Rev 0 to JPN-PSL-SENP-95-108, Engineering Evaluation, Assessment of Auxiliary High Pressure Header Piping for In-House Event Summary 95-058ML20137L141 |
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Saint Lucie |
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09/08/1995 |
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FLORIDA POWER & LIGHT CO. |
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ML20137K821 |
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FOIA-96-485 JPN-PSL-SENP-95, JPN-PSL-SENP-95-108, NUDOCS 9704070161 |
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Category:GENERAL EXTERNAL TECHNICAL REPORTS
MONTHYEARML17229B0841999-04-0707 April 1999 Rev 2 to PSL-ENG-SEMS-98-102, Engineering Evaluation of ECCS Suction Lines. ML17241A4931998-11-0101 November 1998 Statement of Account for Period of 981101-990930 for Suntrust Bank,As Trustee for Florida Municipal Power Agency Nuclear Decommissioning Trust (St Lucie Project). ML17229A7201998-05-0404 May 1998 Five Yr Population Estimates for Ten Mile Area Surrounding for St Lucie Plant. ML17229A6771998-03-27027 March 1998 Status Meeting. ML17229A4861997-09-22022 September 1997 Status Meeting. ML17229A4521997-08-14014 August 1997 Status Meeting for Units 1 & 2. ML17229A4201997-07-11011 July 1997 Status Meeting. ML17229A3901997-06-17017 June 1997 Rev 0 to ER-97-010, Preliminary Waste Characterization of St Lucie Sgs. ML17229A3701997-04-29029 April 1997 Final Analysis of Radiological Consequences of Main Steam Line Break Outside Containment for St Lucie Unit 1 Nuclear Power Plant Using NUREG-0800 Std Review Plan Section 15.1.5, App a, Rev 1 ML20137K9611997-04-0202 April 1997 Rev 0 to JPN-PSL-SENP-95-100, Letdown Pressure Controller PIC-2201 Set Pressure Reduction ML20137L0161997-04-0202 April 1997 Undated Rev 2 to JPN-PSL-SENP-95-101, Engineering Evaluation,Assessment of Effects on Plant Operation of Lifting LPSI Pump Discharge Header Thermal Relief Valve ML20137K7611997-03-25025 March 1997 Maint Rule Baseline Insp Notebook ML17229A2491997-02-21021 February 1997 Status Meeting. ML17229A1841996-12-18018 December 1996 Rev 1 to St Lucie Unit 1 Small Break LOCA Analysis w/30% SG Tube Plugging. ML20137M2121996-12-17017 December 1996 Monthly Indicator Rept, Nov 1996 ML17229A1691996-12-11011 December 1996 Status Meeting on 961211. ML17229A0931996-10-31031 October 1996 Analysis of Odscc/Iga at Tubesheet & Tube Support Locations at St Lucie Unit 1. ML20137M9261996-10-31031 October 1996 Monthly Indicator Rept ML17229A0921996-10-24024 October 1996 Steam Generator Run Time Analysis,Cycle 14, for St Lucie Unit 1 ML20137K6641996-10-18018 October 1996 Rev 1,Self Assessment for St Lucie Npp ML17229A1021996-10-17017 October 1996 Status Meeting on 961017. ML20137N1941996-10-17017 October 1996 Monthly Indicator Rept, Sept 1996 ML17229A0611996-09-30030 September 1996 Psl Self-Assessment. ML20137P4401996-09-13013 September 1996 Rev 31 to St Lucie Plant Radiological Emergency Plan ML20137K8031996-09-0404 September 1996 Evaluation of Temporary Operating Configuration w/1B Main Transformer Out of Svc,For St Lucie Np,Unit 1 ML20137K8221996-09-0303 September 1996 Evaluation of Temporary Operating Configuration w/1B Main Transformer Out of Svc,For St Lucie Np,Unit 1 ML17229A1791996-08-27027 August 1996 Rev 0 to JPN-PSL-SEES-96-059, Engineering Evaluation of Application of Thermo-Lag to Meet Rg 1.75 Requirements. ML20137L0091996-08-22022 August 1996 Rev 0 to JPN-PSL-SEIP-96-067, Engineering Evaluation,Impact of Past Incorrect Calibration of S/G Level Transmitters on Low S/G Level Trip Setpoints ML20137K9451996-07-22022 July 1996 Rev 0 to JPN-PSL-SEMS-96-051, Engineering Evaluation,2B Charging Pump Seal Leakage Evaluation ML20137N7911996-06-28028 June 1996 Scoping Document for Implementation of Maint Rule for Monitoring Effectiveness of Maint on Structures ML20137N2051996-06-14014 June 1996 Monthly Indicator Rept, May 1996 ML20137L3891996-06-10010 June 1996 Rev 0 to JPN-PSL-SENS-96-039, 10CFR50.59 Safety Evaluation, Temporary Configuration for CEDMCS Cooling Sys & Encl ML17228B5051996-05-31031 May 1996 Chapter 15 Event Review & Analysis for 30% SG Tube Plugging. ML20137L3591996-05-24024 May 1996 Rev 1 to JPN-PSL-SEIS-96-028, Safety Evaluation,Wide Range Ni Temporary Sys Alteration ML20137N2111996-05-14014 May 1996 Monthly Indicator Rept, Apr 1996 ML20137L2261996-05-11011 May 1996 Rev 2 to JPN-PSL-SEFJ-96-020, Safety Evaluation,Refueling Equipment Underload & Overload Settings ML20137L2051996-05-0808 May 1996 Rev 1 to JPN-PSL-SEFJ-96-020, Engineering Evaluation, Refueling Equipment Underload & Overload Settings ML20137L1911996-04-29029 April 1996 Rev 0 to JPN-PSL-SEFJ-96-020, Engineering Evaluation, Refueling Equipment Underload & Overload Settings ML17228B4781996-04-18018 April 1996 Plant,Status Meeting for Units 1 & 2. ML20137N2201996-04-17017 April 1996 Monthly Indicator Rept, Mar 1996 ML20137N3431996-03-29029 March 1996 Rev 0 to JPN-PSL-SEMS-96-007, 10CFR50.59 Safety Evaluation for Addition of Three Manual Isolation Valves within Rcgvs Process Vent Lines ML20137N2381996-03-19019 March 1996 Monthly Indicator Rept, Feb 1996 ML17228B4381996-03-15015 March 1996 Status Meeting for Units 1 & 2. ML20137L3461996-03-0505 March 1996 Rev 3 to JPN-PSL-SEFJ-95-023, Safety Evaluation for 1995 Boraflex Blackness Testing Results ML20137L0551996-02-22022 February 1996 Impact of Past Incorrect Calibration of SG Levels of Afas Setpoints,Rev 0. Actual Rept Number JPN-PSL-SEIP-96-068 Rev 0 ML20137R3171996-02-15015 February 1996 Rev 0 to JPN-PSL-SENS-96-003, 10CFR50.59 Safety Evaluation for Chemical & Volume Control System Operation ML17228B0231995-12-31031 December 1995 Plant Ref Simulator Certification Rept. ML20137M4161995-12-21021 December 1995 Independent Assessment of Maint Rule Implementation at Plant, 951211-15 ML20137N3661995-12-18018 December 1995 Monthly Performance Monitoring Mgt Info Rept, Nov 1995 ML20137M2041995-12-15015 December 1995 Rev 2 to JPN-PSL-SEFJ-95-023, Safety Evaluation for 1995 Boraflex Blackness Testing Results 1999-04-07
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML17241A4891999-10-0707 October 1999 LER 99-004-00:on 990912,noted That MSSV Surveillance Was Outside of TS Requirements.Caused by Setpoint Drift.Subject MSSVs Are Being Refurbished & Retested Prior to Unit Startup from SL1-16 Refueling Outage.With 991007 Ltr ML17241A4951999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for St Lucie,Units 1 & 2.With 991014 Ltr ML17241A4741999-08-31031 August 1999 Rev 1 to PCM 99016, St Lucie Unit 1,Cycle 16 Colr. ML17241A4591999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for St Lucie,Units 1 & 2.With 990913 Ltr ML17241A4301999-07-31031 July 1999 Monthly Operating Repts for Jul 1999 for St Lucie Units 1 & 2.With 990805 Ltr ML17241A4111999-07-16016 July 1999 LER 99-007-00:on 990610,unplanned Cooldown Transient Occurred Due to Personnel Error.Trained & Briefed Personnel & Revised Procedures.With 990716 Ltr ML17241A4031999-07-0606 July 1999 LER 99-006-00:on 990605,sub-critical Reactor Trip Occurred Due to Inadvertent MSIV Opening.Caused by Personnel Error. Provided Operation Supervision Instruction to Operating Crews,Stand Down Meetings & Operator Aids.With 990706 Ltr ML17241A4041999-07-0606 July 1999 LER 99-005-00:on 990604,CEA Drop Resulted in Manual Reactor Trip.Caused by Procedural Inadequacies.Procedure Changes Are Planned to Correct Lack of Procedural Guidance for CEA Subgroup Power Switch Replacement.With 990706 Ltr ML17241A4091999-06-30030 June 1999 Monthly Operating Repts for June 1999 for St Lucie,Units 1 & 2.With 990712 Ltr ML17241A3941999-06-30030 June 1999 LER 99-004-01:on 990415,as Found Cycle 10 Psv Setpoints Were Outside TS Limits.Caused by Manufacturing Process Defect. All Three Psvs Were Replaced with pre-tested Valves During Cycle 11 Refueling Outage.With 990630 Ltr ML17355A3681999-06-30030 June 1999 Revised Update to Topical QA Rept, Dtd June 1999 ML17241A3551999-06-0404 June 1999 LER 99-002-00:on 990505,both Trains of Safety Injection Actuation Were Blocked During Surveillance.Caused by Procedure Error.Procedure Revised.With 990604 Ltr ML17241A3631999-05-31031 May 1999 Monthly Operating Repts for May 1999 for St Lucie Units 1 & 2.With 990610 Ltr ML17241A3321999-05-17017 May 1999 LER 99-004-00:on 990415,determined That as Found Cycle 10 Psv Setpoints Outside TS Limits.Root Cause Under Investigation.Psvs Replaced with pe-tested Valves During Cycle 11 ML17241A3271999-05-0606 May 1999 LER 99-003-00:on 990406,ECCS Suction Header Leak Resulted in Both ECCS Trains Being Inoperable & Entry Into TS 3.0.3. Caused by Chloride Induced OD Stress Corrosion Cracking of Piping.Made Code Repairs & Coated Piping.With 990506 Ltr ML17241A3331999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for St Lucie,Units 1 & 2.With 990517 Ltr ML17229B0801999-04-0707 April 1999 LER 99-002-00:on 990311,SG ECT Error Caused Operation with Condition Prohibited by Ts.Caused by Deficiencies in Data Analysis Guideline Instructions.Licensee Will Change Data Analysis Guidelines for Lead Analysts.With 990407 Ltr ML17229B0841999-04-0707 April 1999 Rev 2 to PSL-ENG-SEMS-98-102, Engineering Evaluation of ECCS Suction Lines. ML17229B0791999-04-0707 April 1999 LER 99-001-00:on 990309,discovered Inadequate Design & IST SRs for Iodine Removal Sys (Irs).Caused by Original Design Inadequacies & Personnel Error.Naoh Tank Vent Valve V07233 Was Tagged Open.With 990407 Ltr ML17229B0961999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for St Lucie,Units 1 & 2.With 990408 Ltr ML17229B0541999-03-10010 March 1999 LER 99-001-00:on 990211,inadequate TS SRs for SIT & SDC Isolation Valves Were Noted.Caused by Failure to Correctly Implement TS Srs.Submitted LAR to Align Required TS SR with Design Bases Requirements Being Verified.With 990310 Ltr ML17229B0461999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for St Lucie,Units 1 & 2.With 990310 Ltr ML17229B0051999-01-31031 January 1999 Monthly Operating Repts for Jan 1999 for St Lucie,Units 1 & 2.With 990211 Ltr ML17229A9901999-01-20020 January 1999 LER 98-009-00:on 981223,noted That Facility Operated Outside of Design Basis.Caused by non-conservative MSLB Analysis Inputs.Will Review SR Component Differences Between Units & Will re-baseline LTOP Analysis.With 990120 Ltr ML17229A9961999-01-14014 January 1999 SG Tube Inservice Insp Special Rept. ML17229A9821999-01-0404 January 1999 LER 98-010-00:on 981207,RCS Boron Sample Frequency Required by Ts,Was Exceeded by Twelve Minutes.Caused by Personnel Error.Equipment Clearance Order Was Lifted to Draw Required Sample & Operations Procedure Was Changed.With 990104 Ltr ML17229A9831998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for St Lucie,Units 1 & 2.With 990111 Ltr ML17229A9611998-12-22022 December 1998 LER 97-002-01:on 981204,containment Sump Debris Screen Was Not IAW Design.Caused by Inadequate C/As for Sump Screen Anamolies.All Identified Sump Screen Deficiencies Were Dispositioned &/Or Repaired.With 981222 Ltr ML17229A9561998-12-15015 December 1998 LER 98-008-00:on 981118,missed TS SG U Tube Insp.Caused by Encoding Errors While Using Remote Positioning Fixtures.All SG Tube Surveyed.With 981215 Ltr ML17241A3581998-12-0909 December 1998 Changes,Tests & Experiments Made as Allowed by 10CFR50.59 for Period of 970526-981209. ML17229A9421998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for St Lucie,Units 1 & 2.With 981215 Ltr ML17229A9301998-11-25025 November 1998 LER 98-005-01:on 980807,discovered That New MOV Methodology Caused Past PORV Block Valve Operability Problem.Caused by Inadequacies in Original Vendor MOV Methodology.Planned Valve Mods Will Be Implemented During Cycle 11 1998 Outage ML17229A9021998-11-0404 November 1998 LER 98-008-00:on 981008,inadequate Reactor Protection Sys Trip Bypass TS Was Noted.Caused by Poorly Worded Ts. Submitted LAR to Clarify Power Requirements for High Rate of Power Trips.With 981104 Ltr ML17241A4931998-11-0101 November 1998 Statement of Account for Period of 981101-990930 for Suntrust Bank,As Trustee for Florida Municipal Power Agency Nuclear Decommissioning Trust (St Lucie Project). ML17229A9051998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for St Lucie,Units 1 & 2.With 981110 Ltr ML17229A8871998-10-19019 October 1998 Part 21 Rept Re Potential Defect in Swagelok Stainless Steel Front Ferrule,Part Number SS-503-1 Which Was Machined with Improper Length.C/A Includes Insp Equipment That Will 100% Identify Short Length ML17229A8781998-10-19019 October 1998 Part 21 Rept Re Potential Defect in Swagelok Stainless Steel Front Ferrule,Part Number SS-503-1,which Was Machined with Improper Length.Insp Equipment That Will 100% Identify Short Length ML17229A8771998-10-14014 October 1998 LER 98-006-00:on 980918,inadvertent Afas Actuation Was Noted.Caused by Degradation of Multiple Afas Power Supplies. Replaced Afas Power Supplies & Revised Procedures.With 981014 Ltr ML17229A8761998-10-14014 October 1998 LER 98-007-00:on 980918,identified Discrepancies Between Fire Protection Design Requirements & Field Conditions. Caused by Inadequate Translation & Implementation of Fire Protection Requirements.Procedures Revised.With 981014 Ltr ML17229A8721998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for St Lucie Units 1 & 2.With 981009 Ltr ML17229A8511998-09-0202 September 1998 LER 98-005-00:on 980807,discovered That PORV Margins Were Insufficient to Accommodate Addl Conservatism.Caused by Inadequacies in Original Vendor MOV Methodology.Will Implement Planned Valve Actuator mods.W/980902 Ltr ML17229A8611998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for St Lucie,Units 1 & 2.With 980911 Ltr 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 ML17229A8481998-08-0707 August 1998 Rev 1 to PSL-ENG-SEFJ-98-013, St Lucie Unit 2,Cycle 10 Colr. ML17229A9461998-08-0707 August 1998 Rev 0 to PCM 98016, St Lucie Unit 2,Cycle 11 Colr. ML17229A8301998-07-31031 July 1998 Monthly Operating Repts for July 1998 for St Lucie,Units 1 & 2.W/980814 Ltr ML17229A8201998-07-29029 July 1998 LER 98-007-00:on 980630,inadequate Procedure May Have Resulted in SBO Recovery Complications.Caused by Inadequate Procedures.Attached Caution Tags to Appropriate Control switches.W/980729 Ltr ML17229A7981998-06-30030 June 1998 Monthly Operating Repts for June 1998 for St Lucie,Units 1 & 2.W/980713 Ltr ML17229A7701998-05-31031 May 1998 Monthly Operating Repts for May 1998 for St Lucie,Units 1 & 2.W/980612 Ltr ML17229A7411998-05-28028 May 1998 LER 98-004-00:on 980430,discovered Waste Gas Decay Tank Operation W/O Available Oxygen Analyzers,Which Is Prohibited by Ts.Caused by Inadequate Licensee Review of License Amend. Oxygen Analyzer recalibrated.W/980528 Ltr 1999-09-30
[Table view] |
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A38E88 MENT OF AUZILIARY NIGE PRES 8URE j .
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i TITLE ASSES $NENT OF THE AUXILIARY ~ HIGH PRES $URE HEADER PIPING FOR IN-HOUSE EVENT l
SUMMARY
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i i SECTION TITLE P.AftE
-- Cover 1
-- Review and Approval Record 2 l
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-- Table of contestts 3 j
i j 1.0 Purpose and Description 4 i 4
! 2.0 Background 3.0 Design Bases 4 4.0 Analyses of the Event 5 5.0 Conclusions 6 i '
Verification Summary 6 6.0 References 7 1, 7.0
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JPN-FS'-5ENP-95-102 REVISICN O PAGE 4 CF 7 1.0 PURPCSE AND DESCRIPTICE The purpose of this evaluation is to assess the impact on plant operation and safety associated with pressurizing the auxiliary j high pressure header piping (from the 1A HPSI pump to HCV-3617, 3627, 3637, and 3647) to HPSI pump shutoff head, with RCS l temperature below 236 *F. The plant Technical Specifications restrict HPSI pump operation when RCS temperature is below 236 F. Technical Specification 3.5.3 requires that all high j pressura rsfety injection pumps be disabled and their associated header stop valves closed prior to RCS temperature decreasing r
below this value (References 3 and 2), except as allowed by l l
Specifications 3.1.2.1 ana 3.1.2.3.
2.0 sacIGROUND on September 2, 1995, it was determined that Technical Specification 3.5.3 had been violated when the header stop valve was used to fill and vent the auxiliary high pressure header, and when the 1A HPSI pump was used to perform an in-service leak test of safety relief ~ valve V-3417. The relief valve was being leak i tested to satisfy post-modification testing associated with l relief valve replacement. (Reference 1)
The 1A HPSI pump was started and run with the header stop valve ;
open to perform an in-service leak test. The four injection valves (HCV-3617, 3627, 3637, and 3647) remained closed during_
the event. The pressurizer was controlling RCS pressure with a steam bubbit assurizer liquid ' eval was approximately 50%,
both PORVs war. available for RCS overpressure protection in the l LTOP mode. RCS pressure was 250 psia, and RCS temperature was l
I approximately 120 *F.
Technical Specification 3.5.3.c requires that both HPSI pumps be disabled, and their associated stop valves closed, to provide additional administrative assurance against exceeding the RCS pressure / temperature limits during a mass addition transient (Reference 2, mitigated by a single PORV, when below 236 *F.
Section 3/4.5.3 and Bases)
This engineering evaluation involves an engineered safeguards system and is therefore classified as safety related.
3.0 DESIGN BASE 3 RETIEW Auviliary Hieh h =mure Header Pinine and valves The auxiliary high pressure header must passively maintain the integrity of the HPSI system pressure boundary (Reference 3).
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This fur.ction is acensplished by selecting a design pressure
! rating that is consistent with the maximum, sustained, service conditions expected .Nring normal and post-acciaent operation.
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JPN-FSL-CEWi-95-108
- REVIS!CN O PAGE 5 OT 7 HPST 1A Header Isolation Valves HCV-3617 3627 3637 and ?647 ,
The HPSI 1A header isolation valves must perform the following functions in addition to maintaining pressure boundary integrity l
(Reference 3): ,
- 1. Shall automatically open on a safety injection actuation to '
l admit HPSI purp flow to the associated RCS loop. _
- 2. Shall control HPSI flow to the' associated RCS loop. Changes to the valve positions necessary to control the HPSI flows are performed manually, fr om the control room.
- 3. Shall remain closed during normal plant operation to provide a redundant containment isolation barrier for penetration numbers 36, 37, 38, and 39.
- 4. Shall close remote-manually to provide a redundant containment isolation barrier for penetration numbers 36, 37, 38, and 39, in the event of a passive failure or malfunction in the safety injection system.
- 5. Shall manually open to allow filling the safety injection tanks using the HPSI pumps or the charging pumps.
RCS Low Temoerature Overoressure Protection (LTOP)
Overpressure protection of the reactor coolant system during low temperature condirians is provided' by power operated relief valves (PORVs) N- and V-1404 connec.ed to the pressurizer steam space.
The LTOP setpoints are estSblished to ensure 'ihat RCS overpressurization will not occur from mass or energy addition events. The current LTOP analysis is described in Reference 4.
4.0 ANALYSIS OF THE EVENT The 1A HPSI pump pressurized the auxiliary high pressure header to HPSI pump shutoff head during the leak tes*. The design shutoff head of the Unit 1 HPSI pumps is approximately 1250 psig (Reference 3). The following discussions form the bases for assessment of safety associated with operating the NPSI pump for in-service leak testing, with RCS temperature below 236 F.
Intearity of the Auxiliarv Hiah Pressure Header The piping and valves in this portion of the RPSI system are designed to accommodate charging pump flow through the auxiliary high pressure header for SIT outlet checPAs valve testing, and to such, the piping provide an alternate charging flow path.
system is rated for 2485 sig; consistent with the RCS pressure boundary (Reference 3). This design pressure rating is much higher than the HPSI pump ahutoff head. This piping is not
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.: rN- P S L-S r.' P - 9 5 - 1 C S REVISION C PAGE 6 OF 7 subject to neutron embrittlement, thermal stratification, er other pressurized thermal shock (PTS) concerns. Thus, code allowable stress limits were not exceeded during the in-service test.
HCV-3617. 3627. 3637. 3647 Oeerability These globe valves are oriented such thrat the normal injection flow path results in flow under the valve seat (Reference 3, Sections 7.9.2c and 7.8.2c) . High upstream pressures will not drive, or wedge, the valve disc into the valve seat, or challenge the stem packing. As a rescit, valve operability is not affected by the pump shutoff head.
RCS Low Temnerature Overeressure Protection Valves HCV-3617, 3627, 3637, and 3647 remained closed during the In addition, the fill and vent procedure and the leak test.
automatic SIAS function was bypassed and in the blocked mode.
Under these conditions, an inadvertent SIAS event is not considered credible. There was no adverse impact on RCS temperature / pressure limits. The header isolation valves performed their isolation function and there was no mass or energy addition to the RCS as a result of the alignment.
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5.0 CONCLUSION
S This evaluation mmonstrates that the piping, fittings, and I a j
valves in th6 iary high pressura header _were not affected by i
the alignment, and that code allowable stress limits were not exceeded in the leak test boundary. In addition, there was no l challenge to the RCS 1cs temperature overp essure protection function. Therefert, this event did not adversely impact plant
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1 l 6.0 VERTFTc1 TION StnOOLRY f
The scope of this verification was to review the inputs to dataraine if the results were reasonable. The method used for i this verification consisted of ensuring that the applicable i
references, codes, and regulatory requ:xements were identified and addressed. The inputs are correctly selected and applied.
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The conclusions provided are reasonable with respect to the inputs and discussions. The verifier concurs with the Nuclear safety Related classification of this Engineering Evaluation. The
,' rationale in assigning the safety classification was verified The against the requirements of JPN Quality Instructions.
verifier concurs with the conclusions outlined above.
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IT.* : C I C . . O PACE 7 CF 7 l 7.0 R!??RENCES i
- 1. STA In-House Event Summary (IHE) Number 95-058, dated 9/3/95 j (Preliminary)
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i 2. St. Lucie Unit 1 Technical Specifications, Amendment No. 138 St. Lucie Unit 1 Design Basis Document No. DBD-HPSI-1, High )
) 3.
Pressure Safety Injection System, Revision 0
! FPL Letter to the NRC L-89-408 dated December 5, 1989, Proposed 4.
j License Amendment P-T Lirits'and LTOP Analysis ,
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