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Category:GENERAL EXTERNAL TECHNICAL REPORTS
MONTHYEARML20207L0451999-01-0808 January 1999 Cost-Benefit Risk Analyses:Radwaste Sys for Light Water Reactors ML20248B7341998-05-27027 May 1998 Rev 1 to ES199800777, Engineering Evaluation ML20217P3191998-01-28028 January 1998 Rev 7 to Ccnpp Emergency Action Levels Technical Basis Document ML20135F4741997-03-0606 March 1997 Emergency Action Levels Technical Basis Document, Rev 5 ML20116L9871996-07-25025 July 1996 Portions of Diesel Fuel Oil Sys License Renewal Technical Rept, Written for License Renewal Technical Rept Template Phase 2 Development ML20116L9651996-07-25025 July 1996 Entire Feedwater Sys License Renewal Technical Rept, for License Renewal Technical Rept Template Phase 2 Development ML20116L9481996-07-25025 July 1996 Draft Template of License Renewal Technical Rept ML20116L9761996-07-25025 July 1996 Portions of Component Supports License Renewal Technical Rept, Written for License Renewal Technical Rept Template Phase 2 Development ML20116L9701996-07-25025 July 1996 Portions of Structures License Renewal Technical Rept, Written for License Renewal Technical Rept Template Phase 2 Development ML20117K9691996-06-30030 June 1996 Fitness for Duty Program Performance Data Personnel Subj to 10CFR26, for Period Ending 960630 ML20113E3491996-05-31031 May 1996 USI A-46 Seismic Evaluation ML20112C0201996-05-21021 May 1996 Rev 2 to Aging Mgt Review Rept for Auxiliary Bldg, Final Rept ML20112C0421996-05-21021 May 1996 Rev 2 to Aging Mgt Review Rept for Component Supports ML20112B9701996-05-21021 May 1996 Rev 1 to Aging Mgt Review Rept for Rms (077/079) ML20112C0031996-05-20020 May 1996 Rev 2 to Aging Mgt Review Rept for Turbine Bldg, Final Rept ML20112C0241996-05-20020 May 1996 Rev 3 to Aging Mgt Review Rept for Containment Structure (Sys 059), Final Rept ML20112B9791996-05-20020 May 1996 Rev 2 to Aging Mgt Review Rept for Condensate Storage Tank 12 Enclosure, Final Rept ML20112B9951996-05-20020 May 1996 Rev 2 to Aging Mgt Review Rept for Fuel Oil Storage Tank 21 Enclosure, Final Rept ML20112C0111996-05-20020 May 1996 Rev 2 Aging Mgt Review Rept for Intake Structure, Final Rept ML20112C0361996-05-0909 May 1996 Rev 1 to Aging Mgt Review Rept for Containment Sys (059) ML20112B9641996-05-0101 May 1996 Rev 1 to Aging Mgt Review Rept for Diesel Fuel Oil Sys (023) ML20112B9741996-05-0101 May 1996 Rev 1 to Aging Mgt Review Rept for MFW Sys ML20101J6721996-03-24024 March 1996 Travelers Under Owners Group Vs TSTF Consideration by Needed Date ML20100G1131996-01-31031 January 1996 Rev 3 to Ccnpp EALs Technical Basis Document ML20096D7321996-01-11011 January 1996 Integrated Plant Assessment Methodology, Rev 1 ML20117K9871995-12-31031 December 1995 Rev 2 to Fitness for Duty Program Performance Data Personnel Subj to 10CFR26, for Period Ending 951231 ML20100Q4831995-12-15015 December 1995 1995 Unit II RFO SG 22 All Call Listing ML20113E3551995-11-30030 November 1995 USI A-46 Relay Evaluation ML20087K7921995-08-18018 August 1995 Rev 0 to Calvert Cliffs Nuclear Power Plant Integrated Plant Assessment Methodology ML20086S9221995-07-17017 July 1995 Best Estimate Chemistries for Calvert Cliffs Reactor Vessel Beltline Welds, Rev 1 ML20100Q3291995-05-12012 May 1995 1995 Unit II RFO Steam Generator 21 All Call Listing ML20077M8271995-01-10010 January 1995 Simulator Four-Yr Certification Rept ML20076F8851994-10-13013 October 1994 Probabilistic Risk Assessment Evaluation of Tornado- Generated Missile Impact on Ccnpp EDG Engine Air Intake & Exhaust ML20058G1751993-11-30030 November 1993 Application of Reactor Vessel Surveillance Data to Calvert Cliffs Unit 1 ML20059F8901993-10-15015 October 1993 Nonproprietary Version of Calvert Cliffs Nuclear Power Plant,Unit 1 & 2 Pressurizer Inconel 600 Sleeve Nozzle SAR for Alternative Roll/Plug Repairs ML20056F9881993-08-25025 August 1993 Instrumentation & Control Sys Design Rept, for Emergency Diesel Generator Project ML20046B1541993-07-26026 July 1993 Rev 0 to Electrical Engineeing Design Rept,Edg Project. ML20046A4781993-06-15015 June 1993 Rev 0 to Emergency Action Levels Technical Basis Document. W/Two Oversize Encls ML20056C2521993-05-0101 May 1993 Integrated Plant Assessment Methodology,Vol 2:Component Evaluation ML20064D4081993-03-31031 March 1993 SGs 21 & 22 Eddy Current Testing Final Rept Mar 1993 ML20044C2061993-03-0808 March 1993 Component Level Itlr Screening Results for Reactor Coolant Sys. ML20044C2401993-02-23023 February 1993 Component Level Itlr Screening Results for Containment Sys. ML20126D7051992-12-18018 December 1992 Rev 0 to Civil Engineering Design Rept EDG Project ML20044C2411992-09-30030 September 1992 Component Level Itlr Screening Results for Compressed Air Sys. ML20044C2451992-09-23023 September 1992 Component Level Itlr Screening Results for Salt Water Cooling Sys. ML20066D7871991-01-0707 January 1991 Simulator Certification NRC Submittal Document for Plant Ref Simulator at Calvert Cliffs Nuclear Power Plant ML20058A4781990-06-30030 June 1990 Final Rept on Reactor Vessel Pressure-Temp Limits for Calvert Cliffs Unit 2 for 12 Efpys ML19332B6061989-10-31031 October 1989 Final Rept Low Temp Overpressure Protection Pressure Temp Limits for Calvert Cliffs Unit 1. ML20247R0881989-09-18018 September 1989 Basis for Determination:Unit 1 Safe Operation Re Unit 2 Pressurizer Heater Sleeve Leakage ML19332B6081988-12-31031 December 1988 Final Rept Pressure Temp Limits for Calvert Cliffs Nuclear Power Plant Unit 2. 1999-01-08
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217G6971999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for Calvert Cliffs Npp,Units 1 & 2.With ML20216J8731999-09-10010 September 1999 Rev 52 to QA Policy for Calvert Cliffs Nuclear Power Plant ML20212A4441999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Ccnpp,Units 1 & 2. with ML17326A2011999-08-23023 August 1999 LER 99-004-00:on 990724,reactor Tripped Due to Main Transformer Bushing Flashover.Plant Was Brought to SS & Components Were Tested & Performed Satisfactorily.With 990823 Ltr ML20210S6091999-07-31031 July 1999 Monthly Operating Repts for July 1999 for Ccnpp,Units 1 & 2. with ML20210N6001999-07-27027 July 1999 ISI Summary Rept for Calvert Cliffs Unit 2. Page 2 of 3 in Encl 1 of Incoming Submittal Not Included ML20210B7941999-07-15015 July 1999 SER Denying Licensee Request for Changes to Current Ts,Re Deletion of Tendon Surveillance Requirements for Calvert Cliffs LD-99-039, Part 21 Rept Re Defect of Abb 1200A 4kV Vacuum Breakers. Initially Reported on 990625.Defect Results in Breaker Failing to Remain in Closed Position.Root Cause Evaluation & Corrective Action Plan Being Developed.Licensee Notified1999-06-30030 June 1999 Part 21 Rept Re Defect of Abb 1200A 4kV Vacuum Breakers. Initially Reported on 990625.Defect Results in Breaker Failing to Remain in Closed Position.Root Cause Evaluation & Corrective Action Plan Being Developed.Licensee Notified ML20209F1721999-06-30030 June 1999 Monthly Operating Repts for June 1999 for Calvert Cliffs Npp.With LD-99-035, Part 21 Rept Re Abb 1200A 4KV Vacuum Breakers Performing Trip Free Operation When Close Signal Received by Breaker. Defect Results in Breaker Failing to Remain in Closed Position.Root Cause & CAP Being Developed1999-06-25025 June 1999 Part 21 Rept Re Abb 1200A 4KV Vacuum Breakers Performing Trip Free Operation When Close Signal Received by Breaker. Defect Results in Breaker Failing to Remain in Closed Position.Root Cause & CAP Being Developed ML20196C6981999-06-21021 June 1999 Safety Evaluation Concluding That Use of ASME Section XI Code Including Summer 1983 Addenda as Interim Code for Third 10-year Insp Interval at Calvert Cliffs Units 1 & 2 Until Review of 1998 Code Completed,Would Be Acceptable ML20195K2811999-05-31031 May 1999 Monthly Operating Repts for May 1999 for Ccnpp,Units 1 & 2. with ML20206R5871999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for Ccnpp,Units 1 & 2. with ML20195B3891999-04-30030 April 1999 0 to CENPD-279, Annual Rept on Abb CE ECCS Performance Evaluation Models ML20205N2951999-04-13013 April 1999 Special Rept:On 990314,fire Detection Sys Was Removed from Svc to Support Mod to Replace SRW Heat Exchangers in Unit 2 SRW Room During Unit 2 Refueling Outage.Contingency Measure 15.3.5.A.1 Will Continue Until Fire Detection Sys Restored ML20210T5211999-04-0101 April 1999 Rev 0 to Ccnpp COLR for Unit 2,Cycle 13 ML20205P5441999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for Calvert Cliffs Nuclear Power Plant,Units 1 & 2.With ML20204H6471999-03-21021 March 1999 SER Re License Renewal of Calvert Cliffs Nuclear Power Plant,Units 1 & 2 ML20207M8321999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for Calvert Cliffs Nuclear Power Plant.With ML20203D4311999-02-0505 February 1999 Safety Evaluation Accepting Procedure Established for long-term Corrective Action Plan Related to Containment Vertical Tendons ML20199G4671999-01-20020 January 1999 SER Accepting USI A-46 Implementation for Plant ML20206Q3221999-01-11011 January 1999 Special Rept:On 981226,wide Range Noble Gas Effluent RM Was Removed from Operable Status.Caused by Failure of mid-range Checksource to Properly Reseat.Completed Maint & post-maint Testing & RM Was Returned to Operable Status on 990104 ML20207L0451999-01-0808 January 1999 Cost-Benefit Risk Analyses:Radwaste Sys for Light Water Reactors ML20199F4781999-01-0808 January 1999 Safety Evaluation Concluding That Bg&E Performed Appropriate Evaluations of Operational Configurations of safety-related power-operated Gate Valves to Identify Valves Susceptible to Pressure Locking.Concludes GL 95-07 Actions Were Addressed ML20198S7591999-01-0707 January 1999 SER Accepting Quality Assurance Program Description Change for Calvert Cliffs Nuclear Power Plant,Units 1 & 2 ML20207M2281998-12-31031 December 1998 1998 Annual Rept for Bg&E. with ML20199E2931998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for Calvert Cliffs Npp. with ML20206R9911998-12-0808 December 1998 Rept of Changes,Tests & Experiments (10CFR50.59(b)(2)). with ML20198B2631998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for Calvert Cliffs Nuclear Power Plant,Units 1 & 2.With ML20195H1001998-11-16016 November 1998 Safety Evaluation of First Containment Insp Interval Iwe/Iwl Program Alternative ML20196E2211998-10-31031 October 1998 Non-proprietary Rev 03-NP to CEN-633-NP, SG Tube Repair for Combustion Engineering Designed Plant with 3/4 - .048 Wall Inconel 600 Tubes Using Leak Limiting Alloy 800 Sleeves ML20195E5281998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for Calvert Cliffs Nuclear Power Station,Units 1 & 2.With ML20154Q7191998-10-21021 October 1998 Special Rept:On 980923,unit 1 Wrngm Was Removed from Operable Status.Caused by Failure of Process Flow Transducer.Completed Maint to Remove Process Flow Transducer Input to Wrngm Microprocessor & Completed Formal Evaluation ML20154G3931998-10-0505 October 1998 Safety Evaluation Concluding That Flaw Tolerance Evaluation for Assumed Flaw in Inboard Instrument Weld of Pressurizer Meets Rules of ASME Code ML20154M5841998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for Calvert Cliffs Nuclear Plant,Units 1 & 2.With ML20153C2571998-09-18018 September 1998 Special Rept:On 980830,wide Range Noble Gas Monitor (Wrngm) Channel Was Removed from Operable Status.Caused by Need to Support Performance of Required 18-month Channel Calibr.Will Return Wrngm to Operable Status by 980925 ML20153C1091998-09-18018 September 1998 Part 21 Rept Re Defective Capacity Control Valves.Trentec Personnel Have Been in Contact with Bg&E Personnel Re Condition & Have Requested Potentially Defective Valves ML20151U5441998-09-0404 September 1998 Bg&E ISI Summary Rept for Calvert Cliffs ML20151T5281998-09-0101 September 1998 Special Rept:On 980819,declared Rv Water Level Monitor Channel a Inoperable.Caused by Failure of Three Heated Junction Thermocouples (Sensors) in Lower Five Sensors. Channel a & B Rv Water Level Probes Will Be Replaced ML20151Y1191998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for Calvert Cliffs Nuclear Power Plant Units 1 & 2.With ML20237D4981998-08-19019 August 1998 Safety Evaluation Accepting Licensee Request for Extension of Second ten-year Inservice Insp Interval ML18066A2771998-08-13013 August 1998 Part 21 Rept Re Deficiency in CE Current Screening Methodology for Determining Limiting Fuel Assembly for Detailed PWR thermal-hydraulic Sa.Evaluations Were Performed for Affected Plants to Determine Effect of Deficiency ML20237B9371998-07-31031 July 1998 Monthly Operating Repts for July 1998 for Calvert Cliffs Nuclear Power Plant ML20237D5941998-07-22022 July 1998 Rev 2 to Ccnpp COLR for Unit 2,Cycle 12 ML20236L7521998-07-0606 July 1998 Safety Evaluation Granting Bg&E 980527 Request for Relief from Requirement of Section IWA-5250 of ASME Code for Calvert Cliffs Unit 2.Alternatives Provide Reasonable Assurance of Operational Readiness ML20236F7791998-06-30030 June 1998 Safety Evaluation Authorizing Request for Temporary Relief from Requirement of Subsection IWA-5250 of ASME Code,Section XI for Plant,Unit 1 ML20236R0881998-06-30030 June 1998 Monthly Operating Repts for June 1998 for Calvert Cliffs Nuclear Power Plant,Units 1 & 2 ML20236X3101998-06-19019 June 1998 Rev 1 to Calvert Cliffs Nuclear Power Plant COLR for Unit 2,Cycle 12 ML20249A9571998-06-15015 June 1998 Special Rept:On 980430,fire Detection Sys Was Removed from Svc to Support Mod to Purge Air Sys 27-foot Elevation & 5-foot Elevation East Piping Penetration Rooms.Installed Temporary Alteration & Returned Fire Detection Sys to Svc ML20249A7711998-05-31031 May 1998 Monthly Operating Repts for May 1998 for Ccnpp,Units 1 & 2 1999-09-30
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ATTACHMENT (1) 1 ENGINEERING EVALUATION ES199800777, Revision No. I l
4 l
1 9906010370 980527 PDR ADOCK 05000318' p PDR Baltimore Gas and Electric Company Calvert Cliffs Nuclear Power Plant May 27,1998 l
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ATTACIIMENT 24, ENGINEERING EVALUATION ESP No.: ES199800777 Supp No. 000 Rev. No. 0001 Page 1 of 4
' REASONS FOR ENGINEERING EVALUATION:
Issue Report IR3-002-371 documents that crosion has caused a thru-wall opening at a 1" NPS half-coupling in the Salt Water System. This half-coupling is utilized for instrument 2-SW-5205-Tl which is located on the salt water inlet piping (Line No. 24"LJ-1-2009) leading to No. 21 Component Cooling Water Heat Exchanger. Specifically, the crosion has occurred at the toe of the fillet weld of the half-coupling.
Leakage of the subject half-coupling was also detected during the 1997 RFO (Ref. Issue Report IRI-050-986).
MEU evaluated this condition, and concluded that it was acceptable; however, repair of the leaking half-coupling during the refueling outage was rcquired to meet Generic Letter 91-18 requirements, and therefore, the evaluation was only written to be valid for Modes 5,6, and Defueled. The leak is now occurring during power operation; therefore, the evaluation must be expanded to include Mode 1 Conditions. Also, based on MEUs interpretation of the NDE Inspection Report, erosion is now being detec'ed on the header pipe itselfin the area near the half-coupling. The affcct of the expanded area of crosion on the stnictural integrity of the SSC must be assessed.
This Evaluation is valid for all modes.
DESCRIPTION OF CIIANGE(S):
This evaluation provides rationale that the 24"LJ header pipe integrity is not compromised, that the consequences ofleakage are acceptable.
DETAILED EVALUATION OF CIIANGE(S):
A. Structural Intecrity This section of the evaluation documents that the 24"LJ header pipe integrity is not compromised by the thru wall crosion.
Analysis Methodology Paragraph 104.3.1 of ASME B31.1-1967 discusses requirements for branch connections. The concern is that a pipe having a branch connection is weakened by the hole made in it. In order to compensate for this opening, additional metal around the hole, referred to as reinforcement, is required.
When a half coupling is used, the metal provided by this fitting is automaticallyjudged to provide ad equate reinforcement so no calculational evidence is required to dxument that adequate reinforcement exis s (Ref. ASME B31.1-1967, para.104.3.l(c)2.). However, in the situation addressed in this issue report, erosion hat gone through the wall completely at one point, and significant erosion around the entire half-coupling circumference at that axial location is suspected as well. Therefore, it is not appropriate to credit the reinforcement provided by the half coupling.
As a result, an analysis will be performed to show that even if the half coupling were not present, there is still adequate reinforcement available from the adjacent pipe wall thickness to satisfy the ASME B31.1 reinforcement requirements. j The reinforcement calculation approach was chosen since it provides a reasonable means of assessing the impact of the through-wall defect on the structural integrity of the flawed piping, given the geometry of the flawed area and the mechanism of the flaw initiation. The reinforcement calculation method was chosen over the "through-wall flaw" and " wall thinning" approaches outlined in NRC GL 90-05 since these methods do not address the presence l of the half-coupling opening in the pipe. The " wall thinning" approach would be appropriate for the l erosion / corrosion based type of flaw addressed by this evaluation; however GL 90-05 does not allow its use for through wall flaws. The "through-wall" approach is fracture mechanics based, but the proximity of the flaw to the I
i
ATI'ACHMENT 24, ENGINEERING EVALUATION ESP No.: ES199800777 Supp No. 000 Rev.No. 0001 Page 2 of 4 half-coupling and the corrosion-based nature of the flaw do not support direct application of this method.
Reinforcement Analysis Required reinforcement (in square inches) for a branch connection at a right angle to the header pipe, per ASME B31.1-1967 para 104.3(d)2.(b), is given by:
required reinforcement = 1.07
- d i where ta = required wall thickness of the header pipe d i = 1.78" (ANSI B16.11 - 1980, Table 4) Note that the although the diameter for a 1" half coupling is 1.049",1.78" is consenstively assumed to be the OD of a 1" half coupling. This will consenatively account for header pipe erosion. _
From para 104.1.2(a), the formula for minimum required pipe wall thickness is:
ta = (P
- D. ) / 2 [ SE + 0.4P ] + A where P = 50 psig (Ref M-601 for LJ-l Pipe Class)
D. = 24" (Re. Tube Turns, page B19)
SE = 12,800 psi (Ref ASME B31.1, assuming A-53 welded pipe)
A = 0.0091
- 3 = 0.0273 square inches Note that A is calculated based upon the following. There was a similar occurrence on this section of the header during the 1997 Unit 2 RFO. A UT was performed and found that the minimum wall thickness was 0.389 inches.
A UT was performed this outage, and the minimum wall thickness was found to be 0.280 inches. This is a reduction of 0.109 inches in 12 months, which results in an crosion rate of 0.0091 inches / month. Replacement of the header spool piece is scheduled for early July. Assuming a 3 month further erosion, the w211 thickness is calculated as:
ta = (50
- 24 ) / 2 [ 12800 + 0.4(50) ] + 0.0273 (0.0091
- 3 = 0.0273 inches) ta = 0.G741 inches Therefore, the value for the required reinforcement area is:
1.07
- 1.78 = .142 square inches Available reinforcement (in square inches) for excess pipe wall thickness in the header pipe is 6i ven by (refer to ASME B31.1-l%7 para 104.3(d)2.(c)) ,
A1 = d2 (T6 - ta ) l where di = half width reinforcing zone and is the greater of di and Tb +Th + d i /2 d2= 1.049, the inside diameter of a 1" half coupling ta = 0.0741 (calculated above)
Th = nominal wall thickness,0.280 inches Therefore, A1 = 1.049" (0.280" - 0.0741") = 0.215 square inches Since the available reinforcement area without the half coupling (0.215 square inches) is greater than the required reinforcement area (0.142 square inches), the header pipe qualification is not adversely impacted by the eroded half coupling. Note that this evaluation is good for three months after the date of this evaluation.
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ATTACHMENT 24, ENGINEERING EVALUATION ESP No.: ES199800777 Supp No. 000 lRev.No. 0001 Page 3 of 4
. B. Leak Rate Computation.
Evaluation of the safety significance of the leakage detected on the half-coupling requires that the worst case leak rate which might develop be computed. The worst-case leak rate is computed by assuming the entire half-coupling I
crodes away. The outside diameter of the half-coupling (1.78 inches per ANSI B16.11-1980, Table 4) is therefore assumed to be the diameter of the leak opening from the salt water system.
Though evidence of crosion on the salt water header pipe is indicated by the ultrasonic examinations of the pipe there is still a minimum of 0.280 inches of wall-thickness intact. Also, as seen in reinforcement calculation performed above, even if the erosion of the header pipe is assumed to continue there is still adequate wall-thickness to maintain structural integrity of the header pipe.
The following equations are used to calculate the flow from a square edged orifice in a pipe wall (Crane Technical paper 410, eq. 3-21).
Q = 236 di ' C (AP/p )in C = Ca/ (1-p')"'
p = di / d2 where Q = Volumetric Flowrate (gpm) di = Inside diameter of Orifice d2= Inside Diameter of Header Piping C = Orifice Flow Coefficient C4 = Discharge Coefficient of the Orifice The header pipe is 24" W pipe (wall thickness = 0.375") therefore 2d is 23.25 inches. With di equal to 1.78 inches it is seen that p is 0.08. Using the figure provided on page A-20 of Crane, and assuming turbulent flow the Orifice Flow Coefficient is 0.6. The minimum density occurs at the maximum temperature (90?F) and is 62.116 lbm/ft'. Conservatively using the design pressure of Class U pipe ( 50 psig) as the driving pressure through he orifice yields the following worst-case flowrate:
Q = 236 (1.78)2 (0.6) (50 / 62.I16)"' = 402.52 a 403 gpm !
l This flow rate is a conservative estimate of the worst-case leakage that could result from a complete failure of the 1" NPS half-coupling at 2-SW 5205-TI.
C. Flooding Imnact.
BGE Calculation No. M-90-173, Rev. O evaluates the potential for flooding the Unit 1 & 2 CCW pump Rooms (Room Nos. 201 & 208). This calculation shows that the worst-case direct flooding results from a critical crack in a 14" Safety i Section Line concurrent with fire protection actuation. This event results in a flowrate of approximately 2852.0 gpm. The evaluations per rormed in conjunction with the development of ES-001 Rev. O
" Flooding" demonstrate that no safety-related equipment in the CCW Room or any other room would be impacted
.o ATTACHMENT 24. ENGINEERING EVALUATION ,
ESP No.: ES199800777 Supp No. 000 Rev.No. 0001 Page 4 of 4 by this event. Therefore, the 403 gpm leakage resulting from the complete failure of the 1" NPS half-coupling is bounded by existing evaluations.
D. Imoact on Component Cooling Water (CCW) Heat Exchaaer Performance.
The CCW heat exchangers use Salt Water to remove heat from the Component Cooling Water svstem. During normal plant operation only one heat exchanger is required for cooling service; hewever, during the post-R AS phase of a lhCA, both CCW heat exchangers are assumed to be available. The impact of a 403 gpm salt water
!- leak (computed above for complete loss of half-coupling) in the supply header to one of the beat exchangers is evaluated for its impact on heat removal from the Component Cooling Water System during the post-RAS phase of aLOCA.
~
As described in Section 9.5.2.3 of the UFSAR, salt water flow to the CCW heat exchangers is throttled post-RAS, and this action is prescribed in step V.I.c.(2) of EOP-5 (" Loss of Coolant Axident"). The minimum flow per header pre-RAS is found from Section 9.5.2.3 to be 17,230 gpm (16,830 + 400) while the nummum post-RAS header flow is 15,400 gpm (9,500 + 400 + 5,500). From this it is seen that the salt water flow is throttled approximately 1830 gpm, and therefore, a salt water leak of approximately 403 gpm can be recovered by reducing the amount of throttling. The amount the Salt Water flow is to be throttled is already based on Operator action as seen in Step V.I.k of EOP-5 which instructs that the Salt Water flow to be adjusted to maintain a Component Cooling water flow of 120'F, or less. Therefore, the operators will be adjusting salt water flow to maintain CCW System temperature. Any salt water leakage can be compensated for by increasing the salt water flow prosided the leak rate doesn't exceed the total amount the flow had been throttled. As shown above there is plenty of margin between these two values (403 vs 1830 gpm).
E. Potential loss of Tenuereture Ind%tian.
2-SW-5205-Tl provides local SW inlet temperature indication for 21 CCW heat exchanger. This parameter is not critical to the safe operation of either the SW or CCW systems. The primary indication of SW inlet temperature is from CW001, in addition there are alternate indications of SW inlet temperature from the SRW heat exchangers and No. 22 CCW heat exchanger. As a result the potential loss of temperature indication due to the failure of this Tl does not present a safety concern.
F. Eauioment Soravdown.
The effect of spray on nearby equipment will not impact safety related functions. This is based on the limited number of components in the vicinity (2SW-5260 limit switches, 2SW5173 solenoid, accumulator for 5174), and the low driving pressure (30 psig) out of the orifice.
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