Rev 1 to JPN-PSL-SENP-95-025, Engineering Evaluation,Plant Operation at 2225 Psia Nominal Operating PressureML20137L081 |
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Saint Lucie ![NextEra Energy icon.png](/w/images/9/9b/NextEra_Energy_icon.png) |
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Issue date: |
10/10/1995 |
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From: |
FLORIDA POWER & LIGHT CO. |
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Shared Package |
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ML20137K821 |
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References |
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FOIA-96-485 JPN-PSL-SENP-95, JPN-PSL-SENP-95-025, JPN-PSL-SENP-95-25, NUDOCS 9704070151 |
Download: ML20137L081 (6) |
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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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4 DEC-@7-95 THU 11343 I P1 A ORP 4074669991 P.14 C - 4 ^~ ,
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i RNGINEERING EVALUATION i
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- 2225 PSIA NOMINAL OPERATING PRES 8URE l j
4 ST LUCIE NUCLEAR PLANT UNIT 1 JPN-PSL-5ENP-95-025 i
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, DEC-07-95 THU 11349 IMAGE MGMT CORP 4074669991 P.15 g JPN-PSL-SENP-95-025 REVISION 1 PAGE 2 OF 6
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[I REVISION 1 pAGE 3 0F 6 f 1.0 PURPOFE AND DESCRIPTION i
- ' This evaluation documents an assessment of. the effects of plant operation at 2225 psia nominal RCS pressure. Plant operation isl
- typically at a nominal 2250 psia. This evaluation concludes that plant operation at 2225 psia is within the limits and analyses of the l
echnical specifications, FSAR and plant procedures, and therefore, is l acceptable for normal operation and accident conditions.
l In addition, plant operation at 2225 psia does not require changes tol the technical specifications, is not a change to the plant as described in the FSAR, and does not require changes to plant procedures as described in the FSAR, and therefore, does not require a 50.59 safety evaluation nor NRC approval.
Revision 0 documented the acceptability of plant operation at 2235 psia nominal RCS pressui*e. Revision 1 is issued to document the acceptability of plant operation down to the technical specification minimum value of 2225 paia.
2.0 TECEMICAL SPECIFICATIONS I
The technical specifications have been reviewed and operation at 2225 psia nominal RCS pressure is allowed.
Igehnical Snecificat_ ion, f2.1.1) "
The reactor core safety limit technical specification describes that for .
combinations of THERMAL POWER, pressurizar pressure and maximum cold leg I coolant temperature shall not exceed the limits shown on Figure 2.1-1 of the specification. The limits of the curve prevent overheating and the ,
i onset of DNB. The RPS in, combination with the Limiting Conditions of l operation (LCO) is designed to prevent any anticipated combination of transient conditions for reactor coolant system temperature, pressure, and thermal power level that would result in a DNBR of less than the DNBR limit and preclude the existence of flow instabilities.
Therefore, operating within the LCO limits for DNB parameters assures power operation within the safety limits. Plant operation at a pressure of 2225 psia does not adversely affect safe plant operation or safety l and is within the DNB parameters LCo.
Technical _somelfication. (3/4.2.5)
The DNB parameters technical s requires that cold leg temperature, pressurizer pressure,pecification RCS total flow rate, and axial shape index be maintained within limits.. plant operation at a pressure of 2225 psia is within the pressurizer pressure limit of 2 2225 psia.
Therefore, plant operation at a pressure of 2225 psia does not adversely affect LCo.
safe plant operation or safety and is within the DNB parameters
4 DEC-e7-95 THU 11 50 IMAGE MGMT CORP 4074669991 P.17 lf JPN-PSL-SENP-95-o25 i REVISION 1
] PAGE 4 OF 6 i
I The limits on the DNB related parameters assure that each of the l parametere are maintained within the normal steady state envelope of j; operation assumed in the transient and accident analyses.
l Taehnical specification. (5.4.11 i
4 The design features specification for RCS design pressure and
, temperature is not affected by plant operation at a pressure of 2225 l
- psia. All assumptions for design cyclic or transient limits remain valid.
- ~
l 3.0 EA&R
- The FSAR has been reviewed and operation at 2225 psia nominal RCS i l pressure is allowed. The FSAR analyses support a nominal RCS pressure l 1
- of 2225 psia for both normal operation and accident conditions. l 1
i Nominal Reactor Coolant System (RCS) pressure during steady state
{ conditions as described in various FSAR sections (Sections 1.3, 4.2, j' 4.4, S.1, 5.5, and 9.3) is 2250 psia. FSAR Table 4.4-1 (pg. 4.4-40)
- provides RCS plant thermal 1 hydraulic design parameters for nominal (steady state)and design conditions:
l Nominal (Steady State) Design Conditions l Pressure, psia 2250 2250 i 50
- , 4.0 RCS TEMPERATURE AND PRESSURE The reduction in RCS pressure from 2250 psia to 2225 psia would havel minimal effect on the RCS temperature. For the range of current temperaturesfTSoe, T,.w) the effect on RCS oT has been estimated to be less than 0.1 F. With the minimal effect on the primary temperatures, ;
the, secondary conditions would remain unchanged. '7 b'!q ,Q Mh% c'Z)f4GL D j A-5.0 ACCIDENT ANALYSES 2
~ . _ _
reduction of~the norma.
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J per& ting pressurizer pressure from 2250 psia a
,(
4 to 2225 psia does not Affae* +ha.rsan t'h=ntar is analyses.x Tn ==rety KM1yses supports nt operation in the pressurizer preiisure range of l 2225 psia to 22 psia. The value of 2225 psia corresponds to the current Technic Specification limitjar_the___ reactor _ coolant pressuia./ Plant operation at 2225 psia, therefore, does not exceed anyl system safety _ limits.
Revision 1 to this evaluation addresses operation at the technical specification limit of 2225 psia. The uncertainties used in the UFSAR accident analyses were reviewed and compared with the uncertainties of the instruments used for technical specification compliance. The accident analyses assumes an instrument uncertainty of 122 psi (Ref 10) .
The four instruments averaged (PI-1102 A,B,C & D) have an uncertainty of 14.2 psi (i.e., 24.55//3) assuming a minimum of three operable channels (Ref 6 & 11). Therefore, the uncertainty of the instruments used for
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i DEC-97-95 THU 11:51 IMAGE MGMT CORP 4074669991 P.18
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]j JPN-PSL-SENP-95-025
- REVISION 1
] PAGE 5 0F 6 i
l monitoring primary pressure is within the uncertainty assumed in the i
accident analyses. The technical specification surveillance of l pressurizer pressure is normally via Sigma indicators on the RTGB.
4 However, to ensure plant operation in compliance with the technical i specification limit, the ERDADS display of pressurizer pressure from the
- P-1102 A, B, C & D instrument loops (average of 2 3 loops) may be used to verify pressure. This digital computer based system provides j increased resolution over the analog Sigma meters.
C.0 SETPOIMT AM1 LYSES
, Operation at 2225 psia remains within the current Technical l
- Specification requirements. Protection against exceeding the Linear i Heat Rate limit (21 kw/ft) is provided by the local power density (LPD) i LSSS and LPD LCO, which are dependent on the nuclear power peaking and j core power level, but independent of the operating system pressure, and i will therefore be unaffected. The thermal margin low pressure trip
- (TM/LP) protects against the occurrence of DNB during steady state i
operation and for many, but not all (e.g. Loss of Flow and CEA Drop
- Events) Anticipated operational occurrences (A00s). The reduction in RCs operating pressure (25 psi) will provide a reduced operating margin l
- to the TM/LP setpoint. However, the TM/LP will continue to perform as i required to provide DNB protection.
4
! Similarly, the DNR LCO provides protection against DNB for transients ,
i involving changes in reactor coolant flow or changes in power peaking i which do not significantly change ASI. The~ available margin to the current LCO is dependent on the range of core operating parameters
! evaluated. The lower nominal pressure affects the allowed core power as a function of ASI which is used to verify the adequacy of the current LCO for the Cycle 13 setpoint evaluation. However, the available DNB l LCO margin of 12.9% is more than sufficient to accommodate the lower i nominal pressure because of the small sensitivity of DNE to RCS pressure changes.
j 7.0 PRESSURYSER CONTROL 1
The present instrument loops for cor. trol of pressurizer pressure have been reviewed with respect to operating at 2225 psia. Generally, thel
, system design is flexible enough that control will be the same as 2250 i psia. The proportional heaters and spray control will be modulated to
! maintain the operator selected setting. The backup heaters are energized at 2200 psia (decreasing) which is sufficiently below the 2225 psia operating setting to preclude spurious actuation and unnecessary l q cycling.
The Techaical Specification limit for minimum pressurizer pressure is 2225 psia.
j this setting at The operator least once per is required to verify that they are at or abovel 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. Since the operating setting is reduced, care must be taken channels (PT-1102A, B, C, and D) are in compliance in verifying that pressurizer pressure
- Specification limit. with the Technical l
_ . . . . ~ - . - . - . - - . . . - - . _ . . - . ~ - - . . ~ . - ~ - - - - . . - - . - - . ~ ~ . - . - ~ . . . - . - -
DEC-97-95 7HU 11:52 IMAGE MGMT CORP 4074669991 P.19 i i JPN-PEL-SENP-95-025 i/ REVISION 1 I PAGE 6 OF 6 i
j The- effect of operating at the lower pressure on the scaling calculations for pressurizer pressure and pressurizer level has been l reviewed. The effect of the lower pressure on the specific volumes is l.
insignificant und thus will have minimal impact on the results of the calculations.
j s.o prauer mustnicTroms i None l-J
, 90 mRFERENCES l
l 1. St. Lucie Unit 1 Technical Specifications, Amendnient No. 138 i
- 2. St. Lucie Unit l'FSAR, through Amendment No. 14 l 3. St. Lucie Unit 1 Safety Evaluation Report (SER) and supplements 1
& 2.
l I
- 4. System Description SD9-Rev.1 - Pressurizer Pressure and Level
- control.
i
- 5. PSL 1 Control Wiring Diagrams t
8770-B-327 Sh. 97 Rev. 14 8770-B-327 Sh. 98 Rov. 11 i
8770-B-327 sh. 124 Rev. 8 8770-B-327 Sh. 125 Rev. 7
! 8770-B-327 Sh. 126 Rev. 7 8770-B-327 Sh. 127 Rev. 7 l.
i 8770-B-327 Sh. 128 Rev. 7 8770-B-327 Sh. 129 Rev. 7 8770-B-327 Sh. 130 Rev. 15 8770-B-327 Sh. 372 Rev. 15 i 8770-B-327 Sh. 381 Rev. 16 8770-B-327 Sh. 382 Rev. 16 j 8770-B-327 Sh. 383 Rev. 12 8770-B-327 sh. 384 Rev. 12 l 6. Calculation PSL-1FJI-92-013 Rev. 1 dated 8/7/92 - St. Lucie Unit t
1 Pressuriser Pressure and Hot and Cold Leg Temperature
! Instrument Uncertainties During Normal Operation.
- 7. Calculation PSL-1FJI-93-008 Rev.1 dated 7/23/93 - St. Lucie Unit i
1 RPS/SIAS Pressurizer Pressure Uncertainty Determination (P-
{ 1102A, B, C, D).
i 8.
i Calculation Level Measurement.
19367-ICE-0612-00 Rev. O dated 1/7/79 - Pressurizer
- 9. PSL 1 Setpoint List 8770-B-470 Rev. 13.
- 10. PC/M 054-194, Cycle 13 Fuel Reload.
- 11. St. Lucie Operating Procedure 1-0110057, Rev. 17, Periodic j Surveillance of DNB Margin.
i
.l
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