ML20077J303

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Monthly Operating Rept for Jul 1983
ML20077J303
Person / Time
Site: Salem PSEG icon.png
Issue date: 08/10/1983
From: Miller L, Zupko J
Public Service Enterprise Group
To:
NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
NUDOCS 8308160203
Download: ML20077J303 (20)
v • d • e


Text

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AVERAGE DAILY UNIT POWER LEVEL Docket No. 50-311 Unit Name Salem # 2 Date August 10, 1983 Completed by L. K. Miller Telephone 609-935-6000 Extension 4455 Month July 1983

-Day Average- Daily Power Level Day Average Daily Power Level (MWe-NET) (MWe-NET) 1 0 16 0 2 ,

0 17 0 3 0 18 0 4- 0 19 0 5 0 20 0 6 0 21 0 7 _

0 22 0 8 0 23 0 9 0 24 0 10 0 25 0 11- 0 26 0 12 0 27- 0 13 0- 28 0 14 0 29 0 15 0 30 0 31 304 Pg. 8L1-7 R1 8308160203 830810 -

gDRADOCK 05000311 PDR

)

r OPERATING DATA REPORT Docket No. 50-311 Date August 10, 1983 Telephone 935-6000 Completed by L. K. Miller Extension 44$5

.Cperating Status

1. Unit Name Salem No. 2 Notes
2. Reporting Period July 1983
3. Licensed Thermal Power (!fWt) 3411
4. Nameplate Rating (Gross MWe) ITTI
5. Design Electrical Rating (Net MWe) ITT5
6. Maximum Dependable Capacity (Gross MWe)TTT!I
7. Maximum Dependable Capacity (Net MWe) ITUT
8. If Changes Occur in Capacity Ratings (items 3 through 7) since Last Report, Give Reason N/A
9. Power Level to Which Restricted, if any (Net MWe) N/A
10. Reasons for Restrictions, if any N/A This Month Year to Date Cumulative
11. Hours in Reporting Period 744 5087 15793
12. No. of Hrs. Reactor was Critical 155.1 625.4 ___

11081.0 .

13. Reactor Reserve Shutdown Hrs. 0 3.3 38.9

.14. Hours Generator On-Line 32.6 492.0~ 10629.2

15. Unit Reserve Shutdown Hours 0 0 0
16. Gross Thermal Energy Generated (bnni) 53664 1163047.2 31679596.2 *
17. Gross Elec. Energy Gen 6 rated (boni) 9300 266640 10282890
18. Net Elec. Energy Generated (.MWH) (8646) 213907 97875S4
19. Unit Service Factor 4.4 9.7 68.6 t
20. Unit Availability Factor 4.4 9.7 68.6'
21. Unit Capacity Factor (using MDC Net) 0 3.8 56.0
22. Unit Capacity Factor (using DER Net) 0 3.8 55.6
23. Unit Forced Outage Rate 87.3 35.2 5.3
24. Shutdowns scheduled over next 6 months (type, date and duration of each).

N/A

~25. If shutdown at end of Report Period, Estimated Date of Startup:

N/A

26. Units _ in Test Status '(Prior to Commercial Operation) :

Forecast Achieved 1 Initial' Criticality. 6/30/80 8/2/80 Initial Electricity 9/1/80 6/3/81 Commercial-Operation 9/24/81 10/13/81 8-1-7.R2-Page 3-of.20L 4 - - - , - - ,

l UNIT SHUTDOWN AND POWER REDUCTIONS Docket No. 50-311 Unit Name Salem No.2

~

REPORT MONTH JULY 1983 Date August 10, 1983 Completed by L.K. Miller Telephone 609-935-6000 Extension 4455 Method of Duration Shutting License Cause and Corrective No. Date Type Hours Reason Down Event System Component Action to 1 2 Reactor Report Code 4 Code 5 Prevent Recurrence l

' Nuclear Service l Water Problems83-048 5/28 F 840.0 B 1 ---

WA PIPEXX other Nuclear Residual Heat Removal /

" " " " " " Decay Heat 83-050 7/02 24.0 Nuclear Core 83-052 7/03 "

209.8 " " "

CF HTEXCH Physics Test Nuclear Reactor Coolant /

" " " Recirculating Pumps83-054 7/12 "

200.2 CB PUMPXX Nuclear Core

" " " VESSEL Physics Test 83-056 7/21 "

194.9 RC 83-058 7/29 11.8 Nuclear Steam

" " HA TURBIN Generator Controls83-060 7/30 "

22.7 3 1 2 Reason 3 Method 4 Exhibit G 5 Exhibit 1 F: Forced A-Equipment Failure-explain 1-Manual Instructions Salem as S: Scheduled B-Maintenance or Test 2-Manual Scram. for Prepara- Source C-Refueling 3-Automatic Scram. tion of Data D-Regulatory Restriction 4-Continuation of Entry Sheets E-Operator Training & Licensing Exam Previous Outage for Licensee F-Administrative 5-Load Reduction Event Report G-Operational Error-explain 9-Other (LER) File H-Other-explain (NUREG 0161)

Page 4 of 20

DOCKET NOs 50-311 MAJOR PLANT MODIFICATIONS salem 2 REPORT MONTH~ JULY 1983 DATE: August 10, 1983 COMPLETED BY: L. K. Miller TELEPHONE: (609)935-6000 Ext. 4455 PRINCIPLE SYSTEM SUBJECT

  • DCR NO.

2EC-0505 Fan Coil Units Replace all coils of the fan coil units.

2EC-0665 Dnergency Control Air Provide emergency air compressor cooling Compressor from safety related chilled water system and disconnect existing service water system cooling.

2EC-0677 Switchgear and Perietration Revise dampers CAV12, CAV13 and CAV33 to Areas fail open ac per CD-M-80.

2EC-0761 Reactor Coolant System Install a device to monitor the reactor vessel level.

2EC-0885 Steam Generator Drains & Reroute steam generator blowdown tank vent Blowdown to No. 22 condenser shell.

2EC-1014 Couponent Cooling Water Provide motor operators for component cooling water pumpa discharge header valves No. 21-CC-3 and 22-CC-3.

2EC-1015 Component Cooling Water Provide motor operators for component cooling pump mction header valves No.

2CC17 and 2CCl3. ,

2EC-1056 Pressure and Delta P Replace pressure and differential pressure Transmitters transmitters which must survive MSLB and I4CA conditions with transmitters qualified to lEEE323-1974.

2EC-1058 Hydrogen Recombiners Modify design and change associated hardware, 2EC-1060 Auxiliary Feedwater Replacement of the auxiliary flow transmitters with safety grade instruments.

Radiation Monitoring Systwn~ Relocate RMc channels 2R19, 34 and 13 2EC-1068 electronic equipment to an area of less temperature and humidity.

2EC-ll85 Radiation Monitoring System Addition of five high range main steam line noble gas monitors with detection capability of 103 UCi/cc. The monitors will be safety grade and qualified for post-accident

+

operation.

  • DESIGN CHANGE REQUEST 8-1-7.R1 Page 5 of 20

DOCKET NO3 50-311 MAJOR PLANT MODIFICATIONS

' WMNMt salem 2 REPORT MONTH auty 1983 DATE: August 10, 1983 COMPLETED BY: L. K. Miller TELEPHONE: (609)935-6000 Ext. 4455

  • DCR NO. PRINCIPLE SYSTEM SUBJECT 2EC-1216 Reactor Coolant Head Vent Modify reactor head vent piping in the vicinity of the reactor head.

2EC-1253 Service Water This change calls for the replacement of the two 16" return headers which are located below the valves SW223.

2EC-1254 Service Water Provide interconnection for the service water headers (supply and return) for the chiller condenser and emergency air compressor areas.

2EC-1255 Auxiliary Feedwater Install eight (8) check valves in auxiliary feedwater pump discharge piping at proposed locations.

2EC-1301 CVCS Remove safety injection signal from valves 2CV139 and 2CV140; keeping valves open.

Control Room Console Provide cutouts for various design 2EC-1315 modifications.

2EC-1317 Control Room Side Panel Provide cutouts for the addition of Arrangement instruments.

RHR-Containment Lower the existing anti-vortex baffle from 2EC-1332 El. 81'5 1/2 (bottom of grid) as noted in the Alden Research Lab Report.

Diusel System Provide a permanent source of DC power for 2EC-1356 alternate shutdown procedures for starting the diesel generators.

2EC-1363 Auxiliary Feedvator Provide a 3" cross connection with two inline valves between the diacharge lines on the two motor driven AP pumps.

2EC-1376 Feedwater Replace BF22 feedwater stop check valves with power operated slow closure stop check vnives or add such valves in series after disabling the BS22 check function.

115 Volt AC E-153 Modify the 230V AC power feeds to the vital 2EC-1410 instrument inverters and the essential controls inverters.

  • DESIGN CHANGE REQUEST 8-1-7.Rl.

Page 6 of 20

DOCKET NOS 50-311 MAJOR PLANT MODIFICATIONS S,lm 2

~ UNIT NAME:

REPORT MONTH 3.n,y 3on, August 10, 1983 DATE:

COMPLETED BY: L.K. Miller TELEPHONE: (609) 935-6000 Ext. 4455 PRINCIPLE SYSTEM SUBJECT

  • DCR NO.

Reactor Coolant Replace wide range RTD's with environmentally 2EC-1414 qualified elements.

Circulating Water Replace 90/10 copper-nickel condenser tubes 2EC-1452 in Salem 2 main surface condenser -

replacements as outlined in Detail Specification 81-6412.

Reroute fire protection piping in TGA 2EC-1460 Fire Protection discharge side of condenser to allow system to remain operative during condenser retubing.

Platform Steel - TGA Change weld supports to a bolted design on 2EC-1469 the platform steel access platform for the main steam dump valves to facilitate removal for the main condenser retubing.

Turbine Bypass Steam Increase the time suppression setting of the 2EC-1482 steam ge:Srator feed pump suction controls to 5.0 seconds.

Circulating W?ter System Remove interferences to enable retubing of 2EC-1528 Main Condenser Retubing the Unit No. 2 main condenser.

125V DC Distribution (E220)

Install General Electric type 0275 A 4308 2EC-1543 Protective Relays (E560) Io-Pass Filter in the 125V DC line near the 4kV bus under frequency sensing relays.

Retube No. 22 Component Cooling Heat 2EC-1579 Component Cooling / Service Water Exchanger with titanium tubes in lieu of existing 90/10 CuNi tubes.

Safety Injection System Install the repaired 1SJ4 valve in the place 2EC-1580 of the removed 22SJ40 valve.

Control Room Console Replace the General Electric reactor manual 2EC-1603 trip switches on console. The new switches (2) will not have the removable handle option.

Safety Injection System Change valve packing for valves 2SJ4, 2SJ5, 2EC-1612 2SJ12 and 2SJ13 (Valve Mark No. FA-76) from existing " John Crane 187-I" packing to new "Grafoil Halogenated Die Molded Split Ring not=" _

  • DESIGN CHANGE REQUEST 8-1-7.Rl Page 7 of 20 I

DOC [ETNO 50-311 MAJOR PLANT MODIFICATIONS

' UNIT NAME: SALEM 2 REPORT MONTH auty 1983 DATE: August 10, 1983 .

COMPLETED BY: L.K. Miller TELEPHONE: (609)935-6000 Ext. 4455

  • DCR NO. PRINCIPLE SYSTEM SUBJECT 2EC-1621 Component Cooling Provide for addition of handhole to No. 22 Component Cooling Heat Exchanger and the subsequent patching of same.

2EC-1636 Chemical and Volume Control Replace valve 2CV81 and 2CV82, Mark No. FA-4 with valves having a similar design.

2SC-0274 Incore Thermocouple Change the method of connecting field cable to the Incore Thermocouples.

Component Cooling Provide motor operated valve for the 2SC-0348 Auxiliary Header Isolation Valves 2CC30 and 2CC31.

2SC-0505 Main Turbine Lube Oil Replace 21 & 22 main turbine lube oil cooler tubing bundles with alternate material or change cooler design to plate type exchangers.

2SC-0600 Structural Install a cage on the ladder to #2 pressurizer.

Service Water Install a drainags system from the 10" 2SC-0623 inlet and outlet pipes of the containment fan coil units to the 20" service water discharge piping. System to consist of piping, valves and pumping mechanism to ensure that one FCU can be isolated and drained.

Steam Generator Feedwater Take new bearing retainers and mcJify them 2SC-0651

  1. 21 and 22 Pumps - Pump per Franklin Institute Research Lab Report Journal Bearings F- A5477.

Service Water Install 316 SS piping, fittings and tubing 2SC-0744 in lube oil cooling system on both #21 and 22 Charging Pumps.

Circulating Water Install 316 SS fittings, valves and piping 2SC-0746 on the bearing lube piping to ths circulato i motors. Install break flanges in areas where carbon steel and stainless steel meet ,

  • DESIGN CHANGE REQUEST 8-1-7.R1 t-Pcge 8 of 20 ,

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i DOCKET NO3 50-311 MAJOR PLANT MODIFICATIONS sam 2 UNIT NW:

REPORT MONTF JULY 1983 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: (609)935-6000 Ext 445S SUBJECT

  • DCR NO. PRINCIPLE SYSTEM Containment Penetration Cut penetration cooling air lines and 2SC-0783 Cooling install unions so that check valves can be removed and capped off to provide a positive test boundry.

Service Water Install 6" drain connection between valves 2SC-0786 21SW23 and 22SW23.

Containment Spray / Refueling Provide a hard pipe for the containment 2SC-1125 spray cavity fill line.

Cavity a

  • DESIGN CHANGE REQUEST 8-1-7.R1 Page 9 of 20

I MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 i REPORT MONTH JULY UNIT NAME: Salen 2 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: 609/935-6000 X4455

  • DCR NO. 10CFR50.59 SAFETY EVALUATION 2EC-0505 The installation of coils made of AL-6X tubing (instead of 90/10 Cu/Ni) and utilizing a water box header of (316 S.S.) , both materials being more suitable for the prevailing service water conditions, does not affect any presently performed safety analysis, nor does it create any new safety hazards. No unreviewed safety or environmental questions are involved.

2EC-0665 Changing the cooling medium for the emergency air compressors from service water to chilled water does not affect any presently performed . safety analysis, nor does it create any new safety hazards. No unreviewed safety or environmental questions are involved.

2EC-0677 The damper positions were not used in calculations for the presently performed safety analysis. No unreviewed safety or environmental questions are involved.

2EC-G761 Provision of local reading capability for the reactor vessel liquid level does not create any new safety hazards nor does it af fect any other safety related functions. No unreviewed safety or environmental questions are involved.

2EC-0885 Installation of this DCR will not affect any presently performed safety analysis nor create any new safety hazards. No unreviewed safety or environmental questions are involved.

2EC-1014 Changing the valve cperators from manual to motor operated will not involve any changes to the FSAR, or Technical Specifications. No unreviewed safety or environmental questions are involved.

2EC-1015 Changing the valve operators from manual to motor operated will not involve any changes to the FSAR, or Techhical Spe cifications . No unreviewed safety or environmental questions are involved.

Page 10 of 20

MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 REPORT MONTH JULY UNIT NAME: Salem 2 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: 609/935-6000 X4455

  • DCR NO. 10CFR50.59 SAFETY EVALUATION 2EC-1056 This DCR replaces pressure transmitters located in harsh environments with pressure transmitters which have been environmentally tested. This change should improve the reliability of the system. No unreviewed safety or environmental questions are invovled.

2EC-1058 This change assures the operator of a continuous indication of hydrogen concentration in the containment as required by NUREG 0737. No unreviewed safety or j environmental questions are involved j 1

2EC-1060 This change is for a direct replacement of transmitters. l No unreviewed safety or environmental questions are involved. .

l 2EC-1068 The equipment will be reconnected as per original design.

No unreviewed safety or environmental questions are I involved.

j 2EC-ll85 Installation of this DCR does not affect any presently I

performed safety analysis. No unreviewed safety or environmental questions are involved.

I 2EC-1216 Installation of this DCR does not create any new safety hazards. No unreviewed safety or environmental questions are involved.

2EC-1253 The two lines are upgraded to improve service and durability. No unreviewed safety or environmental questions are involved.

2EC-1254 Installation of this DCR does not create any new safety hazards. No unreviewed safety or environmental questions are involved.

2EC-1255 Addition of these valves will enhance safe operation of the unit by simplifying operator required action. No unreviewed safety or environmental questions are involved.

2EC-1301 Installation of this DCR creates no new safety hazards.

No unreviewed safety or environmental questions are involved.

Page 11 of 20

t MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 REPORT MONTH JULY UNIT NAME: Salem 2 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: 609/935-6000 X4455

  • DC R N O . 10CFh50.59 SAFETY EVALUATION 2EC-1315 Installation of this DCR creates no new safety hazards.

No unreviewed safety or environmental questions are involved.

2EC-1317 This design change does not affect the safe shutdown of the reactor. No unreviewed safety or environmental questions are involved.

2EC-1332 This change does not affect the basic design and function of the RHR sump. No unreviewed safety or environmental questions are involved.

2EC-1356 Providing a permanent source of D.C. starting power for the diesel generator does not affect any safety function or margin. No unreviewed safety or environmental questions are involved.

2EC-1363 Providing the cross connection will enhance system flexibility such that each motor driven auxiliary feedwater pump can feed to all four or any of the four steam generators. No unreviewed safety or environmental questions are involved.

2EC-1376 These operators will ensure positive closure of the stop valves to preclude a release of radioactive material to the outside environment. No unreviewed~ safety or environmental questions are involved.

2EC-1410 This design change enhances plant safety and availability by allowing automatic transfer of vital bus loads in the event of a vital bus inverter failure. No unreviewed safety or environmental questions are involved.

2EC-1414 This design change involves a direct replacement of

. existing equipment. The system function will not change.

No unreviewed safety or environmental questions are involved.

l 2FC-1452 This design change does not affect any presently performed I safety analysis nor does it create any new safety hazards.

No unreviewed safety or environmental questions are involved.

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MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 REPORT MONTH JULY UNIT NAME: Salem 2 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: 609/935-6000 X4455

  • DCR NO. 10CFR50.59 SAFETY EVALUATION 2EC-1460 Rerouting of the fire protection piping does not affect the operability of the fire protection system. No unreviewed safety or environmental questions are involved.

2EC-1469 Installation of the DCR does not create any new safety hazarde. No unreviewed safety or environmental questions are involved.

2EC-1482 This DCR alters a system which is not safety related. The basic function of the equipment is unchanged. No unreviewed safety or environmental questions are involved.

2EC-1528 This change to the service water bay level indication system and change to the 4" backwash of the feedwater system does not change any presently performed safety analysis. No unreviewed safety or environmental questions are involved.

2EC-1543 This change adds a low pass filter electrically upstream o f the 4KV group bus underfrequency relays. No unreviewed safety or environmental questions are involved.

, 2EC-1579 The installation of titanium tubes will not affect the Technical Specifications or result in an unreviewed safety question. The structural integrity of the tube and shell heat exchanger remains intact.

2EC-1580 This change replaced the valve in kind. No unreviewed safety or environmental questions are involved.

2EC-1603 The replacement of the reactor trip switch with one of the same kind, except for the removable handle, does not alter the function of the system. No unreviewed safety or environmental questions are involved.

2EC-1612 The packing replacement will actually enhance the reliability of the valve. No unreviewed safety or environmental questions are involved.

2EC-1621 The addition of a patch fitting as described in the DCR does not present an unreviewed safety hazard. No unreviewed safety or environmental questions are involved.

Page 13 of 20

MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 REPORT MONTH JULY UNIT NAME: Salem 2 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: 609/935-6000 X4455

  • DCR NO. 10CFR50.59 SAFETY EVALUATION 2EC-1636 The pressure rating of the new valves is equivalent to the system pressure rating. The valve material is acceptable for the CVC system. No unreviewed safety or environmental questions are involved.

2SC-0274 This change introduces a superior method of connecting cables, as well as cable that has been environmentally qualified. No unreviewed safety or environmental questions are involved.

2SC-0348 The operators being added allow the valves to close more rapidly to prevent draining of the system. No unreviewed safety or environmental questions are involved.

2SC-0505 The replacement tube bundles and floating heads will upgrade the system because the new material is more resistant to the service water environment.

2SC-0600 The installation of a safety cage around the ladder leading to the No. 2 Pressurizer does not create any new safety hazards. No unreviewed safety or environmental questions are involved.

2SC-0623 Installation of drains for the fan coil unit instruments does not create any new safety hazards. Elimination of drainage onto the floor will eliminate one potential source of contamination. No unreviewed safety or environmental questions are involved.

2SC-0651 This change does not affect any presently performed safety analysis nor does it create any new safety hazards.- No unreviewed safety or environmental questions are involved.

2SC-0744 This change will upgrade the vendor supplied copper based material with small bore piping made of a more corrosion resistant material. No unreviewed safety or environmental questions are involved.

2SC-0746 Installation of this DCR will not create any new safety hazards. No unreviewed safety or environmental questions ,

are involved.

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MAJOR PLANT MODIFICATIONS DOCKET NO.: 50-311 REPORT MONTH JULY UNIT NAME: Salem 2 DATE: August 10, 1983 COMPLETED BY: L.K. Miller TELEPHONE: 609/935-6000 X4455

  • DC R NO. 10CFR50.59 SAFETY EVALUATION 2SC-0783 The installation of the piping unions will not affect the basic function of the system. No unreviewed safety or environmental questions are involved.

2SC-0786 The addition of a low point drain does not alter the basic function or design concept of the system in any way. No unreviewed safety or environmental questions are involved.

2SC-1125 Installation of this DCR does not affect any presently performed safety analysis, not does it create any new safety hazards. No unreviewed safety or environmental questions are involved.

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Page 15 of 20

_ _ - ._. _ _ . _ _ _. ._ __m .

PSE&G SALEM GBERATIBG SDLTIN ,

SAFETY I<EIJEED WORK 00ER IOG . .

SAIIM UNIT NO. 2

- WO 10 DEPT INIT EUJII9ENT TmMurlCRTION

.901581 70 2 22 BC PtNP

FAILURE DESCRIPTICN: DISASSEMBLE, INSPECT, REPIACE, REASSEMBLE BCP SEALS. 820721 CmRECTIVE ACTIN: INSTALIID NEN SEALS. 830415 923952 CD 2 CONT AIR IOCK EL.100 FAILURE DESCRIPTICN: INNER DOCR DRIVE OIAIN IS BROKEN. 830513 CNRECTIVE ACTION: RENDVED CNE LINK AND AEGUSTED 'IURfEUCKIES. DOOR SAT. 830531 923957- CD 2 CCNT PRESS PFLTFF FAILURE DESCRIPTICN: CAPNDP SEP DIVISIN DPMPER @EN. 830601 CmRECTIVE ACTICN: INSTALIED MISSING JENPER BE%EEN TERMINAL 2 AND 'IERMINAL 12. 830601 .

934355 CD '2 23 BCS IOOP FICW CH3 FAILURE DESCRIPTI N: QIANNEL HAS NO ANAIDG It0ICATICN AND RP-4 ION FICW LIGff DID NOT CLEAR NHN FCP WAS BUN. 830613.

COERIETIVE ACTIN: TRANENITTER DEFECTIVE. REPIACED FORCE M0KR, DISC APO MPGUIING COIL. 830621

. 934413 CD 2 23 CHARGING PtNP FAIIURE DESCRIPTICN: 5' GPM IERK 'IO WAS'IE LIQUID SYSITM.- 830616

. CQtRECTIVE ACTICE: REPACKED ALL 5 CYLINDERS. 830623 h

Page 16 of 20 t

, - . , u - _ _ _ _ _ _ _ _ -

.. . .= - . - - - - - - - - - - - - ._ __

PSE&G SALEM GENERATDG SDEICN SAFE 1T PEIA'IED inGK GDER IOG ,

SAIEA UNIT NO. 2 s

WO ND . DEPT LNIT EGJIPPENT wizrnrICATIN _

934423 CD - 2 VALVE T 24SJ54

. FAIMRE DESCRIPTIm- CVERIOPOS 'IRIP MEN ATTEMPT MADE 'ID mm. 830616 t

CORRECTIVE ACTION: F00tO CICSING COIL UNABLE 'IO PULL IN. CCNDCTS & CCNIAC'IOR BDOING UP.

REPIJCED CCNDC10R. 830617

~

l .937627 OD. 2 . VALVE 24MS15 l

FAILURE DESCRIFfI W : VALVE LEPES BY SLImTLY. 810708 CCRRDCTIVE ETION: REPIJCED INSERT, RCD ASSY, RDG, HGDER APO GUIDE. 830620 937628. CD 2 VALVE 21MS11 l.

FAILURE DESCRIPTIm: VALVE LEAKS BY SLIGTLY. 810708 CWRECTIVE ACTION: REPLACED INSERT. BAIANCE & INTERNALS PCCEPTABLE. 830620 j i

2 23 AUX FEED PLMP l 938343 CD FAILURE DESCRIPTIN: 'IRIP COIL IN HSD PANEL 207 APPEARS 'ID BE BURNED UP. 830707 CCRRECTIVE ETICN: REPIACED SCLENOID COIL A!O TRIP COIL. VALVE OPERATES PROPERLY. 830708

'938610' CD 2- VALVE T 24MS167 I

FAIWRE DESCRIPTIW: DO NOP RECEIVE NIM) LIGfr. 830703 CCRRECTIVE ACTION: BLED OIL AND RELEASED AIR. ADDED ABOUP 20 GAL T OIL DURING PROCESS. 830704 938615s CD 2- VALVE 21MS167 FATw RE DESCRIPTIW: VALVE CANNOT BE CEOSED HYDRAULICALLY. 830703 CNRECTIVE ACTIN: STROKED VALVE. ADDED 2 POINfS T OIL. 830704 Page 17 of 20

. . . . .,. ~

PSE&G SALEM GENERATING SIATICN SAFELT RELA'IED WORK GDER ILG .

SAIIM UNIT 2

^

WO NO DEPT LNIT EQUIPMENT IDENTIFICATION 924091' OT 2 VALVES 21, 22, 24LF22 FAILURE DESCRIPTICN: ICITES Di: AWING 'ICO MXII CURRENT. - REPIACE WITH LNIT 1 MOIORS. 830616 CNRELTIVE ACTION: CHANGED LIMITOf00ES AS REQUIRED. 830623 924443 RE 2 INC@E FLUX MAP SYS FAILURE DESCRIPTICN: REPAIR F DRIVE NO SPARE CmPARA'IOR. 830426 CNRECTIVE 7CTIN: REPIACED F AND E DRIVE CWPAR750RS. 830603.

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4

. r REFUELING INFORMATION DOCKET NO.: 50-311 l COMPLETED BY: L.K. Miller UNIT NAME: Salem 2 DATE: August 10, 1983 TELEPHONE: 609/935-6000 '

EXTENSION: 4455 Month July 1983

1. Refueling information has changed from last month:

YES NO X i 2. Scheduled date for next refueling: March 31, 1984 ,

3. Scheduled date for restart following refueling: June 10, 1984
4. A) Will Technical Specification changes or other license amendments be required?

l YES NO X NOT DETERMINED TO DATE 8/1/83 D) Has the reload fuel design been reviewed by the Station Operating Review Committee?

YES NO X If no, when is it scheduled? February 1984

5. Scheduled date(s) for submitting proposed licensing action:

i March 1984 (if required) i 6. Important licensing considerations associated with refueling:

NONE 1

1

7. Number of Fuel Assemblies

A) Incore 193 B) In Spent Fuel Storage 72

8. 1170 Present licensed spent fuel storage capacity:

i Future spent fuel storage capacity: 1170

9. Date of last refueling that can be discharged to spent fuel pool assuming the present i j licensed capacity: March 2000

, 8-1-7.R4 i

Page 19 of 20 l

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SALEM UNIT 2 OPERATIONS

SUMMARY

REPORT JULY 1983 Unit No. 2 began the month shutdown as preparations for mode change continued. The unit entered Mode 4 at 1813 hours0.021 days <br />0.504 hours <br />0.003 weeks <br />6.898465e-4 months <br /> on July 3rd, and Mode 3 at 0915 hours0.0106 days <br />0.254 hours <br />0.00151 weeks <br />3.481575e-4 months <br /> on July 6th. Attempts were made to correct the seal leakage on No. 24 Reactor Coolant Pump (RCP). However, investigation revealed that it was necessary to replace the seal package. The unit was cooled down and the RCP seal package was i replaced. Repairs were also made to No. 23 Coolant Charging Punp relief valve. A unit startup was commenced and Unit No. 2 entered Mode 2 at 1019 hours0.0118 days <br />0.283 hours <br />0.00168 weeks <br />3.877295e-4 months <br /> on July 23rd. On July 27th, the unit tripped due to a technician error while pertorming a functional test on Intermediate Range Channel N-35. On July 28th, at 1409 hours0.0163 days <br />0.391 hours <br />0.00233 weeks <br />5.361245e-4 months <br />, a startup of Unit No. 2 was again commenced. The unit entered Mode 1 at 1946 hours0.0225 days <br />0.541 hours <br />0.00322 weeks <br />7.40453e-4 months <br />, July 28, 1983, and was synchronized at 0458 hours0.0053 days <br />0.127 hours <br />7.572751e-4 weeks <br />1.74269e-4 months <br /> on July 29th. At 0525 hours0.00608 days <br />0.146 hours <br />8.680556e-4 weeks <br />1.997625e-4 months <br /> on July 29th, the unit tripped on a Steam Generator Lo-Lo Level trip on No. 22 Steam Generator during transfer of the feed controls from manual to automatic. The main feedwater regulating valve failed to open as the bypass valve closed. The Unit was again brought critical on July 29th and power was increased until the reactor tripped again at 0245 hours0.00284 days <br />0.0681 hours <br />4.050926e-4 weeks <br />9.32225e-5 months <br />, July 30, 1983. Power was being reduced in preparation for turbine overspeed testing when the turbine tripped on a high level in No. 22 Steam Generator. The feed regulating valves were in manual control when the steam generator level swelled to 67%, causing a turbine trip and reactor trip. Unit No. 2 was again brought critical on July 30, 1983, and entered Mode 1 at 2217 hours0.0257 days <br />0.616 hours <br />0.00367 weeks <br />8.435685e-4 months <br />. The unit was synchronized at 0059 hours6.828704e-4 days <br />0.0164 hours <br />9.755291e-5 weeks <br />2.24495e-5 months <br />, July 31, 1983, and a power escalation was begun.

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O PSEG Pubhc Servu E tectnc ami Gas Corrri cr/ P O. L ox E t howc.ks Bruice, New Jersey 08038 2

Salem Generating Statbn August 10, 1983 Director, Of fice of Inspection and Enforcement U.S. Nuclear Regulatory Commission Washington, DC 20555

Dear Sir:

MONTilLY OPERATING REPORT SALEM NO. 2 DOCKET NO. 50-311 In Compliance with Section 6.9, Reporting Requirements for the Salem Technical Specifications, 10 copies of the following monthly operating reports for the month of July 1983 are being sent to you.

Average Daily Unit Power Level Operating Data Report Unit Shutdowns and Power Reductions Major Plant Modification Summary of Safety Related Maintenance Operating Summary Refueling Information Sincerely yours, J. M. Zupko, Jr.

General Manager - Salem Operations LKM:sbh cc: Dr. Thomas E. Murley Regional Administrator USNRC Region I 631 Park Avenue King of Prussia, PA 19406 Director, Office of Management Information and Program Control U.S. Nuclear Regulatory Commission Washington, DC 20555 Enclosures Page lof 20 8-1-7.R4 The Energy People l l y

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