this SR also includes the

steam flow path for the turbine and the flow controller position.

The 31 day Frequency of this SR was derived from the Inservice Testing Program requirements for performing valve testing at least every 92 days. The Frequency of 31 days is further justified because the valves are operated under procedural control and because improper valve position would affect only the RCIC System. This Frequency has been shown

to be acceptable through operating experience.

(continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RCIC System B 3.5.3 CLINTON B 3.5-25 Revision No. 10-7 BASES SURVEILLANCE SR 3.5.3.3 and SR 3.5.3.4 REQUIREMENTS (continued) The RCIC pump flow rates ensure that the system can maintain reactor coolant inventory during pressurized conditions with

the RPV isolated. The flow tests for the RCIC System are

performed at two different pressure ranges such that system

capability to provide rated flow is tested both at the higher and lower operating ranges of the system.

Additionally, adequate steam flow must be passing through

the main turbine or turbine bypass valves to continue to

control reactor pressure when the RCIC System diverts steam

flow. Since the required reactor steam pressure must be available to perform SR 3.5.3.3 and SR 3.5.3.4, sufficient

time is allowed after adequate pressure and flow are achieved to perform these SRs. Reactor startup is allowed prior to performing the low pressure Surveillance because the reactor pressure is low and the time to satisfactorily

perform the Surveillance is short. The reactor pressure is

allowed to be increased to normal operating pressure since it is assumed that the low pressure test has been

satisfactorily completed and there is no indication or reason to believe that RCIC is inoperable. Therefore, these

SRs are modified by Notes that state the Surveillances are

not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after the

reactor steam pressure and flow are adequate to perform the

test. A 92 day Frequency for SR 3.5.3.3 is consistent with the Inservice Testing Program requirements. The 24 month Frequency for SR 3.5.3.4 is based on the need to perform

this Surveillance under the conditions that apply just prior

to or during startup from a plant outage. Operating

experience has shown that these components usually pass the SR, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

With regard to RCIC steam supply pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 5).

With regard to the measured reactor pressure and flow rate values obtained pursuant to SR 3.5.3.3, as read from plant

instrumentation assumed in Reference 5, are considered to be

nominal values and therefore do not require compensation for instrument indication uncertainties.

With regard to the measured reactor pressure and flow rate values obtained pursuant to SR 3.5.3.4, the values as read from plant indication instrumentation are not considered to be nominal values with respect to instrument uncertainties. This requires additional margin to be added to the limit to

compensate for instrument uncertainties, for implementation in

the associated plant procedures (Ref. 5).

___ (continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RCIC System B 3.5.3 CLINTON B 3.5-26 Revision No. 11-7 BASES SURVEILLANCE SR 3.5.3.5 REQUIREMENTS (continued) The RCIC System is required to actuate automatically to perform its design function. This Surveillance verifies that with a required system initiation signal (actual or simulated) the automatic initiation logic of RCIC will cause the system to operate as designed, including actuation of the system throughout its emergency operating sequence, automatic pump startup and actuation of all automatic valves to their required positions. This Surveillance test also ensures that the RCIC System will automatically restart on an RPV low water level (Level 2) signal received subsequent to an RPV high water level (Level 8) trip and that the

suction is automatically transferred from the RCIC storage tank to the suppression pool. The LOGIC SYSTEM FUNCTIONAL TEST performed in LCO 3.3.5.2, "Reactor Core Isolation Cooling (RCIC) System Instrumentation," overlaps this Surveillance to provide complete testing of the assumed safety function.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the SR, which is based on the refueling cycle.

Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

This SR is modified by a Note that excludes vessel injection during the Surveillance. Since all active components are

testable and full flow can be demonstrated by recirculation through the test line, coolant injection into the RPV is not required during the Surveillance.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 33.

2. USAR, Section 5.4.6.

3. Memorandum from R.L. Baer (NRC) to V. Stello, Jr. (NRC), "Recommended Interim Revisions to LCO's for

ECCS Components," December 1, 1975.

4. Deleted.

5. Calculation 01RI15.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment Air Locks B 3.6.1.2

BASES CLINTON B 3.6-14 Revision No. 4-6 SURVEILLANCE SR 3.6.1.2.1 (continued)

REQUIREMENTS specified in the Primary Containment Leakage Rate Testing Program. Conformance to the Primary Containment Leakage Rate Testing Program requires air lock leakage to be

included in determining the overall primary containment leakage rate.

With regard to leakage rate values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 5).

SR 3.6.1.2.2 The air lock interlock mechanism is designed to prevent simultaneous opening of both doors in the air lock. Since both the inner and outer doors of an air lock are designed

to withstand the maximum expected post accident primary

containment pressure (Ref. 4), closure of either door will

support primary containment OPERABILITY. Thus, the

interlock feature supports primary containment OPERABILITY

while the air lock is being used for personnel transit in and out of the containment. Periodic testing of this interlock demonstrates that the interlock will function as

designed and that simultaneous inner and outer door opening

will not inadvertently occur. Due to the nature of this interlock, and given that the interlock mechanism is only challenged when the primary containment air lock door is opened, this test is only required to be performed upon entering or exiting a primary containment air lock, but is

not required more frequently than once per 184 days. The

184 day Frequency is based on engineering judgment and is

considered adequate in view of other administrative controls. REFERENCES 1. USAR, Section 3.8.

2. 10 CFR 50, Appendix J, Option B.

3. USAR, Section 6.2.1.

4. USAR, Section 15.7.4.

5 Calculation IP-0-0056. TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

PCIVs B 3.6.1.3

BASES CLINTON B 3.6-22b Revision No. 2-8 SURVEILLANCE SR 3.6.1.3.1 (continued)

REQUIREMENTS capability would be required by SR 3.6.1.3.4 and SR 3.6.1.3.7).

The SR is modified by a Note (Note 2) stating that the SR is not required to be met when the purge valves are open for

the stated reasons. The Note states that the 36-inch valves may be opened for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances or special testing on the purge system that require the valves to be open (e.g., testing of containment and drywell ventilation radiation monitors), provided the 12-inch

containment purge and the drywell vent and purge lines are isolated. These primary containment purge valves are capable of closing in the environment following a LOCA.

Therefore, these valves are allowed to be open for limited

periods of time. The 31 day Frequency is consistent with other PCIV requirements.

SR 3.6.1.3.2

This SR verifies that each primary containment isolation manual valve and blind flange that is located outside

primary containment, drywell, and steam tunnel, and is

required to be closed during accident conditions, is closed.

The SR helps to ensure that post accident leakage of

radioactive fluids or gases outside of the primary

containment boundary is within design limits. This SR does

not require any testing or valve manipulation. Rather, it

involves verification that those devices outside primary

containment, drywell, and steam tunnel, and capable of being

mispositioned, are in the correct position. Since

verification of valve position for devices outside primary

containment, drywell, and steam tunnel is relatively easy, the 31 day Frequency was chosen to provide added assurance that the devices are in the correct positions.

Two Notes are added to this SR. The first Note applies to valves and blind flanges located in high radiation areas and allows them to be verified by use of administrative controls. Allowing verification by administrative controls

is considered acceptable, since access to these areas is

typically restricted during MODES 1, 2, and 3 for ALARA reasons. Therefore, the probability of misalignment of (continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

PCIVs B 3.6.1.3

BASES CLINTON B 3.6-26 Revision No. 10-7 SURVEILLANCE SR 3.6.1.3.6 REQUIREMENTS (continued) Verifying that the full closure isolation time of each MSIV is within the specified limits is required to demonstrate

OPERABILITY. The full closure isolation time test ensures

that the MSIV will isolate in a time period that does not exceed the times assumed in the DBA analyses. The Frequency

of this SR is in accordance with the Inservice Testing Program. With regard to isolation time values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and

therefore does not require compensation for instrument indication uncertainties (Ref. 10).

SR 3.6.1.3.7 Automatic PCIVs close on a primary containment isolation signal to prevent leakage of radioactive material from

primary containment following a DBA. This SR ensures that

each automatic PCIV will actuate to its isolation position

on a primary containment isolation signal. The LOGIC SYSTEM

FUNCTIONAL TEST in SR 3.3.6.1.6 overlaps this SR to provide

complete testing of the safety function. The 24 month Frequency is based on the need to perform this Surveillance

under the conditions that apply during a plant outage and

the potential for an unplanned transient if the Surveillance

were performed with the reactor at power. Operating

experience has shown that these components usually pass this

Surveillance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.6.1.3.8

This SR ensures that the leakage rate of secondary containment bypass leakage paths is less than the specified

leakage rate. This provides assurance that the assumptions

in the radiological evaluations of References 1, 2, and 3

are met. The leakage rate of each bypass leakage path is

assumed to be the maximum pathway leakage (leakage through

the worse of the two isolation valves) unless the

penetration is isolated by use of one closed and

de-activated automatic valve, closed manual valve, or blind

flange. In this case, the leakage rate of the isolated

bypass leakage path is assumed to be the actual pathway (continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

PCIVs B 3.6.1.3

BASES CLINTON B 3.6-28a Revision No. 10-7 SURVEILLANCE SR 3.6.1.3.11 REQUIREMENTS (continued) This SR ensures that the combined leakage rate of the primary containment feedwater penetrations is less than the specified leakage rate. The leakage rate is based on water

as the test medium since these penetrations are designed to

be sealed by the FWLCS. The 2 gpm leakage limit has been

shown by testing and analysis to bound the condition

following a DBA LOCA where, for a limited time, both air and

water are postulated to leak through this pathway. The

leakage rate of each primary containment feedwater

penetration is assumed to be the maximum pathway leakage, i.e., the leakage through the worst of the two isolation

valves [either 1B21-F032A(B) or 1B21-F065A(B)] in each

penetration. This provides assurance that the assumptions

in the radiological evaluations of References 1 and 2 are

met (Ref. 15).

Dose associated with leakage (both air and water) through the primary containment feedwater penetrations is considered

to be in addition to the dose associated with all other

secondary containment bypass leakage paths.

The Frequency is in accordance with the Primary Containment Leakage Rate Testing Program.

A Note is added to this SR which states that the primary containment feedwater penetrations are only required to meet

this leakage limit in Modes 1, 2, and 3. In other

conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not

required.

SR 3.6.1.3.12

This SR requires a demonstration that each instrumentation line excess flow check valve (EFCV) which communicates to the reactor coolant pressure boundary (Ref. 16) is OPERABLE by verifying that the valve activates within the required

flow range. For instrument lines connected to reactor

coolant pressure boundary, the EFCVs serve as an additional

flow restrictor to the orifices that are installed inside

the drywell (Ref. 14). The 24 month Frequency is based on the need to perform this Surveillance under the conditions

that apply during a plant outage and the potential for an

unplanned transient if the Surveillance were performed with the reactor at power.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment Pressure B 3.6.1.4

BASES (continued)

CLINTON B 3.6-31 Revision No. 4-6 SURVEILLANCE SR 3.6.1.4.1 REQUIREMENTS Verifying that primary containment to secondary containment differential pressure is within limits ensures that operation remains within the limits assumed in the primary

containment analysis. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency of this SR was developed based on operating experience related to trending primary containment pressure variations during the applicable MODES. Furthermore, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is

considered adequate in view of other indications available

in the control room, including alarms, to alert the operator

to an abnormal primary containment pressure condition.

With regard to differential pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensatioN for instrument indication uncertainties (Ref. 4).

REFERENCES 1. USAR, Section 6.2.1.1.4.

2. USAR, Table 6.2-1.

3. USAR, Section 6.2.

4. Calculation IP-0-0066.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment Air Temperature B 3.6.1.5

BASES CLINTON B 3.6-34 Revision No. 4-6 SURVEILLANCE SR 3.6.1.5.1 (continued)

REQUIREMENTS containment analyses. In order to determine the primary containment average air temperature, an arithmetic average

is calculated, using measurements taken at locations within

the primary containment selected to provide a representative sample of the overall primary containment atmosphere. The

arithmetical average must consist of at least one reading from one location per quadrant as described in Ref. 3.

However, all available instruments should be used in determining the arithmetical average.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this SR is considered acceptable based on observed slow rates of temperature increase within primary containment as a result of environmental heat sources (due to large volume of the primary containment).

Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is considered adequate in

view of other indications available in the control room, including alarms, to alert the operator to an abnormal

primary containment air temperature condition.

With regard to containment air temperature values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument uncertainties.

This requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in the associated plant procedures (Ref. 4).

REFERENCES 1. USAR, Section 6.2.

2. USAR, Table 6.2-4.

3. USAR, Section 7.5.1.4.2.4.

4. Calculation IP-0-0067. TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

LLS Valves B 3.6.1.6

BASES CLINTON B 3.6-37a Revision No. 13-2 SURVEILLANCE SR 3.6.1.6.1 (continued)

REQUIREMENTS pressure and flow are achieved to perform this test.

Adequate pressure at which this test is to be performed

is consistent with the pressure recommended by the valve

manufacturer.

2. The sample population of S/RVs tested to satisfy SR 3.4.4.1 will also be stroked in the relief mode during

"as-found" testing to verify proper operation of the

S/RV. The successful performance of the test sample of

S/RVs provides reasonable assurance that all LLS valves

will perform in similar fashion. After the S/RVs are

replaced, the relief-mode actuator of the newly-

installed S/RVs will be uncoupled from the S/RV stem, and cycled to ensure that no damage has occurred to the

S/RV during transportation and installation. Following

cycling, the relief-mode actuator is recoupled and the proper positioning of the stem nut is independently verified. This verifies that each replaced S/RV will

properly perform its intended function.

The Frequency of the required relief-mode actuator testing is based on the tests required by ASME OM Part 1 (Ref. 3), as implemented by the Inservice Testing Program of Specification 5.5.6. The testing Frequency required by the Inservice Testing Program is based on operating experience and valve performance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.6.1.6.2

The LLS designed S/RVs are required to actuate automatically upon receipt of specific initiation signals. A system

functional test is performed to verify that the mechanical

portions (i.e., solenoids) of the automatic LLS function operate as designed when initiated either by an actual or simulated automatic initiation signal. The LOGIC SYSTEM

FUNCTIONAL TEST in SR 3.3.6.5.4 overlaps this SR to provide

complete testing of the safety function.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass

the Surveillance. Therefore, the Frequency was concluded to

be acceptable from a reliability standpoint.

This SR is modified by a Note that excludes valve actuation.

This prevents a reactor pressure vessel pressure blowdown.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

RHR Containment Spray System B 3.6.1.7

BASES (continued)

CLINTON B 3.6-42 Revision No. 13-2 SURVEILLANCE SR 3.6.1.7.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the RHR containment spray mode flow

path provides assurance that the proper flow paths will

exist for system operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in

position, since these were verified to be in the correct position prior to locking, sealing, or securing. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.

The 31 day Frequency of this SR is justified because the valves are operated under procedural control and because

improper valve position would affect only a single

subsystem. This Frequency has been shown to be acceptable

based on operating experience.

A Note has been added to this SR that allows RHR containment spray subsystems to be considered OPERABLE during alignment

to and operation in the RHR shutdown cooling mode when below

the RHR cut in permissive pressure in MODE 3, if capable of

being manually realigned and not otherwise inoperable. At

these low pressures and decay heat levels (the reactor is

shut down in MODE 3), a reduced complement of subsystems

should provide the required containment pressure mitigation function thereby allowing operation of an RHR shutdown

cooling loop when necessary.

SR 3.6.1.7.2 Verifying each RHR pump develops a flow rate 3800 gpm while operating in the suppression pool cooling mode with flow through the associated heat exchanger ensures that pump

performance has not degraded below the required flow rate

during the cycle. It is tested in the pool cooling mode to

demonstrate pump OPERABILITY without spraying down equipment in primary containment. Although this SR is satisfied by running the pump in the suppression pool cooling mode, the test procedures that satisfy this SR include appropriate acceptance criteria to account for the higher pressure

requirements resulting from aligning the RHR System in the containment spray mode. The Frequency of this SR is in accordance with the Inservice Testing Program.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RHR Containment Spray System B 3.6.1.7

BASES (continued)

CLINTON B 3.6-43 Revision No. 13-2 SURVEILLANCE SR 3.6.1.7.3 REQUIREMENTS (continued)

This SR verifies that each RHR containment spray subsystem automatic valve actuates to its correct position upon

receipt of an actual or simulated automatic actuation signal. Actual spray initiation is not required to meet this SR. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.3.5 overlaps this SR to provide complete testing of the safety

function. The 24 month Frequency is based on the need to

perform this Surveillance under the conditions that apply

during a plant outage and the potential for an unplanned

transient if the Surveillance were performed with the

reactor at power. Operating experience has shown that these

components usually pass the Surveillance. Therefore, the

Frequency was concluded to be acceptable from a reliability

standpoint.

SR 3.6.1.7.4

This Surveillance is performed following activites that could result in nozzle blockage to verify that the spray

nozzles are not obstructed and that flow will be provided

when required. Such activities may include a loss of

foreign material control (of if it cannot be assured),

following a major configuration change, or following an

inadvertent actuation of containment spray. This

Surveillance is normally performed by an air or smoke flow

test. The Frequency is adequate due to the passive nozzle

design and its normally dry state and has been shown to be

acceptable through operating experience.

REFERENCES 1. USAR, Section 6.2.1.1.5.

2. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

3. ASME, Boiler and Pressure Vessel Code,Section XI.

4. USAR, Section 5.4.7 TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

FWLCS B 3.6.1.9

BASES CLINTON B 3.6-47c Revision No. 13-2 ACTIONS C.1.

(continued)

If the inoperable FWLCS subsystem cannot be restored to

OPERABLE status within the required Completion Time, the

plant must be brought to a MODE in which the overall plant risk is minimized. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Remaining in the Applicability of the LCO is acceptable because the plant risk in MODE 3 is similar to or lower than the risk in MODE 4 (Ref. 2) and because the time spent in MODE 3 to perform the necessary repairs to restore the system to OPERABLE status will be short. However, voluntary entry into MODE 4 may be made as it is also an acceptable low-risk state. Required Action C.1 is modified by a Note that prohibits the application of LCO 3.0.4.a. This Note clarifies the intent of the Required Action by indicating that it is not permissible under LCO 3.0.4.a to enter MODE 3 from MODE 4 with the LCO not met. While remaining in MODE 3 presents an acceptable level of risk, it is not the intent of the Required Action to allow entry into, and continue operation in, MODE 3 from MODE 4 in accordance with LCO 3.0.4.a.

However, where allowed, a risk assessment may be performed in accordance with LCO 3.0.4.b. Consideration of the results of this risk assessment is required to determine the acceptability of entering MODE 3 from MODE 4 when this LCO is not met. The allowed Completion Time is reasonable, based on operating experience, to reach the required plant

conditions from full power conditions in an orderly manner

and without challenging plant systems.

SURVEILLANCE SR 3.6.1.9.1 REQUIREMENTS A system functional test of each FWLCS subsystem is performed to ensure that each FWLCS subsystem will operate through its operating sequence. This includes verifying automatic positioning of valves and operation of each

interlock, and that the necessary check valves open.

Adequacy of the associated RHR pumps to deliver FWLCS flow

rates required to meet the assumptions made in the

supporting analyses concurrent with other modes was

demonstrated during acceptance testing of the system after installation. Periodic verification of the capabilities of the RHR pumps is performed under SR 3.5.1.4.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Suppression Pool Average Temperature B 3.6.2.1

BASES CLINTON B 3.6-52 Revision No. 5-3 ACTIONS E.1 and E.2 (continued) If suppression pool average temperature cannot be maintained 120°F, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the reactor

pressure must be reduced to < 200 psig within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and

the plant must be brought to MODE 4 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 without challenging

plant systems.

Continued addition of heat to the suppression pool with pool temperature > 120

°F could result in exceeding the design basis maximum allowable values for primary containment

temperature or pressure. SURVEILLANCE SR 3.6.2.1.1 REQUIREMENTS The suppression pool average temperature is regularly monitored to ensure that the required limits are satisfied.

Average temperature is determined by taking an arithmetic

average of the functional suppression pool water temperature

channels. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency has been shown to be

acceptable based on operating experience. When heat is

being added to the suppression pool by testing, however, it

is necessary to monitor suppression pool temperature more

frequently. Testing that adds heat to the suppression pool excludes RHR pump testing. The 5 minute Frequency during testing is justified by the rates at which testing will heat

up the suppression pool, has been shown to be acceptable

based on operating experience, and provides assurance that

allowable pool temperatures are not exceeded. The

Frequencies are further justified in view of other

indications available in the control room, including alarms, to alert the operator to an abnormal suppression pool

average temperature condition.

With regard to the 95

°F suppression pool average temperature pursuant to this SR, as read from plant indication instrumentation, this limit is considered a nominal value and therefore does not require compensation for instrument

indication uncertainties.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.Frequencyis Suppression Pool Water Level B 3.6.2.2

BASES CLINTON B 3.6-55 Revision No. 8-3 ACTIONS B.1 and B.2 (continued) If suppression pool water level cannot be restored to within limits within the required Completion Time, the plant must

be brought to a MODE in which the LCO does not apply. To

achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 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 3.6.2.2.1 REQUIREMENTS Verification of the suppression pool water level is to ensure that the required limits are satisfied. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this SR was developed considering operating

experience related to trending variations in suppression

pool water level and water level instrument drift during the applicable MODES and to assessing the proximity to the specified LCO level limits. Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal suppression pool water level condition.

With regard to the suppression pool water minimum level values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument

uncertainties. This requires additional margin to be added

to the limit to compensate for instrument uncertainties, for

implementation in the associated plant procedures. The suppression pool maximum water level values are considered to be nominal values and do not require compensation for instrument uncertainties (Ref. 2).

REFERENCES 1. USAR, Section 6.2.

2. Calculation IP-0-0049.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RHR Suppression Pool Cooling B 3.6.2.3

BASES (continued)

CLINTON B 3.6-58a Revision No. 13-2 SURVEILLANCE SR 3.6.2.3.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves, in the RHR suppression pool cooling

mode flow path provides assurance that the proper flow path

exists for system operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in

position since these valves were verified to be in the correct position prior to being locked, sealed, or secured.

A valve is also allowed to be in the nonaccident position, provided it can be aligned to the accident position within the time assumed in the accident analysis. This is acceptable, since the RHR suppression pool cooling mode is

manually initiated. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the

correct position. This SR does not apply to valves that

cannot be inadvertently misaligned, such as check valves.

The Frequency of 31 days is justified because the valves are operated under procedural control, improper valve position would affect only a single subsystem, the probability of an

event requiring initiation of the system is low, and the subsystem is a manually initiated system. This Frequency

has been shown to be acceptable, based on operating

experience.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SPMU System B 3.6.2.4

BASES CLINTON B 3.6-63 Revision No. 0 ACTIONS B.1 (continued) When upper containment pool water temperature is > 120

°F, the heat absorption capacity is inadequate to ensure that

the suppression pool heat sink capability matches the safety

analysis assumptions. Increased temperature has a relatively smaller impact on heat sink capability.

Therefore, the upper containment pool water temperature must

be restored to within limit within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time is sufficient to restore the upper

containment pool to within the specified temperature limit.

It also takes into account the low probability of an event occurring that would require the SPMU System.

C.1 With one SPMU subsystem inoperable for reasons other than Condition A or B, the inoperable subsystem must be restored

to OPERABLE status within 7 days. The 7 day Completion Time

is acceptable in light of the redundant SPMU System

capabilities afforded by the OPERABLE subsystem and the low

probability of a DBA occurring during this period.

D.1 and D.2

If any Required Action and required Completion Time cannot be met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 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 3.6.2.4.1 REQUIREMENTS The upper containment pool water level is regularly monitored to ensure that the required limits are satisfied.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this SR was developed considering

operating experience related to upper containment pool water

level variations during the applicable MODES and considering

the low probability of a DBA occurring between (continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

SPMU System B 3.6.2.4

BASES CLINTON B 3.6-64 Revision No. 8-3 SURVEILLANCE SR 3.6.2.4.1 (continued)

REQUIREMENTS surveillances. Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is considered adequate in view of other indications available

in the control room, including alarms, to alert the operator

to an abnormal upper containment pool water level condition.

A fourth and fifth method (Items d. and e.) may be used to determine that there is sufficient water level combined between the upper containment pool and suppression pool when reactor pressure is less than 235 psig in MODE 3. The water level of the reactor cavity pool portion of the upper containment pool must be greater than el. 824 ft 7 inches, or the suppression pool water level must be greater than 19 ft 9 inches to satisfy this requirement.

With regard to upper containment pool water level values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 4).

SR 3.6.2.4.2

The upper containment pool water temperature is regularly monitored to ensure that the required limit is satisfied.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency was developed based on operating

experience related to upper containment pool temperature

variations during the applicable MODES.

With regard to the water level values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is not considered to be a nominal value with

respect to instrument uncertainties. This requires

additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in the associated plant procedures (Ref. 5).

SR 3.6.2.4.3

Verifying the correct alignment for manual, power operated, and automatic valves in the SPMU System flow path provides assurance that the proper flow paths will exist for system operation. This SR does not apply to valves that are

locked, sealed, or otherwise secured in position, since

these valves 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 potentially being mispositioned are in the correct position.

This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SPMU System B 3.6.2.4

BASES CLINTON B 3.6-65 Revision No. 10-7 SURVEILLANCE SR 3.6.2.4.3 (continued)

REQUIREMENTS The Frequency of 31 days is justified because the valves are operated under procedural control and because improper valve

position would affect only a single subsystem. This

Frequency has been shown to be acceptable through operating experience.

SR 3.6.2.4.4

This SR requires a verification that each SPMU subsystem automatic valve actuates to its correct position on receipt of an actual or simulated automatic initiation signal. This

includes verification of the correct automatic positioning of the valves and of the operation of each interlock and timer. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.4.7

overlaps this SR to provide complete testing of the safety

function. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

This SR is modified by a Note that excludes make up to the suppression pool. Since all active components are testable, makeup to the suppression pool is not required. REFERENCES 1. USAR, Section 6.2.

2. USAR, Chapter 15.

3. USAR, Section 6.2.7.

4. Calculation IP-0-0074.

5. Calculation IP-0-0075.

6. Calculation IP-M-0662.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2

BASES CLINTON B 3.6-76 Revision No. 10-7 SURVEILLANCE SR 3.6.3.2.1 and SR 3.6.3.2.2 REQUIREMENTS These SRs verify that there are no physical problems that could affect the igniter operation. Since the igniters are

mechanically passive, they are not subject to mechanical

failure. The only credible failures are loss of power or burnout. The verification that each required igniter is

energized is performed by circuit current versus voltage measurement.

The Frequency of 184 days has been shown to be acceptable through operating experience because of the low failure occurrence, and provides assurance that hydrogen burn

capability exists between the more rigorous 24 month Surveillances. Operating experience has shown these

components usually pass the Surveillance when performed at a 184 day Frequency. Additionally, these surveillances must

be performed every 92 days if four or more igniters in any

division are inoperable. The 92 day Frequency was chosen, recognizing that the failure occurrence is higher than

normal. Thus, decreasing the Frequency from 184 days to

92 days is a prudent measure, since only two more inoperable

igniters (for a total of six) will result in an inoperable

igniter division. SR 3.6.3.2.2 is modified by a Note that indicates that the Surveillance is not required to be performed until 92 days after four or more igniters in the

division are discovered to be inoperable.

With regard to circuit current and voltage values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 4).

(continued)TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Primary Containment and Drywell Hydrogen Igniters B 3.6.3.2

BASES CLINTON B 3.6-77 Revision No. 10-7 SURVEILLANCE SR 3.6.3.2.3 and SR 3.6.3.2.4 REQUIREMENTS (continued) These functional tests are performed every 24 months to verify system OPERABILITY. The current draw to develop a surface temperature of 1700°F is verified for igniters in inaccessible areas, e.g., in a high radiation area.

Additionally, the surface temperature of each accessible igniter is measured to be 1700°F to demonstrate that a temperature sufficient for ignition is achieved. The

24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown that these components usually

pass the Surveillance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

With regard to current draw and surface temperature values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 4).

______________________________________________________________________________

REFERENCES 1. 10 CFR 50.44.

2. 10 CFR 50, Appendix A, GDC 41.

3. USAR, Section 6.2.5.

4. Calculation IP-0-0076.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Containment/Drywell Hydrogen Mixing System B 3.6.3.3

BASES CLINTON B 3.6-81 Revision No. 6-2 ACTIONS B.1 and B.2 (continued) reasonable period of time to verify that a loss of hydrogen control function does not exist. The verification may be

performed as an administrative check by examining logs or

other information to determine the availability of the alternate hydrogen control system. It does not mean to

perform the surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control system. If the ability to perform the hydrogen control function is maintained, continued operation is permitted with two Containment/

Drywell Hydrogen Mixing Systems inoperable for up to 7 days.

Seven days is a reasonable time to allow two Containment/

Drywell Hydrogen Mixing Systems to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of a LOCA that would

generate hydrogen in amounts capable of exceeding the

flammability limit.

C.1 If any Required Action and associated Completion Time cannot be met, the plant must be brought to a MODE in which the LCO

does not apply. To achieve this status, the plant must be

brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed

Completion Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-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 3.6.3.3.1 REQUIREMENTS Operating each Containment/Drywell Hydrogen Mixing System ensures that each system is OPERABLE and that all associated controls are functioning properly. It also ensures that

blockage, compressor failure, or excessive vibration can be detected for corrective action. The 92 day Frequency is consistent with Inservice Testing Program Frequencies, operating experience, the known reliability of the compressor and controls, and the two redundant subsystems available.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Containment/Drywell Hydrogen Mixing System B 3.6.3.3

BASES CLINTON B 3.6-82 Revision No. 10-7 SURVEILLANCE SR 3.6.3.3.2 REQUIREMENTS

(continued)

Verifying that each Containment/Drywell Hydrogen Mixing System flow rate is 800 scfm ensures that each system is capable of maintaining drywell hydrogen concentrations below

the flammability limit. In practice, verifying that the

system differential pressure is less than 4.4 psid with the

compressor running ensures that the system flow rate is

greater than 800 scfm. Operating experience has shown that

these components usually pass the Surveillance. Therefore, the Frequency was concluded to be acceptable from a

reliability standpoint.

With regard to system differential pressure values used to verify the required system flow rate as read from plant

indication instrumentation, the procedural limit is considered to be not nominal and therefore requires compensation for instrument indication uncertainties (Ref.

3). REFERENCES 1. Regulatory Guide 1.7.

2. USAR, Section 6.2.5.

3. Calculation IP-0-0076.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Secondary Containment B 3.6.4.1

BASES CLINTON B 3.6-88 Revision No. 13-2 ACTIONS C.1 and C.2 (continued) movement of recently irradiated fuel assemblies would not be a sufficient reason to require a reactor shutdown.

SURVEILLANCE SR 3.6.4.1.1 REQUIREMENTS This SR ensures that the secondary containment boundary is sufficiently leak tight to preclude exfiltration under

expected wind conditions. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of this SR

was developed based on operating experience related to

secondary containment vacuum variations during the

applicable MODES and the low probability of a DBA occurring

between surveillances.

Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal secondary containment vacuum condition.

With regard to secondary containment vacuum values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 4).

SR 3.6.4.1.2 and SR 3.6.4.1.3

Verifying that secondary containment equipment hatches and access doors are closed ensures that the infiltration of outside air of such a magnitude as to prevent maintaining

the desired negative pressure does not occur. Verifying

that all such openings are closed provides adequate assurance that exfiltration from the secondary containment

will not occur. In this application the term "sealed" has

no connotation of leak tightness. Maintaining secondary

containment OPERABILITY requires verifying one door in the access opening is closed, except when the access opening is being used for entry and exit. The 31 day Frequency for these SRs has been shown to be adequate based on operating experience, and is considered adequate in view of the other

controls on secondary containment access openings.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Secondary Containment B 3.6.4.1

BASES CLINTON B 3.6-88b Revision No. 13-2 SURVEILLANCE SR 3.6.4.1.4 and SR 3.6.4.1.5 (continued)

REQUIREMENTS conditions. The primary purpose of these SRs is to ensure secondary containment boundary integrity. The secondary purpose of these SRs is to ensure that the SGT subsystem being tested functions as designed. There is a separate LCO with Surveillance Requirements which serves the primary purpose for ensuring OPERABILITY of the SGT System. These SRs need not be performed with each SGT subsystem. The SGT subsystem used for these Surveillances is staggered to ensure that in addition to the requirements of LCO 3.6.4.3, either SGT subsystem will perform this test. The inoperability of the SGT System does not necessarily constitute a failure of these Surveillances relative to the secondary containment OPERABILITY. Operating experience has shown these components usually pass the Surveillance.

Therefore, the Frequency was concluded to be acceptable from

a reliability standpoint.

With regard to drawdown time values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument

indication uncertainties (Refs. 5, 6).

REFERENCES 1. USAR, Section 15.6.5.

2. USAR, Section 15.7.4.

3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

4. Calculation IP-0-0082.

5. Calculation IP-0-0083.

6. Calculation IP-0-0084.

7. Calculation 3C10-1079-001. TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SCIDs B 3.6.4.2

BASES CLINTON B 3.6-94 Revision No. 4-6 SURVEILLANCE SR 3.6.4.2.1 (continued)

REQUIREMENTS Since these SCIDs are readily accessible to personnel during normal unit operation and verification of their position is

relatively easy, the 31 day Frequency was chosen to provide

added assurance that the SCIDs are in the correct positions.

Two Notes have been added to this SR. The first Note applies to valves, dampers, and blind flanges located in

high radiation areas and allows them to be verified by use

of administrative controls. Allowing verification by

administrative controls is considered acceptable, since

access to these areas is typically restricted during

MODES 1, 2, and 3 for ALARA reasons. Therefore, the

probability of misalignment of these SCIDs, once they have

been verified to be in the proper position, is low.

A second Note has been included to clarify that SCIDs that are open under administrative controls are not required to

meet the SR during the time the SCIDs are open.

SR 3.6.4.2.2 Verifying the isolation time of each power operated and each automatic SCID is within limits is required to demonstrate

OPERABILITY. The isolation time test ensures that the SCID

will isolate in a time period less than or equal to that

assumed in the safety analyses. The Frequency of this SR is

92 days.

With regard to isolation time values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 4).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

SCIDs B 3.6.4.2

BASES CLINTON B 3.6-95 Revision No. 10-7 SURVEILLANCE SR 3.6.4.2.3 REQUIREMENTS (continued) Verifying that each automatic SCID closes on a secondary containment isolation signal is required to prevent leakage of radioactive material from secondary containment following a DBA or other accident. This SR ensures that each

automatic SCID will actuate to the isolation position on a

secondary containment isolation signal. The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide

complete testing of the safety function. The 24 month Frequency is based on the need to perform this Surveillance

under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.

Operating experience has shown these components usually pass the Surveillance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

REFERENCES 1. USAR, Section 15.6.5.

2. USAR, Section 6.2.3.

3. USAR, Section 15.7.4.

4. Calculation IP-0-0085.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SGT System B 3.6.4.3

BASES CLINTON B 3.6-101 Revision No. 13-2 SURVEILLANCE SR 3.6.4.3.1 REQUIREMENTS Operating each SGT subsystem from the main control room for

> 10 continuous hours ensures that both subsystems are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan or motor

failure, or excessive vibration can be detected for

corrective action. Operation with the heaters on (automatic heater cycling to maintain temperature) for 10 continuous hours every 31 days eliminates moisture on the adsorbers and HEPA filters. The 31 day Frequency was developed in

consideration of the known reliability of fan motors and controls and the redundancy available in the system.

With regard to operating time values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 10).

SR 3.6.4.3.2 This SR verifies that the required SGT filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The VFTP includes testing HEPA filter

performance, charcoal adsorber bypass leakage and

efficiency, minimum system flow rate, combined HEPA filter

and charcoal adsorber pressure drop, and heater dissipation.

The frequencies for performing the SGT System filter tests

are in accordance with Regulatory Guide 1.52 (Ref. 4) and include testing initially, after 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of system operation, once per 24 months, and following painting, fire, or chemical release in any ventilation zone communicating with the system. The laboratory test results will be verified to be within limits within 31 days of removal of the sample from the system. Additional information is

discussed in detail in the VFTP.

With regard to filter testing values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and

therefore does not require compensation for instrument indication uncertainties (Ref. 11).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SGT System B 3.6.4.3

BASES CLINTON B 3.6-101a Revision No. 13-2 SURVEILLANCE SR 3.6.4.3.3 REQUIREMENTS (continued)

This SR requires verification that each SGT subsystem

automatically starts upon receipt of an actual or simulated

initiation signal.

The LOGIC SYSTEM FUNCTIONAL TEST in SR 3.3.6.2.5 overlaps this SR to provide complete testing of the safety function.

While this Surveillance can be performed with the reactor at

power, operating experience has shown these components

usually pass the Surveillance, which is based on the

refueling cycle. Therefore, the Frequency was concluded to

be acceptable from a reliability standpoint.

SR 3.6.4.3.4 This SR requires verification that the SGT filter cooling bypass damper can be opened and the fan started. This

ensures that the ventilation mode of SGT System operation is

available. While this Surveillance can be performed with

the reactor at power, operating experience has shown these

components usually pass the Surveillance, which is based on

the refueling cycle. Therefore, the Frequency was concluded

to be acceptable from a reliability standpoint.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 41.

2. USAR, Section 6.2.3.

3. USAR, Section 15.6.5.

4. Regulatory Guide 1.52.

5. USAR, Section 6.5.1.

6. USAR, Section 15.6.4.

7. USAR Appendix A.

8. ASME/ANSI N510-1980.

9. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002

10. Calculation IP-0-0086.

11. Calculation IP-0-0087.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Drywell B 3.6.5.1

BASES CLINTON B 3.6-105 Revision No. 4-6 SURVEILLANCE SR 3.6.5.1.1 (continued)

REQUIREMENTS Surveillance is only required to be performed once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each closing. The Frequency of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is

based on operating experience.

With regard to seal leakage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

SR 3.6.5.1.2 This SR requires a test to be performed to verify overall air lock leakage of the drywell air lock at pressures 3.0 psig. Prior to performance of this test, the air lock must be pressurized to 19.7 psid. This differential pressure is the assumed peak drywell pressure expected from the accident analysis. Since the drywell pressure rapidly returns to a steady state maximum differential pressure of 3.0 psid (due to suppression pool vent clearing), the overall air lock leakage is allowed to be measured at this pressure.

An overall air lock leakage limit of 2 scfh has been established to ensure the integrity of the seals. The 24-

month Frequency is based on the need to perform this

Surveillance under the conditions that apply during a plant

outage and the potential for violating the drywell boundary.

Operating experience has shown these components usually pass

the Surveillance. Therefore, the Frequency was concluded to

be acceptable from a reliability standpoint.

This SR has been modified by a Note indicating that an inoperable air lock door does not invalidate the previous successful performance of an 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.

With regard to air lock leakage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Drywell B 3.6.5.1 BASES CLINTON B 3.6-105a Revision No. 9-2 SURVEILLANCE SR 3.6.5.1.3 REQUIREMENTS The analyses in Reference 1 are based on a maximum drywell bypass leakage. This Surveillance ensures that the actual drywell bypass leakage is less than or equal to the acceptable Ak/design value of 1.0 ft 2 assumed in the safety analysis. As left drywell bypass leakage, prior to the first startup after performing a required drywell bypass leakage test, is required to be 10% of the drywell bypass leakage limit. At all other times between required drywell leakage rate tests, the acceptance criteria is based on the design Ak/. At the design Ak/the containment temperature and pressurization response are bounded by the assumptions of the safety analysis. One drywell air lock door is left open during each drywell bypass leakage test such that each drywell air lock door is leak tested during

at least every other drywell bypass leakage test. This

ensures that the leakage through the drywell air lock is

properly accounted for in the measured bypass leakage and

that each air lock door is tested periodically.

This Surveillance is performed at least once every 10 years (120 months) on a performance based frequency. The

Frequency is consistent with the difficulty of performing

the test, risk of high radiation exposure, and the remote

possibility that sufficient component failures will occur

such that the drywell bypass leakage limit will be exceeded.

This Frequency is modified by a note that allows for a one-time deferral of this surveillance until November 23, 2008.

If during the performance of this required Surveillance the

drywell bypass leakage is determined to be greater than the leakage limit, the Surveillance Frequency is increased to at least once every 48 months. If during the performance of

the subsequent consecutive Surveillance the drywell bypass

leakage is determined to be less than or equal to the

drywell bypass leakage limit, the 10-year Frequency may be resumed. If during the performance of the subsequent

consecutive Surveillance the drywell bypass leakage is

determined to be greater than the drywell bypass leakage

limit, the Surveillance Frequency is increased to at least

once every 24 months. The 24-month Frequency must be

maintained until the drywell bypass leakage is determined to

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.specifiedin

the Surveillance

Frequency Control Pro g ram Drywell B 3.6.5.1

BASES CLINTON B 3.6-105b Revision No. 4-6 SURVEILLANCE SR 3.6.5.1.3 (continued)

REQUIREMENTS be less than or equal to the leakage limit during the performance of two consecutive Surveillances, at which time the 10-year Frequency may be resumed. For two Surveillances to be considered consecutive, the Surveillances must be

performed at least 12 months apart.

Since the Frequency is performance based, the Frequency was concluded to be acceptable from a reliability standpoint.

With regard to bypass leakage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

SR 3.6.5.1.4

The exposed accessible drywell interior and exterior surfaces are inspected to ensure there are no apparent physical defects that would prevent the drywell from performing its intended function. This SR ensures that drywell structural integrity is maintained. The Frequency was chosen so that the interior and exterior surfaces of the drywell can be inspected in conjunction with the inspections

of the primary containment required by 10 CFR 50, Appendix J (Ref. 2). Due to the passive nature of the drywell

structure, the specified Frequency is sufficient to identify component degradation that may affect drywell structural integrity. REFERENCES 1. USAR, Chapter 6 and Chapter 15.

2. 10 CFR 50, Appendix J, Option B.

3. Calculation IP-0-0088.

specifiedintheSurveillanceFrequencyControlProgramTheSurveillanceFrequencyis controlledundertheSurveillance FrequencyControlProgram.

Drywell Air Lock B 3.6.5.2

BASES CLINTON B 3.6-111 Revision No. 2-6 ACTIONS D.1 and D.2 (continued) If the inoperable drywell air lock cannot be restored to OPERABLE status within the required Completion Time, the

plant must be brought to a MODE in which the LCO does not

apply. To achieve this status, the plant must be brought to

at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4 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 3.6.5.2.1 REQUIREMENTS The air lock door interlock is designed to prevent simultaneous opening of both doors in the air lock. Since both the inner and outer doors of the air lock are designed to withstand the maximum expected post accident drywell

pressure, closure of either door will support drywell

OPERABILITY. Thus, the door interlock feature supports drywell OPERABILITY while the air lock is being used for personnel transit in and out of the drywell. Periodic

testing of this interlock demonstrates that the interlock will function as designed and that simultaneous inner and outer door opening will not inadvertently occur. Due to the nature of this interlock, and given that the interlock mechanism is only challenged when a drywell air lock door is

opened, this test is only required to be performed once

every 24 months. The 24-month Frequency is based on the need to perform this Surveillance under the reduced reactivity conditions that apply during a plant outage and the potential for violating the drywell boundary. Operating experience has shown these components usually pass the Surveillance. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Drywell Isolation Valves B 3.6.5.3

BASES CLINTON B 3.6-118 Revision No. 2-6 ACTIONS B.1 (continued) With one or more drywell vent and purge penetration flow paths with two drywell isolation valves inoperable, the

affected penetration flow path must be isolated. The method

of isolation must include 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, a closed manual

valve, a blind flange, and a check valve with flow through

the valve secured. The 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Completion Time is

acceptable, due to the low probability of the inoperable valves resulting in excessive drywell leakage and the low probability of the limiting event for drywell leakage occurring during this short time. In addition, the Completion Time is reasonable, considering the time required

to isolate the penetration, and the probability of a DBA, which requires the drywell isolation valves to close, occurring during this short time is very low.

Condition B is modified by a Note indicating this Condition is only applicable to drywell vent and purge penetration

flow paths. For other penetration flow paths, only one

drywell isolation valve is required OPERABLE and, Condition

A provides the appropriate Required Actions.

C.1 and C.2

If any Required Action and associated Completion Time cannot be met, the plant must be placed in a MODE in which the LCO

does not apply. To achieve this status, the plant must be

brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4

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 3.6.5.3.1 REQUIREMENTS Each 24-inch drywell vent and purge supply isolation valve is required to be verified sealed closed at 31 day

intervals. This Surveillance applies to drywell vent and

purge supply isolation valves since they are not qualified to close under accident conditions. This SR is designed to ensure that a gross breach of drywell is not caused by an

inadvertent or spurious drywell vent and purge isolation (continued) periodically Drywell Isolation Valves B 3.6.5.3

BASES CLINTON B 3.6-119 Revision No. 1-1 SURVEILLANCE SR 3.6.5.3.1 (continued)

REQUIREMENTS valve opening. Detailed analysis of these 24-inch drywell vent and purge supply valves failed to conclusively demonstrate their ability to close during a LOCA in time to support drywell OPERABILITY. Therefore, these valves are

required to be in the sealed closed position during MODES 1, 2, and 3. These 24-inch drywell vent and purge supply valves that are sealed closed must be under administrative control to assure that they cannot be inadvertently opened.

Administrative control includes mechanical devices to seal or lock the valve closed, or to prevent power from being supplied to the valve operator. This can be accomplished by removing the air supply to the valve operator or tagging the control switches in the main control room in the closed position. In this application, the term "sealed" has no connotation of leakage within limits. The Frequency is

based on purge valve use during unit operations.

SR 3.6.5.3.2

This SR ensures that the 36-inch and either the 10-inch or the 24-inch drywell vent and purge exhaust isolation valves are closed as required or, if open, open for an allowable

reason. These drywell vent and purge isolation valves are

fully qualified to close under accident conditions;

therefore, these valves are allowed to be open for limited

periods of time. This SR has been modified by a Note

indicating the SR is not required to be met when the 36-inch and either the 10-inch or the 24-inch drywell vent and purge exhaust valves are open for pressure control, ALARA or air

quality considerations for personnel entry, or Surveillances

or special testing of the purge system that require the

valves to be open (e.g., testing of the containment and

drywell ventilation radiation monitors) provided both the

12-inch and 36-inch primary containment purge system supply and exhaust lines are isolated. Normally, the 36-inch drywell vent and purge exhaust isolation valve is open to support operation of the 12-inch Continuous Containment Purge System. This is considered to be within the allowances of the Note. The 31 day Frequency is consistent with the other purge valve requirements.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Drywell Isolation Valves B 3.6.5.3

BASES CLINTON B 3.6-121 Revision No. 10-7 SURVEILLANCE SR 3.6.5.3.5 REQUIREMENTS (continued) Verifying that each automatic drywell isolation valve closes on a drywell isolation signal is required to prevent bypass

leakage from the drywell following a DBA. This SR ensures

each automatic drywell isolation valve will actuate to its

isolation position on a drywell isolation signal. The LOGIC

SYSTEM FUNCTIONAL TEST in SR 3.3.6.1.6 overlaps this SR to

provide complete testing of the safety function. The

24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant

outage and the potential for an unplanned transient if the

Surveillance were performed with the reactor at power, since

isolation of penetrations would eliminate cooling water flow

and disrupt the normal operation of many critical

components. Operating experience has shown these components

usually pass this Surveillance. Therefore, the Frequency was concluded to be acceptable from a reliability

standpoint.

REFERENCES 1. USAR, Section 6.2.4.

2. CPS ISI Manual.

3. Calculation IP-0-0091.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Drywell Pressure B 3.6.5.4 CLINTON B 3.6-124 Revision No. 5-3 BASES ACTIONS B.1 and B.2 (continued) to MODE 4 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 3.6.5.4.1 REQUIREMENTS This SR provides assurance that the limitations on drywell-to-primary containment differential pressure stated

in the LCO are met. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency of this SR was

developed, based on operating experience related to trending

of drywell pressure variations during the applicable MODES

and to assessing proximity to the specified LCO differential

pressure limits. Furthermore, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is

considered adequate in view of other indications available

in the control room, including alarms, to alert the operator

to an abnormal drywell pressure condition.

With regard to drywell-to-primary containment differential pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 6). REFERENCES 1. USAR, Section 6.2.1.

2. USAR, Section 3.8.

3. USAR, Section 6.2.1.1.6.

4. USAR, Section 6.2.7.

5. USAR, Section 3.8, Attachment A3.8.

6. Calculation IP-0-0092.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Drywell Air Temperature B 3.6.5.5

BASES CLINTON B 3.6-127 Revision No. 4-6 SURVEILLANCE SR 3.6.5.5.1 (continued)

REQUIREMENTS average must consist of at least one reading from each elevation (with the exception that elevations 729 ft. 0

inches and 732 ft. 0 inches may be considered the same

elevation) as described in Ref. 3. However, all available

instruments should be used in determining the arithmetical

average.

The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency of the SR was developed based on operating experience related to variations in drywell average air temperature variations during the applicable

MODES. Furthermore, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an

abnormal drywell air temperature condition.

With regard to drywell average air temperature values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument uncertainties.

This requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in the associated plant procedures (Ref. 4).

REFERENCES 1. USAR, Section 6.2.1.

2. USAR, Section 9.4.7.

3. USAR, Section 7.5.1.4.2.4.

4. Calculation IP-0-0093.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Drywell Post-LOCA Vacuum Relief System B 3.6.5.6

BASES CLINTON B 3.6-131 Revision No. 13-2 ACTIONS D.1 and D.2 (continued) the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

E.1 If one drywell post-LOCA vacuum relief subsystem is inoperable for reasons other than Condition A or two or more drywell post-LOCA vacuum relief subsystems are inoperable for reasons other than Condition A, and not restored within the provided Completion Time, the plant must be brought to a condition in which the overall plant risk is minimized. To achieve this status, the plant must be brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Remaining in the Applicability of the LCO is acceptable because the plant risk in MODE 3 is similar to or lower than the risk in MODE 4 (Ref. 2) and because the time spent in MODE 3 to perform the necessary repairs to restore the system to OPERABLE status will be short. However, voluntary entry into MODE 4 may be made as it is also an acceptable low-risk state. The allowed Completion Time is reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

Required Action E.1 is modified by a Note that prohibits the application of LCO 3.0.4.a. This Note clarifies the intent of the Required Action by indicating that it is not permissible under LCO 3.0.4.a to enter MODE 3 from MODE 4 with the LCO not met. While remaining in MODE 3 presents an acceptable level of risk, it is not the intent of the Required Action to allow entry into, and continue operation in, MODE 3 from MODE 4 in accordance with LCO 3.0.4.a.

However, where allowed, a risk assessment may be performed in accordance with LCO 3.0.4.b. Consideration of the results of this risk assessment is required to determine the acceptability of entering MODE 3 from MODE 4 when this LCO is not met. SURVEILLANCE SR 3.6.5.6.1 REQUIREMENTS Each drywell post-LOCA vacuum relief valve is verified to be closed (except when being tested in accordance with SR 3.6.5.6.2 and SR 3.6.5.6.3 or when the drywell post-LOCA vacuum relief valves are performing their intended design

function) to ensure that this potential large drywell bypass

leakage path is not present. This Surveillance is normally

performed by observing the drywell post-LOCA vacuum relief

valve position indication. The 7 day Frequency is based on

engineering judgment, is considered adequate in view of other indications of drywell post-LOCA vacuum relief valve status available to the plant personnel, and has been shown to be acceptable through operating experience.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Drywell Post-LOCA Vacuum Relief System B 3.6.5.6

BASES CLINTON B 3.6-132 Revision No. 13-2 SURVEILLANCE SR 3.6.5.6.1 (continued)

REQUIREMEN Two Notes are added to this SR. The first Note allows drywell post-LOCA vacuum relief valves opened in conjunction

with the performance of a Surveillance to not be considered

as failing this SR. These periods of opening drywell post-

LOCA vacuum relief valves are controlled by plant procedures

and do not represent inoperable drywell post-LOCA vacuum

relief valves. A second Note is included to clarify that

valves open due to an actual differential pressure, are not

considered as failing this SR.

SR 3.6.5.6.2 Each drywell post-LOCA vacuum relief valve must be cycled to ensure that it opens adequately to perform its design

function and returns to the fully closed position. This

provides assurance that the safety analysis assumptions are

valid. A 31 day Frequency was chosen to provide additional

assurance that the drywell post-LOCA vacuum relief valves

are OPERABLE.

SR 3.6.5.6.3

Verification of the drywell post-LOCA vacuum relief valve opening differential pressure is necessary to ensure that

the safety analysis assumptions of <

0.2 psid for drywell vacuum relief are valid. The safety analysis assumes that the drywell post-LOCA vacuum relief valves will start

opening when the dry well pressure is approximately 0.2 psid

less than the containment and will be fully open when this

differential pressure is 0.5 psid. The 24 month Frequency

is based on the need to perform this Surveillance under the

conditions that apply during a plant outage and the

potential for violating the drywell boundary. Operating experience has shown these components usually pass the

Surveillance, which is based on the refueling cycle.

Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

REFERENCES 1. USAR, Section 6.2.

2. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

Division 1 and 2 SX Subsystems and UHS B 3.7.1 CLINTON B 3.7-6 Revision No. 13-2 BASES (continued)

______________________________________________________________________________

SURVEILLANCE SR 3.7.1.1 REQUIREMENTS This SR verifies UHS water volume is 593 acre-feet (excluding sediment). The Surveillance Frequency is in

accordance with UHS Erosion, Sediment Monitoring and

Dredging Program.

With regard to UHS water volume values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 9).

SR 3.7.1.2

Verifying the correct alignment for each manual, power operated, and automatic valve in each Division 1 and 2 SX

subsystem flow path provides assurance that the proper flow

paths will exist for Division 1 and 2 SX subsystem

operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position

prior to locking, sealing, or securing. A valve is also

allowed to be in the nonaccident position and yet considered

in the correct position, provided it can be automatically

realigned to its accident position within the required time.

This SR does not require any testing or valve manipulation;

rather, it involves verification that those valves capable

of potentially being mispositioned are in the correct

position. This SR does not apply to valves that cannot be

inadvertently misaligned, such as check valves.

Isolation of the SX subsystem to components or systems does not necessarily affect the OPERABILITY of the associated SX

subsystem. As such, when all SX pumps, valves, and piping

are OPERABLE, but a branch connection off the main header is isolated, the associated SX subsystem needs to be evaluated

to determine if it is still OPERABLE. Alternatively, it is acceptable and conservative to declare an SX subsystem

inoperable when a branch connection is isolated or a

supported ventilation system is inoperable.

The 31 day Frequency is based on engineering judgment, is

consistent with the procedural controls governing valve

operation, and ensures correct valve positions.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Division 3 SX Subsystem B 3.7.2 CLINTON B 3.7-6a Revision No. 13-2 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.7.1.3 REQUIREMENTS (continued) This SR verifies that the automatic isolation valves of the Division 1 and 2 SX subsystems will automatically switch to

the safety or emergency position to provide cooling water

exclusively to the safety related equipment during an

accident event. This is demonstrated by use of an actual or

simulated initiation signal and is performed with the plant

shut down. This SR also verifies the automatic start

capability of the SX pump in each subsystem. Operating experience has shown that these components usually pass the SR. Therefore, this Frequency is concluded to be

acceptable from a reliability standpoint.

______________________________________________________________________________

REFERENCES 1. Regulatory Guide 1.27, Revision 2, January 1976.

2. USAR, Section 9.2.1.2.

3. USAR, Table 9.2-3.

4. USAR, Section 6.2.1.1.3.3.

5. USAR, Chapter 15.

6. USAR, Section 6.2.2.3.

7. USAR, Table 6.2-2.

8. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

9. Calculation IP-0-0095.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Division 3 SX Subsystem B 3.7.2 CLINTON B 3.7-9 Revision No. 10-7 BASES ______________________________________________________________________________

SURVEILLANCE SR 3.7.2.1 (continued)

REQUIREMENTS Isolation of the Division 3 SX subsystem to components or systems does not necessarily affect the OPERABILITY of the

Division 3 SX subsystem. As such, when the Division 3 SX

pump, valves, and piping are OPERABLE, but a branch

connection off the main header is isolated, the Division 3

SX subsystem needs to be evaluated to determine if it is

still OPERABLE. Alternatively, it is acceptable and

conservative to declare an SX subsystem inoperable when a

branch connection is isolated or a supported ventilation

system is inoperable.

The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve

operation, and ensures correct valve positions.

SR 3.7.2.2

This SR verifies that the automatic isolation valves of the Division 3 SX subsystem will automatically switch to the

safety or emergency position to provide cooling water

exclusively to the safety related equipment during an

accident event. This is demonstrated by use of an actual or

simulated initiation signal and is performed with the plant

shut down. This SR also verifies the automatic start capability of the Division 3 SX pump.

Operating experience has shown that these components usually pass the SR. Therefore, this Frequency is concluded to be acceptable from a reliability standpoint.

______________________________________________________________________________

REFERENCES 1. USAR, Section 9.2.1.2.

2. USAR, Chapter 6.

3. USAR, Chapter 15.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Control Room Ventilation System B 3.7.3 CLINTON B 3.7-16a Revision No. 13-2 BASES ______________________________________________________________________________

ACTIONS G.1, G.2, and G.3 (continued) During movement of irradiated fuel assemblies in the primary or secondary containment, during CORE ALTERATIONS, or during

OPDRVs, with two Control Room Ventilation subsystems

inoperable or with one or more Control Room Ventilation

subsystems inoperable due to an inoperable CRE boundary, action must be taken immediately to suspend activities that

present a potential for releasing radioactivity that might

require treatment of the control room air. This places the

unit in a condition that minimizes the accident risk.

If applicable, CORE ALTERATIONS and movement of irradiated fuel assemblies in the primary and secondary containment

must be suspended immediately. Suspension of these

activities shall not preclude completion of movement of a component to a safe position. If applicable, actions must

be initiated immediately to suspend OPDRVs to minimize the probability of a vessel draindown and subsequent potential

for fission product release. Actions must continue until

the OPDRVs are suspended.

______________________________________________________________________________

SURVEILLANCE SR 3.7.3.1 and SR 3.7.3.2 REQUIREMENTS This SR verifies that a subsystem in a standby mode starts on demand and continues to operate. Standby systems should

be checked periodically to ensure that they start and

function properly. As the environmental and normal

operating conditions of this system are not severe, testing

each subsystem once every month provides an adequate check

on this system.

Monthly heater operation dries out any moisture accumulated in the charcoal from humidity in the

ambient air. The Makeup Filter System must be operated from the main control room for 10 continuous hours with the heaters energized. The Recirculation Filter System (without heaters) need only be operated for 15 minutes to demonstrate the function of the system. Furthermore, the

31 day Frequency is based on the known reliability of the

equipment and the two subsystem redundancy available.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Periodic Control Room Ventilation System B 3.7.3 CLINTON B 3.7-16b Revision No. 13-2 BASES

SURVEILLANCE SR 3.7.3.1 and SR 3.7.3.2 (continued)

REQUIREMENTS With regard to subsystem operation time values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 8, 9).

SR 3.7.3.3

This SR verifies that the required Control Room Ventilation System testing is performed in accordance with the

Ventilation Filter Testing Program (VFTP). The VFTP

includes testing HEPA filter performance, charcoal adsorber

bypass leakage and efficiency, minimum system flow rate (scfm), combined HEPA filter and charcoal adsorber pressure

drop, and heater dissipation in accordance with Regulatory

Guide 1.52 (Ref. 10). The Frequencies for performing the Control Room Ventilation System filter tests are also in

accordance with Regulatory Guide 1.52 (Ref.10). Specific test frequencies and additional information are discussed in

detail in the VFTP.

SR 3.7.3.4

This SR verifies that each Control Room Ventilation subsystem starts and operates on an actual or simulated high

radiation initiation signal. While this Surveillance can be

performed with the reactor at power, operating experience

has shown these components usually pass the Surveillance, which is based on the refueling cycle. Therefore, the

Frequency was concluded to be acceptable from a reliability

standpoint.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Room AC System B 3.7.4 CLINTON B 3.7-21 Revision No. 13-2 BASES

ACTIONS E.1, E.2, and E.3 (continued)

During movement of irradiated fuel assemblies in the primary or secondary containment, during CORE ALTERATIONS, or during

OPDRVs, if the Required Action and associated Completion

Time of Condition B is not met, action must be taken to

immediately suspend activities that present a potential for

releasing radioactivity that might require operation of the

Control Room Ventilation System in the high radiation mode.

This places the unit in a condition that minimizes risk.

If applicable, CORE ALTERATIONS and handling of irradiated fuel in the primary and secondary containment must be

suspended immediately. Suspension of these activities shall

not preclude completion of movement of a component to a safe

position. Also, if applicable, actions must be initiated

immediately to suspend OPDRVs to minimize the probability of

a vessel draindown and subsequent potential for fission

product release. Actions must continue until the OPDRVs are

suspended.

SURVEILLANCE SR 3.7.4.1 REQUIREMENTS This SR verifies that the heat removal capability of the system is sufficient to remove the control room heat load

assumed in the safety analysis. The SR consists of a

combination of testing and calculation. The 24 month

Frequency is appropriate since significant degradation of

the Control Room AC System is not expected over this time

period.

With regard to heat removal capability values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 4).

REFERENCES 1. USAR, Section 6.4.

2. USAR, Section 9.4.1.

3. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

4. Calculation IP-0-0102.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Main Condenser Offgas B 3.7.5 CLINTON B 3.7-24 Revision No. 13-2 BASES

ACTIONS B.1, B.2, and B.3 (continued) in at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Remaining in the Applicability of the LCO is acceptable because the plant risk in MODE 3 is similar to or lower than the risk in MODE 4 (Ref. 4) and because the time spent in MODE 3 to perform the necessary repairs to restore the system to OPERABLE status will be short. However, voluntary entry into MODE 4 may be made as it is also an acceptable low-risk state.

Required Action B.3 is modified by a Note that prohibits the application of LCO 3.0.4.a. This Note clarifies the intent of the Required Action by indicating that it is not permissible under LCO 3.0.4.a to enter MODE 3 from MODE 4 with the LCO not met. While remaining in MODE 3 presents an acceptable level of risk, it is not the intent of the Required Action to allow entry into, and continue operation in, MODE 3 from MODE 4 in accordance with LCO 3.0.4.a.

However, where allowed, a risk assessment may be performed in accordance with LCO 3.0.4.b. Consideration of the results of this risk assessment is required to determine the acceptability of entering MODE 3 from MODE 4 when this LCO is not met. The allowed Completion Time is reasonable, based on operating experience, to reach the required unit

conditions from full power conditions in an orderly manner and without challenging unit systems.

______________________________________________________________________________

SURVEILLANCE SR 3.7.5.1 and SR 3.7.5.2 REQUIREMENTS SR 3.7.5.2, on a 31 day Frequency, requires an isotopic analysis of an offgas sample to ensure that the required

limits are satisfied. The noble gases to be sampled are

Xe-133, Xe-135, Xe-138, Kr-85m, Kr-87, and Kr-88 (Ref. 5).

If the measured release rate of radioactivity increases significantly (by 50% after correcting for expected increases due to changes in THERMAL POWER), an isotopic

analysis is also performed within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the increase is noted, as required by SR 3.7.5.1, to ensure that the increase is not indicative of a sustained increase in the

radioactivity rate. The required isotopic analysis is

intended to support determination of the cause for the

increase in offgas radiation release rates, such as the

onset of leakage from a fuel pin(s). However, there are

certain evolutions (e.g., swapping of the steam jet air

ejectors and regeneration of the offgas system desiccant

dryers) which are known to result in a predictable and

(continued)

Main Condenser Offgas B 3.7.5 CLINTON B 3.7-24a Revision No. 13-2 BASES

SURVEILLANCE SR 3.7.5.1 and SR 3.7.5.2 (continued)

REQUIREMENTS

temporary increase in the indicated offgas radioactivity release rate. These indicated increases in offgas

radioactivity release rates can be caused solely by

increases in offgas flow. Since these increases are due to

an evolution(s) known to cause such an increase and not due to an actual increase in the "nominal steady state fission gas release rate," isotopic analysis of an offgas sample is

not required for these evolutions. In any of these cases, it is prudent to ensure that the offgas radiation level (radioactivity release rate) returns to previous or expected

levels within four hours or as soon as possible following

the evolution. This will confirm that there are no other

causes for the increase in the radioactivity release rate

indication. The 31 day Frequency is adequate in view of

other instrumentation that continuously monitor the offgas, and is acceptable based on operating experience.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Main Turbine Bypass System B 3.7.6 CLINTON B 3.7-27 Revision No. 10-7 BASES (continued)

___

SURVEILLANCE SR 3.7.6.1 REQUIREMENTS Cycling each main turbine bypass valve through one complete cycle of full travel demonstrates that the valves are

mechanically OPERABLE and will function when required. The

31 day Frequency is based on engineering judgment, is

consistent with the procedural controls governing valve

operation, and ensures correct valve positions. Therefore, the Frequency is acceptable from a reliability standpoint.

SR 3.7.6.2

The Main Turbine Bypass System is required to actuate automatically to perform its design function. This SR

demonstrates that, with the required system initiation

signals, the valves will actuate to their required position.

The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit

outage and because of the potential for an unplanned

transient if the Surveillance were performed with the

reactor at power. Operating experience has shown the

24 month Frequency, which is based on the refueling cycle, is acceptable from a reliability standpoint.

SR 3.7.6.3

This SR ensures that the TURBINE BYPASS SYSTEM RESPONSE TIME is in compliance with the assumptions of the appropriate

safety analysis. The response time limits (bypass valve begins to open in 0.1 seconds and 80% of turbine bypass system capacity is established in 0.3 seconds) are specified in applicable surveillance test procedures. The

24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit

outage and because of the potential for an unplanned

transient if the Surveillance were performed with the

reactor at power. Operating experience has shown the

24 month Frequency, which is based on the refueling cycle, is acceptable from a reliability standpoint.

With regard to TURBINE BYPASS SYSTEM RESPONSE TIME values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 3).

(continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Fuel Pool Water Level B 3.7.7 CLINTON B 3.7-29 Revision No. 4-6 BASES (continued)

___

LCO The specified water level preserves the assumption of the fuel handling accident analysis (Ref. 2). As such, it is

the minimum required for fuel movement within the spent fuel

storage pool and upper containment fuel storage pool.

___

APPLICABILITY This LCO applies whenever movement of irradiated fuel assemblies occurs in the associated fuel storage racks since

the potential for a release of fission products exists.

___

ACTIONS A.1

Required Action A.1 is modified by a Note indicating that LCO 3.0.3 does not apply. If moving irradiated fuel

assemblies while in MODE 1, 2, or 3, the fuel movement is

independent of reactor operations. Therefore, inability to

suspend movement of irradiated fuel assemblies is not a

sufficient reason to require a reactor shutdown.

When the initial conditions for an accident cannot be met, steps should be taken to preclude the accident from

occurring. With either fuel pool level less than required, the movement of irradiated fuel assemblies in the associated

storage pool is suspended immediately. Suspension of this

activity shall not preclude completion of movement of an

irradiated fuel assembly to a safe position. This

effectively precludes a spent fuel handling accident from

occurring in the associated fuel storage pool.

___

SURVEILLANCE SR 3.7.7.1 REQUIREMENTS This SR verifies that sufficient water is available in the event of a fuel handling accident. The water level in the

spent fuel storage pool and upper containment fuel storage

pool must be checked periodically. The 7 day Frequency is

acceptable, based on operating experience, considering that

the water volume in the pool is normally stable and water

level changes are controlled by unit procedures.

With regard to fuel pool water level values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 6).

(continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-13b Revision No. 13-2 BASES SURVEILLANCE For the Division 1 and 2 DGs, DG operation is returned to REQUIREMENTS the isochronous mode upon switchover such that rated (continued) speed/frequency is automatically attained. For the Division 3 DG, however, with the DG governor initially operating in

the droop condition during the test mode, operator action may be required to reset the governor for ready-to-load

operation at the required frequency. This difference is

acknowledged in the Bases for SR 3.8.1.17 to address compliance with that SR. Notwithstanding, the condition also requires the Division 3 DG to be considered inoperable if it cannot be ensured that the required frequency would be

attained in the event of a LOCA and a loss of offsite power concurrent with the Division 3 DG being operated or tested with the existing droop setting in effect. Thus, the Division 3 DG is generally considered inoperable while the droop setting is in effect during the performance of SRs that require the DG to be paralleled to the offsite source.

SR 3.8.1.1 This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network

and availability of offsite AC electrical power. The breaker

alignment verifies that each breaker is in its correct

position to ensure that distribution buses and loads are

connected to their preferred power source and that

appropriate independence of offsite circuits is maintained.

The 7 day Frequency is adequate since breaker position is

not likely to change without the operator being aware of it

and because its status is displayed in the control room.

SR 3.8.1.2 and SR 3.8.1.7 These SRs help to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and maintain the unit in a safe shutdown condition.

To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs have been modified by Notes (the Note for SR 3.8.1.7 and Note 2 for SR 3.8.1.2) to indicate that all DG starts for these

Surveillances may be preceded by an engine prelube period and followed by a warmup period prior to loading.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-14 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)

REQUIREMENTS For the purposes of this testing, the DGs are started from standby conditions. Standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as recommended by

the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural

circulation. This allowance is not intended to impose a

maximum limit on engine temperatures. For the purposes of

these SRs, the DG may be started using a manual start

signal, a simulated loss of offsite power test signal by itself, a simulated loss of offsite power test signal in

conjunction with an ECCS actuation test signal, or an ECCS actuation test signal by itself.

In order to reduce stress and wear on diesel engines, the manufacturer recommends that the starting speed of DGs be

limited, that warmup be limited to this lower speed, and

that DGs be gradually accelerated to synchronous speed prior

to loading. These modified start procedures are the intent

of Note 3, which is only applicable when such procedures are

used. SR 3.8.1.7 requires that, at a 184 day Frequency, the DG starts from standby conditions and achieves required voltage

and frequency within 12 seconds. The 12 second start

requirement supports the assumptions in the design basis

LOCA analysis (Ref. 5). The 12 second start requirement may

not be applicable to SR 3.8.1.2 (see Note 3 of SR 3.8.1.2),

when a modified start procedure as described above is used.

If a modified start is not used, the 12 second start requirement of SR 3.8.1.7 applies. Since SR 3.8.1.7 does require 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 intent of Note 1 of SR 3.8.1.2. Similarly, the

performance of SR 3.8.1.12 or SR 3.8.1.19 also satisfies the

requirements of SR 3.8.1.2 and SR 3.8.1.7.

In addition to the SR requirements, the time for the DG to reach steady state operation, unless the modified DG start method is employed, is periodically monitored and the trend evaluated to identify degradation of governor and voltage regulator performance.

(continued)

AC SourcesOperating B 3.8.1 CLINTON B 3.8-15 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.2 and SR 3.8.1.7 (continued)

REQUIREMENTS The normal 31 day Frequency for SR 3.8.1.2 (see Table 3.8.1-1, "Diesel Generator Test Schedule") is consistent with the industry guidelines for assessment of diesel generator performance (Ref. 13). The 184 day Frequency for SR 3.8.1.7 is a reduction in cold testing

consistent with Generic Letter 84-15 (Ref. 7). These Frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.

With regard to required voltage and frequency values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument uncertainties.

This requires additional margin to be added to the limit to

compensate for instrument uncertainties, for implementation

in the associated plant procedures (Refs. 17, 18, 19, 22, 23).

SR 3.8.1.3 This Surveillance demonstrates that the DGs are capable of synchronizing and accepting greater than or equal to the equivalent of the maximum expected accident loads. However, consistent with the recommendations of Regulatory Guide 1.9, Revision 3 (Ref. 16), this surveillance is performed with a DG load equal to or greater than 90 percent of its

continuous rating. A minimum run time of 60 minutes is

required to stabilize engine temperatures, while minimizing

the time that the DG is connected to the offsite source.

Although no power factor requirements are established by this SR, the DG is normally operated at a power factor

between 0.8 lagging and 1.0. The 0.8 value is the design

rating of the machine, while 1.0 is an operational

limitation to ensure circulating currents are minimized.

The normal 31 day Frequency for this Surveillance (see Table 3.8.1-1) is consistent with the industry guidelines for assessment of diesel generator performance (Ref. 13).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-16 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.3 (continued)

REQUIREMENTS Note 1 modifies this Surveillance to indicate that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are

minimized.

Note 2 modifies this Surveillance by stating that momentary transients because of changing bus loads do not invalidate

this test.

Note 3 indicates that this Surveillance shall be conducted on only one DG at a time in order to avoid common cause

failures that might result from offsite circuit or grid

perturbations.

Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to

credit satisfactory performance.

With regard to DG loading values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 20).

SR 3.8.1.4

This SR provides verification that the level of fuel oil in the day tank is at or above the low level alarm setpoint.

The level is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of DG operation at maximum expected post LOCA loads.

The 31 day Frequency is adequate to assure that a sufficient supply of fuel oil is available, since low level alarms are

provided and facility operators would be aware of any large

uses of fuel oil during this period.

With regard to fuel oil level values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 21).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-17 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.5 REQUIREMENTS (continued) Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Removal of water from the

fuel oil day tanks once every 31 days eliminates the necessary environment for bacterial survival. This is an

effective means of controlling microbiological fouling. In

addition, it eliminates the potential for water entrainment

in the fuel oil during DG operation. Water may come from

any of several sources, including condensation, contaminated fuel oil, and breakdown of the fuel oil by bacteria.

Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The Surveillance Frequency is established by Regulatory Guide 1.137 (Ref. 11). This SR is for preventive maintenance. The presence of water does not necessarily represent a failure

of this SR provided that accumulated water is removed during

performance of this Surveillance.

SR 3.8.1.6

This Surveillance demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from its

associated storage tank to its associated day tank. It is

required to support the continuous operation of standby power sources. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for

automatic fuel transfer systems are OPERABLE.

The design of fuel transfer systems is such that pumps operate automatically in order to maintain an adequate volume of fuel oil in the day tanks during or following DG

testing. Therefore, a 31 day Frequency is specified to

correspond to the maximum interval for DG testing.

SR 3.8.1.7 See SR 3.8.1.2.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Periodic removal AC SourcesOperating B 3.8.1 CLINTON B 3.8-18 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.8 REQUIREMENTS (continued) Transfer of each 4.16 kV ESF bus power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of the alternate circuit. The 24 month Frequency of the Surveillance is based on

engineering judgment taking into consideration the plant conditions required to perform the Surveillance, and is

intended to be consistent with expected fuel cycle lengths.

Operating experience has shown that these components usually

pass the SR. Therefore, the Frequency 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, plant

safety systems. Credit may be taken for unplanned events

that satisfy this SR. Examples of unplanned events may

include:

1) Unexpected operational events which cause the equipment to perform the function specified by this surveillance, for which adequate documentation of the required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

SR 3.8.1.9 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 a load

equivalent to at least as large as the largest single load

while maintaining a specified margin to the overspeed trip.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-19 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.9 (continued)

REQUIREMENTS The referenced load for DG 1A is the low pressure core spray pump; for DG 1B, the residual heat removal (RHR) pump; and for DG 1C the HPCS pump. The Shutdown Service Water (SX) pump values are not used as the largest load since the SX

supplies cooling to the associated DG. If this load were to trip, it would result in the loss of the DG. The use of

larger loads for reference purposes is acceptable. This

Surveillance may be accomplished by:

1) Tripping the DG output breaker with the DG carrying greater than or equal to its associated single largest

load while paralleled to offsite power, or while supplying the bus, or

2) Tripping its associated single largest load with the DG supplying the bus.

As required by IEEE-308 (Ref. 14), the load rejection test is acceptable if the increase in diesel speed does not

exceed 75% of the difference between synchronous speed and

the overspeed trip setpoint, or 15% above synchronous speed, whichever is lower.

The 24 month Frequency is consistent with the refuel cycle recommendations of Regulatory Guide 1.9 (Ref. 16).

This SR has been modified by two Notes. The intent of Note 1 is to indicate that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

___________________________________________________________________(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-19b Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.10 (continued)

REQUIREMENTS While the DG is not expected to experience this transient during an event and continue to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can

be corrected or isolated.

In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as

possible, testing must be performed using a power factor 0.9. This power factor is chosen to be representative of the actual design basis inductive loading that the DG would

experience.

The 24 month Frequency is consistent with the refuel cycle recommendation of Regulatory Guide 1.9 (Ref. 16) and is intended to be consistent with expected fuel cycle lengths.

This SR has been modified by a Note. The intent of the Note is to indicate that credit may be taken for unplanned events

that satisfy this SR. Examples of unplanned events may

include:

1) Unexpected operational events which cause the equipment to perform the function specified by this

Surveillance, for which adequate documentation of the required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related

distribution subsystem) connected to one offsite source, while the remaining safety-related (and non-safety related)

distribution systems are aligned to the other offsite source (or unit auxiliary transformers). This minimizes the possibility of common cause failure resulting from offsite/grid voltage perturbations.

This Surveillance should be conducted on only one DG at a time in order to avoid common cause failures that might

result from offsite of grid perturbations.

With regard to DG load and voltage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument

indication uncertainties (Ref. 24).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-21 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.11 (continued)

REQUIREMENTS full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of

operation. In lieu of actual demonstration of the

connection and loading of these loads, testing that

adequately shows the capability of the DG system to perform

these functions is acceptable. This testing may include any

series of sequential, overlapping, or total steps so that

the entire connection and loading sequence is verified.

The Frequency of 24 months is consistent with the refuel cycle recommendations of Regulatory Guide 1.9 (Ref. 16), takes into consideration unit conditions required to perform

the Surveillance, and is intended to be consistent with

expected fuel cycle lengths.

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. Standby conditions mean that the lube

oil is heated by the jacket water and continuously

circulated through a portion of the system as recommended by

the vendor. Engine jacket water is heated by an immersion

heater and circulates through the system by natural

circulation. This allowance is not intended to impose a

maximum limit on engine temperatures. The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical

distribution system, and challenge plant safety systems.

Credit may be taken for unplanned events that satisfy this

SR. Examples of unplanned events may include:

1) Unexpected operational events which cause the equipment to perform the function specified by this

Surveillance, for which adequate documentation of the

required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-22 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.12 REQUIREMENTS (continued) 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.

With regard to DG start time, required voltage and frequency values obtained pursuant to this SR, as read from plant

indication instrumentation, the specified limit is not

considered to be a nominal value with respect to instrument

uncertainties. This requires additional margin to be added

to the limit to compensate for instrument uncertainties, for

implementation in the associated plant procedures (Refs. 17, 18, 19, 22, 23).

The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance and is

intended to be consistent with the expected fuel cycle

lengths. Operating experience has shown that these components usually pass the SR. Therefore, the Frequency was concluded to be acceptable from a reliability

standpoint.

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. Standby conditions mean that the lube

oil is heated by the jacket water and continuously

circulated through a portion of the system as recommended by

the vendor. Engine jacket water is heated by an immersion

heater and circulates through the system by natural

circulation. This allowance is not intended to impose a maximum limit on engine temperatures. The reason for Note 2 is that during operation with the reactor critical, performance of this SR could cause perturbations to the

electrical distribution systems that could challenge

continued steady state operation and, as a result, plant safety systems. Credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-23 Revision No. 10-7 BASES SURVEILLANCE SR 3.8.1.12 (continued)

REQUIREMENTS 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

SR 3.8.1.13

This Surveillance demonstrates that DG non-critical protective functions (e.g., high jacket water temperature) are bypassed on an ECCS initiation test signal and critical

protective functions trip the DG to avert substantial damage

to the DG unit. The non-critical trips are bypassed during

DBAs and provide alarms on abnormal engine conditions.

These alarms provide the operator with necessary information

to react appropriately. The DG availability to mitigate the

DBA is more critical than protecting the engine against

minor problems that are not immediately detrimental to emergency operation of the DG.

The 24 month Frequency is based on engineering judgment, taking into consideration plant conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR. Therefore, the Frequency was concluded to be acceptable from a

reliability standpoint.

The SR is modified by a Note. The intent of the Note is to indicate that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the

required performance is available; and

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-24 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.13 (continued)

REQUIREMENTS 2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

SR 3.8.1.14 Regulatory Guide 1.9, Revision 3 (Ref. 16) requires demonstration once per 24 months that the DGs can start and run continuously at or near 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 . The DGs are to be loaded equal to or greater than 105 percent of the continuous rating for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and equal to or greater than 90 percent of the continuous rating for the remaining hours of the test (i.e., 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months ) (Ref. 16). The DG starts for this Surveillance can be performed either from

standby or hot conditions. The provisions for prelube and

warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.

In order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing must be performed using a power factor 0.9. This power factor is chosen to be representative of the actual design basis inductive loading that the DG could experience.

The 24 month Frequency is consistent with the refuel cycle recommendations of Regulatory Guide 1.9, Revision 3 (Ref.

16); takes into consideration plant conditions required to perform the Surveillance; and is intended to be consistent

with expected fuel cycle lengths.

This Surveillance is modified by two Notes. Note 1 states that momentary transients due to changing bus loads do not invalidate this test. Similarly, momentary power factor

transients above the limit do not invalidate the test. The

intent of Note 2 is to indicate that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-25 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.14 (continued)

REQUIREMENTS

1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required

performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related distribution subsystem) connected to one offsite source, while the remaining safety-related (and non-safety related) distribution systems are aligned to the other offsite source (or unit auxiliary transformers). This minimizes the possibility of common cause failures resulting from

offsite/grid voltage perturbations.

With regard to DG loading capability values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument indication uncertainties (Ref. 20).

SR 3.8.1.15 This Surveillance is consistent with the recommendations of Regulatory Guide 1.108 (Ref. 10), paragraph 2.a.(5), and 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.

With regard to DG loading values obtained pursuant to this SR, as read from plant indication instrumentation, the specified

limit is considered to be a nominal value and therefore does

not require compensation for instrument indication

uncertainties (Ref. 20).

With regard to DG start time, frequency and voltage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a

nominal value with respect to instrument uncertainties. This

requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in

the associated plant procedures (Refs. 17, 18, 19, 22, 23).

The 24 month Frequency is consistent with the refuel cycle recommendations of Regulatory Guide 1.9, Revision 3 (Ref. 16).

__ (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-26 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.15 (continued)

REQUIREMENTS This SR has been modified by two Notes. Note 1 ensures that the test is performed with the diesel sufficiently hot. The requirement that the diesel has operated for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months at full load conditions (i.e., equal to or greater

than 90 percent of the continuous rating) prior to performance of this Surveillance is based on manufacturer

recommendations for achieving hot conditions. Momentary

transients due to changing bus loads do not invalidate this

test. Note 2 allows all DG starts to be preceded by an

engine prelube period to minimize wear and tear on the diesel during testing.

SR 3.8.1.16

As required by Regulatory Guide 1.108 (Ref. 10), paragraph 2.a.(6), this Surveillance ensures that the manual

synchronization and load transfer from the DG to each

offsite power source can be made and that the DG can be

returned to ready-to-load status when offsite power is

restored. It also ensures that the undervoltage logic is

reset to allow the DG to reload if a subsequent loss of

offsite power occurs. The DG is considered to be in

ready-to-load status when the DG is at rated speed and

voltage, the output breaker is open and can receive an

auto-close signal on bus undervoltage, and the load sequence

timers are reset.

Portions of the synchronization circuit are associated with the DG and portions with the offsite circuit. If a failure

in the synchronization requirement of the Surveillance

occurs, depending on the specific affected portion of the

synchronization circuit, either the DG or the associated

offsite circuit is declared inoperable.

The Frequency of 24 months is consistent with the refuel cycle recommendations of Regulatory Guide 1.9 (Ref. 16), and takes into consideration plant conditions required to perform the Surveillance.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-28 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.17 (continued)

REQUIREMENTS ready-to-load operation in order to complete the surveillance for the Division 3 DG. Resetting the governor ensures that the DG will supply the Division 3 bus at the required frequency in the event of a LOCA and a loss of

offsite power while the DG is in a droop condition during the test mode.

The requirement to automatically energize the emergency loads with offsite power is essentially identical to that of

SR 3.8.1.12. The intent in the requirement associated with

SR 3.8.1.17.b is to show that the emergency loading is not

affected by the DG operation in test mode. In lieu of

actual demonstration of connection and loading of loads, testing that adequately shows the capability of the

emergency loads to perform these functions is acceptable.

This testing may include any series of sequential, overlapping, or total steps so that the entire connection

and loading sequence is verified.

The 24 month Frequency is consistent with the refuel cycle recommendations of Regulatory Guide 1.9 (Ref. 16); takes into consideration plant conditions required to perform the

Surveillance; and is intended to be consistent with expected

fuel cycle lengths.

This SR has been modified by a Note. The intent of this note is to indicate that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

1) Unexpected operational events which cause the equipment to perform the function specified by this

Surveillance, for which adequate documentation of the

required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

Testing performed for this SR is normally conducted with the DG being tested (and the associated safety-related distribution subsystem) connected to one offsite source, while the remaining safety-related (and non-safety related) distribution systems are aligned to the other offsite source (or unit auxiliary transformers). This minimizes the

possibility of common cause failures resulting from

offsite/grid voltage perturbations. (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-29 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.18 REQUIREMENTS (continued) Under accident conditions with a loss of offsite power, loads are sequentially connected to the bus by the load sequencing logic (except for Division 3 which has no load sequence timers). The sequencing logic controls the

permissive and starting signals to motor breakers to prevent overloading of the DGs due to high motor starting currents.

The 10% load sequence time 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 and is consistent with the recommendations of

Regulatory Guide 1.108 (Ref. 10), paragraph 2.a.(2).

Reference 2 provides a summary of the automatic loading of

ESF buses.

The Frequency of 24 months is consistent with the refuel cycle recommendations of Regulatory Guide 1.9 (Ref. 16);

takes into consideration plant conditions required to perform the Surveillance; and is intended to be consistent with expected fuel cycle lengths.

This SR is modified by a Note. The reason for the Note is that performing the Surveillance during these MODES may perturb the electrical distribution system, and challenge

plant safety systems. Credit may be taken for unplanned

events that satisfy this SR. Examples of unplanned events

may include:

1) Unexpected operational events which cause the equipment to perform the function specified by this

Surveillance, for which adequate documentation of the

required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

With regard to sequence time values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 25).

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-30 Revision No. 10-7 BASES SURVEILLANCE SR 3.8.1.19 REQUIREMENTS (continued) In the event of a DBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to ESF systems so that the fuel, RCS, and containment design limits are not exceeded.

This Surveillance demonstrates the DG operation, as discussed in the Bases for SR 3.8.1.11, during a loss of

offsite power actuation test signal in conjunction with an

ECCS initiation signal. For load shedding effected via

shunt trips that are actuated in response to a LOCA signal (i.e., "ECCS initiation signal"), this surveillance includes

verification of the shunt trips (for Divisions 1 and 2 only)

in response to LOCA signals originating in the ECCS

initiation logic as well as the Containment and Reactor

Vessel Isolation and Control System actuation logic. In

lieu of actual demonstration of connection and loading of

loads, testing that adequately shows the capability of the

DG system to perform these functions is acceptable. This

testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading

sequence is verified.

The Frequency of 24 months takes into consideration plant conditions required to perform the Surveillance and is intended to be consistent with an expected fuel cycle length of 24 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. Standby conditions mean that the lube

oil is heated by the jacket water and continuously

circulated through a portion of the system as recommended by

the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural circulation. This allowance is not intended to impose a

maximum limit on engine temperatures. The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge plant safety systems.

Credit may be taken for unplanned events that satisfy this

SR. Examples of unplanned events may include:

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-31 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.19 (continued)

REQUIREMENTS 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

With regard to DG start time, required voltage and frequency values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument

uncertainties. This requires additional margin to be added

to the limit to compensate for instrument uncertainties, for

implementation in the associated plant procedures (Refs. 17, 18, 19, 22).

SR 3.8.1.20

This Surveillance is performed with the plant shut down and demonstrates that the DG starting independence has not been

compromised. Also, this Surveillance demonstrates that each

engine can achieve proper speed within the specified time when the DGs are started simultaneously.

The 10 year Frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref. 10).

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. Standby conditions mean that the lube oil is heated by the jacket water and continuously circulated through a portion of the system as recommended by the vendor. Engine jacket water is heated by an immersion heater and circulates through the system by natural circulation. This allowance is not intended to impose a

maximum limit on engine temperatures.

With regard to required voltage and frequency values obtained pursuant to this SR, as read from plant indication (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

AC SourcesOperating B 3.8.1 CLINTON B 3.8-32 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.1.20 (continued)

REQUIREMENTS instrumentation, the specified limit is not considered to be a nominal value with respect to instrument uncertainties.

This requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation

in the associated plant procedures (Refs. 17, 18, 19, 22, 23).

Diesel Generator Test Schedule

The DG test schedule (Table 3.8.1-1) implements the industry guidelines for assessment of diesel generator performance (Ref. 13). The purpose of this test schedule is to provide timely test data to establish a confidence level associated

with the goal to maintain DG reliability at > 0.95 per test.

According to the industry guidelines (Ref. 13), each DG unit should be tested at least once every 31 days. Whenever a DG

has experienced 4 or more valid failures in the last 25 valid tests, the maximum time between tests is reduced to 7 days. Four failures in 25 valid tests is a failure rate of 0.16, or the threshold of acceptable DG performance, and hence may be an early indication of the degradation of DG reliability. When considered in the light of a long history of tests, however, 4 failures in the last 25 valid tests may only be a statistically probable distribution of random

events. Increasing the test Frequency allows a more timely

accumulation of additional test data upon which to base

judgment of the reliability of the DG. The increased test

Frequency must be maintained until seven consecutive failure

free tests have been performed.

The Frequency for accelerated testing is 7 days, but no less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Tests conducted at intervals of less than

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months may be credited for compliance with Required

Actions. However, for the purpose of re-establishing the normal 31-day Frequency, a successful test at an interval of less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months should be considered an invalid test and not count towards the seven consecutive failure free starts, and the consecutive test count is not reset.

A test interval in excess of 7 days (or 31 days, as appropriate) constitutes a failure to meet SRs and results

in the associated DG being declared inoperable. It does

not, however, constitute a valid test or failure of the DG, and any consecutive test count is not reset.

(continued)

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 CLINTON B 3.8-45 Revision No. 7-7 BASES SURVEILLANCE SR 3.8.3.1 (continued)

REQUIREMENTS The 31 day Frequency is adequate to ensure that a sufficient supply of fuel oil is available, since low level alarms are provided and unit operators would be aware of any large uses of fuel oil during this period.

With regard to lube oil inventory values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 11).

SR 3.8.3.2 This Surveillance ensures that sufficient lube oil inventory is available to support at least 7 days of maximum expected

post LOCA load operation for each DG. This minimum volume

requirement is based on the DG manufacturer's consumption

values for the run time of the DG. Implicit in this SR is

the requirement to verify the capability to transfer the

lube oil from its storage location to the DG when the DG

lube oil sump does not hold adequate inventory for 7 days of

maximum expected post LOCA load operation without the level

reaching the manufacturer's recommended minimum level.

A 31 day Frequency is adequate to ensure that a sufficient lube oil supply is onsite, since DG starts and run times are closely monitored by the plant staff.

With regard to lube oil inventory values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 8).

SR 3.8.3.3

The tests of fuel oil prior to addition to the storage tanks 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 and operation. 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 the sample (and corresponding results) of new fuel

and addition of new fuel oil to the storage tanks to exceed

31 days. The limits and applicable ASTM Standards for the (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 CLINTON B 3.8-47 Revision No. 12-5 BASES SURVEILLANCE SR 3.8.3.3 (continued)

REQUIREMENTS Fuel oil degradation during long term storage shows up as an increase in particulate, mostly due to oxidation. The

presence of particulate does not mean that the fuel oil will

not burn properly in a diesel engine. However, the

particulate can cause fouling of filters and fuel oil

injection equipment, which can cause engine failure.

Particulate concentrations should be determined in accordance with ASTM D6217-98(Ref. 6). This method involves a gravimetric determination of total particulate

concentration in the fuel oil and has a limit of 10 mg/l.

It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing.

The Frequency of this Surveillance takes into consideration fuel oil degradation trends indicating that particulate concentration is unlikely to change between Frequency

intervals.

With regard to fuel oil property values obtained pursuant to this SR, as read from plant indication instrumentation, the

specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 9).

SR 3.8.3.4 This Surveillance ensures that, without the aid of the refill compressor, sufficient air start capacity for each DG

is available. The system design provides for multiple start

attempts without recharging when pressurized above the low

pressure alarm setpoint. The pressure specified in this SR

reflects a value at which multiple starts can be

accomplished, but is not so high as to result in failing the

limit due to normal cycling of the recharge compressor.

The 31 day Frequency takes into account the capacity, capability, redundancy, and diversity of the AC sources and other indications available in the control room, including alarms, to alert the operator to below normal air start pressure.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 CLINTON B 3.8-48 Revision No. 12-6 BASES SURVEILLANCE SR 3.8.3.4 (continued)

REQUIREMENTS With regard to air start capacity values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and

therefore does not require compensation for instrument

indication uncertainties (Ref. 10).

SR 3.8.3.5 Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water

environment in order to survive. Removal of water from the

storage tanks once every 92 days eliminates the necessary

environment for bacterial survival. This is the most

effective means of controlling microbiological fouling. In

addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, contaminated

fuel oil, and from breakdown of the fuel oil by bacteria.

Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight

integrity of the fuel oil system. The Surveillance

Frequencies are established by Regulatory Guide 1.137 (Ref. 2). This SR is for preventive maintenance. The

presence of water does not necessarily represent a failure

of this SR provided that accumulated water is removed during

performance of the Surveillance.

REFERENCES 1. USAR, Section 9.5.4.

2. Regulatory Guide 1.137.

3. ANSI N195, Appendix B, 1976.

4. USAR, Chapter 6.

5. USAR, Chapter 15.

6. ASTM Standards: D4057-95; D1298-99; D975-06b; D4176-93; D6217-98.

7. Deleted.

8. Calculation IP-0-0120.

9. Calculation IP-0-0121.

10. Calculation IP-0-0122.

11. Calculation IP-C-0111.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Periodic removal DC SourcesOperating B 3.8.4 CLINTON B 3.8-56 Revision No. 13-2 BASES (continued)

SURVEILLANCE SR 3.8.4.1 REQUIREMENTS Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the battery chargers, which support the ability of the batteries to perform their

intended function. Float charge is the condition in which

the charger is supplying the continuous charge required to

overcome the internal losses of a battery (or battery cell)

and maintain the battery in a fully charged state while

supplying the continuous steady state loads of the

associated DC subsystem. On float charge, battery cells

will receive adequate current to continually charge the

battery. The voltage requirements are based on the nominal

design voltage of the battery and are consistent with the

minimum float voltage established by the battery

manufacturer (2.20 Vpc or 127.6 V at the battery terminals).

This voltage maintains the battery plates in a condition

that supports maintaining the grid life (expected to be

approximately 20 years). The 7 day Frequency is consistent

with manufacturer's recommendations and IEEE-450 (Ref. 9).

With regard to battery terminal voltage values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 13).

SR 3.8.4.2 This SR verifies the design capacity of the battery chargers. According to Regulatory Guide 1.32 (Ref. 10), the battery charger supply is recommended to be based on the

largest combined demands of the various steady state loads and the charging capacity to restore the battery from the

design minimum charge state to the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensure that these requirements can be satisfied. This SR

provides two options. One option requires that each battery

charger be capable of supplying 300 amps for Divisions 1 and 2 (100 amps for Divisions 3 and 4) at the minimum

established float voltage for 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The ampere

requirements are based on the output rating of the chargers.

The voltage requirements are based on the charger voltage level after a response to a loss of AC power. The time period is sufficient for the charger temperature to have stabilized and to have been maintained for at least 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

The other option requires that each battery charger be capable of recharging the battery after a service test

coincident with supplying the largest coincident demands of

the various continuous steady state loads (irrespective or

the status of the plant during which these demands occur).

(continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

DC SourcesOperating B 3.8.4 CLINTON B 3.8-57 Revision No. 13-2 BASES SURVEILLANCE SR 3.8.4.2 (continued)

REQUIREMENTS This level of loading may not normally be available following the battery service test and will need to be supplemented with additional loads. The duration for this

test may be longer than the charger sizing criteria since

the battery recharge is affected by float voltage, temperature, and the exponential decay in charging current.

The battery is recharged when the measured charging current

is < 2 amps. The Surveillance Frequency is acceptable, given the unit conditions required to perform the test and the other administrative controls existing to ensure adequate charger

performance during these 24 month intervals. In addition, this Frequency is intended to be consistent with expected fuel cycle lengths.

With regard to minimum required amperes and duration values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 13).

SR 3.8.4.3 A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The

discharge rate and test length are established with a dummy

load that corresponds to the design duty cycle requirements

as specified in Reference 4.

The Surveillance Frequency of 24 months is an exception to the recommendations of Regulatory Guide 1.32 (Ref. 10) and Regulatory Guide 1.129 (Ref. 11), which state that the battery service test should be performed during refueling

operations or at some other outage, with intervals between tests not to exceed 18 months.

This SR is modified by two Notes. Note 1 allows the performance of a modified performance discharge test SR 3.8.6.6 in lieu of SR 3.8.4.3. This substitution is acceptable because SR 3.8.6.6 represents an equivalent test

of battery capability as SR 3.8.4.3. The reason for Note 2

is that performing the Surveillance would remove a required

DC electrical power subsystem from service, perturb the

electrical distribution system, and challenge safety

systems. Credit may be taken for unplanned events that

satisfy the Surveillance. Examples of unplanned events may

include: (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

Battery Parameters B 3.8.6 CLINTON B 3.8-68 Revision No. 6-5 BASES ACTIONS (continued) E.1 Batteries in redundant trains with battery parameters not within limits, there is not sufficient assurance that battery capacity has not been affected to the degree that the batteries can still perform their required function, given that redundant batteries are involved. With redundant batteries involved, this potential could result in a total loss of function on multiple systems that rely upon the batteries. The longer completion times specified for battery parameters on non-redundant batteries not within limits are therefore not appropriate, and the parameters must be restored to within limits on at least one train within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

F.1 When any battery parameter is outside the allowances of the Required Actions for Condition A, B, C, D, or E, sufficient capacity to supply the maximum expected load requirement is not assured and the corresponding battery must be declared inoperable. Additionally, discovering a battery in one train with one or more battery cells float voltage less than 2.07 V and float current greater tan 2 amps, indicates that the battery capacity may not be sufficient to perform the intended functions. The battery must therefore be declared inoperable immediately.

SURVEILLANCE SR 3.8.6.1 REQUIREMENTS Verifying battery float current while on float charge is used to determine the state of charge of the battery. Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery and maintain the battery in a charged state. The float current requirements are based on the float current indicative of a charged battery. Use of float current to determine the state of charge of the battery is consistent with IEEE Standard 450-1995 (Ref. 3). The 7 day frequency is consistent with IEEE Standard 450-1995.

This SR is modified by a Note that states the float current requirement is not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1. When this float voltage is not maintained, the Required Actions of LCO 3.8.4, ACTION A, are being taken, which provide the necessary and appropriate verifications of the battery condition. Furthermore, the float current limit of 2 amps is established based on the nominal float voltage value and is not directly applicable when this voltage is not maintained. (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Battery Parameters B 3.8.6 CLINTON B 3.8-68a Revision No. 6-5 BASES

SURVEILLANCE SR 3.8.6.2 and 3.8.6.5 REQUIREMENTS (continued) Optimal long-term battery performance is obtained by maintaining a float voltage greater than or equal to the minimum established design limits provided by the battery manufacturer, which corresponds to 127.6 V at the battery terminals, or 2.20 Vpc. This provides adequate overpotential, which limits the formation of lead sulfate and self discharge, which could eventually render the battery inoperable. Float voltage, in this range or less, but greater than 2.07 Vpc, are addressed in Specification 5.5.14. SRs 3.8.6.2 and 3.8.6.5 require verification that the cell float voltages are equal to or greater than the short-term absolute minimum voltage of 2.07 V. The Frequency for cell voltage verification every 31 days for pilot cell and 92 days for each connected cell is consistent with IEEE Standard 450-1995 (Ref. 3).

SR 3.8.6.3

The limit specified for electrolyte level ensures that the plates suffer no physical damage and maintains adequate electron transfer capability. The Frequency is consistent with IEEE 450-1995 (Ref. 3).

SR 3.8.6.4 This surveillance verifies that the pilot cell temperature is greater than or equal to the minimum established design limit (i.e., 65 degrees F). Pilot cell electrolyte temperature is maintained above this temperature to assure the battery can provide the required current and voltage to meet the design requirements. Temperatures lower than assumed in battery sizing calculations act to inhibit or reduce battery capacity. The Frequency is consistent with IEEE 450-1995 (Ref. 3).

SR 3.8.6.6 A battery performance test is a test of constant current capacity of a battery, normally done in the as-found condition, after having been in service, to detect any change in the capacity determined by the acceptance test.

The test is intended to determine overall battery degradation due to age and usage.

The acceptance criteria for this Surveillance is consistent with IEEE Standard 450-1995 (Ref. 3) and IEEE Standard 485 (Ref. 5). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturer's rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even there is ample capacity to meet the load requirements. Furthermore, the battery is (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Battery Parameters B 3.8.6 CLINTON B 3.8-68b Revision No. 9-7 BASES

SURVEILLANCE SR 3.8.6.6 (continued)

REQUIREMENTS (continued) sized to meet the assumed duty cycle loads when the battery design capacity reaches this 80% limit.

The Surveillance Frequency for this test is normally 60 months. If the battery shows degradation, or if the battery has reached 85% of its expected life, the Surveillance

Frequency is reduced to 12 months. Degradation is indicated, according to IEEE Standard 450 (Ref. 3), when the

battery capacity drops by more than 10% relative to its

capacity on the previously performance test or when it is

> 10% below the manufacturer's rating. These Frequencies are based on the recommendations in IEEE Standard 450 (Ref.

3).

This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC

electrical power subsystem from service, perturb the

electrical distribution system, and challenge safety

systems. Credit may be taken for unplanned events that

satisfy the Surveillance. Examples of unplanned events may

include: 1) Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2) Post maintenance testing that requires performance of this Surveillance in order to restore the component to

OPERABLE, provided the maintenance was required, or

performed in conjunction with maintenance required to

maintain OPERABILITY or reliability.

REFERENCES 1. USAR, Chapter 6.

2. USAR, Chapter 15.

3. IEEE Standard 450, 1995.

4. Calculation IP-0-0123.

5. IEEE Standard 485, 1983

6. USAR, Chapter 8.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

InvertersOperating B 3.8.7 CLINTON B 3.8-73 Revision No. 13-2 BASES ACTIONS F.1 and F.2 (continued)

If the inoperable devices or components cannot be restored to OPERABLE status within the associated Completion Time, the plant must be brought to a MODE in which the LCO does

not apply. To achieve this status, the plant must be

brought to at least MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and to MODE 4

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 3.8.7.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers

closed and uninterruptible AC buses energized from the

inverter. The verification of proper voltage and frequency

output ensures that the required power is readily available

for the instrumentation connected to the uninterruptible AC

buses. The 7 day Frequency takes into account the redundant

capability of the inverters and other indications available

in the control room that alert the operator to inverter

malfunctions.

With regard to voltage and frequency values obtained pursuant to this SR, as read from plant indication

instrumentation, the specified limit is considered to be a

nominal value and therefore does not require compensation

for instrument indication uncertainties (Ref. 5).

REFERENCES 1. USAR, Chapter 8.

2. USAR, Chapter 6.

3. USAR, Chapter 15.

4. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

5. Calculation IP-0-0131.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

InvertersShutdown B 3.8.8 CLINTON B 3.8-77 Revision No. 4-6 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, and A.2.

(continued) completed as quickly as possible in order to minimize the time the plant safety systems may be without power or

powered from a constant voltage source transformer.

SURVEILLANCE SR 3.8.8.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and uninterruptible AC buses energized from the inverter. The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the uninterruptible AC

buses. The 7 day Frequency takes into account the redundant

capability of the inverters and other indications available

in the control room that alert the operator to inverter malfunctions.

With regard to voltage and frequency values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

______________________________________________________________________________

REFERENCES 1. USAR, Chapter 6.

2. USAR, Chapter 15.

3. Calculation IP-0-0131.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Distribution SystemsOperating B 3.8.9 CLINTON B 3.8-87 Revision No. 13-2 BASES (continued)

SURVEILLANCE SR 3.8.9.1 REQUIREMENTS Meeting this Surveillance verifies that the required AC, DC, and uninterruptible AC bus electrical power distribution systems are functioning properly, with the correct circuit

breaker alignment. The correct breaker alignment ensures the appropriate separation and independence of the

electrical divisions is maintained, and the appropriate

voltage is available to each required bus. The verification

of proper voltage availability on the buses ensures that the

required voltage is readily available for motive as well as control functions for critical system loads connected to

these buses. The 7 day Frequency takes into account the redundant capability of the AC, DC, and uninterruptible AC bus electrical power distribution subsystems, and other indications available in the control room that alert the

operator to subsystem malfunctions.

With regard to voltage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified

limit is considered to be a nominal value and therefore does

not require compensation for instrument indication

uncertainties (Ref. 6).

REFERENCES 1. USAR, Chapter 6.

2. USAR, Chapter 15.

3. Regulatory Guide 1.93, December 1974.

4. NEDC-32988-A, Revision 2, Technical Justification to Support Risk-Informed Modification to Selected Required End States for BWR Plants, December 2002.

5. USAR, Section 8.3.

6. Calculation IP-0-0132.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Distribution SystemsShutdown B 3.8.10 CLINTON B 3.8-92 Revision No. 4-6 BASES ACTIONS A.1, A.2.1, A.2.2, A.2.3, A.2.4, and A.2.5 (continued)

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The

restoration of the required distribution subsystems should

be completed as quickly as possible in order to minimize the

time the plant safety systems may be without power.

______________________________________________________________________________

SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the required AC, DC, and uninterruptible AC bus electrical power distribution

subsystems are functioning properly, with the buses

energized. The verification of proper voltage availability

on the required buses ensures that the required power is

readily available for motive as well as control functions

for critical system loads connected to these buses. The

7 day Frequency takes into account the redundant capability

of the electrical power distribution subsystems, as well as

other indications available in the control room that alert

the operator to subsystem malfunctions.

With regard to voltage values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 3).

REFERENCES 1. USAR, Chapter 6.

2. USAR, Chapter 15.

3. Calculation IP-0-0132.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SVC Protection Systems B 3.8.11 CLINTON B 3.8-96 Revision No. 3-5 BASES ACTIONS B.1 (continued) status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The Completion Time of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is reasonable, taking into account the low probability of an SVC failure occurring in this time period and the realistic potential for an SVC failure to adversely affect plant equipment.

C.1 If the required SVC protection subsystems cannot be restored to OPERABLE status within the required Completion Time, the SVC must be placed in a configuration for which the SVC Protection System LCO does not apply. This is accomplished by disconnecting the associated SVC from the plant auxiliary power system by opening (at least one of) the SVC main circuit breakers. The Completion Time of one hour allows for an orderly disconnection of the SVC, including evaluation of the resultant impact on required voltage for the onsite ESF busses (i.e., for compliance with LCO 3.8.1, "AC Sources-Operating," or LCO 3.8.2, "AC Sources-Shutdown").

SURVEILLANCE SR 3.8.11.1 REQUIREMENTS The SVC local control panel is checked to confirm satisfactory operation of the SVC Protection System(s).

This includes verifying that no warning or trouble lights that could be indicative of SVC Protection System degradation are present, and checking the overall condition and/or status of relays to qualitatively confirm satisfactory operation of the SVC and SVC Protection System.

The 24-hour Frequency is based on manufacturer's recommendations.

SR 3.8.11.2 A system functional test of each SVC Protection System is performed to ensure that each SVC protection subsystem will actuate to automatically open the associated SVC's main circuit breakers in response to signals associated with SVC failure modes that could potentially damage or degrade plant (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SVC Protection Systems B 3.8.11 CLINTON B 3.8-97 Revision No. 10-7 BASES SURVEILLANCE SR 3.8.11.2 (continued)

REQUIREMENTS equipment. System functional testing should thus include satisfactory operation of the associated relays and testing of the sensors for which failure modes would be undetected. As a minimum, SVC protection subsystem

actuation capability should be verified for response to

signals, actual or simulated, corresponding to the following

potential SVC failure modes or conditions: (1) Overvoltage (2) Undervoltage (3) Phase Unbalance (4) Harmonics (5) Overcurrent

The 24-month Frequency is based on the refueling cycle.

REFERENCES 1. 10CFR50, Appendix A, GDC 17.

2. USAR, Chapter 8.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Refueling Equipment Interlocks B 3.9.1 CLINTON B 3.9-4 Revision No. 7-4 BASES (continued)

SURVEILLANCE SR 3.9.1.1 REQUIREMENTS Performance of a CHANNEL FUNCTIONAL TEST demonstrates each required refueling equipment interlock will function

properly when a simulated or actual signal indicative of a

required condition is injected into the logic. The test also

verifies the relative accuracy of the instrumentation. A

successful test of the required contact(s) of a channel

relay may be performed by the verification of the change of

state of a single contact of the relay. This clarifies what

is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This

is acceptable because all of the other required contacts of

the relay are verified by other Technical Specifications and

non-Technical Specifications tests at least once per

refueling interval with applicable extensions. The CHANNEL

FUNCTIONAL TEST may be performed by any series of

sequential, overlapping, or total channel steps so that the

entire channel is tested.

The 7 day Frequency is based on engineering judgment and is considered adequate in view of other indications of

refueling interlocks and their associated input status that are available to unit operations personnel.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 2

6.

2. USAR, Section 7.

6.1.1. 3. USAR, Section 15.4.1.1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Refuel Position One-Rod-Out Interlock B 3.9.2 CLINTON B 3.9-7 Revision No. 5-5 BASES

ACTIONS A.1 and A.2 (continued)

fuel assemblies. Action must continue until all such control rods are fully inserted. Control rods in core cells

containing no fuel assemblies do not affect the reactivity

of the core and, therefore, do not have to be inserted.

SURVEILLANCE SR 3.9.2.1 REQUIREMENTS Proper functioning of the refuel position one-rod-out interlock requires the reactor mode switch to be in refuel.

During control rod withdrawal in MODE 5, improper

positioning of the reactor mode switch could, in some

instances, allow improper bypassing of required interlocks.

Therefore, this Surveillance imposes an additional level of assurance that the refuel position one-rod-out interlock

will be OPERABLE when required. By "locking" the reactor

mode switch in the proper position (i.e., removing the reactor mode switch key from the console while the reactor mode switch is positioned in refuel), an additional administrative control is in place to preclude operator

errors from resulting in unanalyzed operation.

The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient in view of other administrative controls utilized during refueling operations

to ensure safe operation.

SR 3.9.2.2

Performance of a CHANNEL FUNCTIONAL TEST on each channel demonstrates the associated refuel position one-rod-out

interlock will function properly when a simulated or actual

signal indicative of a required condition is injected into the logic. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The CHANNEL FUNCTIONAL TEST may be performed by any series of sequential, overlapping, or total channel steps so that the entire channel is tested. The 7 day

Frequency is considered adequate because of demonstrated

circuit reliability, procedural controls on control rod

withdrawals, and indications available in the control room

to alert the operator of control rods not fully inserted.

To perform the required testing, the applicable condition

must be entered (i.e., a control rod must be withdrawn from

its full-in position). Therefore, this SR has been modified (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Rod Position B 3.9.3 CLINTON B 3.9-11 Revision No. 0 BASES

SURVEILLANCE SR 3.9.3.1 (continued)

REQUIREMENTS The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency takes into consideration the procedural controls on control rod movement during refueling

as well as the redundant functions of the refueling

interlocks.

REFERENCES 1. 10 CFR 50, Appendix A, GDC 2

6. 2. USAR Section 15.4.1.1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Control Rod OPERABILITYRefueling B 3.9.5 CLINTON B 3.9-1 8 Revision No. 4-6 BASES

SURVEILLANCE SR 3.9.5.1 and SR 3.9.5.2 (continued)

REQUIREMENTS The 7 day Frequency takes into consideration equipment reliability, procedural controls over the scram accumulators, and control room alarms and indicating lights

that indicate low accumulator charge pressures.

SR 3.9.5.1 is modified by a Note that allows 7 days after withdrawal of the control rod to perform the Surveillance.

This acknowledges that the control rod must first be

withdrawn before performance of the Surveillance and

therefore avoids potential conflicts with SR 3.0.3 and

SR 3.0.4.

With regard to CRD scram accumulator pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument uncertainties.

This requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in the associated plant procedures (Ref. 3).

REFERENCES 1. 10 CFR 50, Appendix A, GDC 2

6.

2. USAR, Section 15.4.1.1.

3. Calculation IP-0-0133.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RPV Water LevelIrradiated Fuel B 3.9.6 CLINTON B 3.9-21 Revision No. 4-6 BASES

SURVEILLANCE SR 3.9.

6.1 (continued)

REQUIREMENTS The Frequency of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is based on engineering judgment and is considered adequate in view of the large volume of water and the normal procedural controls on valve positions, which make significant unplanned level changes unlikely.

With regard to RPV water level values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 5).

REFERENCES 1. Regulatory Guide 1.25, March 1972.

2. USAR, Section 15.7.4.

3. NUREG-0 8 00, Section 15.7.4.

4. 10 CFR 100.11.

5. Calculation IP-0-0134.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RPV Water LevelNew Fuel or Control Rods B 3.9.7 CLINTON B 3.9-24 Revision No. 4-6 BASES

ACTIONS A.1 (continued) to ensure that a fuel handling accident cannot occur. The suspension of fuel movement and control rod handling shall not preclude completion of movement of a component to a safe

position.

SURVEILLANCE SR 3.9.7.1 REQUIREMENTS Verification of a minimum water level of 23 ft above the top of the irradiated fuel assemblies seated within the RPV ensures that the design basis for the postulated fuel

handling accident analysis during refueling operations is

met. Water at the required level limits the consequences of damaged fuel rods, which are postulated to result from a

fuel handling accident in containment (Ref. 2).

The Frequency of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is based on engineering judgment and is considered adequate in view of the large volume of

water and the normal procedural controls on valve positions, which make significant unplanned level changes unlikely.

With regard to RPV water level values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Ref. 5).

REFERENCES 1. Regulatory Guide 1.25, March 1972.

2. USAR, Section 15.7.4.

3. NUREG-0 8 00, Section 15.7.4.

4. 10 CFR 100.11.

5. Calculation IP-0-0134.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RHRHigh Water Level B 3.9.8 CLINTON B 3.9-2 8 Revision No. 1-1 BASES

ACTIONS B.1, B.2, B.3, B.4, and B.5 (continued) would not be expected to result in the immediate release of appreciable fission products to the containment atmosphere.

Actions must continue until all requirements of this

Condition are satisfied.

C.1 and C.2

If no RHR shutdown cooling subsystem is in operation, an alternate method of coolant circulation is required to be established within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The Completion Time is modified

such that 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is applicable separately for each

occurrence involving a loss of coolant circulation.

During the period when the reactor coolant is being circulated by an alternate method (other than by the

required RHR shutdown cooling subsystem), the reactor

coolant temperature must be periodically monitored to ensure

proper functioning of the alternate method. The once per

hour Completion Time is deemed appropriate.

SURVEILLANCE SR 3.9.

8.1 REQUIREMENTS This Surveillance demonstrates that the RHR shutdown cooling subsystem is in operation and circulating reactor coolant.

The required flow rate is determined by the flow rate

necessary to provide sufficient decay heat removal

capability. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient in view

of other visual and audible indications available to the

operator for monitoring the RHR subsystem in the control room.

REFERENCES 1. USAR, Section 5.4.7.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

RHRLow Water Level B 3.9.9 CLINTON B 3.9-32 Revision No. 0 BASES

ACTIONS B.1, B.2, B.3, and B.4 (continued) required component is inoperable, then it must be restored to OPERABLE status. In this case, the Surveillances may need to be performed to restore the component to OPERABLE

status. In addition, at least one door in the upper containment personnel air lock must be closed. The closed air lock door completes the boundary for control of

potential radioactive releases. With the appropriate

administrative controls however, the closed door can be

opened intermittently for entry and exit. This allowance is

acceptable due to the need for containment access and due to the slow progression of events which may result from inadequate decay heat removal. Loss of decay heat removal would not be expected to result in the immediate release of appreciable fission products to the containment atmosphere. Actions must continue until all

requirements of this Condition are satisfied.

C.1 and C.2

If no RHR shutdown cooling subsystem is in operation, an alternate method of coolant circulation is required to be established within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The Completion Time is modified such that the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months is applicable separately for each occurrence involving a loss of coolant circulation.

During the period when the reactor coolant is being circulated by an alternate method (other than by the

required RHR Shutdown Cooling System), the reactor coolant

temperature must be periodically monitored to ensure proper

function of the alternate method. The once per hour

Completion Time is deemed appropriate.

SURVEILLANCE SR 3.9.9.1 REQUIREMENTS This Surveillance demonstrates that one RHR shutdown cooling subsystem is in operation and circulating reactor coolant.

The required flow rate is determined by the flow rate necessary to provide sufficient decay heat removal

capability. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient in view

of other visual and audible indications available to the

operator for monitoring the RHR subsystem in the control

room. (continued) TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Reactor Mode Switch Interlock Testing B 3.10.2 CLINTON B 3.10-9 Revision No. 1-1 BASES (continued)

ACTIONS A.1, A.2, A.3.1, and A.3.2

These Required Actions are provided to restore compliance with the Technical Specifications overridden by this Special

Operations LCO. Restoring compliance will also result in

exiting the Applicability of this Special Operations LCO.

All CORE ALTERATIONS except control rod insertion, if in progress, are immediately suspended in accordance with

Required Action A.1, and all insertable control rods in core

cells that contain one or more fuel assemblies are fully inserted within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , in accordance with Required Action A.2. This will preclude potential mechanisms that

could lead to criticality. Suspension of CORE ALTERATIONS

shall not preclude the completion of movement of a component

to a safe condition. Placing the reactor mode switch in the shutdown position will ensure that all inserted control rods

remain inserted and result in operation in accordance with

Table 1.1-1. Alternatively, if in MODE 5, the reactor mode switch may be placed in the refuel position, which will also result in operating in accordance with Table 1.1-1. A Note

is added to Required Action A.3.2 to indicate that this

Required Action is not applicable in MODES 3 and 4, since

only the shutdown position is allowed in these MODES. The allowed Completion Time of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for Required Actions A.2, A.3.1, and A.3.2 provides sufficient time to normally insert the control rods and place the reactor mode switch in the required position, based on operating experience, and is acceptable given that all operations that could increase

core reactivity have been suspended.

SURVEILLANCE SR 3.10.2.1 and SR 3.10.2.2 REQUIREMENTS Meeting the requirements of this Special Operations LCO maintains operation consistent with or conservative to operating with the reactor mode switch in the shutdown position (or the refuel position for MODE 5). The functions

of the reactor mode switch interlocks that are not in

effect, due to the testing in progress, are adequately compensated for by the Special Operations LCO requirements.

The administrative controls are to be periodically verified (by a second licensed operator or other technically qualified member of the unit technical staff) to ensure that the operational requirements continue to be met. The

Surveillances performed at the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Reactor Mode Switch Interlock Testing B 3.10.2 CLINTON B 3.10-10 Revision No. 0 BASES SURVEILLANCE SR 3.10.2.1 and SR 3.10.2.2 (continued)

REQUIREMENTS Frequencies are intended to provide appropriate assurance that each operating shift is aware of and verify compliance

with these Special Operations LCO requirements.

REFERENCES 1. USAR, Section 7.6.1.1.

2. USAR, Section 15.4.1.1.

Single Control Rod WithdrawalHot Shutdown B 3.10.3 CLINTON B 3.10-14 Revision No. 0 BASES ACTIONS A.1 (continued)

of any other LCO's Required Action to insert all control rods. This Required Action includes exiting this Special

Operations Applicability LCO by returning the reactor mode

switch to the shutdown position. A second Note has been added, which clarifies that this Required Action is only applicable if the requirements not met are for an affected

LCO.

A.2.1 and A.2.2

Required Actions A.2.1 and A.2.2 are alternative Required Actions that can be taken instead of Required Action A.1 to

restore compliance with the normal MODE 3 requirements, thereby exiting this Special Operations LCO's Applicability.

Actions must be initiated immediately to insert all

insertable control rods. Actions must continue until all

such control rods are fully inserted. Placing the reactor

mode switch in the shutdown position will ensure that all

inserted rods remain inserted and restore operation in

accordance with Table 1.1-1. The allowed Completion Time of

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the reactor mode switch in the shutdown

position provides sufficient time to normally insert the

control rods.

SURVEILLANCE SR 3.10.3.1, SR 3.10.3.2, and SR 3.10.3.3 REQUIREMENTS The other LCOs made applicable in this Special Operations LCO are required to have their Surveillances met to

establish that this Special Operations LCO is being met. If

the local array of control rods is inserted and disarmed

while the scram function for the withdrawn rod is not

available, periodic verification in accordance with

SR 3.10.3.2 is required to preclude the possibility of

criticality. SR 3.10.3.2 has been modified by a Note, which

clarifies that this SR is not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements, since SR 3.10.3.2 demonstrates that the alternative

LCO 3.10.3.d.2 requirements are satisfied. Also, SR 3.10.3.3 verifies that all control rods other than the

control rod being withdrawn are fully inserted. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

Frequency is acceptable because of the administrative (continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Single Control Rod WithdrawalHot Shutdown B 3.10.3 CLINTON B 3.10-15 Revision No. 0 BASES SURVEILLANCE SR 3.10.3.1, SR 3.10.3.2, and SR 3.10.3.3 (continued)

REQUIREMENTS controls on control rod withdrawals, the protection afforded by the LCOs involved, and hardware interlocks that preclude

additional control rod withdrawals.

REFERENCES 1. USAR, Section 15.4.1.1.

Single Control Rod WithdrawalCold Shutdown B 3.10.4 CLINTON B 3.10-20 Revision No. 1-1 BASES (continued)

SURVEILLANCE SR 3.10.4.1, SR 3.10.4.2, SR 3.10.4.3, and SR 3.10.4.4 REQUIREMENTS The other LCOs made applicable by this Special Operations LCO are required to have their associated Surveillances met

to establish that this Special Operations LCO is being met.

If the local array of control rods is inserted and disarmed while the scram function for the withdrawn rod is not available, periodic verification is required to ensure that

the possibility of criticality remains precluded. The control rods can be hydraulically disarmed by closing the drive water and exhaust water isolation valves.

Electrically, the control rods can be disarmed by disconnecting power from all four directional control valve solenoids. Verification that all the other control rods are fully inserted is required to meet the SDM requirements.

Verification that a control rod withdrawal block has been

inserted ensures that no other control rods can be

inadvertently withdrawn under conditions when position indication instrumentation is inoperable for the affected

control rod. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is acceptable because of

the administrative controls on control rod withdrawals, the

protection afforded by the LCOs involved, and hardware

interlocks to preclude an additional control rod withdrawal.

SR 3.10.4.2 and SR 3.10.4.4 have been modified by Notes, which clarify that these SRs are not required to be met if

the alternative requirements demonstrated by SR 3.10.4.1 are

satisfied.

REFERENCES 1. USAR, Section 15.4.1.1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Single CRD RemovalRefueling B 3.10.5 CLINTON B 3.10-25 Revision No. 1-1 BASES SURVEILLANCE SR 3.10.5.1, SR 3.10.5.2, SR 3.10.5.3, SR 3.10.5.4, and REQUIREMENTS SR 3.10.5.5 (continued)

Periodic verification of the administrative controls established by this Special Operations LCO is prudent to

preclude the possibility of an inadvertent criticality. The

24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is acceptable, given the administrative

controls on control rod removal and hardware interlocks to

block an additional control rod withdrawal.

REFERENCES 1. USAR, Section 15.4.1.1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Multiple Control Rod WithdrawalRefueling B 3.10.6 CLINTON B 3.10-28 Revision No. 0 BASES (continued)

APPLICABILITY Operation in MODE 5 is controlled by existing LCOs. The exceptions from other LCO requirements (e.g., the ACTIONS of LCO 3.9.3, LCO 3.9.4 or LCO 3.9.5) allowed by this Special Operations LCO are appropriately controlled by requiring all

fuel to be removed from cells whose "full in" indicators are

allowed to be bypassed.

ACTIONS A.1, A.2, A.3.1, and A.3.2

If one or more of the requirements of this Special Operations LCO are not met, the immediate implementation of

these Required Actions commences activities which will

restore operation consistent with the normal requirements

for refueling (i.e., all control rods inserted in core cells

containing one or more fuel assemblies) or with the

exceptions granted by this Special Operations LCO. The

Completion Times are intended to require that these Required

Actions be implemented in a very short time and carried

through in an expeditious manner.

SURVEILLANCE SR 3.10.6.1, SR 3.10.6.2, and SR 3.10.6.3 REQUIREMENTS Periodic verification of the administrative controls established by this Special Operations LCO is prudent to

preclude the possibility of an inadvertent criticality. The

24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is acceptable, given the administrative

controls on fuel assembly and control rod removal, and takes

into account other indications of control rod status

available in the control room.

REFERENCES 1. USAR, Section 15.4.1.1.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Fre q uenc yControlPro g ram.

SDM TestRefueling B 3.10.8 CLINTON B 3.10-37 Revision No. 0 BASES (continued)

SURVEILLANCE SR 3.10.8.1 SR 3.10.8.2 and SR 3.10.8.3 REQUIREMENTS The other LCOs made applicable in this Special Operations LCO are required to have applicable Surveillances met to establish that this Special Operations LCO is being met.

However, the control rod withdrawal sequences during the SDM tests may be enforced by the RPC (LCO 3.3.2.1, Function 1b, MODE 2 requirements) or by a second licensed operator or

other qualified member of the technical staff. As noted, either the applicable SRs for the RPC (LCO 3.3.2.1) must be satisfied according to the applicable Frequencies (SR 3.10.8.2) or the proper movement of control rods must be verified (SR 3.10.8.3). This latter verification (i.e.,

SR 3.10.8.3) must be performed during control rod movement to prevent deviations from the specified sequence. These surveillances provide adequate assurance that the specified test sequence is being followed.

SR 3.10.8.4

Periodic verification of the administrative controls established by this LCO will ensure that the reactor is operated within the bounds of the safety analysis. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is intended to provide appropriate assurance that each operating shift is aware of and verifies

compliance with these Special Operations LCO requirements.

SR 3.10.8.5

Coupling verification is performed to ensure the control rod is connected to the control rod drive mechanism and will perform its intended function when necessary. The verification is required to be performed any time a control rod is withdrawn to the "full out" notch position or prior to declaring the control rod OPERABLE after work on the control rod or CRD System that could affect coupling. This Frequency is acceptable, considering the low probability that a control rod will become uncoupled when it is not being moved as well as operating experience related to

uncoupling events.

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

SDM TestRefueling B 3.10.8 CLINTON B 3.10-38 Revision No. 4-6 BASES SURVEILLANCE SR 3.10.8.6 REQUIREMENTS (continued) CRD charging water header pressure verification is performed to ensure the motive force is available to scram the control rods in the event of a scram signal. A minimum accumulator

pressure is specified, below which the capability of the accumulator to perform its intended function becomes degraded and the accumulator is considered inoperable. The minimum accumulator pressure of 1520 psig is well below the expected pressure of 1750 psig. The 7 day Frequency has

been shown to be acceptable through operating experience and takes into account indications available in the control room.

With regard to CRD charging water header pressure values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is not considered to be a nominal value with respect to instrument uncertainties. This requires additional margin to be added to the limit to compensate for instrument uncertainties, for implementation in the associated plant procedures (Ref.

3).

REFERENCES 1. NEDE-24011-P-A, "General Electric Standard Application for Reactor Fuel, GESTAR II" (latest approved

revision).

2. USAR, Section 15.4.9.

3. Calculation IP-0-0136.

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Training Startups B 3.10.9 CLINTON B 3.10-41 Revision No. 4-6 BASES (continued)

SURVEILLANCE SR 3.10.9.1 and SR 3.10.9.2 REQUIREMENTS Periodic verification that the THERMAL POWER and reactor coolant temperature limits of this Special Operations LCO are satisfied will ensure that the stored energy in the

reactor core and reactor coolant are sufficiently low to preclude the need for all RHR subsystems to be aligned in the LPCI mode of operation. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Frequency provides frequent checks of these LCO requirements during the

training startup.

With regard to THERMAL POWER and reactor coolant temperature values obtained pursuant to this SR, as read from plant indication instrumentation, the specified limit is considered to be a nominal value and therefore does not require compensation for instrument indication uncertainties (Refs. 2, 3).

REFERENCES 1. USAR, Section 6.3.3.

2. Calculation IP-0-0137.

3. Calculation IP-0-0138.

TheSurveillanceFrequencyiscontrolledundertheSurveillance

Frequenc yControlPro g ram.

Single Control Rod Withdrawal - Refueling B 3.10.10 CLINTON B 3.10-45 Revision No. 2-12 BASES (continued)

ACTIONS A Note has been provided to modify the ACTIONS related to a single control rod withdrawal while in MODE 5. Section 1.3, Completion Times, specifies once a Condition has been entered, subsequent divisions, subsystems, components, or variables expressed in the Condition discovered to be inoperable or not within limits, will not result in separate entry into the Condition. Section 1.3 also specifies that Required Actions of the Condition continue to apply for each additional failure, with Completion Times based on initial entry into the Condition. However, the Required Actions for each requirement of the LCO not met provide appropriate compensatory measures for separate requirements that are not met. As such, a Note has been provided that allows separate Condition entry for each requirement of the LCO.

A.1 and A.2 If one or more of the requirements specified in this Special Operations LCO are not met, all CORE ALTERATIONS except control rod insertion, if in progress, must be immediately suspended in accordance with Required Action A.1, and actions must be initiated immediately to fully insert all control rods in accordance with Required Action A.2. This will preclude potential mechanisms that could lead to criticality. Suspension of CORE ALTERATIONS shall not preclude the completion of movement of a component to a safe condition and actions to fully insert all insertable control rods must continue until all control rods are fully inserted.

SURVEILLANCE SR 3.10.10.1 and SR 3.10.10.2 REQUIREMENTS Verification that all the control rods, other than the control rod withdrawn for testing, are fully inserted is required to ensure the SDM is within limits. Verification that no other CORE ALTERATIONS are being made is required to ensure the assumptions of the safety analyses are satisfied.

Periodic verification of the administrative controls established by this Special Operations LCO is prudent to preclude the possibility of an inadvertent criticality. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency is acceptable, given the administrative

__

(continued)

TheSurveillanceFrequencyiscontrolledundertheSurveillance FrequencyControlProgram.

Single Control Rod Withdrawal - Refueling B 3.10.10 CLINTON B 3.10-46 Revision No. 2-12 BASES SURVEILLANCE controls on control rod withdrawals, the protection afforded REQUIREMENTS by the LCOs involved, and hardware interlocks that preclude (continued) additional control rod withdrawals.

REFERENCES 1. USAR, Section 15.4.1.1.

v t e Letter Sequence Response to RAI
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RS-10-093, Response to Request for Additional Information Regarding License Amendment Request to Adopt TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B

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RS-10-093, Response to Request for Additional Information Regarding License Amendment Request to Adopt TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B

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