Text

Monthly Operating Rept for Apr 1985
	ML20127J840
Person / Time
Site:	Salem
Issue date:	04/30/1985
From:	Ronafalvy J, Zupko J; Public Service Enterprise Group
To:	; NRC OFFICE OF INSPECTION & ENFORCEMENT (IE)
References
	NUDOCS 8505210602
	Download: ML20127J840 (28)
	v • d • e

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,9 5

AVERAGE DAILY UNIT POWER LEVEL Docket No.

50-311 Unit Name Salem # 2 May 10,1985 Date Completed by. J. P. Ronafalvy

. Telephone 609-935-6000 Extension 4455 Month

' April 1985 Day-Average Daily Power Level Day Average Daily Power Level (MWe-NET)-

(MWe-NET) 1:

0 17-0

'2 0

18

-7 o--

3 0

19 185 4

0 20 417 5

-O' 21 456 6

0 22 492

'7 0

23 0

8

-0 24 424 9

0 25 444 10 0

26 422 11 0

27 0

12 0

28 279 13 0

29 502 14 0

30 508 15 0

31 16 O

Pg. 8,1-7 R1 8505210602 850430 PDR ADOCK 05000311 R

PDR

- r,

OPERATING DATA REPORT Docket No. 50-311 Date May 10,1985 I

Telephone 935-6000 Completed by J. P. Ronafalvy Extension 4455 Operating Status i

11.

Unit Name Salem No. 2 Notes 2.

. Reporting Period April 1985 3.

Licensed Thermal' Power (MWt) 3411 4.

Nameplate Rating (Gross MWe)

TT7F

- -5.

Design Electrical Rating (Net MWe)

TTIT 6.

Maximum Dependable Capacity (Gross MWe)TTTF 7.

Maximum Dependable Capacity (Net MWe) TT5T 8.

If Changes occur in Capacity Ratings (items 3 through 7) since Last Report, Give Reason N/A 1

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 Ell. Hours in Reporting Period 719' 2879 31104

12. No. of Hrs. Reactor was Critical 448.6 448.6 15543.2-

13. Reactor Reserve' Shutdown Hrs.

0 0

3533.6

14. Hours Generator On-Line 244.1 244.1 14856.2

15. Unit Reserve Shutdown Hours 0

0 0

16. Gross Thermal Energy Generated (800{}

407818 407818 44134854

17. Gross Elec. Energy Generated (bDni) 110120 110120 14387770

18. Net Elec. Energy Generated (MWH) 83650 66894 13584730

19. Unit Service Factor 34.0 8.5 47.8 h

20. Unit Availability Factor 34.0 8.5 47.8 L

21. Unit Capacity Factor (using MDC' Net) 10.5-2.1 39.5

22. Unit Capacity Factor (using DER Net) 10.4 2.1 39.2

23. Unit Forced Outag'e Rate 64.5 90.4 42.3

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 I

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

Forecast Achieved Initial Criticality 6/30/80 8/2/80 Initial Electricity 9/1/80 6/3/81 Commercial Operation 9/24/80 10/13/81 8-1-7.R2 I

t

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J Dockat' No. ' 50-3115 l

UNIT SHUTDOWN AND POWER REDUCTIONS '

' Unit Name _Sultm N%2 REPORT MONTH April-1985-Date.

May - 10,19 8 5

-Completed by..J.P.'Ronafalvy

.TelephonW 609-935-6000 Extension 4455

?~

Method of

, Duration Shutting License Cause and Corrective-

'No.

Date Type

. Hours Reason Down' Event

. System 1 Component-Action to 1

2 Rea cbor Report Code 4 Code 5' Prevent' Recurrence Stator Windings HA GENERA Terminals Bushing 85-012 1-14 F

289.6-A 4

Nuclear Steam CH INSTRU Generator Control 85-014 4-13 F

17.9 A

3 Feedwater CH MOTORX Pump Motor j

85-016 4-13 F

2.5 A

1 F

CH PUMPXX Feedwater Pump j

i 85-018 4-13 F

2.7 A

1 85-020 4-14 F-49.5 A

4 HA' TURBIN-LP Turbine Bearings CH PUMPXX Feedwater Pump i

85-022 4-16 F

40.0 A

4 Steam Trap.

CH VALVEX Feedwater System 85-024 4-17 F

17.6 A

3 s

j'85-026 4-18

-F 2.1.

1 HA TURBIN Turbine Testing B

i 85-028 4-18 F

25.7 A

5 CH'

.PUMPXX Feedwater Pump i

CH PUMPXX Feedwater Pump l

85-030 4-20 F

34.7 A

5 j

j CH PUMPXX Feedwater Pump 85-032 4-21 F

206.0 A-5 1

2 Reason 3 Method 4 Exhibit G

'5 Exhibit'l' j

F: Forced

-A-Equipment Failure-explain 1-Manual Instructions Salem as S: Scheduled B-Maintenance or. Test 2-Manual Scram, for Prepara-Source j

C-Refueling 3-Automatic Scram, tion of Data

.D-Regulatory Restriction 4-Continuation of Entry Sheets j

E-Operator Training & Licensing Exam Previous Outage for Licensee i

F-Administrative 5-Load Reduction Event Report j

G-Operational Error-explain 9-Other (LER) File j

H-Other-explain (NUREG 0161) 3 l

6

~

3

~

, Method of Duration Shutting License

'Cause and Corrective'.

No.

Date Type' Hours Reason' EDown

. Eve nt -

System

~ Component

' Action to

~

1 2

- Rea cto r Report Code 4 Code 5 Prevent' Recurrence Other Steam HA'

'TURBIN-Turbine Problems85-034 4-23 F

21.9 A

3 Generator

.85-044 4-26 F

'32.d B-

'l H A' GENERA Main ~ Leads'85-046 4-30 F

21.4 A

5 CH' PUMPXX Feedwater Pump 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 Previous Outage-for Licensee

~

E-Operator Training & Licensing' Exam

.'5-Load Reduction Event Report F-Administrative G-Operational' Error-explain 9-Other

- (LER) File H-Other-explain (NUREG 0161)

iMAJOR PLANT MODIFICATIONS' DOCKET NO.:

50-311

. REPORT'MONTHDAPRIL 1985 UNIT'NAME:

Salem 2-

-DATE:- May 10, 1985 COMPLETED BY:.J.-Ronafalvy TELEPHONE:- 609/339-4455

DCR NO.

PRINCIPLE SYSTEM SUBJECT 4

2EC-2000 Main Steam Replace turbine first stage

'impulseLpressure transmitters PA0195 and PA0216 and mount so-7

~

as to reduce. vibration.

c 2EC-0562 Gaseous Waste-Disposal Move analyzer panel 110-from:

4

.its present location to El.

-122 in the Auxiliary Building.

2EC-0735 Feedwater Relocate contacts on SGFP turbine valves from normally open valves to-operational-valves.

2EC-1075 Main Feedwater Pumps Add an'. additional control-for.

individual steam-generator feed pumps which will have a setpoint'of 190 PSIG with no time suppression.

This~

additional / control'will be fed.

into the turbine drip. system.-

s 2EC-1108A Control Room Console Replace various pushbutton tags with new tags to-

-incorporate temporary dymo tags and engraved modules with.

permanently installed printed ~

tags..Also, replace existing pushbutton bulbs with low

~

wattage bulbs model CM-385.

l 2EC-1265A Moisture Separator Modify six MSR shell side.

Reheat Steam internals to provide for a streamline steam flow and y

enhanced moisture separation and reheat capabilities..

Install outlet' strainers and shell manways.

2EC-1276 Main Steam Turbine.

Replace the L-3 and L-4 stationary blading'with redesigned blades in all three low' pressure turbines.

' Design Change Request 4

-J

c

DCR NO.

PRINCIPLE SYSTEM SUBJECT 2EC-1278-

.21fMain Steam Turbine Replace-low pressure main turbine ~ rotor No. 21 with refurbished rotor from Unit 1.

2EC-1305 Chemical and Volume Butt welding of the valves to Control header making each of them~a "one-piece connection."

The second valve on all vent and drain connections shall be eliminated and replaced with short nipple and scred cap.

2EC-1343 Control Room Console Color code all indicators on the Control Room console to identify their. association with the various vital and non-vital instrument buses.

2EC-1439 Pressurizer Heater The controls for the extension bus breaker does not provide a flashing green light and associated audible when the-breaker trips due to over current or a local trip.

2EC-1589 Cable Trays-Various Retag, repull various cables Systems throughout the plant to match wiring diagrams prior to the implementation of the DCR system.

2EC-1615 Reactor Coolant

1) Provide an insulation box around the safety valve loop seals by modifying the pressurizer insulation.

2)

Install additional supports on the safety valve discharge piping and modify existing supports.

2EC-1620B Reactor Coolant-Wide Revise _ cable designation Range RTD Recorders numbers on wide range RTD cables to reflect vital channels.

Design Change Request L

DCR NO.

PRINCIPLE SYSTEM SUBJECT 2EC-1658

' Control ~ Rods

'Re-identify (not relocate)-

certain selected control banks to achieve a close resemblance to the Unit-1 control rod-pattern.

2EC-1675 Computer Inverter Upgrade: computer inverter.-

2EC-1688 Service Water Replace existing C.S. piping with S.S. at-selected high erosion areas upstream and downstream of 21 and 22 fan coil units.

2EC-1689 Service Water Replace existing C.S.-piping with S.S. at selected high erosion areas upstream and downstream of 23 fan coil unit.

2EC-1690 Service Water Replace existing C.S. piping with S.S. at selected high erosion areas upstream and downstream of #24 and 25 fan coil units.

2EC-1772 RHR Sump Level Install a new upper 3' of probe for the containment sump indication.

The new probe should contain the same resistance per foot as the first 14 ' of probe.

2EC-1811 Miscellaneous Change range of 2PL3325 and Condensate.

2PL33 26 from 0-3004 to 0-600#.

l 2EC-1829 Generator Install a radio frequency Instrumentation monitor.

2EC-1863 21 SI Pump Replace existing lube oil coolers on 21 SI Pump with coolers of similar design characteristics but upgraded materials of construction.

Design Change Request i

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DCR NO PRINCIPLE SYSTEM SUBJECT 2ET-1876-Unit 2 Generator-Test of Vital Bus '2B' 4.16 KV-Diesel Generator supply breaker 2BDD anti pumping circuit and strip' chart monitoring of Vital Bus

'2B' bus differential.

2E-1879 Reactor Coolant Revise setpoints of #21 RCP locked rotor. protection relaying.

2EC-1896 AC Power System Upgrade the fast transfer on 4kv-2C vital buses on undervoltage conditioning.

2EC-1930 Circulating Water Upgrade materials of construction on Circulating Water Pumps 21A, 22A and 22B.

'2EC-1937 500KV Hope Creek /

Provide 125VDC supply Salem' Tie Line supervision.

Reverse CT polarity of the backup pilot wire relay circuit breakers 31X and 23X.

Reverse the transfer trip current direction.

2ET-2004 Spent Fuel Pit Take fluid temperature measurements at various surface and depth locations in spent fuel pool.

2EC-2043 Condenser Air Removal Install a 7/16" dia. flow measuring orifice and 3/4" isolation valve in the air inlet piping of #22 Condenser Vacuum Pump.

2ET-2057 Turbine _ Supervisory Temporarily install both Instrumentation generator end and governor end differential expansion instrumentation manufactured by Bently Nevada.

Design Change Request

[

4

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DCR NO.

PRINCIPLE SYSTEM SUBJECT 2EC-2071 Auxiliary Feedwater Provide low suction pressure trip for each AFW pump, in order to preclude inadvertent.

actuation.

Additional circuitry will be required.

This additional circuitry will allow actuation only when a

" tornado warning" is in effect.

-2SC-0314 Service Water Modify #23 Service Water Pump motor to allow 1 filling of oil-reservoir.

2SC-0364 21A Circulator and Modify condensate, heater.

21 Heater Drain drain and circulating water pump motors to allow. filling of oil reservoirs.

2SC-0570 Control Air

-Assign generation numbers to instrument valves outside the redundant air supply panel,_so called " panel isolation-valves", for all safety significant valves.

2SC-0897 Turbine Aux Cooling Change material of tubing in Unit 2 turbine aux cooling

~

heat-exchangers from Type 90-10 ' copper nickel to a material more. suited to our system.

.2SC-0914 Circulating Water Revise shear pin sprockets

' Traveling Screen on-circulating water traveling screens.

2SC-0941 Circulating Water Install new chain guards cn1 the traveling screens made of fiberglass or other light weight non-corroding material which can be removed by unbolting.

Design Change Request-

m-

=7-lys.

f

^

DCR NO.

PRINCIPLE SYSTEM SUBJECT

.x 2SC-1247 Condenser Air Removal.

Replace #23 and #24 Vacuum Pump coolers with improved type.

2SC-1273 Auxiliary Feedwater The No. 23 Aux Feedwater Pump trip valve 2 MSS 2 presently does not provide indication in the Control Room when it is reset and latched.

Provide s

IP indication on the controls

'l bezel to indicate when the N

trip valve is reset and latched.

o 2SC-1288A Containment Sump Pump Modify control circuit to prevent both pumps from running prior to reaching hi-hi level due to logic error in pump alternating circuit.

2SC-1354 Aux and Fuel Handling Revise long time trip setting Ventilation of ' Auxiliary Building and Fuel

' Handling Building exhaust fans feeder breakers.

~

'2SC-1412A Annunciator System Remove " Condenser Vacuum Low" annunciator window from Panel F and add " Condenser Vacuum Low Low" annunciator window to Panel E.

2SC-1574 Boiler Feed Improve the steam sealing capability of 21-24BF19 valves.

Suggestion:

A)

g i ~

Chesterton Seal-using

-Belleville washers.

B)

Possible labyrinth packing-gland.

I i-

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(

MAJOR PLANT MODIFICATIONS DOCKET NO.:

50-311 REPORT MONTH APRIL 1985 UNIT NAME: Salem 2 DATE:

May 10, 1985 COMPLETED BY:

J.

Ronafalvy TELEPHONE:

609/339-4455

DCR NO.

10CFR 50.59 SAFETY EVALUATION 2EC-2000 The pressure transmitters are being replaced because of a malfunction of the existing transmitters.

There is no change functionally.

No unreviewed safety or environmental questions are involved.

2EC-0562 This change does not affect the function of the Waste Gas Analyzer System nor does it adversely affect any safety related equipment required for the safe shutdown of the Unit.

No unreviewed safety or environmental questions are involved.

2 EC-07 35 This change does not affect safety related equipment.

No unreviewed safety or environmental questions are involved.

2EC-1075-This change adds an additional trip for Steam Generator Feed Pumps.

It does not change the existing circuitry.

No unreviewed safety or environmental questions are involved.

2EC-1108A This is a human factor change and does not alter the function of any component in.the Control Room. -This change is in accordance with NUREG-0700.

No unreviewed-safety or environmental questions are involved.-

2EC-1265A.This change does not affect the presently performed safety analysis nor does it create any new hazardd.

This system

.is not safety related.

No'unreviewed safety or environmental questions are involved.

i; 2EC-1276 This change does not' affect any safety related system or

'f ;"

component.

The replacement of the stationary blades does not affect plant operating procedures.

No unreviewed safety or environmental questions are involved.,

2EC-1278 This change does not affect any safety related system or component.

The replacement of Nos. 21, 22 and 23 Low

,N ressure Main Turbine Rotors with refurbished rotor P

assemblies from Unit l'does not affect plant operating procedures.

No unreviewed safety or environmental questions are involved.

Design Change Request-8

r-

DCR NO.

10CFR 50.59 SAFETY EVALUATION 2EC-1305 This change addressed the intent to increase conservatism and thereby reducing the possibility of future occurrence of cracks / breaks at the test, vent and drain connections.

In addition, the section modulus of the connection will improve resistance to heretofore undetected shock load.

No unreviewed safety or environmental questions are involved.

2BC-1343 This change is only a cosmetic change and does not affect the safe shutdown of the reactor.

No unreviewed safety or environmental questions are involved.

2EC-1439 This change adds a flashing circuit to get the operators attention.

No unreviewed safety or environmental questions are involved.

2EC-1589 This DCR only involves field verification of cable routings and terminations.

No unreviewed safety or environmental questions are involved.

t

f

DCR NO.

10CFR 50.59 SAFETY EVALUATION 2EC-1615 The support modifications will make the safety valve discharge piping code compliant.

The allowable stress levels for emergency conditions are per the ASME code.

A requirement has been instituted;that, following safety valve discharge, the-Unit will be shutdown for inspection of pressurizer safety valve piping.

The supports will not impose any additional' forces on the valves.

The insulation boxes around the pressurizer piping would be seismically designed and.would lower the forces on the discharge piping because of more flashing.resulting from the higher temperature loop seal water.

Temporary thermocouples'will be installed on.each loop seal and each safety valve: inlet flange to monitor and ascertain that loop seal temperature remains above the valve used in analysis-and safety valve temperature remains within 300"F, the allowable valve from the valve manufacturer.

To keep _the valve temperature'below allowable section of

. piping upstream of the valve and the valve itself would remain outside the insulation box.

The last section of insulation has been provided in two different thicknesses to choose from, to. ascertain that valve temperature will not be exceeded.

The loop seal temperature will always stay below' saturation so that water seal will be.always maintained. -Thus, the ability of the valves to-be-leak tight will not be affected and the loop seal will' stay formed.

Together, the support and insulation modifications will make Salem safety valve-discharge piping code compliant' with NUREG 0737, Item II.D.l.

No unreviewed safety-or.

environmental questions are involved.

- 2BC-1620B This change provides for the redesignation of existing "non-vital" associated cables to vital channels.

No cable rerouting or installation is involved.

No unreviewed safety or environmental questions are involved.

_ 2EC-1658

-Electrical failure problems have been considered-but are not;a threat to becoming an unreviewed safety _ question, bc No unreviewed safety or environmental questions are involved.

p i

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a

DCR NO..

10CFR 50.59 SAFETY EV ALUATION -

3 2EC-1675-The computer. inverter is not safety related.

This-change 1 improves the reliability and performance of.the. computer.

irverter.

No unreviewed safety or environmental questions are' involved.

~

2EC-1688 This change replaces highly eroded CS pipe with 316 stainless steel.

This will not change the function of the system and'will ensure its integrity.- Supports-have been modified.or added to ensure the structural integrity of this. Seismic I system.

No unreviewed safety or environmental questions are involved.

2EC-16 89 -

This change replaces highly eroded CS pipe with 316 stainless. steel.

This will not change the function of1 the system and will ensure its integrity.

Supports have.been modified or-added to ensure the structural integrity of

-this Seismic I~ system.. No unreviewed safety or environmental questions are involved.

2EC-1690 This change replaces. highly eroded CS pipe with-316

. stainless steel.

This will not change.the function of the

- system and will ensure its integrity.

. Supports.have been modified cur added to ensure the structural integrity of

- this Seismic I system.

No unreviewed safety or environmental questions are involved.

2EC-1772 Installation of this change enhances the. operators. ability.

to determine actual sump level. ~ Present installation criteria has been adhered to.

The instrumentation functions have not been changed.

No unreviewed safety or environmental questions are involved.

2EC-1811 The intended function of theisystem remains unchanged.

No e-

[

unreviewed safety or environmental questions are involved.

['

2EC-1829 This change is a conventional installation-which does not interface or alter.any safety related equipment nor does.

L it affect the safe shutdown of the Unit.

No unreviewed

(<

safety'or environmental questions are involved.

l l

Design Change Request l

I l

l 1.

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-.2

r 3

DCR NO.

10CFR 50.59 SAFETY EVALUATION 2EC-1863 This DCR upgrades the SI Pump Lube Oil. Coolers.

The replacement coolers are -seismically qualified to :PSE&G seismic I criteria and the 1980 ASME Section III Class 3 -

1981 Summer Addenda for the tube side only.

The shell side is classified to the 1980 ASME-Section VIII, Division I.-.The new coolers will.use titanium tubing.

The. outer sheets will also be titanium.

The shell and bonnet will be.316 stainless steel.

No unreviewed safety or environmental-questions are involved.

2ET-1876 This DCR is a test-of the 4.10 KV. standby diesel generator supply breaker 2BDD anti' pumping circuit and the vital bus "B" differential relay scheme.~ No unreviewed safety or environmental questions are involved.

2EX-1879 This change revises and-verifies the #21 RCP locked rotor protection relay setpoints to determine if the motor is acceptable to remain in service or must be removed for further inspection.

No unreviewed safety or environmental questions are involved.

2EC-1896

'This DCR replaces a seismically qualified undervoltage relay. with another seismically qualified relay per Wyle test report 47-667-1.

.This DCR improves the undervoltage transfer response of the vital 4160 volt busses.

It does not adversely affect any safety related functions or equipment.

The relay will be mounted similar to the mounting-of the test relay. 1k) unreviewed safety or environmental questions are involved.

2EC-1930 This DCR does not affect the presently performed safety analysis nor does it create any new hazards.

The system is not safety related.

No unreviewed safety or environmental questions are involved.

2EC-1937 This DCR increases reliability of a non-safety system.

No unreviewed safety or environmental questions are involved.

--Design Change Request

V.

DCR NO.

10CFR 50.59 SAFETY EVALUATION 2ET-2004

'This test DCR constructs thermal mapsfof..the Unit 2 Spent Fuel Pool-as it currently exists. _ It involves the

~

temporary installation of-four vertical stainless steel

sensing poles..Each pole will be_ temporarily _ inserted into an empty fuel rack in the pool..The poles _will not affect the Spent Fuel Pool or its _ contents.

Each pole weighs-less than 100 lbs. (rack-limit-is 0.46 metric tons). - Also, the racks. are in no dangerfof nbeing damaged

'by the~ poles.since-the poles will be supported by three circular bumper rings at the lower portion of the-poles.

If a pole were to fall.in the pool, it would pose.no threat'to the pool or -its contents since: the spent fuel bundles and the racks are designed to withstand fari greater impacts.

Although the Engineering _ Instructions require the Spent: Fuel Pool Pumps to be tagged out during-the test, in no case will the pool.be Lallowed to exceed

-150*F.

The operators are instructed to startup'the pumps and the exhaust fans immediately upon reaching 115'F.

Calculations show it would take.35.3 days for.the Spent-Fuel Pool to reach 120'F when starting at 80*F and 26.5 days when starting at 90'F.

.Therefore,-based upon a review of the test, no unreviewed safety or environmental questions are involved.

2EC-20 43 The application of the flow measuring orifice will not affect any-presently performed safety analysis since this

. system is not safety related.

No unreviewed safety or environmental questions are involved.

. 2ET-20 57 This test DCR.provides a temporary back-up Turbine

~

Differential-Expansion Local Indication. System.

The Turbine Supervisory Instrumentation is not safety'related and is not a Tech. Spec. instrumentation' system.

The complete installation will be performed in the Turbine r

Hall-and will not compromise or alter any installed safety related system.

No unreviewed safety or environmental' questions are involved.

1 -

L

Design Change Request L

L L

l L

s

DCR NO.

10CFR 50.59-SAFETY EVALUATION 2EC-2071l

.This DCR provides. separate _ low suction pressure trip functions for each of the auxiliary.feedwater pumps.

This assures the required-separation-between-the redundant pump

. control' circuits.

The equipment being used in each of the pump control circuits are qualified Class 1E Components.

'The equipment, mountings, and electrical raceway are installed to their appropriate seismic criteria.

The existing equipment, which will be modified, will continue to maintain its seismic integrity.

. Isolation between the vital control circuit and the non-vital aux. annunciation has been provided as follows:

The annunciator circuit at the arming switch is

' separated from the vital control circuit through qualified safety related separate switch contact blocks.

The cable utilized for the contact signal to the-.TP Cabinets is an existing multiconductor safety related cable' The cable from the TP Cabinets to_the annunciator is designated as its associated non-vital cable in-accordance with CDS-1.

The conductors utilized with the' vital cable are separated

' and isolated by the double insulation Ant the vital and associated signal single conductors of-the cable.

As additional protection,'the Aux. Annunciator System is.

equipped with input relays to provide electrical isolation

-and a ground detection system which would. indicate on either the positive or negative side of1the alarms potential power supply.

All credible means of failure have been addressed I

including: cable system interaction.

No unreviewed safety.

or environmental questions.are involved.

f2SC-0314 The change in the upper b' earing oil fill piping willinot-L affect the operation of the motor.

No unreviewed safety L

or environmental' questions are involved.

L 2SC-0364 The change in the upper and lower bearing oil fill piping will not affect the operation of the motor._ No unreviewed L

safety 1or environmental questions are involved.

Design Change Request i

~_,_..,;_,.-,_-.--.,.L_-u-._-_-_.-_,m,..,_.

/

DCR NO.

-10CFR-50.59 SAFETY EVALUATION

^

12SC-0570 The. generation ~ tags would'not physically affect the

~

Control ~ Air 1 System or any other' plant system. _ The modification' improves:the Unit _ reliability through procedural control.

No unreviewed safety or environmental

' questions are involved.

2SC-0897/

Changing of the tube material of the Turbine Aux. Heat Exchanger ldoes not involve an unreviewed safety question.

The change 'does not alter the design, performance, or operation of'the TAC. system..-This modification;will not.

affect any plant process or discharge and will not affect the existing plant impact.

-2SC-0914 This change is.to a non-safety related system.

No unreviewed safety or environmental questions are involved.

2SC-0941' This change is to a non-safety related system.

No unreviewed safety or environmental questions are involved.

- 2SC-1247 This-change will not alter any plant process or' discharge

and will not affect. thel existing plant. impact.

tha -

'unreviewed safety.or environmental questions are involved.

2SC-1273 This change enhances the operators Control' Room-..

indications for.the #23 Aux. Feed-Pump.-

No unreviewed safety or environmental questions are involved..

2SC-1288A _ All potential. realistic : failure modes have been considered.

No unreviewed safety or environmental-questions are involved.

2 SC-1354 The adjustment of the overcurrent~ protection.on the Aux.

and' Fuel Bldg. Exhaust Fan Motors.will eliminate setpoint drift; problems.

The new setpoints1will still provide adequate overcurrent protection. _No unreviewed safety.or

~

environmental questions are. involved.

2SC-1412A The moving-of an annunciator window to a new location does not affect any safety functions are safety-related equipment.. No unreviewed safety or environmental

~

questions are involved.

e

iDesign Change Request

DCR NO.

10CFR 50.59 SAFETY EVALUATION 2SC-1574 The_ modifications to the BF-19 valve packing will not affect-the safety related requirements of the valves.

The.

modification will minimize the potential for valve stem packing leaks, thereby-increasing valve reliability.

After repacking,.the valves will be tested to verify.

performance parameters as per' Tech. Spec. 4.6.3.1.

The basis for the SAR and the basis for the Tech.-Specs. are not affected-by this' modification.

No unreviewed safety or. environmental-questions.are involved.

Design Change Request m

4

.PSE&G SALEM' GENERATING STATIONL SAFETY ^RELATED WORK ORDER LOG.

ry

' SALEM UNIT 2 WO'NO DEPT' UNIT EQUIPMENT IDENTIFICATION 0099005506 SMD-2 RX CONO-SEALS 1 THRU 5

~ FAILURE. DESCRIPTION:

PLEASE REMOVE CONO-SEALS 1 THRU 5, CLEAN-INSPECT. AND'-

i i

REPLACE..

CORRECTIVE. ACTION:

CLEANED, INSPECTED AND REPLACED THE UPPER AND LOWER' CONOSEAL GASKETS PER M3C-1.

F I

0099017024 l

SIC 2

MAIN STEAM LINE RAD MON.

i.

FAILURE DESCRIPTION:

NO HIGH VOLTAGE MEASURED DURING CHANNEL CALIBRATION PROCEDURE.

PLEASE-INVESTIGATE AND REPAIR.

i CORRECTIVE ACTION:

REPLACED Q1 AND Q2 AND WAS ABLE TO GET THE 550 VDC-i I

WORKING.

COMPLETED CHANNEL CAL.

i 0099018586 j

SIC 2

RMS FAILURE CORRECTION:

PLEASE INVESTIGATE CAUSE OF FAILURE RELAY CAUSING FAILED ALARM ON ANNUNCIATOR PANEL ON 2RPl.

CORRECTIVE ACTION:

REPLACED CR5'ON ALARM CARD IN DRAWER.

PERFORMED APPLICABLE PORTION OF CHANNEL CAL PROCEDURE.

0099018632 l

SIC 2

24 GEN FEED CONTROL' i

l FAILURE CORRECTION: ~

4BF4n VALVE WILL NOT CLOSE WITH CONTROLLER IN AUTO.

PLEAb_ REPAIR.

CORRECTIVE ACTION:

REPLACED CONTROLLER 2FC-500D WITH EO-118 WITH HO-102.

VERIFIED CONTROLLER OPERATING PROPERLY.

s o

SALEM UNIT ~2

~WO NO DEPT UNIT ~ EQUIPMENT IDENTIFICATION-

~

0099157900 SMD 2

21 SI PMP LUBE OIL COOLER FAILURE DESCRIPTION:

THE CONNE'CTIONS INTO THE-COOLER ARE LEAKING.

CORRECTIVE ACTION:

TIGHTENED (1) ~ ONE FULL TURN ON OIL = PIPE..

'0099157926 SMD 2

22 RHR SUMP FAILURE DESCRIPTION:

6 ! INCHES OF WATER ON THE FLOOR ' AND NO HIGH' LEVEL ALARM WAS~ RECEIVED IN THE CONTROL ROOM.

CORRECTIVE ACTION:

TIGHTEN LOOSE WIRE, CHECKED FOR PROPER OPERATION, PMP WILL BE REPLACED WHEN PARTS ARRIVE

-WO # 84-10-25-108-6.

0099159953 SIC 2

MSIV - BYPASS -

FAILURE DESCRIPTION:

BLOWN DIAPHRAGM.

CORRECTIVE ACTION:

REPLACED DIAPHRAGM.

STROKED-VALVE.

0099160005 SMD 2

22MS13 FAILURE DESCRIPTION:

S/G SAFETY VALVE 22MS13 IS LEAKING STEAM EXCESSIVELY.

MAINT. DEPT..PLEASE INVESTIGATE / REPAIR.

CORRECTIVE ACTION:

GAG INSTALLED ON.22 MS 13 CL'OSED' POSITION.

REMOVED GAG - TIGHTENED ADJ_ NUT DOWN 2 TURNS +3 FLATS.

SEE WO 8504100065 DCR 2EC15 80.

i L

~

+

SALEM UNIT.2-

' WO NO DEPT UNIT EQUIPMENT IDENTIFICATION-0099160161 SIC 2

24 MS10 FAILURE DESCRIPTION:

VALVE' LEAKS THRU WITH CLOSED INDICATION.

PLEASE INVESTIGATE AND REPAIR.

CORRECTIVE ACTION:

FOUND ZERO ADJUSTMENT LOOSE.

TIGHTENED'AND CHECKED-OPERATION FROM CONTROL ROOM.

VALVE FUNCTIONED-PROPERLY FOR BOTH OPEN AND CLOSED INDICATION.

0099160251 SMD 2

22MS14 FAILURE DESCRIPTION:

MAINT. DEPT. PLEASE GAG 22MS14 VALVE.

VALVE LISTED PRIMARY DURING PLANT.

CORRECTIVE ACTION:

GAG INSTALLED ON 22 MS14 VALVE IS CLOSED.

REMOVED l,

GAG - TIGHTENED ADJ. NUT 2 TURNS AND.3 FLATS DOWN.

LIFT SET TESTED VALVE TWICE SAT SEE WO 8504100065 DCR 2SC 1580 8504231151 i

SMD 2-REPLACE 23MS46 VALVE FAILURE DESCRIPTION:

RADIOGRAPHY REVEALED HANGER ARM IS' DISTORTED ON' 23MS46 VALVE.

PLEASE REPLACE HANGER ARM ON 23MS46.

CORRECTIVE ACTION:

REPLACED HANGER ARM AND ADDED NEW BONNET GASKET.

8504270076 SIC 2

TH ERMOCOUPLE.

FAILURE DESCRIPTION:

THE OUTBOARD PUMP BEARING ON 23 COMPONENT COOLING PUMP i

WAS READING ONLY APPROX. 75 DEGREES DURING AN EXTENDED RUN..

PLEASE INVESTIGATE AND REPAIR.

CORRECTIVE ACTION:

FOUND INTERNAL SHORT.IN. OUTBOARD MOTOR TEMPERATURE.

2TA-2744A THERMOCOUPLE REPAIRED.

TWISTED LEADS AND L

SOLDERED NEW-LEADS ON THERMOCOUPLE.

INSERVICE READING 102.0 DEGREES F.

I

SALEM UNIT 2-WO NO DEPT UNIT ~ EQUIPMENT IDENTIFICATION.

~8504030130 SIC-2 22 MS18 FAILURE DESCRIPTION:

22MS18LDOES NOT GIVE A CLOSED LIMIT. INDICATION.

I&C DEPT. PLEASE ADJUST LIMITS AND' SECURE. LIMIT SWITCH BRACKET.

CORRECTIVE ACTION:

TIGHTENED LIMIT-SWITCH BRACKET.AND ADJUSTED CLOSED LIMIT SWITCH.

VERIFIED: PROPER INDICATION IN-CONTROL ROOM.

8503310040 SMD 2

21 CHARGING PUMP FAILURE DESCRIPTION:

THE PUMP OUT BOARD SEAL IS. LEAKING EXCESSIVELY.

PLEASE REPAIR. :THIS PMP IS' REQUIRED PRIOR TO ENTERING MODE 3.

CORRECTIVE ACTION:

REPLACED OUTBOARD SEAL.

REPLACED THR.

BRG.

REPLACED RELIEF VALVE AND OIL ~ PUMP ON GEAR BOX.

8503260441 SMD 2

23 SJ 54 ACTUATOR FAILURE DESCRIPTION:

PLEASE INVESTIGATE WITH VENDOR CAUSE OF 23 SJ 54 ACTUATOR FAILURE.

CORRECTIVE ACTION:

HAD VENDER IN TO INVESTIGATE FAILURE OF 23SJ54 ACTUATOR.

INSTALLED LOCKING RINGS.

ORIGINAL FAILURE OCCURRED BECAUSE A COVER PLATE WAS NOT PUT ON 8503180375 SIC 2

23 MS 10 FAILURE DESCRIPTION:

SET-POINT DOES NOT MOVE WHEN ATTEMPTS ARE MADE TO MOVE FROM THE CONTROL ROOM, PLEASE REPAIR.

CORRECTIVE ACTION:

ADJUSTED CLOSED LIMIT SWITCH TO PRODUCE CLOSED INDICATION IN CONTROL ROOM.

SETPOINT OPERATION IS SAT.

e

SALEM-UNIT 2.

WO NO

-DEPT' UNIT EQUIPMENT IDENTIFICATION 8504050408 SMD 2-21 WG COMPRESSOR BKR FAILURE DESCRIPTION:

'BKR 2EX1AX6X:

THE. CLOSING' SPRINGS.WILL'NOT CHARGE..

PLEASE INVESTIGATE AND REPAIR.

CORRECTIVE' ACTION:

REPLACED-BREAKER MOTOR.

.8504060128 SMD 2

MAIN, STEAM SAFETY y

FAILURE DESCRIPTION:

THE SAFETY. VALVE WILL NOT RESEAT.-

PLEASE REPAIR.

THE STEAM GENERATOR.WAS AT 680PSIG.

CORRECTI%6 ACTION:

FOUND SPINDEL NUT JAMMED AGAINST FORK LEVER ~.

REMOVED i

FORK LEVER.AND FREED SPINDEL THEREBY RESEATING VALVE.

THIS ACTION. DOES NOT. EFFECT - LIFT SET POINT. - REMOVED-4 LIFT AND SPINDEL NUT PER DR.

8504060152 4

SMD 2

FAILURE TO START FAILURE DESCRIPTION:

WHEN THE OPERATOR TRIED TO START THE 22 AUX FEED PUMP, THE-PUMP DIDN'T START AND HE~ RECEIVED THE FLASHING GREEN LIGHT.

THE BREAKER WAS FOUND OPEN WITH THE SPRINGS DISCHARGED.

PLEASE~ REPAIR.

l l

CORRECTIVE ACTION:

RES/N 0224A6269-013 FOR 2A100 210C, AND INSTALLED l

I'N 2B1D 22 AUX FEED PUMP.

l-8504060179

}

SMD 2

21 RCP FAILURE DESCRIPTION:

THERE IS A PIN-HOLE LEAK AT THE WELD LOCATED AI VALVE 21_CC.291.

PLEASE REPAIR.

CORRECTIVE ACTION:

GROUND OLD WELD OUT RENEWED WELD.

r SALEM UNIT 2' WO NO ' ' DEPT UNIT EQUIPMENT ~ IDENTIFICATION 8504081214-SIC 2

ROD INSERTION LIMIT FAILURE DESCRIPTION:

THE ROD INSERTION LIMIT.ON THE STRIP. CHARTS DOES-NOT:

AGREE WITH THE TECH SPEC LIMIT NOR THE RX ENG MANUAL.

SEE W.O.#- 8503260263 FOR THE FAILED 1 RETEST.

NOTE THIS IS.THE.SECOND RETEST FAILURE.

CORRECTIVE ACTION:

DISCONNECTED LEAD #16. INPUT TO 2DM-432C AND-CALIBRATED GREEN PEN AS PER PAGE 15 - OF 2IC-2.1.052 RELANDED LEAD 16.

8504091571 SIC ICS 21 LOOP TAVE FAILURE DESCRIPTION:

IT APPEARS THAT 21 LOOP TC HAS FAILED. LOW 21-RCS TAVE IS LOW AND 21 RCS DT IS HIGH.

PLEASE' REPAIR.

CORRECTIVE-ACTION:

PLACED BISTABLES IN SAFE. POSITION TO SATISFY ACTION STATEMENT AS OF 2036.

FOUND 2TM-411B FAILED LOW.

8504101665 SIC 2

1RP1 FAILURE DESCRIPTION:

12 STEPS OFF BANK POSITION CORRECTIVE ACTION:

RECALIBRATED SIGNAL CONDITIONING MODULE DETERMINED NEW AC VALVES FOR 228 100 STEPS AND VERIFIED CAL UNITE NEW DATA FAND RETURNED TO SERVICE.

8504150992 SIC 2

MSIV DRN. VALVE FAILURE DESCRIPTION:

THIS VALVE WILL NOTlOPEN.

PLEASE INVESTIGATE. AND REPAIR.

CORRECTIVE ACTION:

REPLACED SOLENOID ' VALVE PER I&C-14.1.021.

"L

T w

- SALEM GENERATING STATION MONTHLY' OPERATING.

SUMMARY

UNIT NO.-2 APRIL 1985 SALEM UNIT NO. 2 The" period began ~ with the Unit. operating in Mode 4- (hot shutdown).as Lthe'second refueling / turbine outageldrew to a close.

Alignment-and testing of -the 'new 22 Aux. Feedwater Pump was. completed.f On 4/5/85-at 2232 hours0.0258 days 0.62 hours 0.00369 weeks 8.49276e-4 months ,- the ' Unit entered _ Mode 3 (hot 1. standby).' ;On ~ 4/6/85, 22MS14

-(Steam. Generator 1 Safety. Valve) failed to reseat.

The valve-was subsequently adjusted and retested _ satisfactorily.

Selected. Steam Generator safety. valves 1were. retested to verify ' proper 'setpoint (s).

On 4/10/85 at 2259 hours0.0261 days 0.628 hours 0.00374 weeks 8.595495e-4 months , the Unit entered Mode 2 (criticality).-

Zero Lpower physics testing was initiated ~and completed.

On-4/13/85~at 0136 hours0.00157 days 0.0378 hours 2.248677e-4 weeks 5.1748e-5 months the. Unit 1was synchronized and~ power. operation' commenced.- At 0143 hours0.00166 days 0.0397 hours 2.364418e-4 weeks 5.44115e-5 months on 14/13/85,.the Unit tripped. as a result of No. 24 Steam-Generator Low Level coincident with a Steam Flow / Feed-Flow mismatch.

At - 0850. hours on; 4/13/85, 'the Unit-was brought critical- (Mode 2).

The Unit' remained in Mode.2 pending corrective actions to-621 and'#22-

~

Steam Generator Feed -Pumps. _With completion of-the Mechanical Overspeed Protection adjustment to #21 Steam Generator Feed Pump

'(SGFP)',- the Unit was synchronized on 4/17/85 at,1916 hours0.0222 days 0.532 hours 0.00317 weeks 7.29038e-4 months .

At 1928 hours0.0223 days 0.536 hours 0.00319 weeks 7.33604e-4 months on 4/17/85, the Unit. tripped as a result of No. 24 Steam Generator (S/G)= Low-Low Level.

Water: bad accumulated in'the reheat

' steam line which was. injected-into the #21 SGFP resulting in the

reduction of feed flow followed by the trip.

The Unit' was synchronized-at-1306 hours on 4/18/85.

At 2103l hours the Unit was removed from service to conduct the Turbine Overspeed Test.

Following a satisfactory test the Unit was~ returned to service at 2310 hours0.0267 days 0.642 hours 0.00382 weeks 8.78955e-4 months .

On 4/23/85 at 0022 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months , the Unit tripped on Low Turbine Oil (Pressure while switching from.one Turbine Lube Oil Cooler at another.- The Unit' was synchronized at 2215 hours0.0256 days 0.615 hours 0.00366 weeks 8.428075e-4 months the same day.

On 4/26/85 at 2300 hours0.0266 days 0.639 hours 0.0038 weeks 8.7515e-4 months , the Unit was removed from service to facilitate repairs to the "hotspot" on "C" Phase of the Isolated Phase' Bus.

The Unit was returned to service at 0700 hours0.0081 days 0.194 hours 0.00116 weeks 2.6635e-4 months on 4/28/85.

As the period _ ended,

' the ' Unit was. operating at 50% power as adjustments to #22 SGFP piping t

' supports continue.

l-l 4

4 E

REFU EL'ING - INFORMATION.

DOCKET NO.:

50-311 COMPLETED BY:

J. Ronafalvy UNIT NAME:~ Salem 2-DATE:

May 10,'1985 TELEPHONE:

609/935-6000 EXTENSION:

4455

~ Month April 1985' L1..

Refueling information has changed from last month:

YES X

-NO 2

Scheduled _date for next refueling:

September 6, 1986 3.

Scheduled date for restart following refueling: November 16, 1986

~4.

JL) I Will Technical Specification changes or other license amendments be required?

YES NO Not determined to date B)

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

YES NO X

If no, when is it scheduled?

August 1986 5.

Scheduled date(s)' for submitting proposed licensing action:

August 1986 if required-

~6.

Important licensing considerations associated with refueling:

NONE 27.

Number of Fuel Assemblies:

JL)

Incore-193 B)

In Spent Fuel Storage 140 8.

Present licensed spent fuel storage capacity:

1170 Future spent fuel storage capacity:

1170 9.

Date of last refueling that can be discharged to spent fuel pool assuming the present licensed capacity:

March 2003 8-1-7.R4 L

~F 0 PSEG Public Service Electric and Gas Company P.O. Box E Hancocks Bridge, New Jersey 08038 Salem Generating Station May 10, 1985 Director, Office of Inspection and Enforcement U.S. Nuclear Regulatory Commission Washington, DC 20555

Dear Sir:

MONTHLY 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 April 1985 are being sent to you.

Average Daily Unit Power Level Operating Data Report Unit Shutdowns and Power Reductions Major Plant Modification Safety Related Work Orders Operating Summary Refueling Information Sincerely yours,

l A

.ft e

J. M.

Zupko, Jr.

General Manager - Salem Operations JR: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 Enclosure g/k 8-1-7.R4 i

)\\

The Energy People

%2189 (20M) 1181

ML20127J840

Text

SUMMARY

Dear Sir:

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