ML18102A761

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Monthly Operating Rept for Dec 1996 for Salem Unit 2. W/970115 Ltr
ML18102A761
Person / Time
Site: Salem PSEG icon.png
Issue date: 12/31/1996
From: GARCHOW D F, HELLER R
Public Service Enterprise Group
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
NUDOCS 9701220284
Download: ML18102A761 (12)
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  • Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038-0236 Nuclear Business Unit U. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 Attn.: Document Control Desk MONTHLY OPERATING REPORT SALEMNO. 2 DOCKET NO: 50-311 January 15, 1997 In compliance with Section 6.9.1.6, Reporting Requirements for the Salem Technical Specifications, the original copy of the monthly operating report for the month of December is being sent to you. RH:pc Enclosures C Mr. H. J. Miller David F. Garchow General Manager -Salem Operations Regional Administrator USNRC, Region I 475 Allendale Road King of Prussia, PA 19046 220034 ' . 9701220284 961231 PDR ADOCK 05000311 R PDR The power is in your hands. 95-2168 REV. 6/94
  • OPERATING DATA REPORT
  • Docket No: Date: Completed by: Robert Phillips Telephone:

Operating Status 1. Unit Name Salem No. 2 Notes 2. Reporting Period December 1996 3. Licensed Thermal Power (MWt) 3411 4. Nameplate Rating (Gross MWe) 1170 5. Design Electrical Rating (Net MWe) 1115 6. Maximum Dependable Capacity(Gross MWe) 1149 7. Maximum Dependable Capacity (Net MWe) 1106 8. If Changes Occur in Capacity Ratings (items 3 through 7) Report, Give Reason NA 9. Power Level to Which Restricted, if any (Net MWe) 10. Reasons for Restrictions, if any 11. Hours in Reporting Period 12. No. of Hrs. Rx. was Critical 13. Reactor Reserve Shutdown Hrs. 14. Hours Generator On-Line 15. Unit Reserve Shutdown Hours 16. Gross Thermal Energy Generated (MWH) 17. Gross Elec. Energy Generated (MWH) 18. Net Elec. Energy Gen. (MWH) 19. Unit Service Factor 20. Unit Availability Factor 21. Unit Capacity Factor (using MDC Net) 22. Unit Capacity Factor (using DER Net) 23. Unit Forced Outage Rate NA This Month Year to Date 744 8784 0 0 0 0 0 0 0 0 0 0 0 0 -3706 -38420 0 0 0 0 0 0 0 0 100 100 50-311 01/10/97 339-2735 since Last N/A Cumulative 133417 78083.6 0 75229.5 0 187781005 78648898 74702634 56.4 56.4 50.6 50.2 30.6 24. Shutdowns scheduled over next 6 months (type, date and duration of each) Refueling extension.

25. If shutdown at end of Report Period, Estimated Date of Startup: First quarter of 1997. 8-1-7.R2

DAILY UNIT POWER LE., ._. Docket No.: 50-311 Unit Name: Salem #2 Date: 01/10/97 Completed by: Robert Phillips Telephone:

339-2735 Month December 1996 Day Average Daily Power Level Day Average Daily Power Level (MWe-NET) (MWe-NET) 1 0 17 0 2 0 18 0 3 0 19 0 4 0 20 0 5 0 21 0 6 0 22 0 7 0 23 0 8 0 24 0 9 0 25 0 10 0 26 0 11 0 27 0 12 0 28 0 13 0 29 0 14 0 30 0 15 0 31 0 16 0 P. 8.1-7 Rl NO. DATE 3859 12/01/96 F 1 2 F: Forced S: Scheduled DURATION TYPE 1 (HOURS) REASON 2 720 F,C Reason A-Equipment Failure (explain)

B-Maintenance or Test C-Refueling D-Requlatory Restriction UNIT SHUTDOWN AND POWER REDUCTIONS REPORT MONTH December 1996 METHOD OF SHUTTING DOWN REACTOR 4 LICENSE EVENT REPORT # ----------

zz 3 Method: 1-Manual 2-Manual Scram SYSTEM CODE 4 E-Operator Training & License Examination F-Administrative 3-Automatic Scram 4-Continuation of Previous Outage 5-Load Reduction 9-0ther G-Operational Error (Explain)

H-Other (Explain)

COMPONENT CODE 5 DOCKET NO.:

___ _ UNIT NAME: Salem #2. DATE: 01-10-97 COMPLETED BY: Robert Ph i-l l fps TELEPHONE:

609-339-2735

' CAUSE AND CORRECTIVE ACTION TO PREVENT RECURRENCE zzzz Refueling Scheduled Extension 4 -Exhibit G -Instructions for Preparation of Data Entry Sheets for Licensee Event Report CLER) File CNUREG-0161) 5 Exhibit 1 -Same Source *

  • IOCFR50.59 EVALUATIONS MONTH: DECEMBER 1996 DOCKET NO: UNIT NAME: 50-311 SALEM2 CONTACT: TELEPHONE:

R. HELLER 609-339-5162 The following items were evaluated in accordance with the provisions of the Code of Federal Regulations IOCFR50.59.

The Station Operations Review Committee has reviewed and concurs with these evaluations.

1. Design Change Packages (DCP) 2EC-3337, Pkg. 1 2EC-3384, Pkgs. 1-4 2EC-3402, Pkg. 1 2EC-3407, Pkg. 1 "P250 Computer/Computer Inverter Replacement" Rev. 1 -This DCP involved the replacement of the existing P250 Plant Computer System with a Westinghouse Distributed Processing Family system. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-114) "SIG Primary Manway Bolting Replacement/Hole Restoration" Rev. 1 -This DCP upgraded the primary manway bolting on the Salem Unit 2 Steam Generators Nos. 21 -24. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-058) "Main Turbine Lube Oil Separator Replacement" Rev. 0 -This DCP replaced the existing lube oil purification equipment, centrifugal separator and feed pump with a Kaydon Turbo-Toe Oil Purification System. The Toc is a self contained, skid mounted, oil purification unit. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-042) "Steam Trap Replacement Project" Rev. 0 -This DCP replaced steam traps in the Main Steam System. The components of each assembly removed included the steam trap, the bypass valve(s), the isolation valves, the drain valves, and the bypass restricting orifice (where installed).

Each installation was replaced with a strainer and restricting orifice coupling.

The orifice bore size is dependent on condensate flow requirements.

A blowdown line with

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R. HELLER 609-339-5162 isolation valve was installed to permit periodic blowdown of the strainer.

This line also serves as an orifice bypass. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-050) "Install NI 6 Main Steam Line Radiation Monitors" Rev. 0 -This DCP installed N16 main steam line radiation monitors to detect steam generator tube leakage and monitor leak rate changes. This package consists of the installation of four detector/preamplifier assemblies, four heater controller assemblies, one set of monitor electronics and interface equipment and one four channel recorder.

In addition, all conduit, conduit support and cable installation along with cable insulation resistance and continuity testing was performed under this package. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-101) "Turbine Driven Auxiliary Feedwater Pump Enclosure Floor Drain And Door Tightness Modification" Rev. 0 -This DCP added a new floor drain in the #23 Auxiliary Feedwater Pump enclosure.

The new floor drain with a loop seal was installed adjacent to the existing floor drain. The existing floor drain in the Auxiliary Feedwater Pump enclosure and floor drains in the pipe alley on El. 84'-0 11 of the Auxiliary Building were sealed with safety related stainless steel plates. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-103) "Removal of Tavg. Hi Rod Insertion Limit Input Instrumentation" Rev. 0 -This DCP removed Hagan Isolators 2TM412L & 2TM412K along with associated signal and power wiring. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-152)

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R. HELLER 609-3 3 9-5162 "Component Cooling Letdown Temperature Control Valve 2CC71 Modification" Rev. 0 -This DCP: 1.) Added new safety-related limit switch on safety related outside containment isolation CVC valve 2CV7; 2.) Replaced valve 2CC71 's actuator with a safety related actuator; 3.) Added a safety related 125 VDC solenoid operated valve in the Component Cooling valve 2CC71 actuator tubing; 4.) Added manual instrument isolation valves in parallel with the solenoid operated valve to bypass the containment isolation signal or fail close condition to permit the 2CC71 valve to be opened during an alternate shutdown scenario; 5.) Reconfigured controller 2TC-130CC to direct acting for operation of the new fail closed actuator installed on 2CC71, and 6.) Changed valve/actuator assembly from fail open to fail closed. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-152) "Condensate and Main Steam System Chemical Injection/Sample Internal Sparger Pipe Removal" Rev. 0 -This DCP removed chemical injection and sample spargers at various locations within the main steam and condensate system. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-089) "Service Water Pump Strainer Backwash Valves" Rev. 0 -This DCP modified the system to allow each strainer backwash valve to be replaced during individual service water pump outages. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-147) "Main Steam Coil Drain Tank Discharge Line Check Valve Additions" Rev. I -This DCP added/installed six new check valves in the main steam coil drain tank discharge lines to the sixth point feedwater heaters. The valves were installed downstream of the 21, 22 & 23 RD80 and RD87 manual

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  • 10CFR50.59 EVALUATIONS MONTH: DECEMBER 1996 DOCKET NO: UNIT NAME: 50-311 SALEM2 2. Temporary Modifications TMOD 96-075 3. Safety Evaluation (S/E) CR 961117074 DRSE 01 CONTACT: TELEPHONE:

R. HELLER 609-339-5162 valves, and upstream of the 22, 21 & 23RD5 and 38 air operated valves. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-133) "Auxiliary Building Ventilation System" Rev. 0 -The Auxiliary Building Ventilation (ABV) System is designed to maintain the Auxiliary Building at a negative pressure with respect to atmosphere during normal and emergency plant operations.

This temporary modification allows the differential pressure (dP) controller 2PA6951C, to be placed in the manual mode of operation to allow for constant exhaust flow rate during system balancing.

There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-173) "Change to Mode 5 (Cold Shutdown)

Considering Part 21 28V and 125V Control Relays" -This safety evaluation addresses a 1 OCFR21 notification that was issued on November 1, 1996 by Farwell & Hendricks, Inc., a supplier oflatching type relays to PSE&G for use in the Salem plants. The 1 OCFR21 notification identified the possibility that certain relays, Struthers-Dunn MSD B255 latching relays with DC latching coils, could fail to latch on demand, or fail to remain latched until signaled to reset. The defect is due to an inadequate mechanical latching force, and it is limited to relays that were manufactured after September, 1992. These relays are being replaced with fully qualified relays in a prioritized manner. Not all suspect relays will be replaced prior to Salem Unit 2 Mode 6 entry. The potential for these relays to unlatch with Salem Unit 2 in Modes 5 and 6 changes the facility as described in the SAR. Therefore this safety evaluation was presented to SORC in accordance with NAP-6 and NAP-59. (SORC 96-175) l_,. * *

  • 10CFR50.59 EVALUATIONS MONTH: DECEMBER 1996 DOCKET NO: UNIT NAME: 50-311 SALEM2 Mode 6 Core Redesign SW39 Air Operator 22/23 ccw 4. UFSAR 96-15 CONTACT: TELEPHONE:

R. HELLER 609-339-5162 "Mode 6 Reload Safety Evaluation" -The purpose of this evaluation is to analyze and verify the acceptability of the core redesign for Mode 6. An additional safety evaluation for Modes 5-1 will be presented at a later time. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-177) "Minor Modification for Diesel Generator SW39 Air Operator Modification, Salem Units 1 and 2" -The minor modification is for the installation of a retainer clip to hold the declutching pin in place on the SW39 valve actuators.

This retaining clip would provide an added assurance that the valve handwheel would not engage. The minor modification applies to both Unit 1 and Unit 2 SW39 valves. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-178) "Removal of 22/23 Component Cooling Water Pump Room Door" -This evaluation addresses all of the issues associated with the removal of 22/23 Component Cooling Water Pump Room Door. This modification reduces the possibility of losing more than one Component Cooling Water pump on loss of a room cooler. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-179) "UFSAR Change Notice 96-155 POPS/LTOP Analysis Review for PIRS 960828068

& 961011129" -A previously performed safety evaluation permitting 10% tube plugging for Salem S/Gs and its impact on the RCS volume and LTOP is the subject ofPIR# 961011129.

The RCS volume and LTOP impact also being reviewed under the PIR 960828068 is about the impact of the T.S. specified volume tolerances.

It's review and impact is bounded by the review of the 10% SIG tube plugging evaluated for the PIR# 961011129.

The effect of the reduced RCS volume in I I _J

  • 10CFR50.59 EVALUATIONS MONTH: DECEMBER 1996 DOCKET NO: UNIT NAME: 50-311 SALEM2 96-16 5. Procedures TS2.SE-SU.ZZ-0001 (Q) CONTACT: TELEPHONE:

R. HELLER 609-339-5162 either case on the L TOP parameters has been addressed in this 50.59. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-180) "UFSAR Change Notice 96-169, Change Temperature Range in UFSAR for SP AV System" -This change revises Section 9.4.6.1 of the Salem UFSAR to reflect recent GOTIDC model analyses and equipment evaluations.

These analyses model changes to the SP AV system implemented by modification 2EC-3298 which removed six (6) switchgear room exhaust fans, added two (2) 100% exhaust fans, changed ductwork, and changed system operations configurations.

The SP AV system consists of three 50% supply fans, two 100% Switchgear room exhaust fans, and two 50% Electrical Penetrations exhaust fans. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-181) "Startup and Power Ascension Sequencing Procedure" Rev. 1 -This procedure controls the sequence in which Startup and Power Ascension test activities are performed.

This procedure established Plant Performance Hold Points, and will document the completion of all required activities prior to proceeding beyond each Hold Point. This procedure also establishes Planned Assessment Hold Points, and will document the completion of all required activities prior to proceeding beyond each Hold Point. There is no reduction in the margin of safety as defined in the basis for any Technical Specification. (SORC 96-181)

  • REFUELING INFORMATION MONTH: DECEMBER 1996 MONTH: DECEMBER 1996
  • DOCKET NO: UNIT NAME: CONTACT: TELEPHONE:

50-311 SALEM2 R.HELLER 609-339-5162

1. Refueling information has changed from last month: YES . X . NO _. _. 2. Scheduled date for next refueling: (currently in outage) Scheduled date for restart following refueling: (to be determined)
3. a. Will Technical Specification changes or other license amendments be required?

YES. . NO. X NOT DETERMINED TO DATE,,__.

______.. b. Has the reload fuel design been reviewed by the Station Operating Review Committee?

YES. X . NO,,__. ---"'" If no, when is it scheduled? 5. Scheduled date(s) for submitting proposed licensing action: . n/a 6. Important licensing considerations associated with refueling:

7. Number of Fuel Assemblies:
a. Incore 193 b. In Spent Fuel Storage 584 8. Present licensed spent fuel storage capacity:

1632 Future spent fuel storage capacity:

1632 9. Date oflast refueling that can be discharged to the spent fuel pool assuming the present licensed capacity:

March 2012

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  • SALEM GENERATING STATION MONTHLY OPERATING

SUMMARY

-UNIT 2 DECEMBER 1996 SALEM UNIT NO. 2 The Unit remained shutdown for the entire period. According to commitments from PSE&G and a subsequent confirmatory action letter from the NRC, the Unit will remain shutdown pending completion of the following actions:

  • Appropriately address long standing equipment reliability and operability issues
  • After the work is completed, conduet a restart readiness review to determine for ourselves the ability of each Unit to operate in a safe, event free manner
  • After the restart review, meet with the NRC and communicate the results of that review
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