ML081420443
| ML081420443 | |
| Person / Time | |
|---|---|
| Site: | Millstone  |
| Issue date: | 05/20/2008 |
| From: | Bischof G T Dominion, Dominion Nuclear Connecticut |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 07-0450H, NLOS/MAE R1 | |
| Download: ML081420443 (19) | |
Text
Dominion Nuclear Connecticut, Inc.
Dominion Boulevard, Glen Allen, Virgini" 2)()60\\c'eh Address: www.dom.com May 20,2008 U.S.Nuclear Regulatory Commission Attention:
Document Control Desk One White Flint North 11555 Rockville Pike Rockville, MD 20852-2738 Serial No.: 07-0450H NLOS/MAE: R1'Docket No.: 50-423 License No.: NPF-49 DOMINION NUCLEAR CONNECTICUT, INC.MILLSTONE POWER STATION UNIT 3 SUPPLEMENTAL INFORMATION REGARDING STRETCH POWER UPRATE LICENSE AMENDMENT REQUEST MISCELLANEOUS UPDATES TO THE LICENSE AMENDMENT REQUEST Dominion Nuclear Connecticut, Inc.(DNC)submitted a stretch power uprate license amendment request (LAR)for Millstone Power StationUnit3 (MPS3)in letters dated July 13, 2007 (Serial Nos.07-0450 and 07-0450A), and supplemented the submittal by letters dated September 12, 2007 (Serial No.07-04508), December 13, 2007 (Serial No.07-0450C), March 5, 2008 (Serial No.07-04500), March 27, 2008 (Serial No.07-0450E)and April 24, 2008 (Serial No.07-0450F).The NRC staff forwarded requests for additional information (RAls)in October 29,2007, November 26,2007, December 14,2007, December 20,2007 and April 23, 2008 letters.DNC responded to the RAls in letters dated November 19, 2007 (Serial No.07-0751), December 17, 2007 (Serial No.07-0799), January 10, 2008 (Serial Nos.07-0834, 07-0834A, 07-0834C, and 07-0834F), January 11, 2008 (Serial Nos.07-08348, 07-0834E, 07-0834G, and 07-0834H), January 14, 2008 (Serial No.07-08340), January 18, 2008 (Serial Nos.07-0846, 07-0846A, 07-08468, 07-0846C, and 07-08460), January 31, 2008 (Serial No.07-08341), February 25, 2008 (Serial Nos.07-0799A and 07-0834J), March 10, 2008 (Serial Nos.07-0846E and 07-0846F), March 25, 2008 (Serial No.07-0834K), April 4, 2008 (Serial No.07-0834L), April 29, 2008 (Serial No.08-0248)and May 15, 2008 (Serial No.08-248A).DNC is providing miscellaneous updates to some license amendment request sections in the attachment to this letter.The updates affect Section 5.6 of Attachment 1 of the LAR and the following licensing report sections (Attachment 5): Table 1.0-1 of Section 1.0.1, Section 2.2.2.2.2.3, Section 2.4.1.2.3.8 and Table 2.12-1 of Section 2.12.1.The information provided by this letter does not affect the conclusions of the significant hazards consideration discussion in the December 13, 2007 DNC letter (Serial No.07-0450C).
Serial No.07-0450H Docket No.50-423 SPU License Amendment Updates Page 2 of 3 Should you have any questions in regard to this submittal, please contact Ms.Margaret Earle at 804-273-2768.
Sincerely, Gerald T.Bischof Vice President-Nuclear Engineering COMMONWEALTH OF VIRGINIA COUNTY OF HENRICO The foregoing document was acknowledged before me, in and for the County and Commonwealth aforesaid, today by Gerald T.Bischof, who isVicePresident
-Nuclear Engineering of Dominion Nuclear Connecticut, Inc.He has affirmed before me that he is dUly authorized to execute and file the foregoing document in behalf of that Company, and that the statements in the document are true to the best of his knowledge and belief.MARGARET*.IENNEn Notary PublIC 3)'-f.30;z.
Commonweolth of Virginia My Commlulon Expire.Aug 31.2001 Serial No.07-0450H Docket No.50-423 SPU License Amendment Updates Page 3 of 3 Commitments made in this letter: See Attachment Attachment cc: U.S.Nuclear Regulatory Commission Region I Regional Administrator 475 Allendale Road King of Prussia, PA 19406-1415 Mr.J.G.Lamb Project Manager U.S.Nuclear Regulatory Commission One White Flint North 11555 Rockville Pike Mail Stop 0-881A Rockville, MD 20852-2738 Mr.J.D.Hughey Project Manager U.S.Nuclear Regulatory Commission One White Flint North 11555 Rockville Pike Mail Stop 0-883 Rockville, MD 20852-2738 NRC Senior Resident Inspector Millstone Power Station Director Bureau of Air Management Monitoring and Radiation Division Department of Environmental Protection 79 Elm Street Hartford, CT 06106-5127 Serial No.07-0450H Docket No.50-423 ATTACHMENT LICENSE AMENDMENT REQUEST STRETCH POWER UPRATE LICENSE AMENDMENT REQUEST MISCELLANEOUS UPDATES TO THE LICENSE AMENDMENT REQUEST MILLSTONE POWER STATION UNIT 3 DOMINION NUCLEAR CONNECTICUT, INC.
Serial No.07-0450H Docket No.50-423 Attachment, Page 1 of 15 Stretch Power Uprate License Amendment Request Miscellaneous Updates To The License Amendment Request By letter dated July 13, 2007 (Serial No.07-0450), as supplemented by additional letters, Dominion Nuclear Connecticut, Inc.(DNC), licensee of Millstone Power Station, Unit NO.3 (MPS3), submitted the application,"Dominion Nuclear Connecticut, Inc., Millstone Power Station Unit 3, License Amendment Request, Stretch Power Uprate," to the U.S.Nuclear Regulatory Commission (NRC).The proposed license amendment would allow an increase in the maximum authorized power level from 3,411 megawatts thermal (MWt)to 3,650 MWt, and make changes to the technical specifications, as necessary, to support operation at the stretch power level.The following parts of the license amendment request (LAR)are being updated.The updated parts are provided together with reason for change: 1.Table 1.0-1 of Section 1.0.1, General Overview of the Millstone Power Station, Unit 3 SPU Licensing Report, Attachment 5: Updated table: Table 1.0-1 MPS3 Power Uprate Planned Modification I SYSTEMI REASON I MODIFICATION COMPONENT DESCRIPTION Main Feedwater Pump Turbine replacement Improves plant performance due to increased flow.Turbine Building HVAC Modified ductwork to Improves margin regarding temperature provide additional limits for the condensate pump motor ventilation cooling in windage.the condensate pump area.Control Building Control Building auto Reduces control room dose following a Ventilation initiation of pressurized fuel handling accident.filtration following I Control Building L isolation signal.
Serial No.07-0450H Docket No.50-423 Attachment, Page 2 of 15 SYSTEM/MODIFICATION REASON COMPONENT DESCRIPTION Turbine Generator 1)Control valve Provide proper indication for SPU position demand vs.conditions.
lift settings for the valve position cards 2)Changes to power load imbalance circuits 3)Sensor rescaling for steam pressure changes 4)Instrument scaling 5)Main control board meter scale changes Component Cooling Increase in piping Permits reactor cooldown.Water design temperature between RHS and Component Cooling Water Heat Exchanger Instrumentation
&Setpoint changes Control Systems 1)BOP system 1)Provides proper indication for SPU conditions.
2)Feedwater pump 2)Improves performance regarding proper system operation.
3)Pressurizer level 3)Supports the revised analysis control regarding loss of normal feedwater and accommodate RCS shrink and swell at 4)Electronic filter on SPU conditions.
Thot signal 4)Improves operational margin for observed Thot temperature spikes.5)PRT level alarm 5)Supports the revised analysis regarding loss of normal feedwater and accommodate RCS shrink and swell at SPU conditions.
6)Condenser steam 6)Permits proper operation during SPU dump trip valve conditions.
control 7)P-8 setpoint change 7)Improves performance regarding proper system operation.
Serial No.07-0450H Docket No.50-423 Attachment, Page 3 of 15 SYSTEM/MODIFICATION REASON COMPONENT DESCRIPTION Pipe Support Pipe support Improve margin regarding SPU Modifications:
modifications conditions.
Condensate, Feedwater, Component Cooling Water, and Containment Recirculation ECCS Permissive for opening Reduces severity of the inadvertent cold leg injection ECCS actuation analysis, due a logic that valves requires both an SI signal and a low RCS I pressure signal to exist before I automatically opening the cold leg injection valves.I nstrument Loop First stage turbine Provides proper indication for SPU Rescaling pressure conditions.
L Reason for change: Serial No.07-0450H Docket No.50-423 Attachment, Page 4 of 15 SYSTEMI CHANGE REASON FOR CHANGE COMPONENT Main Feedwater Pump Turbine replacement No change Turbine Building HVAC Modified ductwork to No change provide additional ventilation cooling in the condensate pump area.Control Building Control Building auto Ventilation initiation of pressurized filtration following No change Control Building isolation signal.Turbine Generator 1)Nell.'operating point 1)GE determined that existing generator for generator excitation is acceptable as is for SPU.excitation 2)Control valve 2)No change position demand vs.lift settings for the valve position cards 3)Changes to power 3)No change load imbalance circuits 4)Throttle pressure 4)GE determined that the existing throttle and excess throttle pressure and excess throttle pressure pressure circuit scaling is acceptable as is for SPU.recalibrations 5)Sensor rescaling for 5)No change steam pressure changes 6)Instrument scaling 6)No change 7)Main control board 7)Detailed design change determined
&panel meter scale that present meters are acceptable with changes only a scale replacement necessary for replacements SPU.
Serial No.07-0450H Docket No.50-423 Attachment, Page 5 of 15 SYSTEM!CHANGE REASON FOR CHANGE COMPONENT Component Cooling Increase in piping No change Water design temperature between RHS and Component Cooling Water Heat Exchanger.
Instrumentation
&Setpoint changes: No change Control Systems 1)BOP system 2)Feedwater pump 3)Pressurizer level control 4)Electronic filter on Thot signal 5)PRT level alarm 6)Condenser steam dump trip valve control 7)P-8 setpoint change Pipe Support Pipe support Final stress calculations resulted in Modifications:
mod ifications acceptable loads for extraction steam Condensate, supports.The containment recirculation Feedwater Component support modifications were omitted from Cooling Water, and the original license amendment request.Extraction Steam Containment Recirculation ECCS Permissive for opening"Permits elimination" is changed to cold leg injection"Reduce severity" inthe"Reason" valves column.Analysis for an inadvertent ECCS actuation is still performed.
The modification reduces the severity of this event.
Serial No.07-0450H Docket No.50-423 Attachment, Page 6 of 15 SYSTEMI CHANGE REASON FOR CHANGE COMPONENT I nstrument Loop 1)Isophase bus duct Calculation error underestimated present Rescaling Gaoler flow cooler capabilities, which are acceptable for SPU.2)MSR steam flow MSR flow optimization implemented in July, 2007, reduced required steam flow such that present range is acceptable for SPU.3)First stage turbine No change pressure 2.Licensing report Section 2.4.1.2.3.8, Reactor Protection, Safety Features Actuation, and Control Systems, other Systems, Attachment 5: a.Delete the following paragraph: "Main Steam System Instrumentation The main steam evaluation determined that the moisture separator reheater steam supply increases approximately 5 percent.(Section 2.5.5.1, Main Steam,Table2.5.5.1-1)
As a result, the measurement range of the moisture separator reheater steam supply flow instrument loops will be rescaled to accommodate this increased flowrate." Reason for change: MSR flow optimization implemented in July, 2007, reduced required steam flow such that present range is acceptable for SPU.b.Replace the following paragraph: "Condensate and Feedwater System Instrumentation The condensate and feedwater system evaluation is described in Section 2.5.5.4, Condensate and Feedwater.
As a result of that evaluation, the two main feed pump turbine speeds will increase and the speed control loop differential pressure input will change from the existing 140 psid (nominal)to approximately 212 psid (nominal)for the SPU conditions.(Section 2.5.5.4, Condensate and Feedwater)."
Serial No.07-0450H Docket No.50-423 Attachment, Page 7 of 15 With"Condensate and Feedwater System Instrumentation The condensate and feedwater system evaluation is described in Section 2.5.5.4, Condensate and Feedwater.
As a result of that evaluation, the two main feed pump turbine speeds will increase andthespeed control loop differential pressure input will change from the existing 140 psid setpoint (nominal)to approximately 175 psid (nominal)for the SPU conditions.(Section 2.5.5.4, Condensate and Feedwater)." Reason for change: Original calculation used overly conservative bounding design assumptions.
Detailed design based on expected SPU operating points results in a lower required differential pressure setpoint.3.Licensing report Section 2.2.2, Pressure-Retaining Components and Component Supports, Attachment 5: a.In Section 2.2.2.2.2.3, Results, replace the following paragraph (page19): "The results of the evaluations of the BOP piping and support systems listed in Section 2.2.2.2.2.1 (Introduction) have determined that these systems remain acceptable for SPU conditions, with the exception of the recirculation spray, feedwater, condensate, and MSR vent and drain systems, which willrequirepipe support modifications to accommodate the revised loads due to SPU." With"The results of the evaluations of the BOP piping and support systems listed in Section 2.2.2.2.2.1 (Introduction) have determined that these systems remain acceptable for SPU conditions, with the exception of the recirculation spray, feedwater and condensate piping systems, which will require pipe support modifications to accommodate the revised loads due to SPU." Reason for change: Final stress calculations resulted in acceptable loads for the Moisture Separator Reheater (MSR)vent and drain piping supports.This change will make the description in the above mentioned LAR section consistent with updated Table 1.0-1,"MPS3 Power Uprate Planned Modification".
Serial No.07-0450H Oocket No.50-423 Attachment, Page 8 of 15 b.In Section 2.2.2.2.2.3, Results, replace the following paragraph (page20): "The results of the pipe support evaluations for systems impacted by SPU concluded that all supports remain acceptable, with the exception of several pipe supports on the recirculation spray, feedwater, condensate and MSR vent and drain piping systems which will require modification to accommodate the revised loads due to SPU." With"The results of the pipe support evaluations for systems impacted by SPU concluded that all supports remain acceptable, with the exception of several pipe supports on the recirculation spray, feedwater and condensate piping systems which will require modification to accommodate the revised loads due to SPU." Reason for change: Final stress calculations resulted in acceptable loads for the Moisture Separator Reheater (MSR)vent and drain piping supports.This change will make the description in the above mentioned LAR section consistent with updated Table 1.0-1,"MPS3 Power Uprate Planned Modification".
c.In Section 2.2.2.2.3, Conclusion, replace the following part (page 2.2-20): "ONC concludes that pipe stress levels for BOP piping will remain within allowable stress limits.ONC also concludes that all supports remain acceptable, with the exception of several pipe supports on the recirculation spray, feedwater, condensate and MSR vent and drain piping systems which will require modification to accommodate the revised loads due to SPU." With"ONC concludes that pipe stress levels for BOP piping will remain within allowable stress limits.ONC also concludes that all supports remain acceptable, with the exception of several pipe supports on the recirculation spray, feedwater and condensate piping systems which will require modification to accommodate the revised loads due to SPU." Reason for change: Final stress calculations resulted in acceptable loads for the Moisture Separator Reheater (MSR)vent and drain piping supports.This change will make the description in the above mentioned LAR section consistent with updated Table 1.0-1,"MPS3 Power Uprate Planned Modification".
Serial No.07-0450H Docket No.50-423 Attachment, Page 9 of 15 4.Table 2.12-1 of Section 2.12.1, Approach to SPU Power Level and Test Plan, Attachment 5: Updated table: Table 2.12-1 SPU Power Ascension Test Plan Summary I SYSTEMI MODIFICATION TESTS I COMPONENT DESCRIPTION Main Feedwater Pump Turbine replacement 1)Post modification testing 2)Monitor pump speed 3)Monitor discharge pressure and flow I 4)Monitor pump vibration I 5)Confirm increased main feed pump I I turbine steam flow at anticipated values Turbine building HVAC Modified ductwork to 1)Post modification testing after ductwork provide additional modifications are complete.ventilation cooling in the condensate pump area.Control Building Control Building auto Series of post-modification tests to verify Ventilation initiation of filtered changes: recirculation following 1)Equipment calibration Control Building 2)Input of various control signals isolation signal.3)Manipulation of component controls 4)Cycling of components 5)System operation.
Turbine Generator 1)Control valve Series of post-modification tests to verify position demand vs.changes: lift settings for the 1)Equipment calibration valve position cards 2)Input of various control signals 2)Changes to power 3)Manipulation of component controls load imbalance 4)Cycling of components circuits 5)System operation 3)Pressure sensor 6)Confirm proper indication for uprated and instrument loop conditions.
rescaling for steam pressure changes 4)Instrument scaling 5)Main control board meter scale replacements Serial No.07-0450H Docket No.50-423 Attachment, Page 10 of 15 SYSTEMI MODIFICATION TESTS COMPONENT DESCRIPTION Instrumentation
&Setpoint changes 1)Verify setpoint changes correctly Control Systems 1)BOP system implemented via the MPS3 design 2)Feedwater pump control program.3)Pressurizer level 2)Verify proper system operation at control uprated conditions.
4)Electronic filter on 3)Post modification test.Thot signal 5)PRT level alarm 6)Condenser steam dump trip valve control 7)P-8 setpoint change Pipe Support Pipe support 1)NDE Modifications:
RSS, mod ifications 2)QC inspections CCP, FWS, and CND 3)Vibration monitoring 4)System walk-downs ECCS Permissive for opening Series of post-modification tests to verify cold leg injection changes: valves 1)Equipment calibration 2)Input of various control signals I 3)Manipulation of component controls 4)Cycling of components.
I Instrument Loop First stage turbine 1)Post modification testing Rescaling pressure 2)Confirm proper indication for uprated conditions.
Rod Control System Deletion of auto rod Series of post-modification tests to verify control changes: 1)Input of various control signals 2)Manipulation of component controls to show that control rods do not withdraw under control inputs that previously would have resulted in outward rod motion.
Serial No.07-0450H Docket No.50-423 Attachment, Page 11 of 15 SYSTEM!MODIFICATION TESTS COMPONENT DESCRIPTION POWER ASCENSION TESTING
SUMMARY
Reactor, RCS piping NA Vibration monitoring in-service Ventilation Systems NA Ventilation system operability test (TRM)Chemical and Volume NA Maintain primary and secondary Control System chemistry within the requirements of the Chemistry Control Program.Plant Process NA Verify calorimetric calculation is correct.Computer Reactor Core NA Utilize plant procedures for post-refueling power physics testing and MPS3 uprate power ascension testing to verify applicable core design parameters.
NSSS NA 1)Utilize MPS3 uprate power ascension testing procedure to trend parameters, evaluate data, and rescale instrumentation Nuclear Instrumentation, turbine impulse pressure).
2)Ensure systems that determine reactor thermal power are properly calibrated.
Engineered Safety NA Utilize MPS3 Technical Specification Features (ESF)surveillance program to verify ESF Equipment Systems operability.
Plant Radiation Levels NA Utilize MPS3 Radiation Protection Manual to verify acceptable plant radiation levels.
Reason for change: Serial No.07-0450H Docket No.50-423 Attachment, Page 12 of 15 SYSTEM/MODIFICATION REASON FOR CHANGE COMPONENT DESCRIPTION Main Feedwater Pump Turbine replacement No change feed\"Jater Heater Modify level oontrol Erroneously included in Table 2.12-1.valves due to Level control valves are acceptable for inoreased drain flO't\'s SPU.Turbine Building HVAC Modified ductwork to No change provide additional ventilation cooling in the condensate pump area.Control Building Control Building auto No change Ventilation initiation of filtered recirculation following Control Building isolation signal.Turbine Generator 1)New operating point 1)GE determined that existing generator for generator excitation is acceptable as is for SPU.exitation 2)Control valve 2)No change position demand vs.lift settings for the valve position cards 3)Changes to power 3)No change load imbalance circuits 4)Throttle pressure 4.a)GE determined that the existing and exoeS6 throttle throttle pressure scaling is acceptable pressure oirouit as is for SPU.reoalibrations 4.b)Non-SPU modification will eliminate excess throttle pressure circuit per GE recommendation.
5)Sensor rescaling for 5)No change steam pressure changes 6)Instrument scaling 6)No change 7)Main control board 7)Detailed design change determined
&panel meter scale that present meters are acceptable with replacements only a scale replacement necessary for SPU.
Serial No.07-0450H Docket No.50-423 Attachment, Page 13 of 15 SYSTEMI MODIFICATION REASON FOR CHANGE COMPONENT DESCRIPTION Instrumentation
&Setpoint changes Control Systems 1)BOP system 1)No change 2)Feedwater pump 2)No change 3)Pressurizer level 3)No change control 4)Electronic filter on 4)No change Thot signal 5)PRT level alarm 5)No change 6)Condenser steam 6)No change dump trip valve control 7)P-8 setpoint change 7)No change Pipe Support Pipe support Changed to agree with revised Table Modifications:
modifications 1.0-1.QSS,lR SS G G\/\/pM , rv, r.CCP, FWS, and SW CND ECCS Permissive for opening No change cold leg injection valves I nstrument Loop 1)Isophase bus duct 1)Calculation error underestimated Rescaling cooler flm', present cooler capabilities, which are acceptable for SPU.2)MSR steam flow 2)MSR flow optimization implemented in July, 2007, reduced required steam flow such that present range is acceptable for SPU.3)First stage turbine 3)No change pressure Rod Control System Deletion of auto rod No change control Serial No.07-0450H Docket No.50-423 Attachment, Page 14 of 15 SYSTEM!MODIFICATION REASON FOR CHANGE COMPONENT DESCRIPTION POWER ASCENSION TESTING
SUMMARY
Reactor, RCS piping NA No change Ventilation Systems NA No change Chemical and Volume NA No change Control SystemPlantProcess NA No change Computer Reactor Core NA No change NSSS NA No change Engineered Safety NA No change Features (ESF)Equipment Plant Radiation Levels NA No change 4.Attachment 1 of LAR, Section 5.6, RCS Low Pressure Permissive for Opening the ECCS Charging Injection Valves Following a Safety Injection, page 18: Replace the following paragraph:
The current analysis for aninadvertentsafety injection actuation at power documented in FSAR Section 15.5.1 shows that there is 10.7 minutes for operator action to preclude water relief from the pressurizer safety valves for which the pressurizer safety valves are not designed.Because of the higher RCS average temperature associated with the increased power level, a higher pressurizer level is needed to assure the pressurizer heaters will not uncover during a routine reactor trip.The higher pressurizer level will reduce the margin for operator action." With: "The current analysis for an inadvertent safety injection actuation at power documented in FSAR Section 15.5.1 shows that there is 10.48 minutes for Serial No.07-0450H Docket No.50-423 Attachment, Page 15 of 15 operator action to preclude water relief from the pressurizer safety valves for which the pressurizer safety valves are not designed.Because of the higher ReS average temperature associated with the increased power level, a higher pressurizer level is needed to assure the pressurizer heaters will not uncover during a routine reactor trip.The higher pressurizer level will reduce the margin for operator action." Reason for change: A design change,"charging system alternate minimum flow line modifications," which was implemented during MPS3 refueling outage No.11, prior to the submittal of the SPU LAR, modified the time for operator action that resulted in a change to the 10.7 minute time frame.The FSAR currently states: "Operator action at 10 minutes to ensure that at least one PORV is unblocked is assumed to occur such that a relief path is full open at 10.48 minutes and water relief through the PSRVS is precluded."