ML13024A406
| ML13024A406 | |
| Person / Time | |
|---|---|
| Site: | McGuire, Mcguire  |
| Issue date: | 01/02/2013 |
| From: | Capps S D Duke Energy Carolinas |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| TAC ME8213, TAC ME8214 | |
| Download: ML13024A406 (17) | |
Text
Duke STEVEN D. CAPPSVice PresidentAr"Energy. McGuire Nuclear StationDuke EnergyMG01 VP / 12700 Hagers Ferry Rd.Huntersville, NC 28078980-875-4805980-875-4809 faxSteven. Capps@duke-energy. cornJanuary 2, 2013 10 CFR 50.90U. S. Nuclear Regulatory CommissionWashington, D.C. 20555ATTENTION: Document Control DeskSubject: Duke Energy Carolinas, LLC (Duke Energy)McGuire Nuclear Station, Units 1 and 2Docket Nos. 50-369 and 50-370Revision to a Response to a Request for Additional InformationRegarding License Amendment Request Related to MeasurementUncertainty Recapture Power Uprate (TAC Nos. ME8213 and ME8214)This letter provides revised responses to questions 50 and 53 in a September 7, 2012 NuclearRegulatory Commission (NRC) request for additional information (RAI) related to aMarch 5, 2012 McGuire Nuclear Station (MNS) Units 1 and 2 License Amendment Request(LAR) submitted pursuant to 10 CFR 50.90 in support of a measurement uncertainty recapture(MUR) power uprate.The original responses to MUR LAR RAI questions 50 and 53 were provided viacorrespondence dated November 1, 2012. A revision to responses provided in that submittal isnecessary to accommodate LAR implementation timeframes different from those described inthe original responses. The revised responses are provided in Enclosure 1. Enclosure 2provides a proposed Unit 1 License Condition reflecting the revised responses. Enclosure 3documents a regulatory commitment described in this submittal. Enclosure 4 provides revisedMNS MUR LAR pages reflecting changes described in this submittal. Enclosures 1 through 4supersede the corresponding Enclosures provided in the November 1, 2012 submittal.The conclusions reached in the original determination that this LAR contains No SignificantHazards Considerations and the basis for the categorical exclusion from performing anEnvironmental/Impact Statement have not changed as a result of the revised RAI responsesand other information provided in this submittal.www.duke-energy.comr "liJanuary 2, 2013Nuclear Regulatory CommissionPage 2Please contact Richard E. Abbott at 980-875-4685 if additional questions arise regarding thisLAR.Sincerely,Enclosurescc: w/enclosuresV. M. McCreeRegional Administrator, Region IIU.S. Nuclear Regulatory CommissionMarquis One Tower245 Peachtree Center Ave., NE, Suite 1200Atlanta, GA 30303-1257J. H. Thompson (addressee only)Project Manager (MNS)U.S. Nuclear Regulatory Commission11555 Rockville PikeMail Stop 0-8 G9ARockville, MD, 20852-2738J. ZeilerNRC Senior Resident InspectorMcGuire Nuclear StationW. L. Cox ill, Section ChiefNorth Carolina Department of Environment and Natural ResourcesDivision of Environmental HealthRadiation Protection Section1645 Mail Service CenterRaleigh, NC 27699-1645 January 2, 2013Nuclear Regulatory CommissionPage 3OATH AND AFFIRMATIONSteven D. Capps affirms that he is the person who subscribed his name to the foregoingstatement, and that all the matters and facts set forth herein are true and correct to the best ofhis knowledge.Steven D. Capps, Vice-Pa, McGuire Nuclear Stationý5!n-Subscribed and sworn to me:'J2 ( '- 1Datei P ubri cICres: &5/My commission expir
Enclosure
IMcGuire Nuclear Station'sRevised Responses to MUR LAR RAI Questions 50 and 53 In TheSeptember 7, 2012 NRC Request for Additional InformationBy letter dated March 5, 2012 (Agencywide Documents Access and Management System(ADAMS), Accession No. ML12082A210), as supplemented, Duke Energy Carolinas, LLC(Duke Energy, the licensee), submitted a license amendment request (LAR) to change theMcGuire Nuclear Station, Units 1 and 2 (McGuire 1 and 2), Technical Specifications (TSs). Theproposed change revises the TSs to implement a measurement uncertainty recapture (MUR)power uprate for McGuire 1 and 2.As part of an email dated September 7, 2012, the NRC issued MUR LAR RAI questions 50 and53. The original responses -to these questions, provided as part of correspondence datedNovember 1, 2012, were based upon the MUR implementation schedule at that time. However,an assessment of activities necessary to implement MUR upon approval of the MUR LAR hasidentified items which could impact the current Unit 1 and Unit 2 MUR implementationschedules. Consequently, a revision to responses provided in the November 1, 2012 submittalis necessary. The below revised responses replace the original responses to RAI questions 50and 53 provided in Enclosure 1 of the November 1, 2012 submittal.NRC Question 50In the letter by Duke Energy dated July 16, 2012, in response to the NRC staff RAI question 40,the licensee stated that the degraded voltage relay settings at the safety-related buses will notbe changed under post-MUR uprate conditions. Therefore, any changes in switchyard voltagesafter MUR implementation will be dependent on plant loading. Any change in these post-MURswitchyard voltages will be discussed and communicated with the TSO [Transmission SystemOperator] prior to implementation of the MUR.Provide assurance, including the use of a regulatory commitment as appropriate, that anychanges in the switchyard voltages required (so as not to impact the degraded voltage relaysettings), corresponding to the post-MUR uprate and HP Turbine replacement conditions, will beevaluated prior to the implementation of MUR uprate.Page 1 of 7 Revised McGuire ResDonse to NRC Question 50The McGuire Nuclear Station (MNS) Unit 1 High Pressure (HP) Turbine Replacement isscheduled to be implemented during the Spring 2013 1EOC22 Refueling Outage (RFO),currently scheduled to start on approximately March 16, 2013 and end on approximatelyApril 20, 2013. Due to vendor delays, the Unit 1 Generator Stator/Exciter Replacement hasbeen rescheduled to occur during the Fall 2014 1EOC23 RFO, currently scheduled to start onapproximately September 20, 2014 and end on approximately October 24, 2014. Installation ofthe Unit 1 CheckPlus Leading Edge Flow Meter (LEFM) system is scheduled to occur during the1 EOC22 RFO. Post-installation acceptance testing of the Unit 1 CheckPlus LEFM system isscheduled to be completed online (after startup from the 1 EOC22 RFO) during Unit 1 FuelCycle 23, currently scheduled to start on approximately April 20, 2013 and end onapproximately September 20, 2014. Unit 1 MUR implementation, which is not dependent onimplementation of the HP Turbine and Generator Stator/Exciter Replacements, is currentlyscheduled to occur online during Unit 1 Fuel Cycle 23, after successful post-installationacceptance testing of the Unit 1 CheckPlus LEFM system.Despite the rescheduled Unit 1 Generator Stator/Exciter Replacement, after implementation ofthe Unit 1 MUR uprate and Unit 1 HP Turbine Replacement, it is anticipated that Unit 1 will havethe capability to realize the maximum expected post-MUR uprate megawatts thermal (MWt)power level and, from a reliability perspective, the existing Unit 1 Generator Stator/Exciter willallow Unit 1 to generate the maximum expected post-MUR uprate megawatts electrical (MWe).MNS switchyard voltages required (so as not to impact the degraded voltage relay settings),corresponding to Unit 1 post-MUR uprate conditions, will be evaluated prior to implementation ofMUR on Unit 1. However, if at the time of this evaluation, Unit 1 is not capable of realizing theexpected maximum post-MUR Uprate MWt power level and/or Unit 1 is not capable ofgenerating the expected maximum post-MUR uprate MWe, then an additional evaluation will beperformed when Unit 1 has these capabilities. If this additional evaluation is necessary, anychanges in the MNS switchyard voltages required (so as not to impact the degraded voltagerelay settings), corresponding to conditions associated with the additional Unit 1 MWt capabilityand/or the additional Unit 1 MWe capability, will be evaluated prior to raising Unit 1 reactor corefull steady state power to the expected maximum post-MUR uprate MWt power level and/orprior to Unit 1 generating the expected maximum post-MUR uprate MWe. Consistent with theabove, as documented in Enclosure 2, MNS would accept a Unit 1 License Conditionaddressing the below. Enclosure 2 replaces the corresponding Enclosure 2 in theNovember 1, 2012 submittal providing the original responses to MUR LAR RAI questions 50and 53:MNS switchyard voltages required (so as not to impact the degraded voltage relaysettings), corresponding to Unit 1 post-MUR uprate conditions, will be evaluated prior toimplementation of MUR on Unit 1. However, if at the time of this evaluation, Unit 1 is notcapable of realizing the expected maximum post-MUR uprate MWt power level and/orUnit 1 is not capable of generating the expected maximum post-MUR uprate MWe, thenan additional evaluation will be performed when Unit 1 has these capabilities. If thisPage 2 of 7 additional evaluation is necessary, any changes in the MNS switchyard voltagesrequired (so as not to impact the degraded voltage relay settings), corresponding toconditions associated with the additional Unit 1 MWt capability and/or the additionalUnit 1 MWe capability, will be evaluated prior to raising Unit 1 reactor core full steadystate power to the expected maximum post-MUR uprate MWt power level and/or prior toUnit 1 generating the expected maximum post-MUR uprate MWe.MNS Unit 2 HP Turbine Replacement, MNS Unit 2 Generator Stator/Exciter Replacement, andinstallation of the Unit 2 CheckPlus LEFM system occurred during the Unit 2 2EOC21 RFO,which ended on November 30, 2012. Post-installation acceptance testing of the Unit 2CheckPlus LEFM system was completed online during Unit 2 Fuel Cycle 22. Unit 2Fuel Cycle 22 started on November 30, 2012 and is scheduled to end on approximatelyMarch 8, 2014. MUR implementation is currently scheduled to be implemented on Unit 2 onlineduring Unit 2 Fuel Cycle 22. After MUR implementation, Unit 2 will have the capability to realizethe expected maximum post-MUR uprate MWt power level and the expected maximum post-MUR uprate MWe. Any changes in the MNS switchyard voltages required (so as not to impactthe degraded voltage relay settings), corresponding to the Unit 2 post-MUR uprate conditionswill be evaluated prior to implementation of the MUR uprate on Unit 2.Consistent with the above, this RAI response provides the following MNS switchyard voltagerelated regulatory commitment. This commitment is documented in Enclosure 3 which replacesthe corresponding Enclosure 3 in the November 1, 2012 submittal providing the originalresponses to MUR LAR RAI questions 50 and 53:Any changes in the MNS switchyard voltages required (so as not to impact the degradedvoltage relay settings), corresponding to the Unit 2 post-MUR uprate conditions will beevaluated prior to implementation of the MUR uprate on Unit 2.Note, as part of the July 16, 2012 response to NRC staff RAI question 40, MNS providedminimum 230 KV and 500 KV switchyard voltages agreed upon between MNS and the TSO forN-1 (generator trip) conditions for the pre-MUR uprate and post-MUR uprate operatingconditions. The implementation plan described above did not result in any changes to theminimum switchyard voltages provided in the response.Page 3 of 7 NRC Question 53In the letter by Duke Energy dated March 5, 2012, it states that:Duke Energy requests approval of this amendment request by October 5, 2012 to supportimplementation during the Unit 2 Fall 2012 refueling outage. Implementation of theapproved amendment on Unit 1 is scheduled to occur during the Spring 2013 refuelingoutage.The NRC staff typically requires that license amendments are implemented within 30 days ofissuance of the amendment. Please provide additional clarification and justification for yourproposed time frame for implementation of the license amendment.McGuire Response to NRC Question 53The MNS Unit 1 HP Turbine Replacement is scheduled to be implemented during the Spring2013 1EOC22 RFO, currently scheduled to start on approximately March 16, 2013 and end onapproximately April 20, 2013. Due to vendor delays, the Unit 1 Generator Stator/ExciterReplacement has been rescheduled to occur during the Fall 2014 1EOC23 RFO, currentlyscheduled to start on approximately September 20, 2014 and end on approximately October 24,2014. Installation of the Unit 1 CheckPlus LEFM system is scheduled to occur during the1 EOC22 RFO. Post-installation acceptance testing of the Unit 1 CheckPlus LEFM system isscheduled to be completed online (after startup from the 1 EOC22 RFO) during Unit 1 FuelCycle 23, currently scheduled to start on approximately April 20, 2013 and end onapproximately September 20, 2014. Unit I MUR implementation, which is not dependent onimplementation of the HP Turbine and Generator Stator/Exciter Replacements, is scheduled tooccur online during Unit 1 Fuel Cycle 23, after successful post-installation acceptance testing ofthe Unit 1 CheckPlus LEFM system.An assessment of MNS activities necessary to implement MUR upon approval of the MUR LARhas identified items which could impact the above Unit 1 MUR implementation schedule. Anevaluation is in progress to determine the final impact on the Unit 1 MUR implementationschedule. If the above schedule is impacted, the worse case Unit 1 MUR implementationschedule changes could result in Unit 1 MUR implementation occurring after the end of the1 EOC23 RFO. In order to accommodate the current Unit 1 MUR implementation schedule andthe potential worse case Unit 1 MUR implementation schedule changes, as part of NRCapproval of the MNS MUR LAR, MNS requests the NRC specify the Unit 1 MUR amendmentshall be implemented in the time period between the start of Unit 1 Fuel Cycle 23 and 30 daysafter the end of the 1 EOC23 RFO.Page 4 of 7 MNS Unit 2 HP Turbine Replacement, MNS Unit 2 Generator Stator/Exciter Replacement, andinstallation of the Unit 2 CheckPlus LEFM system occurred during the Unit 2 2EOC21 RFO,which ended on November 30, 2012. Post-installation acceptance testing of the Unit 2CheckPlus LEFM system was completed online during Unit 2 Fuel Cycle 22. Unit 2Fuel Cycle 22 started on November 30, 2012 and is scheduled to end on approximatelyMarch 8, 2014. MUR implementation is currently scheduled to be implemented on Unit 2 onlineduring Unit 2 Fuel Cycle 22. Therefore, Duke Energy requests approval of the MNS MUR LARby January 25, 2013 to support the scheduled MUR implementation on Unit 2.An assessment of MNS activities necessary to implement MUR upon approval of the MUR LARhas identified items which could impact the above Unit 2 MUR implementation schedule. Anevaluation is in progress to determine the final impact on the Unit 2 MUR implementationschedule. If the above schedule is impacted, the worse case Unit 2 MUR implementationschedule changes could result in Unit 2 MUR implementation occurring after the end of the2EOC22 RFO, currently scheduled to begin on approximately March 8, 2014 and end onapproximately April 2, 2014. In order to accommodate the current Unit 2 MUR implementationschedule and the potential worse case Unit 2 MUR implementation schedule changes, as partof NRC approval of the MNS MUR LAR, MNS requests the NRC specify the Unit 2 MURamendment shall be implemented in the time period between the start of Unit 2 Fuel Cycle 22and 30 days after the end of the 2EOC22 RFO.During development of this RAI response, MNS performed a review of the MNS MUR LARsubmitted on March 5, 2012 to determine if the above implementation plan would require anychanges to statements and conclusions in the LAR and RAI responses to date. This reviewidentified the below additional required LAR changes. The revised pages are provided inEnclosure 4. These revised pages replace both the corresponding pages in Enclosure 4 of theNovember 1, 2012 submittal providing the original responses to MUR LAR RAI questions 50and 53 and the corresponding pages in the March 5, 2012 MUR LAR:* Revise implementation related text in the first paragraph of Enclosure 1, Page E1-3, ofthe LAR to be consistent with the implementation plan described in this RAI response.* Revise the marked up Technical Specification (TS) Page 1.1-5 in Attachment 2, PageA2-4 of the LAR and add Page A2-6 of the LAR to ensure the Definition of RTP reflectsthe appropriate MWt consistent with the MUR implementation schedule. Since MURuprate will be implemented on a staggered basis for each Unit, the revised marked upTS Page 1.1-5 will have a footnote indicating this change is accomplished by the use ofa temporary footnote. This footnote indicates that, following implementation of MUR onthe respective Unit, the value of RTP shall be 3469 MWt.Page 5 of 7
- Revise RTP TS definition related text in Enclosure 1, Page E1-3, of the LAR to indicate,the TS change is accomplished by the use of a temporary footnote. This footnoteindicates that, following implementation of MUR on the respective Unit, the value of RTPshall be 3469 MWt.* Revise Attachment 1 of the LAR dated March 5, 2012 to add a commitment to ensuresubmittal of a follow-up administrative license amendment request to delete thesuperseded footnote on TS Page 1.1-5 described above. This follow-up amendment willbe submitted within 180 days after implementation of the MUR uprate on the last Unit.As part of the review to determine if the above implementation plan would require any changesto statements and conclusions in the LAR and RAI responses to date, the impact on the gridrelated statements and conclusions in the LAR and RAI responses was assessed. Systemperformance was assessed using the same methodology used to provide the basis for the gridrelated statements and conclusions to date. This assessment was performed consideringconditions that envelope:" Conditons which will exist during execution of the MUR uprate, HP TurbineReplacements, and Generator Stator/Exciter Replacements consistent with theimplementation schedule described above, including conditions which would exist if,after the Unit 1 MUR uprate, Unit 1 cannot achieve the expected maximum post-MURuprate MWt power level and/or the expected maximum post-MUR uprate MWe.* Conditions which would exist if, as a result of the possible schedule impacts identifiedduring the assessment of MUR implementation activities, the potential worse case MURimplementation schedule changes are realized and Unit 1 and/or Unit 2 MURimplementation does not occur until after the end of the 1 EOC23 RFO and 2EOC22RFO respectively.Based upon the above assessment, system performance during all stages of MURimplementation will remain acceptable. Note, it was identified that a clarification is neededregarding the response to MUR LAR RAI question 1.c provided in correspondence datedMay 29, 2012. This clarification is provided in the below revised response to RAI question 1.cwhich replaces the RAI question 1.c response provided on May 29, 2012. No other requiredchanges in the grid related statements and conclusions in the LAR and RAI responses wereidentified. The clarification to the RAI question 1.c response does not impact the results of theassessment described above.NRC Question I.cProvide the MVARs (mega-voltampere-reactive) required, corresponding to the maximumMW generation expected, based on the agreement with the transmission system operatorand meeting the voltage requirement at the switchyard.Page 6 of 7 Revised McGuire Response to Question 1.cAt the point of interconnection, the MVARs required to meet the voltage requirements at theswitchyard and corresponding to the maximum acceptable MW generation of approximately1185 MWe/Unit, is 468 MVAR lagging and (-) 297 MVAR leading. These MVAR valueswere calculated using a 0.93 power factor (pf) lagging and a 0.97 pf leading requirement asspecified in Duke's Facility Connection Requirements. These pf requirements supersedethe 0.95 pf lagging and a 0.95 pf leading requirement specified in Duke's Large GeneratorInterconnection Agreement which was the basis for the March 29, 2012 response toRAI question 1 .c. All grid studies and documented generator capabilities support the abilityof the new generators to meet the system requirements.Page 7 of 7 RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION BY THE OFFICE OFNUCLEAR REGULATION REGARDING A MCGUIRE LICENSE AMENDMENT TO SUPPORTA MEASUREMENT UNCERTAINTY RECAPTURE (MUR) POWER UPRATEEnclosure 2MNS Unit I License Condition Proposed In This RAI ResponseProposed Unit I License ConditionMNS switchyard voltages required (so as not to impact the degraded voltage relaysettings), corresponding to Unit 1 post-MUR uprate conditions, will be evaluated priorto implementation of MUR on Unit 1. However, if at the time of this evaluation, Unit 1is not capable of realizing the expected maximum post-MUR uprate MWt power leveland/or Unit 1 is not capable of generating the expected maximum post-MUR uprateMWe, then an additional evaluation will be performed when Unit 1 has thesecapabilities. If this additional evaluation is necessary, any changes in the MNSswitchyard voltages required (so as not to impact the degraded voltage relay settings),corresponding to conditions associated with the additional Unit 1 MWt capabilityand/or the additional Unit 1 MWe capability, will be evaluated prior to raising Unit 1reactor core full steady state power to the expected maximum post-MUR uprate MWtpower level and/or prior to Unit 1 generating the expected maximum post-MUR uprateMWe.
RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION BY THE OFFICE OFNUCLEAR REGULATION REGARDING A MCGUIRE LICENSE AMENDMENT TO SUPPORTA MEASUREMENT UNCERTAINTY RECAPTURE (MUR) POWER UPRATEEnclosure 3List of MNS Switchyard Voltage Related CommitmentsCommitment Commitment DateAny changes in the MNS switchyard Prior to implementation of the MUR uprate onvoltages required (so as not to impact the Unit 2.degraded voltage relay settings),corresponding to the Unit 2 post-MURuprate conditions will be evaluated.
RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION BY THE OFFICE OFNUCLEAR REGULATION REGARDING A MCGUIRE LICENSE AMENDMENT TO SUPPORTA MEASUREMENT UNCERTAINTY RECAPTURE (MUR) POWER UPRATEEnclosure 4Revisions to Pages In MNS MUR LAR Dated March 5, 2012 Enctosure 1 EVALUATION OF PROPOSED CHANGESLicense Amendment RequestMarch 5, 2012 Page E1-3The Unit 2 HP turbine/Main Generator changes were completed during the Unit 2 EOC21 outage in Fall2012. The Unit 1 HP turbine and main generator changes are scheduled for the Unit 1 EOC22 outage(Spring 2013) and the Unit 1 EOC23 outage (Fall 2014) respectively. The turbine/generator changesand LEFM are independent of one another but were designed to work together. Duke Energy is notrequesting NRC approval for the turbine/generator changes except for the change to TS Table 3.3.1-1,as noted above. The remainder of the turbine/generator changes will be installed in both units under 10CFR 50.59.3 DETAILED DESCRIPTION OF PROPOSED CHANGESTo accommodate a rated thermal power level of 3469 megawatts thermal for McGuire Units 1 and 2,Duke Energy proposes to modify the Operating License, Technical Specifications and TechnicalSpecification Bases. The proposed changes are listed below:TS 1.1, Definition of Rated Thermal PowerRATED THERMAL POWER will change from 3411 MWt to 3469 MWt.Since MUR Uprate will be implemented on a staggered basis for each Unit, this change isaccomplished by the use of a temporary footnote which indicates, following implementation of MURon the respective Unit, the value of RATED THERMAL POWER shall be 3469 MWt.TS Table 3.7.1-1, OPERABLE Main Steam Safety Valves (MSSVs) versus Maximum Allowable PowerRange Neutron Flux High Setpoints in Percent of RATED THERMAL POWERAs discussed in Technical Specification (TS) Bases 3.7.1, Actions A.1 and A.2, operation with oneor more MSSVs inoperable is permissible if THERMAL POWER is proportionally limited to the reliefcapacity of the remaining MSSVs. The basis for determining the reduced high flux trip setpoint isdetailed in TS Bases 3.7.1, Actions A.1 and A.2. With the MUR uprate, there is an increase insteam flow as shown in Enclosure 2, Table IV-1. Revised maximum allowable power range neutronflux high setpoints were calculated and resulted in changes to TS Table 3.7.1-1 with 4 and 3MSSVs per steam generator OPERABLE. The setpoint with 2 MSSVs per steam generatorOPERABLE was within the round off error and was not changed. This TS change can beimplemented on both units in the common McGuire Units 1 and 2 TS since the limitation onTHERMAL POWER is conservative for the unit that has not yet implemented the MUR changes.Operating Licenses Page 3 -Maximum Power LevelFor each of the two operating licenses, the steady state licensed power level will change from 3411MWt to 3469 MWt.Selected Licensee Commitments (SLCs)As discussed in Enclosure 2, Criterion 1 from ER-157P, Rev. 8, a Selected Licensee Commitment(SLC) is being added to support this LAR. The new SLC adds functionality requirements for theleading edge flow meters and appropriate Required Actions and Completion Times when an LEFMis not functional. The SLC changes are not provided as part of this LAR, but are being controlledusing the 10 CFR 50.59 process.4 TECHNICAL EVALUATIONMcGuire Units 1 and 2 are presently licensed for a Rated Thermal Power (RTP) of 3411 MWt. A moreaccurate feedwater flow measurement supports an increase to 3469 MWt. The technical evaluation forthis MUR power uprate addressed the following categories: the feedwater flow measurement techniqueand power measurement uncertainty, accidents and transients that remain bounded at the higherpower level, accidents and transients that are not bounded at the higher power level,mechanical/structural/material component integrity and design, electrical equipment design, systemdesign, operating, emergency, and abnormal procedures including associated operator actions,environmental impact, and any changes to the Technical Specifications including protective systemsetpoints. The evaluation conclusions are summarized in Enclosure 2, in the format of NRC RegulatoryIssue Summary (RIS) 2002-03 (Reference 1.2).
Attachment
2 TECHNICAL SPECIFICATION MARKUPSLicense Amendment RequestMarch 5, 2012Page A2-4Definitions1.11.1 Definitions (continued)QUADRANT POWER TILTRATIO (QPTR)RATED THERMAL POWER(RTP)REACTOR TRIPSYSTEM (RTS) RESPONSETIMESHUTDOWN MARGIN (SDM)QPTR shall be the ratio of the maximum upper excoredetector calibrated output to the average of the upper excoredetector calibrated outputs, or the ratio of the maximum lower excoredetector calibrated output to the average of the lower excore detectorcalibrated outputs, whichever is greater.RTP shall be a total reactor core heat transfer rate to thereactor coolant of 3411 MWt. -AThe RTS RESPONSE TIME shall be that time interval fromwhen the monitored parameter exceeds its RTS trip setpointat the channel sensor until loss of stationary gripper coil voltage.The response time may be measured by means of any series ofsequential, overlapping, or total steps so that the entire responsetime is measured. In lieu of measurement, response time may beverified for selected components provided that the components andthe methodology for verification have been previously reviewedand approved by the NRC.SDM shall be the instantaneous amount of reactivity by which thereactor is subcritical or would be subcritical from its present conditionassuming:a. All rod cluster control assemblies (RCCAs) are fully insertedexcept for the single RCCA of highest reactivity worth, which isassumed to be fully withdrawn. However, with all RCCAs verifiedfully inserted by two independent means, it is not necessary toaccount for a stuck RCCA in the SDM calculation. With anyRCCA not capable of being fully inserted, the reactivity worth ofthe RCCA must be accounted for in the determination of SDM;andb. In MODES I and 2, the fuel and moderator temperatures arechanged to the nominal zero power design level.SLAVE RELAY TESTMcGuire Units I and 2A SLAVE RELAY TEST shall consist of energizing each slave relayand verifying the OPERABILITY of each slave relay. The SLAVERELAY TEST shall include, as a minimum, a continuity check ofassociated testable actuation devices.1.1-5.Amendment Nos. 255/235
Attachment
2 TECHNICAL SPECIFICATION MARKUPSLicense Amendment RequestMarch 5. 2012Paae A2-6Paoe 2-6ITechnical Specification Page 1.1-5 InsertInsert 1:* Following implementation of MUR on the respective Unit, the value ofRTP shall be 3469 MWt.
Attachment
1 LICENSEE COMMITMENTSLicense Amendment RequestMarch 5, 2012Page Al-1ATTACHMENT ILICENSEE COMMITMENTSThe following commitment table identifies those actions committed to by Duke Energy Carolinas, LLC(Duke Energy) in this submittal. Other actions discussed in the submittal represent intended or plannedactions by Duke Energy. They are described to the Nuclear Regulatory Commission (NRC) for theNRC's information and are not regulatory commitments.Commitment Completion Date1 Any revisions to setpoint calculations or calibration procedures necessary Prior to implementation ofto reflect the increased rated thermal power will be implemented. All the MUR power uprate.maintenance procedures for the new equipment added for the MUR upratewill be implemented.2 Duke Energy will complete modificationsrelated to the MUR power uprate Prior to implementation ofidentified in Enclosure 2, VII.2.B. the MUR power uprate.3 Duke Energy will revise any impacted operating procedures and complete Prior to implementation ofall training of operators on the changes related to the MUR power uprate. the MUR power uprate.4 Duke Energy will develop maintenance procedures for the Cameron Prior to implementation ofequipment, develop a preventive maintenance program, and train the MUR power uprate.maintenance personnel on those procedures, prior to implementation ofthe MUR.5 Acceptance testing following installation of the CheckPlus systems in the Prior to implementation ofMcGuire units will confirm that as built parameters are within the bounds of the MUR power uprate.the error analyses.6 A Selected Licensee Commitment will be added to address functional Prior to implementation ofrequirements for the LEFMs and appropriate Required Actions and the MUR power uprate.Completion Times when an LEFM is not functional.7 An "LEFM System Trouble" alarm window will be added to the control Prior to implementation ofroom alarm panel to alert the operator when there is a problem with the the MUR power uprate.LEFM.8 The procedure related to temporary operation above full steady-state Prior to implementation oflicensed power levels will be reviewed and modified as necessary. the MUR power uprate.9 Duke Energy will re-evaluate the Loss-of-Coolant Accidents (UFSAR Prior to implementation of15.6.5) consistent with the reload methodology, the MUR power uprate.10 Duke Energy will submit a follow-up administrative license amendment Within 180 days afterrequest to delete the superseded footnote on Technical Specification Page implementation of the MUR1.1-5. uprate on the last Unit.