ML19029B023

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1977 Annual Operating Report, Salem Generating Station, Unit No. 1
ML19029B023
Person / Time
Site: Salem  PSEG icon.png
Issue date: 03/22/1978
From:
Public Service Electric & Gas Co
To:
Office of Nuclear Reactor Regulation
References
Download: ML19029B023 (46)
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Text

0 1977 ANNUAL OPERATING REPORT SALEM GENERATING STATION PS~G UNIT NO. 1 The Energy People .

----------- ------~-- --- --,

- NOTICE -

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  • itEtUfrAfIDif1l~CKETL.FltE COPY DEADLINE RETURN DATE RECORDS FACILITY BRANCH

_ _ _ _ _ _J

  • ANNUAL OPERATING REPORT OF
  • SALEM GENERATING STATION .

FOR 1977

  • . DOCKET NO. 50-272 LICENSE NO. DPR-70

\__

  • (
  • TABLE OF CONTENTS
  • -i-
  • SECTION I INTRODUCTION Salem Generating Station is a PWR of 3338 MWt rated power, operated by Public Service Electric and Gas Company and located in Salem,
  • New Jersey. The Nuclear Steam Supply System is a Westinghouse 4-loop plant. The architect engineer was PSE&G Co., and the constructor was United Engineers and Constructors. The condenser
  • cooling method.is circulating water from the Delaware River. The plant is subject to license DPR-70 issued August 13, 1976, pursuant to Docket Number 50-272. The date of initial reactcr criticality was December 11, 1976, and commercial generation of power began
  • June 30, 1977.

This report was prepared by Mr. R. A. Silverio, Assistant to Manager (609-365-7000 Ext. Salem 510)

  • Major personnel changes during the e year included the Maintenance Engineer, Mr. R. A. Silverio being desig-nated as the Assistant to Manager while Mr. Stanley LaBruna assumed the position of Maintenance Engineer. Mr. James Gueller replaced Mr. Norman Millis as the Senior ~erformance Supervisor - Chemistry e and HP
  • SECTION II HIGHLIGHTS Initia1 criticality was achieved on December 11, 1976. After zero power physics tests were completed, the Unit was synchronized on
  • December 25, 1976 to complete the power escalation program. This program consisted of a combination of physics and plant response tests that were conducted at various power plateaus between 10%

and 100% power. This startup program was completed on July 30, 1977

  • with the generator trip test from 100% power, although the Unit was declared commercial on June 30, 1977.

During the latter six months of the year the Unit operated at a e capacity factor of 42.5% for a total of 2,186,310 MWe hours. Unit load decreases were mostly due to the need for cleaning secondary system strainer.s as described in Section III, Summary of Operating Experience.

An eleven week outage was taken to complete the L-4 stage modification of shrouding on all low pressure turbines; SECTION III

SUMMARY

OF OPERATING EXPERIENCE

  • The following is a chronological description of plant operations including other pertinent items of interest for the period January 1, 1977 to December 31, 1977:
  • 1-1 No. 1 Turbine Generator was synchronized at 1508. The Unit was to run at minimum load in preparation for an overspeed test.
  • 1-2 A reactor/turbine trip occurred at 0303 caused by low level in 11 Steam Generator in conjunction with a feed flow/steam flow mismatch. The Unit was at minimum load with feed control in manual *
  • At 0519 the reactor was taken critical and a series of overspeed tests run as part of the startup test program.

The Unit was synchronized at 1559 and a reactor/turbine trip initiated at 1634 as part of a Loss of Off Site Power Test.

The reactor was taken critical at 2008 .

1-3 The Unit was synchronized at 0300.

At 0353 a reactor/turbine trip was caused by Hi-Hi level

  • in 14 Steam Generator. The Unit was at minimwn load with level control in manual.

The reactor was taken critical at 0512 and the turbine-

  • generator was synchronized at 0833.

At 1016 a reactor/turbine trip was initiated as part of the Shutdown from Outside the Control Room Test. A non-isolable leak was found on the letdown line and an outage was required for repairs. The outage ended on 1-7 .

1-7 The reactor was taken critical at 2013 .

  • 1-8 The Unit was synchronized at 0219.

At 1504 a reactor/turbine trip occurred caused by low-low

  • level in 14 Steam Generator. The Unit was at minimum load with level control in manual.

The reactor was taken critical at 2140 .

  • 1-9 The Unit was synchronized at 0316.

At 1247 the Unit was taken off the line in order to repair a

  • flange leak on 12W Interceptor Valve
  • 1-10 The Unit was synchronized at 0608.
    • At 0944 a *reactor/turbine trip was caused by low-low level in 14 Steam Generator. The Unit was at minimum load with level control in manual *
  • The reactor was taken critical at 1212.

At 1604 the reactor was taken subcritical in order to comply with a Technical Specification Action Statement concerning

1-11 The reactor was taken critical at 1147 and synchronized a~ 1513 .

At 1844 the Unit was taken off the line to replace failed steam. generator feed pump suction strainers. The Unit then remained off the line unti'l 1-18 because of problems with *two

  • 1-18 The reactor was taken critical at 1518.

1-19 The Unit was synchronized at 1511. At 1710 a Hi-Hi level

  • 1-20 The reactor was taken critical at 0057.

At 0405 the turbine was rolled but a Hi-Hi level in 11

  • Steam Generator caused a turbine and feed pump trip. The feed control system was in manual.

The Unit was synchronized at 0623 *.

  • 1-22 At 0602 a reactor/turbine trip occurred following the transfer of full length control rod control power from the regular to the backup supply. The trip was traced to a fault in the backup power supply. The Unit then went to cold shutdown to repair a steam leak in 12 Steam Generator steam flow sensing line *
  • 1-23 The reactor was.taken critical at 1136.

The Unit was synchronized at 1444 *

  • 1-25 With the Unit at 265 MWe gross, the Unit tripped at 1438 due to a loss of excitation. This*was the first time the voltage regulator was placed in automatic. The voltage became very unstable; the regulator was taken out of service
  • and voltage manually reduced but due to control sensitivity a value low enough to cause a loss of excitation trip was reached *
  • The reactor was taken critical at lS56 and the Unit synchro-nized at 1727 .

1-28 With the Unit at 265 MWe gross, the Unit tripped at 1528 during the course of a regular surveillance test due to a

  • procedural error
  • The reactor was taken critical at 1641 and the Unit synchronized at 1836 .
  • At 2209 the Unit was taken off the line due to the loss of five of the six circulating water pumps when river ice caused the loss of the traveling screens d11e to overload.
  • The reactor tripped even though it was at three percent power due to the freezing of a turbine first stage pressure sensing line which incorrectly indicated turbine power .
  • After repairs were made the reactor was taken critical at 2336.

.,\ ......

1-29 The Unit was synchronized at 0128.

At 0421 a reactor/turbine trip was caused by low-low level in 12 Steam Generator. The low level was caused by the sudden loss of steam generator feed pump suction pressure which was caused by a rapid plugging of the condensate

  • pump suction strainers.

The reactor was taken critical at 0626 and the Unit was synchronized at 0725. Load was restricted to 275 MWe gross

  • since the last series of transients had seriously affected se~ondary chemistry and time was required to return chemistry to normal *
  • 2-1 At 1319 a reactor/turbine trip was caused by low-low level in 12 Steam Generator which was caused by loss of steam generator feed pump suction pressure. The Unit was at
  • 275 MWe gross *
  • The reactor was taken critical at 2211.

2-2 The Unit was synchronized at 0406.

  • At 0748 a reactor/turbine trip was caused by low-low level in 12 Steam Generator level which was caused by a loss of steam generator feed pump suction pressure
  • The reactor was taken critical at 0903 and the Unit synchronized at 1031 *
  • 2-3 The reactor was taken critical at 0022 and the Unit synchronized at 0147.
  • 2-6 At 2023 the Unit was removed from service due to river ice causing problems with the Circulating Water System. *The Unit was put back iri service at 2226.
  • 2-8 W~th the Unit at 340 MWe gross a ten percent load swing test was conducted. With all controls in automatic load was first decreased 110 MWe (10% of full load) and after the plant stabilized the load was increased the same amount. No major
  • problems were found
  • 2-10 At 1223 a reactor/turbine trip was caused by low-low level
  • gross and feedwater control was in automatic. The event
  • was caused by 12 Main Stearn Isolation Valve drifting closed which caused an increase in steam generator pressure which prevented adequate feed flow *
  • The reactor was taken critical at 2033 and the Unit was synchronized at 2234 *
  • 2-11 ~t 0947 a reactor/turbine trip was caused by low-low level

... ---* .. in 12 Steam Generator which was caused by 12 Main Steam

  • I Isolation Valve closing when a technician removed air from

The reactor was taken critical at 1134 and the Unit was

  • synchronized at 1509.

2-15 The Unit output was increased to 505 MWe gross.

  • 2-20 During the course of a startup physics, test, reactor power was reduced from 50% to 30% before being returned to 50%.

2-21 At 0528 load was reduced from 500 MWe gross to 290 MWe gross

2-24 At 1430 the Unit was tripped from 500 MWe gross as part

-~*"-***

of a startup test. The trip led to a planned maintenance outage, the main purpose of which was to replace a main generator hydrogen cooler. The outage lasted until 3-9 .

  • 3-9 At 0436 the reactor was taken critical and at 1005 the Unit was synchronized.
  • At 1449 a reactor/turbine trip occurred during a scheduled surveillance test. A fault in the Sol'id State Protection System caused both steam generator feed pumps to trip and the Unit went out on low-low level in 12 Steam Generator *
  • The reactor was taken critical at 1625 and the Unit synchronized at 1818 .

3-12 At 1030 the Unit output reached 850 MWe gross. At 1220 power was reduced to 500 MWe gross to clean feed and condensate pump suction strainers.

3-16 At 0236 while performing a Reactor Coolant System dilution in accordance with a startup test and with the Unit stable

  • at 840 MWe gross, T/AVG suddenly began decreasing.

sequent investigation revealed inadvertent valve operation Sub-at the boric acid evaporator. The load was reduced to 340 MWe gross. At the same time a position indicator for

  • No. 3 Governor Valve broke causing a false indication in the overspeed protection circuit which started to close the governor and interceptor valves. The Unit was manually tripped at 0357 *
  • The reactor was taken critical at 2130.

3-17 The Unit was synchronized at 0444 *

  • 3-18 At 1500 a reactor/turbine trip was caused by a loss of reactor coolant flow when power was lost to two operating reactor coolant pumps. Subsequent investigation revealed

. ........* a spurious opening of a 500kV breaker .

The reactor was taken critical at 2048 and the Unit synchronized at 2316 *

  • 3-20 Reactor power varied between 63% and 24% due to problems with the quadrant power tilt .ratio *
  • 3-22 Reactor power was maintained at 49% while investigating problems with the quadrant power tilt ratio.

The Units output was increased to 880 MWe gross.

  • 3-23 3-25 With the Unit at 870 MWe gross a ten pe!cent load swing test was conducted. The load was first decreased to 720 MWe and after the plant had s.tabilized was increased back to 870 MWe .

3-27 Reactor power was decreased from 75% to 50% to clean r

{ steam generator feed pump suction strainers.

  • 3-28 At 0330 Unit output was returned to 880 MWe gross.

3-29 At 1359 with the Unit at 870 MWe gross a 50% load rejection

  • was* performed as part of a startup test.

to 320 MWe. No problems were encountered.

Load was. decreased 3-30 At 1308 with the Unit operating at 870 MWe gross a reactor/

The outage lasted until 4-3.

4-3 The reactor was taken critical at 1258 and the Unit synchronized at 2236.

4-4 At 1019 the Unit was taken off the line and the reactor taken subcritical due to excessive Reactor Coolant System identified

  • leakage.

checked.

A containment entry was made and a series of valves Reactor Coolant System identified leakage was then determined to be well within limits and the reactor was taken critical at 1944 and the Unit was synchronized at 2303 .

4-5 The Unit output was increased to 950 MWe gross.

. 4-6 The load on the Unit was reduced to 620 MWe to allow for the cleaning of feed and condensate pump suction strainers.

4-7 The Unit output was increased to 1030 MWe gross .

4-9 12 Governor Valve position linkage broke forcing a load reduction to 470 MWe gross for repairs .

  • cause of the dropped rod.

4-12 The reactor was taken critical at 0340 and the Unit synchronized at 0832

  • At 1001, power to 14 Reactor Coolant Pump was lost when transferring a bus from the station to auxiliary power transformer
  • At 103,2,

(

14 Reactor Coolant Pump was restarted and the ensuing transient caused a 14 Steam Generator Hi-Hi level turbine/reactor trip followed by a safety injection due

  • to high steam flow and low T/AVG.

4-13 The reactor was taken critical at 1721 and the Unit was synchronized at 2000. Power was limited to 560 MWe gross

  • due to repairs required to 12 Condensate Pump upper motor bearing.
  • 4-21 Unit output returned to 1030 MWe gross.

4-22 Power was reduced to 550 MWe gross for condenser inspections and feed and condensate pump suction strainer

  • cleaning
  • 4-29 . At 1052 the reactor was tripped manually from 90% power when the operators noticed the control rods stepping in,
  • 200 MWe on the generator, and the E-H trip light on the E-:a energized.

4-30 At 0829 the reactor. was taken critical and the Unit was

  • synchronized at 1132. Load was limited to 270 MWe due to an inoperable valve in the charging system
  • 5-4 At 0901 a Unit shutdown was started to repair several valves in the Charging and Letdown System. The outage lasted
  • until 5-7
  • At 1100 the reactor tripped from 4% power due to a steam flow/feed flow mismatch in conjunction with a low level
  • in 14 Steam Generator. The trip was caused by a technician working on a steam flow channel.

5-7 The reactor was taken critical at 1613 and the Unit was

  • synchronized at 1828
  • 5-9 The Unit output was returned to 1030 MWe gross.
  • 5-13 Load was decreased to 550 MWe to clean steam generator feed pump suction strainers.

5-14 The Unit output was returned to 1030 MWe gross.

5-18 The Unit was removed from service to torque up on leaking steam generator manways *

  • 5-19 The Unit was synchronized at 1653.

5-20 The Unit output was increased to 1110 MWe gross .

  • 5-22 Unit load was decreased to 90% to repair 13 Governor Valve
  • position linkage.

5-23 Unit output was increased to rated load of 1136 MWe gross.

5-25 At 0930 reactor power was rapidly decreased to 55% due to a failure of 11 Steam Generator Feed Pump .

  • 6-1 Unit output was returned to 1136 MWe gross .

6-4 At 1053, with the Unit at full load, a reactor/turbine trip

  • occurred. An electrical fault in the cable for 14 Reactor Coolant Pump caused the pump to trip and the Unit to trip on loss of reactor coolant flow.* Subsequent investigation revealed extensive damage to the reactor coolant pump cable
  • and a pressurizer heater transformer. The repairs necessitated an outage that ended 6-18.

6-17 The reactor was taken critical at 1522 .

6-18 The Unit was synchronized at 0325.

6-21 Unit output was returned to 1136 MWe gross. At 1518 a turbine

  • runback occurred from 100% to*92% power. It was caused by a procedural error in a functional test.

6-22 At 2013 load was reduced to 70% to clean condensate pUinp e(

suction strainers.

6-24 Three startup tests were run that required load changes.

  • One test involved a slow power dec~ease from 100% to 80%

followed by a slow power increase from 80% to 100%. The second test was a rapid 10% load swing test from 100% to 90%

and then after equilibrium had been established a return to

  • 100%. The third and final test was a 50% load rejection test from full power. All tests were run successfully.

6-26 As part of the startup test program a generator trip test

  • from 100% power was conducted. The trip was initiated by opening the generator output breakers at 1013. The reactor was taken critical at 1942 and maintained at 10-B amps for a ~enon follow test .

6-29 The Unit output was returned to 1136 MWe gross. At 2315

  • the load was reduced to 50% to clean 12 Steam Generato*r feed pump suction strainer.

6-30 The Unit was declared commercial at 0001.

  • 7-4 At 2308 the Unit load was decreased to 70% to clean condensate pump suction strainers.
  • 7-5 unit load returned to 1136 MWe. At 1518 a reactor/turbine trip was caused by an under voltage condition on the reactor coolant pump busses. The undervoltage condition was caused by oscillations in the_ generator voltage regulator *
  • The reactor was taken critical at 2322.

7-6 The Unit was synchronized at 0500 *

  • At 2111 with the Unit at minimum load a reactor/turbine trip occurred. It was caused by a low level in 12 Steam Generator in conjunction with a steam/feed flow mismatch. The event
  • was .caused by an oscillation in the feed flow control circuit.

7-7 The reactor was taken critical at 0031 and the Unit synchronized at 0403

  • The Unit output was increased to 1080 MWe gross by 1500.

7-8 Unit load was reduced to 535 MWe gross in order to clean

  • feed and condensate pump suction strainers.

At 1327 a shutdown of the Unit was started in order to repack a non-isolable valve in the Charging System. The

  • outage lasted until 7-13.

7-13 The reactor was taken critical at 0230 and the Unit was synchronized at 0647 *

  • 7-14 The Unit output was returned to 1110 MWe gross.

7-17 At 2045 the unit tripped from 100% power due to a faulty

  • auto stop oil pressure switch.*

7-18 The reactor was taken critical at 0759. The Unit was synchronized at 1116 and was at full load by 2225 *

  • 7-20 At 0550 a power reduction was started in order to comply with a Technical Specification Action Statement concerning the Boric Acid System *
  • At 2025 the Action Statement was terminated and the Unit began increasing load *
  • 7-21 At 2028 a rapid load decrease from 100% to 70% power was started when 11 Condensate Pump became inoperable. At 2033 load was 70% and 11 .Condensate Pump was out of service *
  • 7-22 Reduced load to 30% to clean feed and condensate pump suction stra.;Lners.

7-25 At 0450 the Unit was removed from service.because of high

  • back pressure in the condenser. The cause was a loss of seal water to the vacuum pumps.

The Unit was returned to service at 0644

  • 7-28 At 2340 the Unit returned to full load.
  • 7-30 At 0700 the Unit was tripped from 100% power as part ot a required startup test .

The reactor was taken critical at 1604 and the Unit was synchronized at 180.8.

7-31 Load was limited to 80% due to two circulating water pumps out of service

  • 8-3 At 1624 a reactor/turbine trip occurred from 100% power during the performance of a required surveillance procedure.
  • A technician failed to block the intermediate range channels prior to placing a switch to normal.

The reactor was taken critical at 2246 .

  • 8-4 At 0111 the Unit was synchronized.

8-5 Unit operating at full load.

  • l.- At 2305 power was reduced to 60% to clean feed pump suction strainers *
  • 8-8 Unit operating at full load.

8-12 At 2102 power was reduced to 60% to clean feed pump suction strainers *

  • 8-13 At 1324 a reactor/turbine trip occurred from 54% power caused by a low level -in 12 Steam Generator in conjunction with a steam flow/feed flow mismatch *
  • The reactor was taken critical at 1540 and the Unit was synchronized at 1949 *
  • At 2311 a reactor/turbine trip occurred from 39% power caused by a loss of hydraulic oil pressure. The oil pressure switches were calibrated and found acceptable .

8-14 The reactor was taken critical at 0646. The Unit was synchronized at 0850 and full power was reached at 2150 .

  • 8-16 Unit load reduced to 70% to clean condensate pump suction strainers.
  • 8-17 Unit load reduced to 53% to clean feed pump suction strainers.

8-18 Unit operating at full load.

8-20 Unit.load reduced to 50% to clean feed pump suction strainers.

8-21 Unit operating at full load *

  • 8-26 Reduced load to 50% to run a load capability test with one feed pump and one condensate pump out of service.

8-27 Unit operating at full load.

8-30 Reduced load to 55% to clean feed pump suction strainers and then returned the Unit to full power .

  • 9-1 The Unit operated at essentially full load until 9-13.

9-13 Unit load reduced to 60% to clean condensate and feed pump strainers

  • 9-14 Unit operating at full load.

9-15 Unit load reduced to 54% to clean condensate and feed pump

  • strainers.

9-16 Unit operating at full load .

  • A power reduction was started at 1830 to remove Unit from

(

service for a maintenance outage .

At 2345 a reactor/turbine trip occurred. It was caused by a low-low level in 12 Steam Generator. Prior to the

  • -trip, 12 Steam Generator Feed Pump had blown a gasket on the suction strainer cleanout flange. The pump had been tripped and isolated but 11 Steam Generator Feed Pump did not pick up speed either in automatic or manual *
  • 9-17 Began maintenance outage. The main purpose of the outage was to modify the L-4 stage, shrouding on all low pressure turbines. The modification was proposed by the turbine
  • manufacturer to minimize harmonic induced vibration in the L-4 rows of turbine blades. The modification will reduce the pro~ability of vibration induced fatigue cracking at the blade roots. The work was done under the turbine
  • manufacturer's warranty. The outage ended 11-24.

11-23 The reactor was taken critical at 1211. The remainder of the day was spent rolling the turbine at various speeds to check vibration.

At 2311 while increasing turbine speed to 1020 RPM the Unit tripped on high vibration. The turbine was then

  • placed on the turning gear to allow the shaft to straighten.

11-24 The turbine remained on the turning gear until 1100. The turbine was then rolled to 1800 RPM. No balancing was

  • necessary.

The Unit was synchronized at 1718 and load was increased to 140 MWe_ gross for turbine stretching prior to the

11-25 At 0525 the Unit was removed from service in preparation

At 2143 the Unit was synchronized .

  • 11.;,.26 At 1856 the Unit was taken out of service to repair a non-isolable failed steam pressure tap on the turbine.

11-27 The Unit was synchronized at 0230 and load was limited to

  • 270 MWe gross.

At 2215 a reactor/turbine trip occurred due to a loss of auto-stop oil. No definite reason was found ..

11-28 At 0519 the reactor was taken critical and the Unit was synchronized at 0939. Power escalations were limited to 3% per hour because of fuel warranty restrictions

  • 11-29 At 1000 the Unit output reached 500 MWe gross. Load was restricted to 50% while cleaning *steam generator feed pump suction strainers .

At 2100 a load reduction was initiated to take the Unit off I

the line to repair the steam generator feed pump suction

  • valves. The. outage lasted until 12-3
  • 12-3 The reactor was taken critical at 2030 and the Unit synchronized at 2331 *
  • 12-4 Unit output increased to 60% load.

12-5 At 1831 a reactor/turbine triE occurred. The Unit tripped

  • because of low~low level in 12 Steam Generator. The low level was caused by loss of feed pump suction pressure.

12-6 The reactor was taken critical at 0240 and the Unit was

  • synchronized at 0518 .
  • At 2Q34 a re~ctor/turbine trip occurred. The Unit tripped because of low-low level in 12 Steam Generator. The low level was caused by loss of feed pump suction pressure .
  • The reactor was taken critical at 2204.

12-7 The Unit was synchronized at 0016.

  • At 1600 the Unit output was 640 MWe gross.

12-8 At 0637 a turbine runback occurred reducing load from

  • 860 MWe to 610 MWe gross~ It was caused by a turbine first stage pressure channel failing high. The run back was stopped by placing both reactor and turbine control in manual *
  • 12-9 The Unit reached full load of 1135 MWe gross.

12-10 Power was reduced to 70% at 2026 for cycling of heater

  • drain pumps as part of a program to clean the Feed* and Condensate System.
  • 12-12 Unit output returned to full load of 1136 MWe and remained
  • at full power until 12-16.

12-16 Reduced load to 70% to clean condensate pump strainers.

  • 12-17 The Unit output returned to full load.

Power was reduced to 70% at 2011 for cycling of heater

  • dra~n pumps as part of a program to clean the Feed and Condensate System.

12-19 Unit output was returned to full load of 1136 MWe and

  • remained at full power until 12-22
  • 12-22 Power was reduced to 70% for cycling of heater drain pumps and cleaning of condensate pump suction strainers .

12-23 Unit output was returned to full load of 1136 MWe and remained at full power until 12-25 *

  • 12-25 Reduced load to 50% to cycle heater drain pumps and to clean steam generator feed pump suction strainers *
  • 12....;26 -At 2135 Unit output was returned to full load.

12-27 Reduced load to 70% to clean condensate pump suction strainers.

Returned to full load

  • 12-28 Reduced load to 70% to clean condensate pump suction strainers.

Returned to full load .

  • 12-29 At 1330 a reactor/turbine trip occurred caused by 14 Steam Generator steam flow/feed flow mismatch in conjuncton with a low level. This was caused by a spurious trip of 11 Steam Generator Feed Pump.

The reactor was taken critical at 2151 and the Unit was synchronized at 2338 *

  • 12-30 At 1830 the Unit output was returned to full load.

12-31 Reduced load to 70% to clean condensate pump suction strainers.

SECTIO'N IV SALEM GENERATING STATION COMPLETED DESIGN CHANGE REQUESTS SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0004 M915 CHILLED WATER . THERMOWELL MODIFICATION TO EQUIP.PERFORMS SAME FUNCT. &

INCREASE SENSITIVITY MEETS APPLICABLE REQUIREMENTS.

ED-0006 GOOO EQUIP. DRAINS CHANGE SEVERAL 2" EQUIP. NOT SAFETY RELATED DRAINS FROM 12 UNIT EQUIP.

DRAINS TO 11 UNIT FLOOR DRAINS ED-0007 F700 FEEDWATER . REPLACE SOLENOIDS FOR VALVES CHANGED TO MEET ORIG.DESIGN BF-19 AND BF-40 COHMITTHENT FOR RESPONSE TIME.

ED-0008 C900 RAD. MONITORING REPLACEMENT OF VALVES lVC-7 VALvE CHANGE HAKES SYS.OPERATE THRO lVC-14 WITH NEW TYPE AS ORIGINALLY DESIGNED.

ED-0012 F700 FEEDWATER VIBRATION DAMPENCR FOR NOT SAFETY RELATED RECIRC. LINE ED-0013 M530 WASTE DISPOSAL- INSTALLATION OF STEAM TRAPS IN NOT SAFETY RELATED LI QUID BORIC ACID AND WASTE EVAP.

CONDENSATE RETURN LINES ED-0016 WlOO CHEM. TREATMENT MOVE PANEL NOT SAFETY RELATED ED-0018 MOOO PLATFORMS RELOCATION OF PLATFORM TO NOTE 1 AVOID INTERFERENCES ED-0020 R400 PWR. TO N.I.S. SOLATRON REPLACEMENT NOTE 2 ED-0021 M600 SERVICE WATER VIBRATION RESTRAINTS FOR 8" NOTE 3 BYPASS ED-0022 M910 AUX.BLDG.VENT. SETPOINT CHANGE-EXHT.FLANGE NOT SAFETY RELATED INLET GUIDE VANES SYST SAFETY DCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0023A M600 SERVICE WATER INSTALL NEEDLE VALVES TO VARY NOTE 4 CLOSING TIME OF VALVE SW-58 ED-0024 Rl20 SOLID STATE CIRCUIT MODIFICATION - NOTE 5 PROTECTION DIODES ED-0025 N620 CONT.SPRAY REPLACE ORIFICE PLATE FE-930 EQUIP.PERFORMS SAME FUNCT.

ED-0026 M600 SERVICE WATER MODIFICATION TO BYPASS NOTE 6 VALVING SW-48 ED-0027 M600 SERVICE WATER MOTOR MODIFICATIONS NOTE 7 ED-0029 M600 SERVICE WATER PROVIDE CATHODIC PROT. FOR NOT SAFETY RELATED SW PUMPS ED-0030 M250 SECURITY SYSTEM REPLACEMENT OF EXISTING FUNCTION NOT CHANGED.

PUSHBUTTONS FOR DOOR EGRESS NOT SAFETY RELATED WITH MICROWAVE MOTION DETECTORS ED-0031 TlOO ELECTRO-HYDRAULIC CHANGE OF TURB.TRIP-REACTOR CHANGE MADE TO MEET TECH.

CONTROL (EHC) TRIP SETPOINT FOR TURB.STOP SPEC. REQUIREMENT.

VALVE CLOSURE ED-0032 C900 RAD.MONITORING REPLACEMENT OF SAMPLE PUMP FUNCTION NOT CHANGED.

WITH NEW TYPE NEW PUMP HORE RELIABLE.

ED-0034 W200 DEMIN.WATER COATING OF FLANGE TO PREVENT NOT SAFETY RELATED CORROSION ED-0036 M600 CONTROL AIR REMOVAL OF SEAL-IN CONTACT INCREASES SYSTEM FROM CONTROL AIR CONT.ISOL. RELIABILITY ONLY.

VALVE SOLENOID CIRCUIT ED-0037 M250 SECURITY SYSTEM ADDITION OF LOGIC MODULES TO NOT SAFETY RELATEp REDUCE WIND-GENERATED FENCE ZONE ALARMS ED-0039 M915 CHILLED WATER REDUCE SIZE OF SERVICE WATER NOTE 8 RECIRC.PUMP IMPELLER FOR CHILLER-COND. 8.75 TO 6.5"

-?.1-

SYST SAFETY DCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0043 M600 SERVICE WATER ADD SILT SETTLING CHAMBER TO NOT SAFETY RELATED AVOID PLUGGING OF INSTR.LINE ED-0044 R400 NIS REPLACE CHANNEL I,II AND III NOT SAFETY RELATED 0.5kVA SOLATRONS WITH 0.25kVA UNITS ED-0045 R500 ROD CONTROL INSTALL FILTER ON EXISTING NOT SAFETY RELATED SOLATRON ED-0047 G210 MAIN STEAM ELIMINATE CONDRNSATE POCKET SATISFIES ORIG.~OOAL IN Fl 5 4 2 Rl'XlJIREMNI'.

ED-0047A G210 MAIN s*rEAM ELIMINATE CONDENSATE POCKET IN SATISFIES ORIG. FUNC'l'IrnAL LOW PRES.LEG OF F1522 & Fl542 RmUIREMNI'.

ED-0048 El30 4kV REVISE 4kV GROUP BUS CIRC.TRIP NOT SAFETY RELATED SETPOINT AND TEST POINTS ED-0049 C900 RAD.MONITORING CHANGE THE HIGH ALARM SETPOINT NOT SAFETY RELATED FOR CHANNELS 1R21 & 1R34 FROM 15MR/HR TO lR/HR ED-0051 El54 COMP.& INVERTER REPLACE COMPUTER-INVERTER NOT SAFETY RELATED POWER SUPPLY TO ELIMINATE DC OVERSHOOT ED-0052A TlOO TURB. E.H.C. CHANGE TERM'N PTS FOR TURB.SPEED NOT SAFETY RELATED COMPUTER INPUT CABLE 1CP90FO TO PROVIDE CORRECT SIGNAL TYPE ED-0053 E500 GEN.PROTECTION INSTALL AN "A CONTACT" OF EXCITER NOT SAFETY RELATED BREAKER TO INTERLOCK T-G TRIP DURING TURB. 'l'RIP CllECKS ED-0055 NlOO eve RPR.3/4" VENT CONN. ON LTDWN LINE NOTE 9

.:..24-

SYST SAFETY DCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0056 F800 MISC.CONDENSATE BLANK OFF ORIFICE IN BYPASS NOT SAFETY RELATED AROUND VALVE 1MC4 ED-0057 TOOO LP TURBINE LP TURB. SHROUD WELDING NOT SAFETY RELATED L-4 ROW ED-0058 G220 MAIN STEAM TURNING VANE MODIFICATION- NOT SAFETY RELATED COLD & HOT REHEAT .PIPING ED-0059 TOOO MAIN TURBINE ADDITION OF TURB.VIBRATION NOT SAFETY RELATED MONITOR ,'

ED-0063 Fl30 MAIN GEN.& CHANGE REGULAR OVER-EXITATION NOT SAFETY RELATED TRANSFORMER STV RELAY PICKUP VOLTAGE FROM 110% TO* 115%

ED-0064 F700 STM.GEN.FW REMOVE MIN. STOPS FROM li'W HEATER NOT SAFETY RELATED AND CONDENSATE INLET VALVES ll,12,13CN22 & CN27.

CHG VALVE SERV.PRESS.RATING TO 710 PSIG FROM 585 PSIG 13CN22 &

CN27 CHANGES.

ED-0065 M200 FIRE PROT. PROVIDE HORNS IN ROOMS ON ELEV. NOT SAFETY RELATED 100' ABOVE PENET.AREA THAT WILL ALARM C02 RELEASE ED-0066 WlOO CHEM.TREATMENT MJDIFY Sl'IMPLE PIPING NOT SAFETY RELATED ED-0072 F700 STM.GEN.FEED & REDUCE CONDENSER SPARGER OPEN NOT SAFETY RELATED CONDENSATE AREA FOR J:,OW LOAD RECIRC. LINE ON COND.PUMPS ED-0075 G210 SAFETY INJ. ADD VIBRATION ELIMINATORS TO ENABLES PIPING TO PERFORM LINE . ITS DESIGN FUNCTION.

ED-0076 F600 HTR.VENTS & ADD ADDITIONAL PIPE SUPPORT NOT SAFETY RELATED DRAINS SYST SAFETY OCR .NO. CODE PRINCIPAL SYSTEM SUBJECT

~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~-

EVALUATION ED-0077 F700 HT G. ST M. & COND. ADD ATMOSPHERIC VENT TO COND. NOT SAFETY RELATED RECEIVER TK-AIR BYPASS TO COND.RETURN LINE & VACUUM BKR.TO BORIC ACID EVAP.&

BATCH TANKS ED-0078 MOOO CONTROL AIR REROUTE HOR.TO AVOID INTER- NOTE 10 FERENCE (SECT.ON UNIT 2 SIDE UNISOLABLE FROM UNIT 1)

ED-0080 Rl20 SOLID STATE MODIFY THE TEST CIRCUITS FOR ENABLES SYSTEM TO MEET PROT. (SSPS) THE SSPS K RELAYS TO PROVIDE ORIG.DESIGN FUNCTION.

THE REQUIRED BLOCKING FUNCTIONS ED-0083 T800 CIRC.WATER FAD.& INSTALL CONCENTRIC COLUMN NOT SAFETY RELATED STABILIZERS FOR ALL SCREEN WASH BEARING LUBE PMPS.

ED-0090A PIPING SPEC. REVISE ADDENDA I & IA TO ELIM. NOT SAFETY RELATED 61-6200 SUPERFLOUS NOE REQ. ON 2" &

SMALLER PIPING ED-0092 NlOO eves REVISE 11 & 12 CHG.PMP.AUX.LUBE NOTE 11 OIL PMP CIRCUITRY TO ELIM.START

& STOP WITH CHARGING PMPS.

ED-0093 El54 INVERTERS ADD BLOWN FUSE INDICATORS NOTE 12 ED-0096 G210 MAIN STEAM ADD CONTACT FROM SOLID STATE EUTIP.PERroIM3 SN>E PROT. SYS. TO PREVENT QPR. HYDRAULIC FU?Cl'ION.

PROBLEMS IF VA.IS TRIPPED COINCIDENT WITH TESTING ED-0098 M600 SERVICE WATER PIN SPLINE ADAPTER TO DRIVE SLEEVE NOTE 13 IN OPERATOR OF VAI.VES 11, 12SW21 USING SET-SCREW ED-0099 C300 OVERHEAD TEMP.CHANGE OF INPUT TYPE FROM NO NOT SAFETY RELATED ANNUNCIATOR TO NC FOR WINDOW C-28 SPENT FUEL PIT LOW LEVEL TO BLOCK SIGNAL NOW AS PIT IS EMPTY

-?fi-

SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0104 T800 CIR.WATER ADD ENTRAINMENT SAMPLERS TO NOT SAFETY RELATED BAYS llA AND 12A ED-0105 G220 MOISTURE-SEP. INTERCHANGE INSTR.TUBING FOR NOT SAFETY RELATED REHTR.-STM & MAIN STM COIL DRN.TK LOW &

DRAINS HIGH LVL CONTROLLER ED-0107 G210 MAIN STEAM REMOVE CLAMPING CIRCUITS FROM WILL ELIMINATE SPURICXS VALVE CONTROLLERS ON ALL MS-10 VALVES OPERATIC:t'1 1\S ORIG.DESI~.

TO PREVENT MISOPERATION ED-0110 M940 CONT.VENT. MODIFY SUPPORT OF CRDM.VENT. NOT SAFETY RELATED FAN & THERMOWELL ED-0116 El60 11 AUX. REVERSE W4M AND WM CURRENT NOT SAFETY RELATED TRANSFORMER CONNECTIONS ED-0117 F700 SG FW ADD ELBOW STRAINERS TO SGFP NOT SAFETY RELATED SUCTION ED-0120 MlOO eves ALTER AIR SUPPLY TO CV172 TO PERMIT CLOSURE DURING DILUTE-BORATE MODE OF OPERATION ED-0121 T800 CIRC.WTR. CHANGE ALRM SETPOINT OF CIRC. NOT SAFETY RELATED WTR.SCREEN WASH & BEARING LUBE PMP STR.HIGH DIFF.PRESS.

TO .12 PSI ED-0122 Rl20 NUCLEAR INSTR.- MODIFY O.H.ANN.ALARM CIRCUITRY NOT SAFEEY RELATED SOLID STATE PROT. OF WINDOW D5 & D21 TO BLOCK SYS. ALARMS AT POWER -

ED-0123 WlOO CHEM.TREATMENT ADD TIME DELAY RELAY TO ALARM NOT SAFETY RELATED CIRCUIT OF KA-3279 IN ORDER TO MAINTAIN ALARM WHEN SCANNING FROM POINT TO POINT SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0124 M600 SAFETY INJ. STIFFEN BASEPLATE OF 112 NOTE 14 SAFETY INJ.PMP.MOTOR ED-0125 C900 RAD.MONITORING REPLACE GM TUBES FOR Rl4 EUJlP. PERFOJM3 S1\ME FUNCT .A9 *

(TRACER LAB)WITH JOHNSON ORIG. DESirnED BLUE TUBE ED-0126 T300 TURD.GLAND CORRECT PRESSURE REGULATION NOT SAFETY RELATED SEALING STM & PROBLEM LEAK OFF ED-0128 C900 RAD.MONITORING SETPOINT CHANGE - Rl8 NOT SAFETY RELATED MONITOR ED-0136 PlOO FRESH WATER REVISE OPERATIHG SEQUENCE NOT SAFETY RELATED OF PUMPS 2 AND 3 ED-0145 R200 RX COOLANT CHANGE RCP SEAL SHIMPACK THK. NOT SAFETY RELATED ED-0148 R200 RX COOLANT ADD AUTOMATIC CONTROL SYS.& NOT SAFETY RELATED ALM.TO LIMIT RX COOLANT SYS.

OVERPRESSURIZATION ED-0149 M510 WASTE DISPOSAL CHANGE SOLENOID VALVE SV398 & WJIP. PERFOJU.S SAm ~. A9 SV402 TO ASCO TYPE FT8321A2 TO ORIGINALLY DESIGIBD INCREASE VALVE 1WL99 & lWLlOB RESPONSE TIME ED-0152 MlOO FRESH WATER PROVIDE TIE-IN POINT FOR NOT SAFETY RELATED PRETREATMENT PLANT ED-0153 SWITCHGEAR CHANGE SCALE ON CONTROLLER NOT SAFETY RELATED VENTIL. TA-9539-lC FROM 0-100 TO 0-200 ED-0155 G216 STM.GEN.DRNS.& RESET pH ALARM FROM 8.5-9.0 NOT SAFETY RELATED BLOW DOWN TO 8.4-9.1 SYST SAFETY DCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0156 El30 4kV VITAL BUS CHANGE 1B4D & 1C4D 4160/480V REVISED SETPl'. OOES ml' TRANSFORMER OVERCURRENT RELAY CXM>IO<<SE POOi'. OF E}JUIP. 1\$

SETTING TO PREVENT TRIPPING DESIGIED.

DURING START ED-0157 F200 CONDENSATE MODIFY CONDENSATE PMP MTR. TO NOT SAFETY RELATED

'COMPLY WITH PRESENT MFG.STDS.

ED-0164 F200 CONDENSATE RESET CATION CONDUCTIVITY NOT SAFETY RELATED ALARM 0.9 TO 0.5 MICROMHOS ED-0165 G216 S.GEN.PRNS.& ADD 1.5" OF CONVENTIONAL INSUL. NOT SAFETY RELATED BLWDN- TO UNINSUL.SGD&B LINES TO REDUCE HEAT IN NORTH PENE.BLDG.

ED-0171 T800 CIRC.WTR. MODIFY TRAVELING SCREENS TO NOT SAFETY RELATED ACCEPT CONTINUOUS OPERATION ED-0173 NlOO eves REVISE VIBRATION ELIMINATOR NOTE 15 DESIGN ON 13 CHG PMP SUCT.LINE FROM LEAF SPRING TO TORSION

..... PLATE TYPE ED-0174 G216 SG BLOWN ALTER HANGERS STEEL FOR ACCESS NOTE 15 TO 14GB4 ED-0176 MCOO CONTROL AIR REJ,OCATE INST. TRAYS T-2017C & F't.ltCl' .ASPEX:"l'S OF SYS. .ME T-2018C DUE TO PIPE INTERFERENCE IDl' awr.ED.

ED-0178 El60 Ul & 12 STA. PWR CHANGE 11 & 12 STA.PWR.XFMER. NOT SAFETY RELATED TRANSFORMERS INTERLOCK FROM 52/ST OF BS2-3 &

BS5-6 TO 52 AUX.CONTACT ED-0179 C900 RAD.MONITORING RECALCULATION OF RlB (LIQ.RAD NOT SAFETY RELATED WASTE)WARNING & ALARM SETPTS.

ED-0180 M400 FENCE LIGHTING LOCATE FIXTURE INSIDE FENCE NOT SAFETY RELATED LINE NEAR BARGE SLIP SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-:0181 CONDENSERS ADD 4 BAFFLES TO 4 CONDENSER NOT SAFETY RELATED CONNECTIONS TO MIN.DAMAGE TO CONDENSER TUBES ED-0184 F600 HTR.DRN.PMP ENCAPSULATE END TURN INSUL. NOT SAFETY RELATED MOTORS ED-0187 T800 CIRC.WTR. MODIFY FISH COUNTING POOL TO NOT SAFETY RELATED COMPLY WITH REQ. OF ETS APP. D ED-0188 R600 lEP PZR.XFMR. DISCONNECT XFMR.TEMP.ALARM NOT SAFETY RELATED SETPT OF 190°C-THIS IS NOT ABOVE DES.CONDITIONS ED-0190 G216 STM.GEN.DRNS .& REPLACE GAGES TL-6233,TL-6997 NOT SAFETY RELATED BLOWN. & TL-6998 WITH A NEW RANGE TO COMPLY WITH DES.SPECS.

ED-0192 W240 NON-RAD.WASTE INSTALL MICRO TYPE LIMIT SWITCH NOT SAFETY RELATED ON VALVES iLW26, 11LW9 & 12LW9 DUE :TO EXCESSIVE MAINT.

ED-0200A P250 SECURITY UPGRADING & ADDITIONS OF SECURITY NOT SAFETY RELATED SYS.EQUIP.INSIDE PLANT STA.BLDGS.

TO COMPLY WITH 10CFR73.55 REQ.

ED-0211 M910 AUX.BLDG.VENT. CHANGE CONNECTION OF PltESS SWITCH M.l\ffiIN OF SAFETY' 001' mDnD PD7540 INPUT FROM OUTPUT TO INPUT IMPKJVE SYS'l'EM OPERATION.

OF TA7539-1C CONTROLLER ED-0212 EllO FLASHOVER PROT. WITHDRAW N4C RELAY & DISABLE NOT SAFETY RELATED OF 500kV GEN. PJCllAV RELAY TARGET BKR.

ED-0225 NlOO eves REVISE SUCTION PIPING TO 113 DESIGN CRITERIA NOT CHG.PMP.TO ELIMINATE GAS CHANGED.

POCKETS*

ED-0226 G210 MAIN STEAM MODIFY MAIN STM.COIL ORN. TK. NOTE 16 PIPING HANGERS TO REDUCE MAGNITUDE OF VIBRATION

SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0227 R200 REACTOR COOLANT CHANGE ALLOWABLE SEAL WATER NOTE 17

!NJ.TEMP.FOR RCP FROM 130 TO 140°F ED-0232 N520 SOLID RADWASTE INSTALL SAMPLE CONN IMMED. NOT SAFETY RELATED UPSTR.OF VA.lWSB ON EVAP.

BOT.XFER PMP.RECIRC.LINE ED-0237 P200 REACTOR COOLANT REPLACE PZR.HTR.400A FUSES NOT SAFETY RELATED WITH 450 A FUSES ED-0238 F500 GEN.PROT. INSTALL JUMPER BETWEEN TERM. NOT SAFETY RELATED 15 & 16 OF NEG.SEQUENCE RELAY 1NC77B ED-0241 M200 FIRE PROT. ADD 6" GATE VALVES TO SUPPLY NOT SAFETY RELATED HORS. FOR FUTURE MODIF.

ED-0242 T900 TURD.AUX. CHANGE SETPT.ON H2 COLD GAS NOT SAFETY RELATED COOLING EXCITER COLD GAS & STATOR COOLING WTR. TO W RFC.

ED-0246 R200 PRESSURIZER REPLACE POSITIONERS AND I/p FUNCT.IS NOT CHANGED.

TRANSDUCERS FOR THE PZR SPRAY VALVES PSl AND PS3 ED-0256 F700 FEEDWATER CHANGE SGFP MIN.SUCT.PRESS. NOT SAFETY RELATED SETPT. TO 215 PSIG ED-0265 M600 SERVICE WATER CHANGE MTL. OF TUBE SHEETS SAFETY ANALYSES OF SYSTEM 001' TO s. s. AFFEL"l'ED BY awa.

ED-0268 MCOO SERVICE WATER REVISE PIPING TO COIL BANKS IN SAFETY ANALYSES OF SYSTEM 001' 112 FCV DUE TO REPLACEMENT WITH AFFECI'ED BY awa.

UNIT 2 COIL BANK ED-0269 GlOO BLEED STM. REMOVE LAGGING ON Ill & 12 FW NOT SAFETY RELATED llTR. & PIPING INSIDE CONDENSER NECK TO PRECLUDE CONDENSER TUBE DAMAGE

-~1-

SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION ED-0270 MCOO CONTROL AIR ADD UNIONS TO LINES WHICH ARE SAFm'Y' l\NALYSES OF SYS.

INSTALLED WITHIN THE PULL SPACE 001' AFFH:l'ED.

OF THE FAN COIL UNIT COIL BANKS 111,12,13 & 14 FAN COILS ED-0276 W300 NON-RADIOACTIVE CHANGE SETPT OF HA1468 & VALVE NOT SAFETY RELATED WASTE lLWlS FROM pH 6.5-8.5 TO 6-9 ED-0280 C900 RAD.MONITORING REVISE SETPT OF R-18 NOTE 18 ED-0290 TlOO EHC REPL. SOLIDSTATE CONTROLS INC NOT SAFETY RELATED PWR.SUPPLIES WITH LAMBDA ELECTRONICS COPR.PWR.SUPPLIES ED-0303 NllO REACTOR COOLANT REVISED PGS.FOR CRD INST.BOOK NOT SAFETY RELATED MD-0009 M915 CHILLED WTR. INSTALL DRYER-FILTERS IN LIQ. NOTE 19 FREON LINE MD-0010 NlOO eves ADD VALVING & PIPING TO NOT SAFETY RELATED FACILITATE N2 PURGE OF PWST MD-0018 M400 LIGHTING INSTALL 3 LGTN.FIXTURES ON NOT SAFETY RELATED PANEL "TllD" CB 113 MD-0021 N220 RHR SYS MACH.RHR PMP UPPER BEARING SYS. FllOCT. 001' OU\NGED.

ADAP.PLATE TO PREV.OIL BUILDUP MD-0023 M600 SERVICE WATER MOVE WTR.LINES TO 1115 SERVICE SYS.~.001' OWGm.

MD-0026 G216 STM.GEN/BLDWN CHANGE OVERLOAD PROT.RELAYING NOT SAFETY RELATED FOB-3PH TO B.D.TRANS.PMP.MTR.

MD-0035 T300 TURD.GLAND SEAL INSTALL FLANGES IN INTERCEPT NOT SAFETY RELATED STM.& LEAKOFF VALVE LEAKOFF LINES TO FACILIT.

TURB.COVER REMOVAL MD-0037 El70 PWR.SYS. REVISE FEED TO BILLING METERING NOT SAFETY RELATED METERING FROM 112-MAC-CAB TO 114-MJ\C-CAB

-32..;,

SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION MD-0038 N510 N2 SUPPLY-GASEOUS ENLARGE N2 SUPPLY NOT SAFETY RELATED RADWASTE MD-0040 MBOO COMPRESSED AIR ADD ADDITIONAL SUPPLY TO NOT SAFETY RELATED T.G. AREA MD-0042 M400 T.G. AREA PROVIDE FEED FOR WELDING NOT SAFETY RELATED LIGHTING ROD OVENS MD-0053 M940 CONT.-PERSONNEL REVISE CIRCUITRY TO GIVE NOT SAFETY RELATED ACCESS HATCH BETTER INDICATION OF DOOR STATUS MD-0061 F200 STM.GEN.FEEDPUMPS PROVIDE ACCESS HOLE IN NOT SAFETY RELATED 11 & 12 BASEPLATE MD-0075 GOOO MAIN TURB. INSPECT & MODIFY TURD. NOT SAFETY RELATED BLADES PER W AID 7703 MD-0084 PERSONNEL ACCESS* PROVIDE PROBE INPUT TO NOT SAFETY RELATED HATCH-CONT. OVERHEAD ANN. DISPLAY C-43

..... MD-0089 M810 HSE.HTG.BOILER INSTALL MECH.SEAL IN BOOSTER NOT SAFETY RELATED FEED & FEED PMP DUE TO PACKED PMPS EXCESSIVE LEAKAGE MD-0090 NlOO eves PRI.WTR. REPLACE TEMP.INSUL.ON 2 & 4" NOT SAFETY RELATED RECOVERY OUTLET LINES FROM PWST.INSTALL PERM.INSUL.UP TO AUX.

MD-0105 M530 WASTE DISP. PROVIDE TRK.CONN ON WASTE MON. NOT SAFETY RELATED LIQ. TK.PMP.DISCH.LINE FOR USE WHEN CIRCULATORS ARE OUT MD-0107 MBOO COMP.AIR TIE IN FOR PORTABLE AIR NOT SAFETY RELATED

! COMPRESSOR

SYST SAFETY DCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION MD-0108 N520 SOLID RADWASTE ADD TRK CONN.ON SPENT RESIN NOT SAFETY RELATED STG,TK,DISCH.LINE TO SOLID RADWASTE SYST.

MD-0109 M530 WASTE DISPOSAL INSTALL TRK.CONN,FOR WASTE NOT SAFETY RELATED EVAP.BOTTOMS OD-0006 M600 SERVICE WATER CHANGE "AUTO START"SETPT ON NOTE 20 SERV.WTR.PMP.FROM 90 TO 80 PSIG OD-0019 Nl20 CUC-BORIC ACID INSTALL ONE l" CHK,VALVE NOT SAFETY RELATED RECOVERY TO PREVENT BACKFLOW INTO PRIMARY SYSTEM OD-0020 M530 WASTE DISPOSAL INSTALL ONE 2" CHK,VALVE NOT SAFETY RELATED LIQUID TO PREVENT BACKFLOW INTO PRI.SYS.FROM 11 OR 12WL147 OD-0027 F320 CONDENSATE INSTALL A LINE & BY-PASS VALVE, NOT SAFETY RELATED AROUND 11CN32 & 12CN32 VALVES TO PREVENT DAMAGE TO PMP AFTER ITS ISOLATION PD-0007 NlOO eves ADDITION OF A TIME DELAY INTO EXJJIP. PERf\'.)JM) SAm FtH:T. &

CONTROL FOR VALVE CV172 MEFl'S ORIG;DESirn JIDJ, PD-'0011 Pl20 SOLID STATE MODIF.OF PWR.SUPPLY WIRING NOTE 21' PROT.SYS. TO PREVENT INADVERTENT REACTOR TRIPS PD-0013 Rl20 SOLID STATE ADDITION OF RELAYING TO PREV. FUOCT.SAFETY mt).tul' ALTERED.

PROT.SYS. DESTRUCTION OF SOURCE RANGE 011\NGE rn8URES D;JUIP. POOi'. &

DETECTORS UPON PWR.LOSS RELIABILITY.

PD-0014 R400 NIS - PROVIDE IMPROVED CONT.EVAC. NOT SAFETY RELATED

.~

SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVAL).JJ\TION PD-0015 Rl20 SOLID STATE REPOSITIONING OF RELAYS TO NOTE 22 PROT.SYS. PROVIDE NORMALLY CLOSED CONTACTS PD-0017 C900 RAD.MONIT.SYS. REPL.OF ALL W TYPE 11 BF 1' FUNCT.NOT CHANGED RELAYS IN RMS THAT ARE SAFETY RELATED PD-0021 E550 U & 2 UNIT CHG.CURRENT SOURCE FROM NOT SAFETY RELATED METERING PWR. PHASE 3 TO 2 AS REQ.BY PWR.FACT.

PD-0028 R600 SMPL.SYS.& CHANGE SNAP-LOK LIMIT SWITCH NOT SAFETY RELATED PZR.RELIEF SYS. TO MICROSWITCH TYPE IN ORDER TO CUT MAINT.MAN-HOURS PD-0029 CAOOO METEOROLOGICAL CHG.LABEL ON INSTR.XA-8495 NOT SAFETY RELATED COL.SYS. TO READ "WIND SPEED/DIRECT.

ELEV.33" INSTEAD OF EL.30 PD-0035 Rl20 SSPS PROV.BLOCKING FNCT.FOR TEST CIWQD 'IO f.£Rl' ORIG.

CIRC.K-6031K-610(TRA.A) & DESirn.

K-6021K-6091K-610(TRA.B)

PD-0036 C300 AUX.ANNON. REVISE NOMENCLATURE FOR POINTS NOT SAFETY RELATED 1573 & 594 TO DELETE REF. TO llSW20 & l3SW20 DELETE PTl650 FOR 1SW26 PD-0040 M500 SOUND PWR. PROVIDE JACK AT EL.194 ON NOT SAFETY RELATED PHONE CONT.PLANT VENT PD-0041 M600 SERVICE WATER PROVIDE "PERM.HTR.IN PENET. NOT SAFETY RELATED AREA EL.78 VLV.ROOMS 'll'O PREVENT FREEZE-UP SYST SAFETY DCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALAUTION PD-0043 M510 WST.DISP.GAS INSTALL 0-3000 PSIG GAGE NOT SAFETY RELATED AT N2 TRK.FILL TO AUX.BLDG.

NEAR 1NT70 PD-0045 C900 RAD.MONIT. ADD AUDIBLE ALM.TO NOT SAFETY RELATED PARTICULATE MONT.1R6B & 1R20A PD-0048 M600 SERVICE WATER PROVIDE 30 SEC.DELAY TO CLOSE NOTE 23 11SW20,13SW20,1SW26 UPON RECEIPT OF ISO.SIGNAL FROM SEC PD-0049 M600 SERVICE WATER REVISE CONT.FOR VLV.11,12,13,14 & NOTE 24 15SW57 TO ASSURE SYS.OPER.AT 750 GPM WHEN REQ.

PD-0053 G220 MAIN STEAM MODIF.SLOPE OF ALL FLOW TAPS 61\.TISFns ORIG. FUOCT.

FROM M.S.FLOW NOZZLE TO PRECLUDE RFXl.JIREM'NI'S

  • POCKETING SEE ED-0047 PD-0054 R400 NIS CHG.NR41, 42, 43, 44 TO INDICATE NOT SAFETY RELATED UPPER & LOWER FLUX ON 'rHE SAME RECORDER PD-0059 M915 CHILLED WTR. ADD SUCT.PRESS.GAGES TO 11 & 12 NOT SAFETY RELATED CHILLED WTR.PMPS.TO MEET ISI REQ.

PD-0065 C900 RAD.MONIT. ADD 4 TWO PEN RECORDERS TO RMS NOT SAFETY RELATED RACKS TO IMPROVE PRESENTATION OF INFORMATION PD-0066 P400 NIS REPLACE N45 RECORDER WITH HORE NOT SAFETY RELATED RELIABLE TYPE MAINT.FREQ.TOO HIGH PD-0068 F320 COND.AIR INSTALL VAC.GAGE ON EACH AIR HOR NOT SAFETY RELATED PD-0076 T800 CIRC.WTR. RELOCATE CONDR.OUTLET RTD'S TO NOT SAFETY RELATED GIVE MORE ACCURATE READINGS PD-0090 C900 RAD.MONIT. MODIFY CHANNEL ALARM 'I'O MAKE NOT SAFETY RELATED IT LOCK IN. AN ALM.CONDITION REQ.MANUAL RESET

-'36-

SYST SAFETY OCR NO. CODE PRINCIPAL SYSTEM SUBJECT EVALUATION PD-0093 TlOO MAIN TURB.EHC ADD 5.0 MFD 50V PWER W NOT SAFETY RELATED RECOMMENDATION INSTALL FLOW METER IN CHILLED WATER PD-0094 T900 TURB.AUX. TO IMPROVE OPERATING CAPACILITY NOT SAFETY RELATED COOLING OF TAC PMPS INSTALL GAGES TO SUCTION*SIDE PD-0108 R500 FULL LGTH.ROD MODIFY WIRING ERROR TO PREVENT NOT SAFETY RELATED CONTROL INJECTION OF LINE NOISE INTO CONTROL CIRCUIT PER W RECOMM.

PD-0109 R500 FULL LGTH.ROD REPL.CHASE-SHAWMUT FUSES IN NOT SAFETY RELATED CONTROL CROM CIRCUITS WITH BUSSMANN FUSES TO PRECLUDE ROD DROPS PER W RECOMM.

PD-0117 W200 DM PLANT INSTALL TEFLON LINED PIPE AT NOT SAFETY RELATED DILUTION WTR.MIXING TEE DUE TO FREQ.LINE LEAKS PD-0121 R400 NUC.INSTR. W RECOMM.A BEAD OF RTV TO TOP NOT SAFETY RELATED

& BOTTOM OF GSKTS.FOR NEUTRON DETECTOR WELLS TO IMPROVE SEALING SS-0003 M200 FIRE PROT. CHANGE ALM.ON WET PIPE SPRINK. NOT SAFETY RELATED CODE D ALARM IN BAILING AREA TO MATCH LOCAL PULL STATION

  • SAFETY EVALUATION NOTES (Referenced in Preceeding Tables, pg. 22-37)
  • SECTION IV
1. This design change is only a minor arrangement change to avoid interferences. It does not affect the function of the item or
  • alter any possible interactions of the item with other safety related equipment. An unr.eviewed safety question is not involved.
2. In replacing the 0.5 kVA Solatron LVR Regulator with a 0.25 kVA
  • Solatron CVS Regulator to reduce the interaction between the regulator and the output st~ge of the lD Inverter, it is only an equipment change, it is NOT an unreviewed safety question since function requirements are unchanged *
3. This design change does not functionally alter the Service Water Piping System. The hangers added meet the present piping design criteria for the system and does not present an unreviewed safety question as defined in 10CFRS0.59.
4. The installation of the needle valve on the "E" port of solenoids
  • 5. Change required to correct testing deficiency to the Solid State Protection System general warning/reactor trip circuit as per NRC and safety requirements *
  • 6. This change is being made to increase system reliability only.

System failure analyses are not adversely affected. An unreviewed safety question does not exist in that addition of a series valve identical to the one already installed does not create a

  • possibility for an accident of a type previously reviewed, nor does 'it increase the probability of a presently reviewed accident or malfunction *
7. Proposed design change will not affect equipment operating characteristics. The proposed repair is based on manufacturers
  • recommendation to improve operating reliability per Allis Chalmers letter dated 10-20-76. Therefore, this modification does not involve any of the criteria of an unreviewed safety question per 10CFRS0.59 *
  • 8. The smaller size impeller will reduce the total pr~ssure head and w~ll reduce the erosion on chiller condenser 'tubes. This smaller size impeller will also meet the system requirements *
  • 9. Engineering re-evaluation of the system shows that the vent is not essential for continued safe operation of the system .

. Deletion of the vent will not detrimentally effect system

  • operation. The definition of an unreviewed safety question is not satisfied, the vent is not required for safe shutdown of the system.
  • ,- 10. This change will not increase the chance of an accident or malfunction as evaluated in the Safety Analysis Report or as evaluated by considering any other criteria. Margins .of safety as defined in the Tech. Spec. "will not be reduced. The. afore-
  • mentioned comments are accurate since this change only involves relocating small bore pipe in order to avoid interferences.
11. New design has been reviewed and determined not to create new
  • potential malfunctions or increase the probability of previously analyzed ~alfunctions or accidents.
  • 12. This change does not modify functional operation, it only adds monitoring circuitry. Additional circuitry cannot increase the probability of failures.
13. Modification does not degrade any safety related equipment, a9gravate any previously analyzed accident, or change the basis of any Technical Specification ..
  • 14. Change will reduce vibration but will not affect other performance characteristics. Performance of motors safety
l. function will not be not be affected by this change. Therefore,
  • no criteria of an unreviewed safety question are involved.
15. This design change does not affect any presently performed safety analysis nor does it create any new safety hazards *
  • The basis of the Technical Specifications are not affected.
16. Actually, there is no change, it is only recognition of slight differences of instrumentation between the Salem plant and the
17. The functional operation of the Pressurizer Spray Control Loop remains uncha~ged. Instruments are to be replaced to improve
  • system reliability.
18. Revision of Radiation Channel Rl8 setpoint based upon result of radiochemical analysis of waste holdup and/or monitoring
  • tanks, setpoint shall be in accordance with the Salem Environmental Technical.Specifications.
  • 19. Will remove foreign.material from liquid Freon and as such will prolo~g the life of the equipment. This item not discussed in FSAR, or Technical Specifications. No new failure modes for the system are introduced, nor are any present modes aggravated *
  • 20. Nonconservative direction setpoint change has been analyzed and determined to not reduce safety margins required by Technical Specifications basis *
  • 21. No change in system function and no failure modes would be created which could cause or increase the potential for acci:dents or malfunctions. Change will improve operational
  • reliability *
22. These circuits do not have any safety function. DCR was checked safety related due to interface with SSPS Test
  • Cabinets. Change ensures proper system operation consistent with original design criteria.
23. The change improves system operability and does not affect
  • the safety analysis for containment pressure/temperature transients. The additional relay does not add the potential for other failures which would negate the safety function of isolating service water to the Turbine Building *
24. Improves system operation by reducing transient pressures at Fan Cooler Units. Operational requ*irements are not affected *
  • {
  • SECTION V PERSONNEL RADIATION EXPOSURE

.PUBl.IC SERVICE El.ECTRIC ~GAS COMPANY

11..SH l'l:ISbS1"" SiEiiEii/*ii)IG :-n-s*i P.O. aox 169* HAHCOCKS BRIDGE* NEW JERSEY 09038 NCI ~e:i;;seNliE- ' 11,_lt 111\Ell Bf JSB Fl:lrteTIB14 i<ef91H
  • REPORT PERIOD 1/ 1/77 TO t:?/31/77 TOTAi. F'ERSONNEI..

REACTOR OPERATIONS I Ji4 Q *NTiH 'ttlf;-

SURVEI~ANCE p;~s;>1t';1a Q Q 1Q' OPERATING PERSONNEi.. 0 0 108:33 0 ll1 10 ~co Wi:1'1.TW PH¥SICS Pi~SQ'IN&:I. 0 CHEMISTRY PERSONNEi. 11 0 0 3981 5 SUP&:R"ISQRY FER 5 QNNEL.

ENGINEERING PERSONHEI. 0,.,

0 0

0 0

3 7,a,7 0 189

    • o10 T I c .PC"FSONNEJ 0 a 673 *o ;a SECURITY PERSONNEi. 0 0 0 0 90:5 RQJJTTNF MAINTFNANCf HAINTEJ'4ANCE PERSONNEL. .....,., 6 3 4217 290 3076 neEsarxNa e~eanNNEI o* 10J6* Q *10 HEA~TH PHYSICS PERSONNEi.. 0 0 0 0
  • cwEetr5rpy pc-psnNNE' SUPERVISORY ENGTNf:"RtNa I I C PERSONNEi.

SFCt!prry PERSONNEi

~RSONNEL.

e~1snNNEJ 0

1 0

l 0

0 0

c 0

0 0

  • ~*

'0 , 10 0

4:5 463

?O 0 o. 0 10 . "'O INSERVICE INSPECTION HQ IN TENA NCC" pcy5nNNfI .., 0 -a ,174 ,,,, 1 1 . 6, OPERATING PERSONNEi. 2 0 0 0 45 HEAi TH l>HYSIC::S ='"'R50f:Ulf;'J 0 0 0 0
  • CHEMISTRY PERSONHEI.

511pc:'£Vt501y PFBSONNEJ

.ENGINEERING PERSONNEL.

0 O*

0 0

0 1

0 0

10 r.e1 0

on 0

9960

. 0

-tg3

, ............_.r_...s..i;c:;~p~,..~F~sunu>~,N~fl:;i.......................................~o._.........go.............oi................~~~o~......_.;~~--......-*~~::o... ......_

  • J SECURITY PERSONNEL. 0 0 0 0 5 0 l

. :i

~S~P~E~C::~T~A~li-,,M~A~I~N~TEL11N~A~NCH;.1F:;....--

MAINTENANCE PERSONNEL 26 3 1:?6  :?170 5 0 0 '0 HEALTH PHYSICS PERSONNEi. 0 0

0 0

0 0 ...... 10

"'C ,60....

SUPERVISORY PERSONNEi.  :? 1 l 13.:.o 3887 ENGINEERING PFRSONNF!' 0 0 0 0 ..,"TO I I C PERSONNEi. 0 0 4020 0 0 0 0 0 WASTE PROCESSING 0 , 0 -o ?C OPERATING PERSONNEi.

HFA*TH PHYSICS PFF 5 QNNF1 0

0 0

0 .,

0 0 Q

0 0

0 0

  • CHEMISTRY PERSONNEi.

SPERUTSORY PERSONNFJ ENGINEERING PERSONNEL.

' ' r PFnsnNN£'

SECURITY PERSONNEi.

0 0

0 Q

0 0

0 0

0 0

2 0

0 0

Q 10 0

0

?

0 0

0 0

0 0

500 ct 0

MAINTENANCE: PERSONNEi. 0 0 0 0 0 0 OPERQTING PFRSONNEI 0 0 Q 0 0 HEAi.TH PHYSICS PERSONNEL 0 0 0 0

, 0

~"'F""T srgy OC'?SONNFl 0 Q 0 Q 0 SUPERVISORY PERSONNEL 0 0 0 0 0 0 C'NG INF:"R I NG OC"ftSONN[l 0 0 Q 0 0 0 I I C PERSONNEi.

SEC::!jffITI PC'iiSONNfl 0

0 0

0 0 0 0

0 0

0 0

PUBl.IC SERVICE El.ECTRIC I GAS COMPANY SA' ~?! Nl!C 1 ~AF GEb't=*ATLG ;-:.T*

P.O. BOX 169* HANCOCKS BRIDGE* NEW JERSEY 08038 REPORT PERIOD 1/ 1/77 TO 1:?/:!1/77 TOTAL f'ERSONNEI. NUMBER OF MAN-~REM

  • TOTP.l..

MA HIT'fNANC"' P"'FSONNE!

OPERATING PERSONNEi..

HEAi TH p .. ysrco; C-C'PSOtJNEJ 30 44 3

0 0 r,3

..,,, ..7. 67id0 CHEMISTRY PERSONNEL 11 0 4:?41 .;,aa S!IE'C';ur5npv ec:ssnNNE! d =-o-r' *oza ENGINEERING f'ERSONtlEI.. 0 16 10 S76 10313 I \ c:: Pl"S'SONNEL 1; ,) a =o;.

SECURITY P::RSONNEL 0 0 0 10

  • (lpANp TOH!

PUBLIC SERVICE ELECTRIC l GAS COMPANY

  • ANNUAL WHOLEBODY EXPOSURES FOR THE CALENDAR YEAR 1977 ANNUAL DOSE RANGES NUMBER OF INDIVIDUALS

<REM> IN EACH RANGE

============ ===============
  • NO MEASURABLE EXPOSU~E 203 MEASURABLE EXPOSURE LESS THAN .100 982
  • .100 .250 167

.250 .soo 111

      • .soo .750 40

.750 1.000 14

  • 1.000 2*000 8 2.000 3.000 1
  • (

......... 3.000 4.000 0 4.000 s.ooo 0

  • s.ooo 6.000 0 6.000 1.000 0 1.000 a.ooo 0
  • s.ooo 9.000 0 9.ooo 10.000 0 10.000 11.000 0 11.000 12.000 0 12.000+ 0
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