ML12240A009
| ML12240A009 | |
| Person / Time | |
|---|---|
| Site: | Crystal River  |
| Issue date: | 08/21/2012 |
| From: | Franke J A Progress Energy Carolinas |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| 3F0812-02, TAC ME6527 | |
| Download: ML12240A009 (28) | |
Text
- 0 Progress EnergyCrystal River Nuclear PlantDocket No. 50-302Operating License No. DPR-72August 21, 20123F0812-02U.S. Nuclear Regulatory CommissionAttn: Document Control DeskWashington, DC 20555-0001Subject: Crystal River Unit 3 -Response to Second Request for Additional Information toSupport NRC Electrical Engineering Branch (EEEB) Technical Review of theCR-3 Extended Power Uprate LAR (TAC No. ME6527)References: 1. CR-3 to NRC letter dated June 15, 2011, "Crystal River Unit 3 -LicenseAmendment Request #309, Revision 0, Extended Power Uprate" (ADAMSAccession No. ML 112070659)2. Email from S. Lingam (NRC) to D. Westcott (CR-3) dated June 7, 2012, "RE:Crystal River, Unit 3 EPU LAR -Draft RAIs from Electrical Branch (EEEB)(TAC No. ME6527)"3. NRC to CR-3 letter dated July 17, 2012, "Crystal River Unit 3 NuclearGenerating Plant -Request For Additional Information For Extended PowerUprate License Amendment Request (TAC No. ME6527)" (ADAMSAccession No. ML 12194A417)Dear Sir:By letter dated June 15, 2011, Florida Power Corporation requested a license amendment toincrease the rated thermal power level of Crystal River Unit 3 (CR-3) from 2609 megawatts(MWt) to 3014 MWt (Reference 1). On June 7, 2012, via electronic mail, the NRC provided adraft request for additional information (RAI) needed to support the EEEB technical review ofthe CR-3 Extended Power Uprate (EPU) License Amendment Request (LAR) (Reference 2). Byteleconference on June 25, 2012, CR-3 discussed the draft RAI with the NRC to confirm anunderstanding of the information being requested. On July 17, 2012, the NRC provided a formalRAI required to complete its evaluation of the CR-3 EPU LAR (Reference 3).The attachment to this correspondence, "Response to Second Request for Additional Information-Electrical Engineering Branch Technical Review of the CR-3 EPU LAR," provides the formalresponse to the RAI.In support of the EPU technical review RAI responses, three enclosures are being provided to theattachment. Enclosure 1, "CR-3 EPU -New or Replaced EQ Components," provides specificenvironmental qualification (EQ) design information for the new and replacement componentsrequiring qualification in accordance with 10CFR50.49. Enclosure2, "Summary ofQualification -EFW Pump Recirculation Line Differential Pressure Switches," provides theCrystal River Nuclear Plant -A15760 W. Powerline StreetCrystal River, FL 34428 U.S. Nuclear Regulatory Commission Page 2 of 33F0812-02environmental qualification results associated with the new differential pressure switches for theemergency feedwater pump recirculation line modification. Enclosure 3, "CR-3 ElectricalFigures," provide simplified diagrams of selected CR-3 electrical configurations to support theRAI responses.This correspondence contains no new regulatory commitments.If you have any questions regarding this submittal, please contact Mr. Dan Westcott,Superintendent, Licensing and Regulatory Programs at (352) 563-4796.SinceJon
- FrankeVice PresidentCrystal River Nuclear PlantJAF/gweAttachment: Response to Second Request for Additional Information -Electrical EngineeringBranch Technical Review of the CR-3 EPU LAREnclosures:1. CR-3 EPU -New or Replaced EQ Components2. Summary of Qualification -EFW Pump Recirculation Line Differential PressureSwitches3. CR-3 Electrical Figuresxc: NRR Project ManagerRegional Administrator, Region IISenior Resident InspectorState Contact U.S. Nuclear Regulatory Commission Page 3 of 33F0812-02STATE OF FLORIDACOUNTY OF CITRUSJon A. Franke states that he is the Vice President, Crystal River Nuclear Plant for FloridaPower Corporation; that he is authorized on the part of said company to sign and file with theNuclear Regulatory Commission the information attached hereto; and that all such statementsmade and matters set forth therein are true and correct to the best of his knowledge, information,and belief.VicePresidentCrystal River Nuclear Plant/The foregoing document was acknowledged before me this ____ day ofO2012, by Jon A. Franke.Signature of Notary PublicState &qCAROLYN E. PORTMANNM Commission # DD 937553--Mamh 1, 2014 I(Print, type, or stamp CommissionedName of Notary Public)Personally / ProducedKnown V -OR- Identification FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 / LICENSE NUMBER DPR-72ATTACHMENTRESPONSE TO SECOND REQUEST FOR ADDITIONALINFORMATION -ELECTRICAL ENGINEERING BRANCHTECHNICAL REVIEW OF THE CR-3 EPU LAR U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 1 of 9RESPONSE TO SECOND REQUEST FOR ADDITIONALINFORMATION -ELECTRICAL ENGINEERING BRANCHTECHNICAL REVIEW OF THE CR-3 EPU LARBy letter dated June 15, 2011, Florida Power Corporation (FPC) requested a license amendmentto increase the rated thermal power level of Crystal River Unit 3 (CR-3) from 2609 megawatts(MWt) to 3014 MWt (Reference 1). On June 7, 2012, via electronic mail, the NRC provided adraft request for additional information (RAI) needed to support the Electrical EngineeringBranch (EEEB) technical review of the CR-3 Extended Power Uprate (EPU) LicenseAmendment Request (LAR). By teleconference on June 25, 2012, CR-3 discussed the draft RAIwith the NRC to confirm an understanding of the information being requested. On July17, 2012,the NRC provided a formal RAI required to complete its evaluation of the CR-3 EPU LAR.For tracking purposes, each item related to this RAI is uniquely identified as EEEB X-Y, with Xindicating the RAI set and Y indicating the sequential item number.1. (EEEB 2-1)In response to EEEB 1-2 dated April 16, 2012, the licensee stated that the new equipment listedin the original LAR (dated June 15, 2011) Section 2.3.1, "Environmental Qualification [EQ] ofElectrical Equipment," are being evaluated in the associated CR-3 Engineering Changepackages. The licensee also stated that finalization of the EPU plant modifications is currently inprogress and includes the associated EQ evaluations which will be completed once the specificlocation and type of component is known.In view of above the NRC staff has the following questions:a) The licensee's EQ equipment and component design finalization and the determination of thespecific location(s) have not been completed for the EPU operation, and therefore the NRCstaff cannot accept the response without the submittal of the completed design. The licenseeneeds to provide the completed design information with type of equipment, specific location,and category/environmental characteristics, with a complete list of all new and replacementequipment (with Tag number(s)) that need to be environmentally qualified under EPUconditions.Response:Enclosure 1, "CR-3 EPU -New or Replaced EQ Components," to this attachment provides atabular listing of the new and replacement components requiring qualification in accordancewith 10 CFR 50.49, "Environmental qualification of electric equipment important to safetyfor nuclear power plants." For each listed component, Enclosure 1 includes the expectedequipment tag numbers; the vendor and model number; and the associated location bybuilding and zone, Also, the pre-EPU value, EPU value, qualified value, and margin areprovided for the EQ parameters impacted by EPU conditions; pressure, temperature, andradiation.Specifically, Enclosure 1 provides EQ design information for the following:* The turbine driven emergency feedwater (EFW) pump recirculation line differentialpressure indicating switches and solenoid valve; refer to Enclosure 1, Items (B) and (E).
U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 2 of 9" The new transmitters associated with the atmospheric dump valves and the FastCooldown System; refer to Enclosure 1, Items (H), and (I).* The new transmitters, penetrations, and motor operator valves associated with the LowPressure Injection (LPI) System cross-tie line and the Reactor Coolant System (RCS) hotleg injection (HLI) line; refer to Enclosure 1, Items (D), (F), and (G).* The new transmitters and temperature elements associated with the Inadequate CoreCooling Mitigation System and the EQ classification change to eight core exitthermocouples (CETs); refer to Enclosure 1, Items (A), (C), and (D)." The CET cable routing, which are commodity components in the applicable electricalpenetration; refer to Enclosure 1, Items (F) and (J)." RCS HLI blowdown line solenoid valves; refer to Enclosure 1, Item (E).b) The licensee's response in (iii) dated April 16, 2012, is that a vendor qualification packagefor the new differential pressure switches associated with the emergency feedwater (EFW)system is being finalized for the new EQ components. The NRC staff needs the final EQdetails of the new differential pressure switches to complete the safety review.Response:The new different pressure switches associated with the EFW pump recirculation linemodification have established qualification to EPU conditions as documented in theassociated vendor qualification package (VQP). Enclosure 2, "Summary of Qualification -EFW Pump Recirculation Line Differential Pressure Switches," to this attachment providesthe VQP results associated with the new differential pressure switches.c) The licensee stated in response (iv) dated April 16, 2012, that eight core exit thermocouplesare being upgraded to safety-related in support of the new Inadequate core cooling mitigationsystem. Clarify if upgrading means that these thermocouples will be new equipment? Alsoclarify whether these thermocouples are being added to the EQ master list. If so, provideinformation that demonstrates that the EQ of these components bounds EPU conditions.Response:Upgrading the existing CETs is accomplished by replacing the existing non-EQ CETs withnew CETs qualified in accordance with 10 CFR 50.49.The new safety-related CETs are the same model currently qualified by the CR-3 EQProgram. Thus, the new CETs are being added to the CR-3 EQ master list and included inthe associated VQP. Enclosure 1 to this attachment includes the new CETs and shows thatthe qualification of these components bound the EPU conditions.
U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 3 of 92. (EEEB 2-2)In response to EEEB 1-5 dated April 16, 2012, the licensee stated that with the exception of thereactor building sump transmitter capillary tubes, electrical equipment important to safety isinstalled above the expected flood level.Provide clarification that the sump transmitter and its wiring to the equipment are also above theexpected flood level so that the function is not impacted by any flooding conditions during EPUoperation. Provide a discussion how these are appropriately qualified.Response:Currently, the CR-3 reactor building (RB) sump transmitter is an assembly consisting of acontainment sump transmitter installed above the maximum RB flood level of 102 ft. elevation,with connecting sealed sensing capillary tubes routed down into the RB sump to measure RBsump water level from the bottom of the RB sump to the top of the RB sump cavity. Thiscurrent RB sump transmitter assembly is designed to operate under maximum calculatedflooding conditions. Since the RB flood level has not changed as a result of EPU conditions, thisRB sump level transmitter assembly remains qualified per the existing VQP. The electronictransmitter and instrumentation wiring remains located above the maximum RB flood level bydesign. The only portion of the RB sump transmitter assembly exposed to submerged (flooding)conditions is the sealed capillary tubes. The non-electrical capillary tubes are not subject to theeffects of flooding and do not provide water intrusion paths to the RB sump transmitter orassociated wiring. Thus, the RB sump transmitter, including instrumentation wiring to plantequipment, is not impacted by flooding during EPU operation and can continue to perform itssafety function.3. (EEEB 2-3)In response to EEEB 1-8 dated April 16, 2012, regarding short-circuit current available at theisolated phase bus (IPB) duct versus the IPB short-circuit capacity rating, the licensee stated thatthe changes that impact electrical calculations are not yet included in the formal calculations, butare evaluated using the electrical system calculation Impact Assessment process to ensure thatthe composite effect of the electrical system changes are acceptable. The licensee further statedthat additional changes due to EPU operation are being evaluated and are expected to bebounded by the equipment ratings.Provide the summary of the final results of the completed calculation to demonstrate that themaximum short circuit capacity of the IPB is adequate to support operation at EPU conditions.Response:Electrical calculations have been revised to include the major EPU upgrades; e.g., maingenerator upgrade, feedwater booster pumps, condensate pumps, and IPB-duct cooler motors.The fault current impact, as a result of other pending EPU changes, will be insignificant bycomparison to these large IPB electrical loads; the cumulative momentary fault current of otherpending IPB loads is estimated to be less than 100 amperes. As such, further changes that mayimpact the final EPU electrical configuration will have minimal impact on the short circuitcapability of the IPB.
U. S. Nuclear Regulatory Commission3F0812-02AttachmentPage 4 of 9Table 1, "CR-3 Isophase Bus Momentary Duty Summary," provides the IPB momentary faultcurrent capability and the momentary duty results during EPU operation for the IPB sectionsassociated with the CR-3 main generator, main transformers, and the unit auxiliary transformer(UAT). The Electrical Transient Analyzer Program (ETAP) conservatively compares the totalfault current momentary duty at a device location to the equipment fault current momentarycapability. The asymmetrical total momentary duty is calculated by applying the multiplicationfactor (M.F.) to the symmetrical total momentary duty. The M.F. is calculated by the ETAPsoftware based on the system reactance (X) and resistance (R); X/R ratio.Per the CR-3 ETAP momentary duty summary report and as indicated in Table 1, the IPB ductbetween the main generator and the main transformers deviate from the applicable asymmetricaldevice momentary duty capability. In these cases, as described in Institute of Electrical andElectronics Engineers (IEEE) 551 -2006, "IEEE Recommended Practice for Calculating Short-Circuit Currents in Industrial and Commercial Power Systems," (Reference 3), more refinedcalculations are used to determine the fault current momentary duty acceptability. In general,electrical equipment will not be subjected to the total fault current, but will be subjected to thefault current contribution from upstream sources or downstream sources depending on thelocation of the fault.For the CR-3 IPB duct, the upstream sources contribute the larger fault current. Thus, todetermine if the IPB duct was acceptable, the upstream symmetrical contribution was multipliedby the M.F. so that the upstream asymmetrical fault current contribution can be compared to thedevice capability.Table 1: CR-3 Isophase Bus Momentary Duty SummaryIsophase Bus Section CR-3 UATSymmetrical Total Momentary Duty (kA rms) 232.5M.F. 1.651Asymmetrical Total Momentary Duty (kA rms) 383.9Asymmetrical Device Momentary Capability (kA rms) 479.0Results AcceptableIsophase Bus Section CR-3 Main GeneratorSymmetrical Total Momentary Duty (kA rms) 233.5M.F. 1.652Asymmetrical Total Momentary Duty (kA rms) 385.7Asymmetrical Device Momentary Capability (kA rms) 345.0Upstream Contribution Bus CR-3 Main Transformers IPBSymmetrical Upstream Contribution (kA rms) 131.4Asymmetrical Upstream Momentary Duty (kA rms) 217.1Results AcceptableIsophase Bus Section CR-3 Main TransformersSymmetrical Total Momentary Duty (kA rms) 234.8M.F. 1.651Asymmetrical Total Momentary Duty (kA rmis) 387.7Asymmetrical Device Momentary Capability (kA mis) 321.0Upstream Contribution Bus 500 kV GridSymmetrical Upstream Contribution (kA rms) 129.6Asymmetrical Upstream Momentary Duty (kA rmis) 213.9Results Acceptable U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 5 of 9As shown in Table 1, the revised IPB ETAP calculation results, which include the major EPUelectrical loads, are acceptable. The asymmetric upstream momentary duty of the CR-3 maingenerator IPB is approximately 217 kA, which is within the IPB momentary capability of 345 kAand conservative with respect to the cited 250 kA in RAI Response EEEB 1-8 in the FPC toNRC letter dated April 16, 2012 (Reference 2); the asymmetric upstream momentary duty of theCR-3 main transformers IPB is approximately 213 kA, which is within the IPB momentarycapability of 321 kA; and the asymmetric total momentary duty of the CR-3 UAT IPB isapproximately 384 kA, which is within the IPB momentary capability of 479 kA. As such, therevised CR-3 electrical calculations demonstrate that the maximum short circuit capacity of theIPB is acceptable and adequate margin exists to support operation at EPU conditions.4. (EEEB 2-4)In response to EEEB 1-11 dated April 16, 2012, the licensee stated that subsequent to thesubmittal of the CR-3 EPU LAR, the licensee discovered an incorrect design input in thenonsafety related electrical transient analyzer program analysis. This condition was evaluated inthe corrective action program and the short-circuit analysis has been re-done. The analysisindicates that the short-circuit ratings are exceeded at EPU conditions on several nonsegregatedbus ducts that require modification for higher short-circuit rating. As a result, the licensee statedthat the five 4160 volt nonsegregated bus duct sections will be replaced prior to EPU operation.Identify the five 4160 volt nonsegregated bus duct sections discussed above and provide thecontinuous and short-circuit current ratings at EPU operation. Clarify if this modification is apart of the Regulatory Commitment in Attachment 10 of the LAR, where it is stated that "CR-3will implement all EPU modifications."Response:The sections of the 4160 V non-segregated bus duct that are identified for replacement to supportCR-3 operation are indicated in Figure 1, "Markup of FSAR Figure 8-2 -Electrical One LineDiagram Composite," and Figure 2, "Isometric of 4160 V Non Segregated Bus ReplacementProject," of Enclosure 3, "CR-3 Electrical Figures," to this attachment and include the bus ductsections between 4160 V engineered safeguard (ES) buses 3A and 3B, and, the 4160 V unitbuses 3A and 3B. Table 2, "Replacement Bus Duct -EPU Continuous and Short-CircuitRatings and Duty," provides a list of the continuous and short-circuit ratings of each of themodified sections of non-segregated bus duct and the continuous and short-circuit duty of the bussections in operation at EPU conditions.Table 2: Replacement Bus Duct -EPU Continuous and Short-Circuit Ratings and DutyTotalMomentary MomentaryContinuous Continuous Short-Circuit Short-CircuitUAT 4160 V Bus Duct Section Rating Duty Rating Duty(amperes) (amperes) (Asymm. kA (Asymm. kArms) rms)Note 23000A bus section in unit 3000 1721 86.0 69.5switchgear room2000 A bus section to Unit Bus 2000 1734 86.0 69.53A 200_73_8. 69.5 U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 6 of 9TotalMomentary MomentaryContinuous Continuous Short-Circuit Short-CircuitUAT 4160 V Bus Duct Section Rating Duty Rating Duty(amperes) (amperes) (Asymm. kA (Asymm. kArms) rms)Note 22000A bus section to Unit Bus 3B 2000 1721 86.0 69.12000A bus sections from the unit 965switchgear room to the ES Bus 2000 Note 1 86.0 64.23B switchgear room IoteI1200A bus sections to ES Buses 1200 965 86.0 63.63A and 3B Note INote 1: ES Bus 3A and ES Bus 3B are not aligned to the UAT during power operations. ES Bus 3Aand ES Bus 3B may be aligned to the UAT when the plant is in cold shutdown conditions. Thecontinuous duty value represents the maximum calculated loading during UAT backfeedoperation and is not expected to change as a result of EPU operation.Note 2: Total momentary short-circuit duty values will decrease slightly when the bus sections arereplaced due to the slightly higher reactance parameter of the new bus sections.As shown in Table 2, the continuous duty of the 4160 V nonsegregated bus duct sections remainwithin the associated continuous ratings. However, replacement of these nonsegregated bus ductsections is required to ensure the short-circuit fault current is within the momentary short-circuitrating of the nonsegregated bus duct at EPU conditions. Therefore, this modification is arequired modification for implementing EPU at CR-3 and is included in the scope ofmodifications identified in the second regulatory commitment in Attachment 10 of the EPU LAR(Reference 1).5. (EEEB 2-5)In response to EEEB 1-12 dated April 16, 2012, the licensee provided a discussion on the ClasslE battery system for the EFW System pump recirculation line modification. The licensee statedthat this modification adds 2 amperes to the B-positive battery and less than 2 amperes to thediesel driven EFW (emergency feedwater pump (EFP-3) battery.a) Provide the latest direct current (DC) one line diagram of the Class 1 E battery and the EFP-3battery systems. Provide a discussion on the configuration of the B-positive and B-negativeClass 1E station batteries.Response:To correct RAI Response EEEB 1-12 in FPC to NRC letter dated April 16, 2012(Reference 2), the EFW System pump recirculation line modification adds less than2 amperes to the B-negative battery; not the B-positive battery. The response does correctlystate that this modification adds less than 2 amperes to the diesel driven EFW pump (EFP-3)battery.Figure 3, "CR-3 FSAR Figure 8-8A -Electrical One Line Diagram 250/125V DC System,"and Figure 4, "Simplified 125/250 VDC Electrical Power System Train One Line Diagram,"
U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 7 of 9are provided in Enclosure 3 to this attachment. Figure 3 is a block diagram showing theClass 1E batteries, chargers, and DC electrical distribution panels. Figure 4 is a simplifiedelectrical schematic of one train of the Class lE batteries and associated chargers.For each Class lE DC electrical power train, one Class 1E 250 VDC battery bank is center-tapped (PN) to create two 125 VDC electrical distribution subsystems as shown in Figure 4.Since the two banks of each battery are connected in series at the PN terminal, the nominalvoltage across the entire battery (P to N) is approximately 250 VDC. Thus, the A stationbattery consists of battery banks 3A1 and 3A2. The terminals for bank 3A1 (A-positive) areP (+) and PN (-), and the terminals for bank 3A2 (A-negative) are N (-) and PN (+). The Bstation battery consists of battery banks 3B1 and 3B2. The terminals for bank 3B1 (B-negative) are N (-) and PN (+), and the terminals for bank 3B2 (B-positive) are P (+) and PN(-).Figure 5, "EFP-3 Battery System Block Diagram," of Enclosure 3 to this attachment providesa block diagram showing the EFP-3 battery, charger, and the EFP-3 DC electricaldistribution panel. Figure 6, "Simplified EFP-3 DC Power System One Line Diagram," ofEnclosure 3 to this attachment provides a one line diagram of the EFP-3 battery system.As illustrated in Figures 5 and 6, the EFP-3 battery consists of one 125 VDC battery bank(DPBA- 1 D) and one 125 VDC battery charger (DPBC- 1 J).b) Clarify that the above additional loads will not adversely impact the capacity margin of theClass lE battery and the EFW (EFP-3) battery systems.Response:To clarify the less than 2 ampere loading increase to the Class 1 E battery and the EFP-3battery systems described in RAI Response EEEB 1-12 of FPC to NRC letter dated April 16,2012 (Reference 2), the new DC loads are conservatively assumed to be energized for the fullstation blackout (SBO) coping period of 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. In addition, the cumulative DC electricalcalculation impact assessment includes the DC powered solenoids associated with the newRCS HLI blowdown line modification. Also, the cumulative DC electrical calculationimpact assessment includes battery capacity impacts associated with other pending plantmodifications not directly related to EPU operation. This cumulative assessment indicates:1) an additional 17 ampere-hours (A-H) usage projected for the 'A-negative' Class lEbattery; 2) an additional 24 A-H usage projected for the 'B-negative' battery; 3) an additional8 A-H usage projected for the EFP-3 battery; and 4) the voltage throughout the Class 1E125/250 VDC Electrical Distribution System is essentially unchanged and the Class lE125/250 VDC DC Electrical System voltage profile calculations are not adversely impactedas a result of the EPU modifications. Therefore, it is concluded that the additional DCloading, as a result of EPU, will not adversely impact the capacity margin of the Class 1Ebattery and the EFP-3 battery systems.c) The licensee stated that "In accordance with the CR-3 engineering change process, theelectrical loading calculation will be revised to incorporate the actual DC electrical loadingimpacts from the EPU operation and EPU-related modifications following finalization of themodifications to confirm the battery loading is acceptable for operation at EPU conditions."
U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 8 of 9Provide the summary of the final results of the completed calculation to demonstrate that thebattery loading is bounded at EPU conditions by the available battery capacity.Response:Per the CR-3 engineering change process, DC electrical calculations are not formally revisedprior to the as-built electrical configuration unless there is a significant impact to theelectrical calculation. However, a DC electrical calculation impact assessment has beenperformed and the plant DCSYSTEM software has been re-run to determine the cumulativeeffect on the CR-3 safety related DC System to ensure battery loading margin is acceptableduring EPU operation. This assessment considered the EPU modifications and other pendingplant modifications and uses conservative loading values such that when the calculation isrevised, the final electrical calculation merely confirms the loading is adequate.Table 3, "CR-3 Safety Related Battery Cumulative Capacity Change," provides a summaryof the cumulative DC electrical calculation impact assessment on the CR-3 safety relatedClass 1E 125/250 VDC System, based on EPU and other plant modifications, and includesthe safety related battery capacities in A-H.Table 3: CR-3 Safety Related Battery Cumulative Capacity ChangeBattery Pre-EPU EPUCR-3 Station Capacity Required Required A-H LoadingBattery Rating SBO Capacity SBO Capacity Increase(8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> A-H) (4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> A-H) (4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> A-H)A-positive (3A1) 1708 768 768 0A-negative (3A2) 1708 761 778 17B-positive (3B2) 1708 779 779 0B-negative (3B1) 1708 565 589 24EFP-3 (DPBA-1D) 231 22 30 8Based on the results of this cumulative DC electrical calculation impact assessment, thesafety related battery loading, including additional DC loading as a result of EPUmodifications, is bounded by the available Class lE and EFP-3 battery capacities andadequate margin exists to support operation at EPU conditions.Also, the EPU modifications have been evaluated for impact to the non-Class lE 125/250VDC Electrical System and it is concluded that the non-Class lE 125/250 VDC ElectricalSystem calculation is not adversely impacted as a result of the EPU modifications since thesteady state current increase is less than 1 ampere. Thus, the non safety related batteryloading, as a result of EPU modifications, is bounded by the available non Class 1E batterycapacity and adequate margin exists to support operation at EPU conditions.References1. FPC to NRC letter dated June 15, 2011, "Crystal River Unit 3 -License AmendmentRequest #309, Revision 0, Extended Power Uprate." (ADAMS Accession No.ML1 12070659)
U. S. Nuclear Regulatory Commission Attachment3F0812-02 Page 9 of 92. FPC to NRC letter dated April 16, 2012, "Crystal River Unit 3 -Response to Request forAdditional Information to Support NRC Electrical Systems Branch (EEEB) TechnicalReview of the CR-3 Extended Power Uprate LAR (TAC No. ME6527)." (ADAMSAccession No. ML 12114A002)3. Institute of Electrical and Electronics Engineers (IEEE) Report IEEE 551 -2006, "IEEERecommended Practice for Calculating Short-Circuit Currents in Industrial andCommercial Power Systems."
FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 / LICENSE NUMBER DPR-72ENCLOSURE 1CR-3 EPU -NEW OR REPLACED EQ COMPONENTS U. S. Nuclear Regulatory Commission3F0812-02Enclosure 1Page 1 of 2CR-3 EPU -NEW OR REPLACED EQ COMPONENTSPressure (psig) Temperature (*F) Radiation (rads)Tag BuildingComponent Tag Vendor Model ilZone Pre Qualified Pre Qualified Pre QualifiedEPU Value Margin EPU Value rgin EPU ValueIM-3F-TE*,Core Exit IM-7E-TE*,Temperature IM-1 3F-TE*,Elements IM-9G-TE*, AREVA 9029603-101 RB/39 54.2 54.9 66 16.6 302 302 570 268 1.11 1.30 2.01E+08 7.10E+07IM-1 1 K-TE*, E+08 E+08IM-9M-TE*,(A) IM-5K-TE*,IM-7M-TE*Differential EF-62-FS1,Pressure EF6-S,1.86 1.O+799E0Switch EF-62-FS2, ITT Barton 580A-2 IB /14 N/A 8.85 10 2.0 N/A 150 180 30 N/A E+04 1.00E+07 9.98E+06EF-62-FS3(B)Pressure 4.70 5.76Transmitter RC-223-PT Rosemount 1154GP9RA RB/38 54.2 54.9 110 60.6 302 302 420 118 E+07 E+07 1.1OE+08 5.24E+07(C)Pressure RC-224-PT,ad DH-64-DPT, 11 54SH9RADifferential DH6-P,15S9A4.70 5.76Prere DH-65-DPT, Rosemount 1154HH5RAN RB/38 54.2 54.9 85 35.6 302 302 420 118 4+0 5.7 1.16E+08 5.84E+07Pressure DH-66-PT, 0018 E+07 E+07Transmitter DH-67-PT(D) I IIIISolenoid EFV-180 11Z519-002 11 / 14 N/A 8.85 69 61.0 N/A 471 492 21 N/A 2.00 2.OOE+08 1.80E+08Operated Target Rock E+07Valve Corporation(E) DHV-222, TBD 1.83223, 227, Note 1 RB / 40B N/A 54.9 69 19.6 N/A 302 492 190 N/A E+08 2.OOE+08 1.70E+07228RB / 38 4.70 5.76Rc E 39 54.2 54.9 74.5 25.1 302 302 371 69 4.0 5.7 1.28E+08 7.04E+07Reactor EPA's: 7GZ5- & 39 E+07 E+07Building PEN-327, Conax 10001-01/02Penetration PEN-328, Co n EEDTHRUs:Pet PEN-408 poration 7PX8-12000- AB / 37 & 115 6.06 1.87(F) 01 64 Atm. Atm. 7 IN/ 12 Note 2 E+05 E+06 1.28E+08 1.26E+08 U. S. Nuclear Regulatory Commission3F0812-02Enclosure 1Page 2 of 2CR-3 EPU -NEW OR REPLACED EQ COMPONENTSPressure (psig) Temperature (*F) Radiation (rads)Tag Building V r Z T PreComponent Number Vendor Model / Zone Pre EPU Qualified Margin Pre EPU Qualified Margin Pre EPU Qualified MarginEPU Value EPU Value EPU ValueMotorOperated DHV-514, Limitorque SBM-0 RB / 38 54.2 54.9 70 20.6 302 302 420 118 1.60 1.83 2.04E+08 2.10E+07Valve 614 Liioqe-. ..E+08 E+08(G)Pressure MS-122-PT, IB / 17, 8.90 1.10Transmitter Rosemount 1153GD9RA 17 1.3 8.85 85 77.0 322 322 420 98 1.16E+08 1.16E+08H) MS-i123-PT 16 E+04 E+05(H)MU-23-Differential DPT13,Pressure MU-23- 1154SH9RATransmitter DPT14, Rosemount 1154HH5RAN AB / 3 Atm. Atm. 85 N/A 97 97 420 323 2.16 4.17 1.16E+08 1.12E+08MU-23- E+06 E+06OP~iS,0018DPT15,(I) MU-23-DPT16Various Kerite RB /39 54.2 54.9 80 30.6 302 302 325 23 N/A 5.76 1.OOE+08 4.24E+07Company E+07Tape _Scotch 27,Teiat Scotch 70,Termination 130C Bishop 6. 8 80 7330and Splices Various Kerite W926 and/or IB/ 17 6.2 8.85 80 72.0 322 322 325 3 N/A 1.10 1.OOE+08 9.99E+07Company Permacel P- &57(J) _212Kerite 115 2.00Various Company AB/37 Atm. Atm. 80 N/A 120 Note 2 325 210 N/A E+07 1.OOE+08 8.OOE+07Note 1: The specific model of Target Rock solenoids for the new Reactor Coolant System hot leg injection blowdown valves (DHV-222, 223,be, as a minimum, qualified using the current Target Rock EQ certification criteria.227, 228) have not been identified. However, the solenoids willNote 2: The maximum temperature of 115°F in the auxiliary building at EPU conditions is lower than the pre-EPU temperature value due to an adjustment in the EQ calculations; pre-EPU maximumtemperature of 120°F represents the maximum temperature in the emergency diesel generator building and is not representative of the maximum auxiliary building temperature.
FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 / LICENSE NUMBER DPR-72ENCLOSURE 2SUMMARY OF QUALIFICATION -EFW PUMPRECIRCULATION LINE DIFFERENTIAL PRESSURESWITCHES U. S. Nuclear Regulatory Commission3F0812-02Enclosure 2Page 1 of 1SUMMARY OF QUALIFICATIONEFW PUMP RECIRCULATION LINE DIFFERENTIAL PRESSURE SWITCHESTAG NO: EF-62-FS1, EF-62-FS2, FUNCTION: Control EFV-180 SYSTEM: EFW SERVICE: EFW Flow ControlEF-62-FS3COMPONENT LOCATION: Intermediate Building ELEV. 95-0", EFP-2 Area ZONE: 14COMPONENT DESCRIPT: Differential Pressure SwitchVQP NUMBER: INST-B040-18-EPU EQ CATEGORY: 10CFR50.49COMPONENT ENVIRONMENT DOCUMENTATION REFERENCES QUALIFICATIONDATA METHODENVIRONMENTAL CR-3 QUALIFIED TEST CR-3 SPECIFICATION VQP REFERENCEPARAMETER VALUE VALUE REFERENCE LOCATIONMANUFACTURER: OPERATINGIlT BARTON TIME 6 MONTHS > 6 MONTHS EQPPD-EPU TAB El TEST & ANALYSIS(HR)PEAKMODEL/TYPE: PAMOEA YE TEMPERATURE 150 180 TAB D1 NOTE 2.1 TAB D1 NOTE 2.1 TEST & ANALYSIS580A-2 (OF)PEAKPRESSURE 8.85 10 EQPPD-EPU, ZONE 14 TAB F1, PAGE 19 TEST(PSIG)RELATIVEHUMIDITY 100 90* EQPPD-EPU, ZONE 14 TAB F1, PAGE 73 TEST(%)__ _ _ _ _ _CHEMICAL NOT APPLICABLE NOT APPLICABLE EQPPD-EPU, ZONE 14 TAB D1, NOTE 6 NOT APPLICABLESPRAYRADIATION 1.86 E+4 (TID) 1.00 E+ 7 EQPPD-EPU, ZONE 14 TAB D1, NOTE 3 TEST(RADS)LOOP ACC. CALC:111-0002 AGING 25 YEARS* 60 YEARS* EQPPD-EPU, ZONE 14 TAB El TEST & ANALYSISSUBMERGENCE 2" NOT APPLICABLE EQPPD-EPU, ZONE 14 TAB D, NOTE 5 ANALYSISAging time is calculated from the time of installation to the time of license termination (i.e., 25 years).The testing documented a minimum of 90% humidity; however, when the differential pressure switches are installed in a sealed NEMA 4 insulated enclosure, the humidity will not increase above the90% tested value. Thus, the differential pressure switches are qualified for humidity; refer to TAB 14.
FLORIDA POWER CORPORATIONCRYSTAL RIVER UNIT 3DOCKET NUMBER 50-302 / LICENSE NUMBER DPR-72ENCLOSURE 3CR-3 ELECTRICAL FIGURES Figure 1Markup of FSAR Figure 8-2 -Electrical One Line Diagram Composite
Figure 2Isometric of 4160 V Non Segregated Bus Replacement Project
Figure 3CR 3 FSAR Figure 8-8A -Electrical One Line Diagram 250/125V DC System
Figure 4Simplified 125/250 VDC Electrical Power System Train One Line Diagram20 VDCIn VDC 125 VDCImBATTERY BATTrERYCAMCHARMEBATTERY BANK BATTERY BANKTEST JACKLI I I ,DC OUTPUT SWITCHESDC ONE CLOSED ATA TOE DBATTERYI Figure 5EFP-3 Battery System Block Diagram Figure 6Simplified EFP-3 DC Power System One Line Diagram125 VDCIBATTERYT** I* A* -lw * * -.P