Text

Annual Results & Data Rept,1980.
	ML19347C916
Person / Time
Site:	Point Beach
Issue date:	02/27/1981
From:	; WISCONSIN ELECTRIC POWER CO.
To:	;
Shared Package
ML19347C915	List: ML19347C914; ML19347C916;
References
	NUDOCS 8103100335
	Download: ML19347C916 (95)
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TABLE OF CONTENTS Page

1.0 INTRODUCTION

1 2.0 HIGHLIGHTS c 2.1 Unit 1 1 2.2 Unit 2 1 3.0 FACILITY CHANGES, TESTS AND EXPERIMENTS 3.1 Amendments to Facility Operating Licenses 2 3.2 Facility or Procedure Changes Requiring NRC Approval 3 3.3 Tests or Experiments Requiring NRC Approval 3 3.4 Design Changes 4 .

3.4.1 Unit 1 4 3.4.2 Unit 2 7 3.4.3 Common 10 3.5 Procedure Changes 14 4.0 NUMBER OF PERSONNEL AND MAN-REM EXPOSURE BY WORK AND JOB FUNCTION 4.1 1980 59 5.0 STEAM GENERATOR TUBE INSERVICE INSPECTION 5.1 Unit 1 60 5.2 Unit 2 70 gQ3l

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1.0 INTRODUCTION

The Point Beach Nuclear Plant, Units 1 and 2, utilize identical pressurized water reactors rated at 1518 MWt each. Each turbine generator is capable of producing 497 MWe net (524 MWe gross) of electrical power. The plant is located ten miles north of Two Rivers, Wisconsin, on the west shore of Lake Michigan.

2.0 HIGHLIGHTS 2.1 Unit 1 For the period 01-01-80 through 12-31-80, which included a 32-day refueling outage, two steam generator inspection outages, a trip resulting from the inadvertent deenergization of a vital bus p inverter, a brief outage following the clogging of the circulating water traveling screens with alewives, and two trips resulting from vibrations in the feedwater system, Unit 1 operated at an average capacity factor of 57.0% and a net efficiency of 30.5%. The unit and reactor availability were 78.6% and 79.0%, respectively. Unit 1 generated its 31 billionth kilowatt hour (gross) on 02-09-80; its 32 billionth kilowatt hour on 07-01-80; and its 33 billionth kilowatt hour on 10-30-80.

2.2 Unit 2 For the period 01-01-80 through 12-31-80, which included a 34-day refueling outage, a steam generator maintenance outage, a brief outage to repair a moistt.;e separator reheater dump valve, a trip due to the failure of a rod drive power supply, a shutdown to perform secondary plant maintenance prior to the Unit I refueling, and a shutdown due to Technical S; 'cification requirements for an out-of-service safety injection pump, Unit 2 operated at an average capacity factor of 82.5% and a net efficiency of 32.1%. The unit and reactor availability were 86.4% and 87.4%, respectively. Unit 2 generated its 27 billionth kilowatt hour (gross) on 02-23-80; its 28 billionth kilowatt hour on 07-08-80; its 29 billionth kilowatt hour on 09-29-80; and its 30 billionth kilowatt hour on 12-21-80.

3.0 FACILITY CHANGES, TESTS AND EXPERIEMENTS 3.1 Amendments to Facility Operating Licenses During the year 1980, there were seven license amendments issued by the U. S. Nuclear Regulatory Commission to both Facility Operating License DPR-24 for Unit 1 and Facil.ty Operating License DPR-27 for Unit 2. These license amendments are listed by date of issue and summarized as follows.

3.1.1 03-19-80, Amendment 42 to DPR-24, Amendment 47 to DPR-27 These amendments changed the Technical Specifications to -

upgrade the qualification requirements for the Radiochemical Engineer and Health Physicist.

e-3.1.2 04-03-80, Amendment 43 to DPR-24, Amendment 48 to DPR-27 These amendments issued miscellaneous administrative changes to the Technical Specifications and approved a revised organizational structure for the plant staff.

3.1.3 04-29-80, Amendment 44 to DPR-24, Amendment 49 to DPR-27 Inese amendments authorized reactor operations at either 2250 or 2000 psia for Unit 2 and restricted operation for Unit 1 to 2000 psia primary system pressure.

3.1.4 05-20-80, Amendment 45 to DPR-24, Amendment 50 to DPR-27 These amendments added to the Technical Specifications Limiting Conditions for Operation and surveillance require-ments for the low temperature overpressure mitigating system and corrected several clerical inconsistencies.

3.1.5 09-19-80, Revised Order for Modification of Licenses, DPP-24 and DPR-27 This order amended the licenses to add a provision requiring complete and full response to IE Bulletin No.79-01B not I later than 11-01-80.

3.1.6 10-24-80, order for Modification of Licenses, DPR-24 and DPR-27 This order amended the licenses to add provisions to the Technical Specifications requiring envirereental qualifi-cation of all safety-related electrical equipment by no later than 06-30-82 and to require complete and audit able records of environmental qualifications methods available by 12-01-80.

3.1.7 12-17-80, Amendment 46 to DPR-24, Amendment 51 to DPR-27 These amendments eliminated procedural steps in the Technical Specifications for testing of the containment spray additive valves.

3.2 Facility or Procedure Changes Requiring Nuclear Regulatory Commission Approval There were no plant moficiations or procedure changes during 1980, beyond those authorized with license amendments as noted previously, which required Nuclear Regulatory Commission approval.

3.3 Testc or Experiments Requiring Nuclear Regulatory Commission Approval There were no tests or experiments at Point Beach Nuclear F.lant in 1980 which required Nuclear Regulatory Commission approval.

l 3.4 Design Changes 3.4.1 Unit 1

a. Containment Crane (E-137)

Radio controls were installed on the containment polar crane.

Summary of Safety Evaluation: Not nuclear safety related.

b. 480 V Switchgear (E-171)

Security-related modification. No comment. .

Summary of Safety Evaluation: Not nuclear safety related.

Y

c. Connunications (E-209)

Additional Gai-tronics speakers were installed on El. 8' of the primary auxiliary building in the No. I pipevay, No. 2 pipevay and charging pump cubicle in reponse tc C 611etin No. 79-18 investigations.

Summary of Safety Evaluation: Not nuclear safety related.

d. Turbine Supervisory Instrumentation (IC-174)

Indication was installed on the main control board to inform operating personnel of turbine bearing vibration or shaft eccentricity on the turbograf.

Summary of Safety Evaluation: Not nuclear safety related.

e. Safeguards (IC-204)

Containment spray circuitry was mod '.ed so the spray system is automatically activated when che two 2/3 contairment high/high pressure matrix signals are generated. Spray pump control circuitry was modified such that if the spray pump is running from an auto or manual safeguards system start and a loss of AC occurs, the pump vill be automatically restarted I when AC is restored. Spray pump control circuitry was modified such that if a containment spray signal simultaneous with a safety injection signal and loss of AC occurs, the pump will start in an appropriate sequence to accommodate Diesel loading.

Summary of Safety Evaluation: The modification ensures containment spray will occur in the event safety injection is reset and spray is required.

f. Containment Ventilation Isolation (IC-242)

The modification disabled the local / remote control switch for the containment purge exhaust valve (PC-3212A&B) which had the feature.

Summary of Safety Evaluation: Removal of the switches prevent automatic openings following reset of containment ventilation isolation; maintaining two-valve isolation of the ventilation system in all situations.

g. Containment Isolation (IC-250)

Per NUREG-0578 requirements, a "T" signal was added to steam generator blowdown isolation valves 1CV-2042 and ICV-2045.

Summary of Safety Evaluation: The modification provides automatic double barrier isolation by diverse signals upon receipt of a valid safety injection signal.

h. Containment Isolation (IC-252)

Per NUREG-0578 requirements, a "T" signal was added to steam generator blowdown sample isolation valves 1CV-2083 and ICV-2084.

Summary of Safety Evaluation: The modification provides automatic double barrier isolation by diverse signals upon receipt of a balid safety injection signal.

i. Charging System (M-391)

Pressure pulsation dampeners were installed on the discharge of each of the charging pumps.

Summary of Safety Evaluation: The dainpeners minimize vibration thereby reducin- pipe connection fatigue failure.

j. Steam Drains (M-493)

The south dump header drains were rerouted from the condenser inlet to the low pressure trap header to prevent overheating of the condenser when vacuum is being raised and when vacuum is being maintained while the unit if off-line.

Summary of Safety Evaluation: Not nuclear safety related.

k. Charging System (M-502) ,

Pressure pulsation' dampener suction stabilizers were installed on each of the charging pumps.

bummary of Safety Evaluation: This modification reduces hidrogen off-gassing during suction stroking which can cause hydraulic shocking during compression stroking of the positive displacement pumps.

1. Service Air (M-570)

A 1\" connection was installed in the facade to facilita sludge lancing required hookups.

Summary of Safety Evaluation: Not nuclear safety related.

m. Service Water (M-582) .

Larger internals were installed in TCV-12A to permit greater water flow for control of component cooling system temperature.

Summary of Safety Evaluation: Not nuclear safety related.

n. Fire Protection (M-595)

Five hose reels were installed in the containment, with water supply from the service water system, to fulfill commitments made in response to NRC staff position PF-26.

Summary of Safety Evaluation: Not nuclear safety related.

o. Post-Accident Containment Atmosphere Sampling (M-647)

A bypass loop and septum sampling system was installed in the R11/R12 cubicle which included provisions for puring of he lines back to containment with service air.

Summary of Safety Evaluation: A more viable means of post-accident atmosphere sampling is provided.

p. Moisture Separator Reheater Grating (M-653)

Grating was installed in the void between the I-beams on each end of the moisture separator reheaters to facilitate 1 personnel access and enhance industrial safety.

Summary of Safety Evaluation: Not nuclear safety related.

q. Lube Oil Reservoir (M-689)

A concrete dike was installed around the reservoir to fulfill NRC fire protection review commitments.

Summary of Safety Evaluation: Not nuclear safety related.

3.4.2 Unit 2

a. Containment Crane (E-158)

Radio controls were installed on the containment polar crane.

Summary of Safety Evaluation: Not nuclear safety related.

b. Containment Spray (IC-205)

Per NUREG-0578 requirements, a "T" signal was added to steam generator blowdown isolation valves 2CV-2042 and 2CV-2045.

Summary of Safety Evaluation: The modification provides automatic double barrier isolation by diverse signals upon receipt of a valid safety injection signal.

c. Communications (E-210)

Additional Gai-tronics speakers were installed in the turbine building non-nuclear room, outside area and heating boiler room; and in the primary auxiliary building No. 3 pipeway, No. 4 pipeway and charging pump cubicle in response to IE Bulletin No. 79-18 investigations.

Summary of Safety Evaluation: Not nuclear safety related.

d. Main Control Board Indication (IC-135)

Status lights for overpower AT runback were installed on panel C04 for each of the four channels.

Summary of Safety Evaluation: Not nuclear safety related.

e. Extraction Steam (IC-138)

The existing heating steam moisture separator level controller was replaced by a more reliable pneumatic controller manufactured by a different vendor.

I Summary of Safety Evaluation: Not nuclear safety related.

f. Turbine Supervisory Instrumentation (IC-175)

Indication was installed on the main control board to inform operating personnel of turbine bearing vibration or shaft eccentricity on the turbograf.

Summary of Safety Evaluation: Not nuclear safety related.

g. Pressurizer Pressure 2/3 Safety Injection Annunciation (IC-203)

First-out annunciation in the control room and on the computer alarm typewriters was provided for the pressurizer pressure 2/3 safety injection annunciation modification completed per IC-193 (reported in 1979 report).

Summary of Safety Evaluation: The modification was necessary to provide proper annunciation and recording of a safety injection caused by low pressurizer pressure.

h. Residual Heat Removal Piping (M-386)

A vent valve and 3/8" tubing were added which extended the -

system pressure boundary to permit refilling suction line piping without violating double-valve protection and to reduce existing hazards to personnel caused by the poor location of the high point vent.

Summary of Safety Evaluation: Not nuclear safety related.

i. Charging System (M-503)

Pressure pulsation dampener suction stabilizers were installed on each of the charging pumps.

Summary of Safety Evaluation: This modification reduces hydrogen off-gassing during suction stroking which can cause hydraulic shocking during compression stroking of the positive displacement pumps.

j. Containment Cooler Throttle Valve (M-510)

SW-273, a carbon steel valve, was replaced with a correctly sized stainless steel valve.

Summary of Safety Evaluation: Replacement of the heavily throttled valve (throttling causing internal pressure boundary erosion) with a more erosion-resistant stainless steel valve improves system integrity.

k. Service Air (M-578)

A 1" connection was installed in the facade to facilitate sludge lancing required hookups.

Summary of Safety Evaluation: Not nuclear safety related.

1. Service Water (M-583)

Larger internals were installed in TCV-12B to permit greater water flow for control of component cooling system tempetature.

_J

Summary of Safety Evaluation: Not nuclear safety related.

m. Fire Protection (M-594)

Five hose reels were installed in the containment with water supply from the service water system to fulfill commitments made in response to NRC staff position PF-26.

Summary of Safety Evaluation: Not nuclear safety related.

n. Pressurizer Relief Tank Access (M-601)

. A ladder and platform were installed on the tank to facilitate personnel access to the tank top and to improve industrial safety.

o Summary of Safety Evaluation: Not nuclear safety related.

o. Waste Liquid (M-616)

The leakoff line was extended into the bottom of the reactor coolant drain tank to provide sparging and a vent hole was installed in the drain line as an anti-syphon.

Summary of Safety Evaluation: Not nuclear safety related.

p. Steam Generator Blowdown Tank Access (M-625)

A platform was installed to facilitate personnel access to the tank and associated valves thus improving industrial safety.

Summary of Safety Evaluation: Not nuclear safety related.

q. Post-Accident Containment Atmosphere Sampling (M-648)

A bypass loop and septum sampling system was installed in the Ril/R12 cubicle which included provisions for purging of the lines back to containment with service air.

Summary of Safety Evaluation: A more viable means of post-accident atmosphere sampling is provided.

r. Fuel Handling (M-652)

An extension was added to the periscope support to support and restrain the thimble plug tool.

Summary of Safety Evaluation: Since the existing bracket was designed to withstand the weight of the periscope which is approximately twice the weight of the thimble plug tool, the modified bracket can withstand the lesser weight.

_g.

s. Moisture Separator Reheater (M-657)

Grating was installed in the void between the I-beams on each end of the moisture separator reheaters to facilitate personnel access and enhance industrial safety.

Summary of Safety Evaluation: Not nuclear safety related.

t. Lube Oil Reservoir (M-690)

A concrete dike was installed around the reservoir to fulfill NRC fire protection review commitments.

Summary of Safety Evaluation:

Not nuclear safety related.

3.4.3 Common v

a. Communications (E-196)

The handsets for Gai-tronics units near the main control boards were modified to provide a two-position thumbswitch for channel selection and a pushbutton for paging. The modification enhances communications abilities for the operators assigned to the control panels.

Summary of-Safety Evaluation: Not nuclear safety related.

b. Communications (E-208)

Security-related modification. No comment.

Summary of Safety Evaluation: Not nuclear safety related.

c. Communications (E-211)

Additional Gai-tronics units were installed in the primary auxiliary building in the El. 8' and 26' holdup tank cubicles and El. 46' waste gas compressor cubicle in response to IE Bulletn No. 79-18 investigations.

Summary of Safety Evaluation: Not nuclear safety related. q

d. Auxiliary Building Crane (E-216)

Limit switches were changed to prevent carrying loads over the north spent fuel pit during reracking of the south pit and an additional limit switch was installed to provide an exclusion area required by Technical Specifications.

Summary of Safety Evaluation: During reracking of the south pit there is freshly discharged fuel in the north pit. Per Technical Specifications, no motion of the main crane hook can occur over fuel which has been subcritical for less than one year.

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e. Safeguards Bus Tie Breaker Indication (E-232)

Red lenses for indication on B03/B04, A05/A06, and 1A03/2A04 were changed to red lenses with center-drilled holes to provide for more distinctive indication and enhancement of operator awareness. This modification completed final corrective action for LER 80-005 (Unit 2).

Summary of Safety Evaluation: Not nuclear safety related.

f. Laundry and Hot Shower Tank (M-479)

Piping was modified and a filter was installed to reduce sludge buildup in the tank.

" Summary of Safety Evaluation: Not nuclear safety related.

g. Radwaste Solidification System (M-514)

Air blasters were installed in the cement storage silo to remove cement buildup on the silo sides.

Summary of Safety Evaluation: Not nuclear safety related.

h. Blowdown Evaporator (M-517)

The relief stack off of the evaporator was cut off allowing it to exhaust inside the cubicle; and the penetration to the Unit 2 facade was capped.

Summary of Safety Evaluation: Relief valve radioactive release monitoring is now provided via the auxiliary building stack.

i. Cable Spreading Room (M-545)

An additional entrance was installed at the south end of the east wall at El. 26' to provide an alternate personnel entrance route if a fire prohibited use of the other i entrance.

Summary of Safety Evaluation: Not nuclear safety related.

j. Radwaste Storage (M-569)

Ten concrete storage containers with lids were installed underground alongside the Unit 1 facade with drainage to the facade sumps. The containers are being used to temporarily store low level solidified waste prior to shipment.

Summary of Safety Evaluation: Adequate shielding and drainage to a controlled area have been provided and the modification reduces radioactivity exposure to personnel, this improving the plant ALARA program.

k. House Heating Boilers (M-579)

Heating boiler chemical addition piping was modified to ensure proper chemical delivery to each boiler.

Summary of Safety Evaluation: Not nuclear safety related.

1. Warehouse Grating (M-592)

Additional grating mezzanines were installed with building lighting modified as required.

Summary of Safety Evaluation: Not nuclear safety related.

m. Gasoline Storage Tank (M-612)

A 1,000 gallon capacity underground gasoline storage tank -

with associated metering devices was installed to ensure unleaded gas is available for personnel emergency use.

Summary of Safety Evaluation: Not nuclear safety related.

n. Buildings and Facilities (M-631)

A sink with appropriate doemstic water hookups was installed in the Unit I non-nuclear room for cleaning and disinfecting Bio-Pak 60 SCBA units.

Summary of Safety Evaluation: Not nuclear safety related.

o. Potable Water (M-636)

Bypass piping was installed to reduce the time required for tank liner repairs.

Summary of Safety Evaluation: Not nuclear safety related.

p. Fuel Oil Storage Tank Access (M-641)

Access platforms were installed to the foam chambers on T32A&B to enhance personnel industrial safety and foam i delivery pipe supports were added.

Summary of Safety Evaluation: Not nuclear safety related.

q. Radiation Monitor Access (M-659)

An access ladder and platform were installed for the new combined air ejector monitor to enhance personnel industrial safety.

. Summary of Safety Evaluation: Not nuclear safety related.

r. Lube Oil Storage Tank (M-667)

A concrete dike was installed around the tank to fulfill NRC fire protection review commitments.

Summary of Safety Evaluation: Not nuclear safety related.

s. Fuel Oil Supply (M-704)

Approximately 400' of the 2" HB-22 fuel oil supply piping to the emergency Diesel generators was relocated in order to permit construction of the new technical support center and maintenance shop.

Summary of Safety Evaluation: Facility design was not changed; the existing piping run was relocated. Pressure and

flow ratings of the system remain unchanged.

t. Water Treatment Piping (M-723)

PVC piping, originally installed for possible emptying of the concentrated boric acid tanks or spray additive tank was stubbed and capped where necessary to maintain fire wall barrier integrity.

Summary of Safety Evaluation: Not nuclear safety related.

u. Emergency Diesel Room Ventilation (M-685)

Ventilation air flow through the room was reversed for one fan such that outside air rather than turbine hall air can be used for ventilating should a fire in the turbine hall preclude access to the Diesel room.

Summary of Safety Evaluation: Not nuclear safety related.

v. Circulating Water System (M-697)

Four 6.5' square concrete pipes were installed in the south I half of the intake crib to prevent ice blockage in the rock crib during the wintertime.

Summary of Safety Evaluation: Not nuclear safety related.

3.5 Procedure Changes All of the following procedures were reviewed per the requirements of 10 CFR 50.59 and evaluated for their safety implications. They were all approved by the Manager's Supervisory Staff.

3.5.1 OP-1A, Cold Shutdown to Low Power Operation, devision 20, 08-22-79 (performed 12-21-79, Unit 1)

Step 4.20 was modified to specify a temperature band of 400 F to 420 F for leak testing to establish a proper differential pressure across the steam generator tubes. (Temporary) 3.5.2 OP-1A, Cold Shutdown to Low Power Operation, Revision 21, 01-25-80 -

In Step 2.15 the reactor coolant system temperatures were specified for both units at which steam removal can be initiated .

for increasing turbine speed above 600 rpm. In Steps 2.19 and 3.5 typographical errors were corrected. In Step 4.5 a band for withdrawing control and shutdown rods was inserted since an exact number is not required. A sentence was added to Step 4.21.3 to jog the safety injection pumps and verify operational ability and proper discharge pressure. In Step 4.30 the specific value for no-load Tavg was deleted to prevent confusion because of lower Unit 1 temperatures. (Permanent) 3.5.3 OP-1A, Cold Shutdown to Low Power Operation, Revision 21, 01-25-80 (performed 03-12-80, Unit 2)

Steps 3.1.2, 3.1.3, 3.1.4, 3.1.5, and 3.1.6 were deleted because no maintenance was performed to the systems involved. Step 4.13 was deleted because the outage was not a refueling shutdown.

Steps 4.16, 4.18.1, 4.18.3, 4.18.4, 4.18.5, 4.18.6, 4.18.7, 4.18.8, 4.18.9, 4.18.10, 4.20.4, and 4.24.4 wer- modified to perform a hot leak check of the steam generator manways with a bubble in the pressurizer. A portion of Step 4.21.3 regarding jogging of the safety injection pumps was moved to follow step 4.21.5 after the bypass valve had been opened to ensure that pump suctions were full of water. (Temporary) 3.5.4 OP-1A, Cold Shutdown to Low Power Operation, Revision 21, 01-25-80 p (performed 04-04-80, Unit 1)

Steps 4.13, 4.16, 4.17, 4.18.1, 4.18.3, 4.18.6, 4.18.7, 4.18.9, 4.19, 4.20.4 (Note), and 4.24.4 were changed to perform a leak check hot with a bubble in the pressurizer. The portion of Step 4.21.3 dealing with jogging of the safety injection pumps was moved to the end of Step 4.21.5 to conduct this evolution at the proper time. Step 4.27.2 was modified to keep the letdown gas stripper off-line until nitrogen has been removed from the system. (Temporary) 3.5.5 OP-1A, Cold Shutdown to Low Power Operation, Revision 21, 01-25-80 (performed 08-07-80, Unit 1)

Step 4.18.5 was revised to change the primary leak test pressure to reference applicable Technical Specification 15.4.3.

(Temporary) 3.5.6 OP-1A, Cold Shutdown to Low Power Operation, Revision 22, 08-20-80 Step 4.18.5 was revised to change the primary leak test pressure to reference applicable Technical Specification 15.4.3.

(Permanent) 3.5.7 OP-1A, Cold Shutdown to Low Power Operation, Revision 22, 08-20-80 (performed 12-27-80, Unit 1) e Step 4.5 to close the reactor trip breakers and withdraw all shutdown and control rods 4-16 steps was not performed because of previously experienced rod drive problems. Likewise, Step 4.23 which calls for rod movement, was deleted. Step 4.13 was moved to between Steps 4.20 and 4.21 to perform the leak test with a bubble following performance of same without a bubble in the pressurizer. (Temporary) 3.5.8 OP-1B, Reactor Startup, Revision 8, 07-22-77 (performed 08-09-80, Unit 1)

A gographical error in Step 4.6 to reference a power level of amps was corrected. (Temporary) 10 3.5.9 OP-1B, Reactor Startup, Revision 9, 08-19-80 10 amps was In Step 4.6 a reference to a powe.r level of 10 corrected. (Permanent) 3.5.10 OP-1B, Reactor Startup, Revision 9, 08-19-80 (performed 11-18-80, Unit 2)

Step 3.1 was changed to permit low power physics testing with only one high head safety injection pump per WMTP 9.6.

(Temporary) 3.5.11 OP-1C, Low Power Operation to Normal Power Operation, Revision 15, 04-19-78 (performed 12-23-79, Unit 1)

Step 3.3 was modified to indicate no-load Tavg for Unit 1 as 522 F (for low temperature operation) versus the normal 547*F.

(Temporary) 3.5.12- OP-1C, Low Power Operation to Normal Power Operation, Revision 15, 04-19-78 (performed 03-13-80, Unit 2)

In Step 3.3 no-load Tavg was changed to 522 F because of stretch operation. (Temporary) 3.5.13 _0P-1C, Low Power Operation to Normal Power Operatica, Revision 15, 04-19-78 (performed 06-11-80, Unit 1)

Step 3.3 was corrected to indicate no-load Tavg on Unit 1 as 522 F. Steps 4.23 and 4.24 were deleted because they were not required for a hot startup. (Temporary) 3.5.14 OP-1C, Low Power Operation to Normal Power Operation, Revision 16, 07-07-80 In Step 3.3 specific operating temperatures were deleted and no-load Tavg substituted because of the differences between units. Throt.ghout the procedure typographical and editorial ^

corrections were made. In addition, Steps 4.49 and 4.54 were revised to alloy opening the bypasses around the crossover steam dump system moto'r-operated valves open on a startup when positive '

pressure is indicated on the crossover header and then reshutting bypasses when the MOV's are open. Step 2.12 was revised for condensate pump operation because the conversion factors for heater drain flow were recalculated. (Permanent) 3.5.15 OP-1C, Low Power Operation to Normal Power Operation, Revision 16, 07-07-80 (performed 09-13-80, Unit 2)

Steps 4.4, 4.9, 4.15, 4.17, 4.20, 4.21, 4.22, and 4.41 were changed to reflect that automatic control of the turbine EH system was not possible and therefore, the system had to be manually controlled. (Te nporary) 3.5.16 OP-3A, Normal Power Operation to Low Power Operation, Revision 5, 10-21-74 (performed 04-11-80, Unit 2)

Steps 4.11 and 4.20 were changed to reflect the actual temperature the plant was controlled at because of stretch operation. (Temporary) 3.5.17 OP-3A, Normal Power Operation to Low Power Operation, Revision 6, 04-28-80 Step 2.6 was added to equalize boron concentrations between the pressurizer and the reactor coolant system and to detail methods a for increasing spray flow. In Steps 4.2.2 and 4.3 specific Reactor Engineering instruction step references w ere deleted so the procedure would not have to be revised concucrent with the REI if steps are renumbered. Step 4.9 was deleted because it was considered that operation of the heater drain pumps for continuous sparging and removal of sparge water would reduce the possibility of water hammer. In Step 4.19 temperature values were modified to account for the different operating temperatures between Unit 1 and Unit 2. Step 4.23 was added to secure equipment per OP-13A requirements. (Permanent) 3.5.18 OP-3B, Reactor Shutdown, Revision 5, 05-12-78 (performed 03-05-80, Unit 1)

Step 3.2 was re' vised to specify the reactor coolant system temperature to be no-load Tavg for Unit 1 and 540 F for Unit 2.

(Temporary) 3.5.19 OP-3B, Reactor Shutdcwn, Revision 6, 04-24-80 Step 2.6 was revised to provide instructions for equalization of boron concentration in the pressurizer and the reactor coolant system to within 100 ppm by increasing spray flow through the pressurizer. A sentence was added to note that spray flow can be increased by energizing additional heaters and/or adjusting spray valve position. Step 3.2 was modified to account for normal operating temperature differences between Unit 1 and Unit 2.

Step 4.5 was deleted because all part-length rods have been removed. (Permanent) 3.5.20 OP-3C, Hot Shutdown to Cold Shutdown, Revision 22, 07-26-79 (performed 02-28-80, Unit 2)

In Step 4.18, the safety injection pumps' bypass valve was corrected to be SI-825C. (Temporary) 3.5.21 OP-3C, Hot Shutdown to Cold Shutdown, Revision 22, 07-26-79 (performed 03-05-80, Unit 1)

Steps 4.4.1 through 4.4.3 were added to perform a 2000 psid primary-to-secondary leak test of the steae generators. Step 4.3 was deleted and was rewritten as Step 4.4.3 to maintain pressure during the test. Step 4.7.1 was added to return the low-low steam pressure signal to normal following the test (it had been bypassed in Step 4.4.1). In Step 4.18 the valve was changed out per modification request to an air-operated valve and assigned number SI-825C. (Temporary) 3.5.22 OP-3C, Hot Shutdown to Cold shutdown, Revision 23, 07-17-80 Several clerical type errors were corrected and valve numbers were fully identified. In Step 2.2 the methods for equalization of boron concentration between the pressurizer and reactor coolant system w'ere defined. Addenda "A", for conducting a 2000 psid test, was incorporated with procedural changes in Steps 4.4 and 4.7 to accomplish same. (Permanent) 3.5.23 OP-4A, Filling and Venting the Reactor Coolant System, Revision 14, 08-27-79 (performed 04-04-80, Unit 1)

In Step 4.2 the requirement to have the purge exhaust fan running was deleted to permit the closing and testing of the purge supply and exhaust fans to establish containment integrity. (Temporary) 3.5.24 OP-4A, Filling and Venting Reactor Coolant System, Revision 14, 08-27-79 (performed 12-20-80, Unit 1)

Step 4.17 was modified to better vent the reactor coolant pump seal water lines and pump cavity via the labyrinth seal differential pressure transmitter and the No. 1 seal differential pressure transmitter. (Temporary) 3.5.25 OP-4D, Draining the Reactor Coolant System, Revision 13, 8-27-79, (performed 07-27-80, Unit 1)

Step 6.2 which calls for hookup of the suction duct on the hot leg steam generator primary manway was changed. The testing work ,

called for it to be on the cold leg. The wording was changed to allow either leg, which is appropriate for the repair work to be performed. (Temporary) .

3.5.26 OP-4D, Draining the Reactor Coolant System, Revision 14, 07-31-80 Step 6.2 was revised to attach the suction duct to the appropriate steam generator leg for repair or maintenance purposes. (Permanent) 3.5.27 OP-4D, Draining the Reactor Coolant System, Revision 14, 07-31-80, (performed during Refueling 8, 11-80, Unit 1)

Section 6.0, which calls for purging the steam generators of radioactive gas following draining, was delayed until af ter the steam generator primary manways were removed. (Temporary) 3.5.28 OP-7A, Placing Residual Heat Removal System in Operation, Revision 13, 05-12-79 (performed during Refueling 6, Unit 2)

Steps 4.9, 4.11 and 4.15 were changed to meet the requirements of Section XI to qualify this operation as an inservice operationa..

pressure test. (Temporary) 3.5.29 OP-7A, Placing Residual Heat Removal System in Operation, Revision 14, 10-08-83 A caution note was added following Step 4.13 to prevent boiling i~

in the residual hea: removal heat exchangers by providing adequate component cooling water prior to starting warmup of the heat tschangers. (Permanent) 3.5.30 OP-13A, Secondary Systems Startup and Shutdown, Revision 17, 08-08-79 (shutdown portion performed 03-06-80, Unit 1)

Steps 5.1 and 5.2 were changed to reflect reduced Unit 1 temperature; i.e., no-load, and 540 F Tavg for Unit 2.

(Permanent) 3.5.31 OP-13A, Secondary Systems Startup and Shutdown, Revision 18, 07-17-80 Steps 5.1 and 5.2 were revised because of Tavg differences between units. Step 5.11 was added to secure the heater drain pump when no heater drain tank cooling is possible. Step 5.17, to secure the steam generator feed pump lube oil pump, was deleted because the pump should be left running unless tagged out. Step 5.18 was revised to have the vacuum priming system in operation except during extended outages. Throughout the procedure minor clerical errors were corrected and valve numbers were fully identified. (Permanent)

~

3.5.32 E0P-1A, Large Loss of Reactor Coolant, Revision 17, 02-05-80 The procedure underwent a general rewrite to (1) provide clarification and instructions to the operators; (2) incorporate THI bestinghouse Owner's Group recommendations; (3) provide environmental readings for instrumentation which could be affected during an accident. Included were provisions for verification of the reactor coolant system heat removal, auxiliary feedwater flow and safety injection flow, and operation of the pressurizer spray valve or power-operated relief valve to maintain pressurizer level. (Permanent) 3.5.33 E0P-2A, Secondary Coolant Break, Revision 10, 02-05-80 The procedure was retitled from " Steam Line Break". Environmental readings for instrumentation which could be affected during an accident were incorporated. Westinghouse Owner's Group recommendations regarding verification of safety injection flow, auxiliary feedwater flow, reactor coolant system heat removal, and safety injection reset were incorporated, including the conditions under which safety injection can be terminated.

(Permanent) 3.5.34 E0P-3A, Steam Generator Tube Rupture, Revision 11, 02-05-80 Westinghouse Owner's Group recommendations and environmental readings for instrumentation were incorporated. Steps were added for identification of the faulted steam generator. Subcooling requirements between the faulted and non-faulted steam generator were inserted. In Step 4.20 a sentence was added that if both reactor coolant pumps are running following restoration of off-tite power (if applicable), the pump in the faulted steam generator loop should be secured. (Permanent) 3.5.35 E0P-4A, Reactor Coolant Leak, Revision 3, 02-05-80 The discussion section was revised to clarify that the primary plant unidentified leakage is greater than 10 gpm but safety injection has not occurred, since the leak may be greater than charging pump capacity. A step was added to notify the Duty &

Call Technical Advisor as well as the Duty & Call Superintendent.

A section was added to provide directions to the operator if it is apparent that a safety injection will occur (including instructions to proceed to E0P-1A, Large Loss of Coolant).

(Permanent) 3.5.36 E0P-4A, Reactor Coolant Leak, Revision 3, 02-05-80 (change approved 03-19-80)

A caution note was added before Step 4.3.3 to ensure that 50 F subcooling is meintained prior to spraying down the pressurizer.

Step 4.3.3 was e.rpanded to spray down the pressurizer to decrease i plant pressure to approximately 1400 psig by holding open an instrument air containment isolation valve switch (1/2 ICV-3047 or 3048); then releasing the switch and ensuring the valve returns to the shut position. A second caution note was added following Step 4.3.3 to repressurize the containment instrument air header slowly to prevent rapid depressurization on the instrument air supply header. (Tempor ary) 3.5.37 E0P-5A, Emergency Shutdown, Revision 7, 02-05-80 A symptom of pressurizer low pressure actuating safety injection -

initiation was added. Notification of the Duty & Call Technical Advisor as well as the Duty & Call Superintendent was incorporated. (Permanent) 3.5.38 E0P-5B, Recovery from Spurious Cafety Injection, Revision 1, 02-05-80 Step 4.3 was added to shut the letdown orifice isolation valves to prevent relief valve lifting. (Permanent) 3.5.39 E0P-12A, Oil and Hazardous Material Spill Control, Revision 3, 12-01-80 The procedure was revised to adhere to the requirements in Environmental Protection Agency regulation Title 40 Part 117,

" Determination of Reportable Quantities for Hazardous Substances", and the facility's WPDES permit. (Permanent) 3.5.40 RP-1A, Preparation for Refueling, Revision 11, 02-05-80 Step 3.3 was changed to specify the actual reactor coolant system total gross activity allowed. In Step 3.4 refueling water storage tank requirements were clarified. In Steps 4.16, 4.17 and 4.18, references to part-length rods were deleted and remaining steps were renumbered. New Step 3.6 was added to install the refueling cavity drain line cleanout flange. The flange is removed after the cavity is drained to provide a flow I path during an accident condition from the cavity to the containment floor. (Permanent) 3.5.41 RP-1A. Preparation for Refueling, Revision 11, 02-05-80 (performed 12-01-80, Unit 1)

In Step 3.3 reactor coolant system purification was greater than 0.05 pCi/ml because the reactor coolant system was being aerated per Chemistry request. (Temporary) 3.5.42 RP-1B, Recevery from Refueling, Revision 7, 01-25-80 A note was added after Step 4.31 to ensure the seal ring is raised at least 12' above the cavity floor to prevent it from becoming a missile hazard. Steps 4.30 and 4.31 concerning part-length rod drives were deleted because the rods are no longer installed. (Permanent) 3.5.43 RP-1C, Refueling, Revision 8, 2-22-80 Position titles were corrected as requirea to reflect current terminology. In Step 3.7 count rates were specified to be

" gross" to keep from overreacting to small increases. Step 3.7.5 was rewritten for better clarification. Step 3.10 was expanded for reactivity changes indicated by a significant change in coant rate (greater than 20%) that the prior steps should be repeated to determine the cause of the increase. A greater than 5%

increase will require a boron sample to be taken but will permit continued fuel movement. Step 3.11 was revised to clarify what actions are taken to determine if count rates are acceptable prior to disengaging an assembly. Step 3.12.3 was changed to clarify the required number of five-second count rates prior to establishing a new baseline. Step 3.18 was revised to specify refueling cavity water levels sufficient to keep manipulator radiation levels as low as reasonably achievable. A sentence was added to 3.20 to point out that the manipulator will r.ot engage a misoriented assembly. Steps 3.27 and 3.28 were added to prevent free-standing assemblies and binding assemblies. Step 3.29 was added to inspect rodolets. Step 3.30 was added to obtain express permission from the Core Loading Supervisor to bypass interlocks.

A sentence was added to Step 4.16 to require both source range ,

detectors to be outputting to the control board recorder. A wording clarification was made in 4.18. Step 4.20 was added to require completion of ORT #15, checkout of the fuel manipulator and fuel transfer system. Several steps were revised to specify periodicity requirements for completing required data sheets.

(Permanent) 3.5.44 RP-1C, Refueling, Revision 8, 02-22-80 (performed 12-07-80, Unit 1)

Following the six-hour suspension of fuel movement on 12-06 because of manipulator problems, Step 3.10 of the procedure which calls for normalized baseline calculations was inadvertently omitted. The computer trend of ICRR showed no change, however.

(Temporary) 3.5.45 RP-1D, Filling and Draining the Refueling Cavity, Revision 5, 02-05-80 Steps 3.5, 5.7 and 6.7 were added to provide a flow path from the refueling cavity to the containment floor during accident conditions via the cleanout flange. In Step 5.6 reference to OP-8B was deleted because the procedure has been canceled.

(Permanent) 3.5.46 RP-2A, Receipt of New Fuel Assemblies, Revision 7. 02-07-80 Step 5.1 was revised to perform a survey of the truck prior to its admittance to the truck access area. Step 5.12 was changed to clarify shipping requirements for empty containers. Numerous typographical errors were corrected throughout the procedure and other minor revisions were made for clarification purposes.

3.5.47 RP-4A, Full-Length Control Rod Drive Shaft Unlatching and Latching, Revision 2, 07-07-80 In Step 4.1.19 a phrase was added to clarify removal of the drive shaft from the upper internals package. In Step 4.2.3 a sentence was added to raise the drive shaft approximately six inches to allow the latch fingers to be completely pulled clear of the rod socket to prevent hang-up. (Permanent) 3.5.48 IT-01 (Unit 1), Inservice Testing of High Head Safety Injection Pumps, Revision 4, 03-I2-80 Cycling of 878B&D during the test was deleted because the Technical Specifications require high head safety injection valves to be open at all times when the unit is at power. Steps were added to leave flow lined up for inspection of check valve leakage. (Permanent) 3.5.49 IT-01 (Unit 1), Inservice Testing of High Head Safety Injection Pumps, Revision 4, 03-12-80 (performed 10-03-80)

In Step 3 18 the manner for recording recire isolation valve 876B line flow and pressure was clarified. (Temporary) 3.5.50 IT-01 (Unit 1), Inservice Testing of High Head Safeht Injection Pumps, Revision 5, 10-06-80 In Step 3.18 the manner for recording recirc isolation valve 876B line flow and pressure was clarified. (Permanent) 3.5.51 IT-02 (Unit 2), Inservice Testing of High Head Safety Injection Pumps, Revision 4, 03-12-80 i

Cycling of 878B&D during the test was deleted because the Technical Specifications require high head safety injection valves to be open at all times when the unit is at power. Steps were added to leave flow lined up for inspection of check valve leakage. (Pe rmanent) 3.5.52 IT-02 (Unit 2), Inservice Testing of High Head Safety Injection Pumps, Revision 5, 10-16-80 In Step 3.18 the manner for recording recirc isolation valve 876B line flow and pressure was clarified. (Pe rmanent) 3.5.53 IT-03 (Unit 1), Inserting Testing of Low Head Safety Injection Pumps (RHR), Revision 4, 04-10-80 Step 3.3 was revised to open RHU-1 and RHU-2. These valves had previously been overlooked when v31ving in the pressure gauges.

In Step 3.13 the time for stopping P10B was added for consistency with prior steps. Step 3.14 was added to close the valves opened in Step 3.3. (Permanent) 3.5.54 IT-04 (Unit 2), Inservice Testing of Low Head Safety Injection Pumps (RHR), Revision 4, 04-10-80 Step 3.3 was revised to open RHU-1 and RHU-2. These valves had previously been overlooked when valving in the pressure gauges.

In Step 3.13 the time for stopping P10B was added for consistency

. with prior steps. Step 3.14 was added to close the valves opened in Step 3.3. On page 3 (data sheet), pressure gauge numbers were corrected. (Permanent) 3.5.55 IT-05 (Unit 1), Inservice Testing of Spray Pumps and Eductor Supply Check Valves 847A&B, Revision 4, 10-09-80 In Steps 3.5 and 3.10 typographical errors were corrected.

Beginning in Step 3.20 and through to the end of the test, provisions for cycling of the 860 and 870 valves were made to be in accordance with Technical Specification 15.4.5.B requirements but without removal of both trains from service at the same time.

(Permanent) 3.5.56 IT-06 (Unit 2), Inservice Testing of Spray Pumps and Eductor Supply Check Valves 847A&B, Revision 4, 10-09-80 In Steps 3.5 and 3.10 typographical errors were corrected.

Beginning in Step 3.20 and through to the end of the test, provisions for cycling of the 860 and 870 valves were made to be in accordance with Technical Specification 15.4.5.B requirements but without removal of both trains from service at the same time.

(Permanent) 3.5.57 IT-08 (Unit 1), Inservice Testing of Turbine-Driven Auxiliary Feed Pump, Revision 5, 08-25-80 Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of auxiliary feed main flow path valve lineup was added.

(Persanent) 3.5.58 IT-09 (Unit 2), Inservice Testing of Turbine Driven Auxiliary Feed Pump, Revision 5, 08-25-80 Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of auxiliary feed main flow path valve lineup was added.

(Permanent) 3.5.59 IT-10, Inservice Testing of Electrically-Driven Auxiliary Feed Pumps, Revision 5, 08-25-80 Precc; tion 3.2 was added to verify that sufficient auxiliary feed flow per Te hnical Specification requirements is available prior to the test. Second operator verification of auxiliary feed flow path valve lineup was added. Throughout the procedure valve numbers were corrected to include the complete identification:

i.e., air-operated valve, etc. (Permanent) 3.5.60 IT-10, Inservice Testing of Flectrically-Driven Auxiliary Feed Pumps, Revision 5, 08-25-80 (performed 09-05-80)

In Steps 4.22.4 and 4.23 a typographical error of AF-55 -

(condensate storage tank suction) was corrected to AF-52.

(Temporary) 3.5.61 IT-10, Inservice Testing of Electrically-Driven Auxiliary Feed Pumps, Revision 6, 09-09-80 In Steps 4.22.4 and 4.23 a typographical error of AF-55 (condensate storage tank suction) was corrected to AF-52.

(Permanent) 3.5.62 IT-40, (Unit 1), Inservice Testing of safety Injection Vaives (Quarterly), Revision 6, 11-24-80 In Step 4.2 the order of opening valves SI-V5 and SI-D17 was reversed to ensure that water is not blevn out of the vent. A typographical error was corrected in Step 3.1. In Items 4.6.5 and 4.13.5 " chain" was changed to " shut" because the valve should be in that position. (Permanent) 3.5.63 IT-45 (Unit 2), Inservice Testing of Safety Injection Valves (Quarterly), Revision 5, 11-24-80 In Step 4.2 the order of opening valves SI-V5 and SI-D17 was reversed to ensure that water is not blown out of the vent. In Items 4.6.5 and 4.13.5 " chain" was changed to " shut" because the valve should be in that position. (Permanent)

I 3.5.64 IT-80 (Unit 1), Inservice Testing of Main and Radwaste Steam Valves (Ouarterly), Revision 3, 04-10-80 Step 2.1 was deleted because the atmospheric steam dump "alves are no longer f sted per Section XI requirements. (Permanent) 3.5.65 IT-85 (Unit 2), Inservice Testing of Main Steam valves (Quarterly),

Revision 3, 04-10-80 Step 2.1 was deleted because the . atmospheric steam dump valves are no longer tested per Section XI requirements. (Pe rmanent) 3.5.66 IT-90 (Unit 1), Inservice Testing of Auxiliary Feedwater Valves (Quarterly), Revision 2, 08-25-80 Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of auxiliary feed main flow path valve lineup was added. Throughout the procedure valve numbers were corrected to include the complete valve identification. (Permanent) 3.5.67 IT-95 (Unit 2), Inservice Testing of Auxiliary Feedwater Valves (Quarterly), Revision 2, 06-25-80 Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of

= auxiliary feed main flow path valve lineup was added. Throughout the procedure valve numbers were corrected to include the complete valve identification. (Permanent) 3.5.68 IT-100, Inservice Testing of Common Auxiliary Feedwater Valves (Quarterly), Revision 2, 08-25-80 Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of auxiliary aed main flow path valve lineup was added. Throughout the procedure vr.lve numbers were corrected to include the complete valve identification. (Permanent) 3.5.69 IT-140 (Unit 1), Inservice Testing of Auxiliary Feedwater System Check Valves (Cold Shutdown), Revision 5, 08-25-80 Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of auxiliary feed main flow path valve lineup was added. Throt;ghout the procedure valve numbers were corrected to include the complete valve identification. The procedure was revised to bring the turbine up to speed by throttling valve MS-126 rather than the turbine trip valve. (Permanent) 3.5.70 IT .45 (Unit 2), Inservice Testing of Auxiliary Feedwater l System Check Valves (Cold shutdown), Revision 5, 08-25-80 J

Precaution 3.2 was added to verify that sufficient auxiliary feed flow per Technical Specification requirements is available prior to the start of the test. Second operator verification of auxiliary feed main flow path valve lineup was added. Throughest the procedure valve numbers were corrected to include the complete valve identification. The procedure was revised to bring the turbine up to speed by throttling valve MS-126 rather than the turbine trip valve. (Permanent)

3.5.71 IT-170 (Unit 1), Pressure Isolatio.. ~.1ve Position Verification Test, nevision 0, 12-2, u (performed 12-24-80)

Steps 3.3.1, 3.3.2, 3.3.4, 3.3.9, 3.4.6, 3.4.7, and 3.4.14 were modified because of CV-853C&D leakage. Steps 3.4.2, 3.4.16, and 3.5.1 were modified to check red locks not shut on valve 897A&B to vent off the pressure gauge prior to testing. (Temporary) 3.5.72 IT-170 (Unit 1), Pressure Isolation Valve Position Verification Test, Revision 0, 12-22-80 (performed 12-27-80)

Only valves 6678, 700, 701, 720, 853A&B were tested following securing of residual heat removal. Steps 3.3.4, 3.4.7, and 3.4.9 were deleted because reactor makeup water was not used as a -

pressure source. Step 3.5.1 was modified because valves 897A&B were left open and red locks were installed on 879B and 884.

(Temporary) .

3.5.73 IT-230 (Unit 1), Leak Test of Class 1 Components Following a Refueling Shutdown, Revision 1, 04-29-79 (performed 12-24-80)

Step 4.24 was modified to raise system pressure to 2085 psig because the unit is operating at reduced pressure. (Temporary) 3.5.74 IT-230 (Unit 1), Leak Test of Class 1 Components Following a Refueling Shutdown, Revision 2, 12-26-80 Step 4.24 was expanded to include raising system pressure to 2085 psig when the unit is operating at a reduced pressure versus normal operating pressure of 2335 psig. (Permanent) 3.5.75 ORT #3 (Unit 1), Safety Injection Actuation with Loss of Engineered Safeguards AC, Revision 10, 11-05-80 Step 4.32 was added to restore electrical power to buses from their normal sources; i.e., A03 to A05, A04 to A06, A05 to B03 and A06 to B04. (Permanent) 3.5.76 ORT 3 (Unit 1), Safety Injection Actuation with Loss of Engineered Safeguards AC, Revision 10, 11-05-80 (performed 12-17-80)

Step 4.19.1 calling for unblocking of safety injection was delayed to verify relay latching of the manual relay. Step 4.26 was rewritten to include additional Appendix "A" entries required to verify safeguards systems do not secure upon safety injection, containment isolation, and containment ventilation reset. An additional step was included in 4.26 to open the service water valves which were kept shut until after safety injection reset to verify the valves did not reopen, and the related step was removed from Step 4.25.3. Step 3.5.5 was modified to check the safety injection sequence to all service water pumps. In Step 4.21 a typographical error was corrected. (Temporary) 3.5.77 ORT #3 (Unit 1), Safety Injection Actuation with Loss of Engineered Safeguarcis .W, Revision 11, 11-04-80 (retest performed 12-17-80)

During the retest which only necessitated performing "B" train loss of AC because of 4D emergency Diesel problems, all portions of the test not applicable for this retest were deleted.

3.5.78 ORT #3 (Unit 2), Safety Injection Actuation with Loss of Engineered Safeguards AC, Revision 9, 09-12-79 (performed 05-02-80, Unit 2)

Step 3.12 was added to accomplish the loss of AC portion of the spray system following completion of a system modification. In Step 4.8 and 4.21 the feed regulating valves and bypass controllers were not installed and were tested separately. In Step 4.19.1, unblocking safety injection was delayed to verify relatching of manual relays. A typographical correction was made i-' Step 4.20.4. In Step 4.22 valves MOV-2907 and 2908 were not tested because maintenance on cooler throttle valve 273 was being conducted. In Steps 4.23 and 4.27.5 a note was added because the breaker for 2P2C must be checked locally since the pump is DC-driven. In Step 4.25.5 the safety injection pumps were started in preparation to determine whether they continue running after reset of safety injection. Step 4.26 was expanded to note the requirement for Appendix "A" and "C" entries. Step 4.26.6 was added to open the service water valves that had been kept shut until af ter safety injection reset to verify they did not reopen. Step 4.26.5 was added to secure the safety injection pumps started in Step 4.25.4. (Temporary) 3.5.79 ORT #3 (Unit 2), Safety Injection Actuation with Loss of Engineered Safecuards AC, Revision 10, 11-05-80 In Step 4.20.4 the name for P32A-F, service water pumps, was corrected. In Step 4.23 a note was added to check breaker position for 2P2C locally. Step 4.32 was added to restore electrical power to buses from their normal sour:es- i.e., A03 to A05, A04 to A06, A05 to B03 and A06 to B04. (Permanent) 3.5.80 ORT #5 (Unit 1), Sump "B" to Residual Heat Removal Pump Suction Valves' Hydro, Revision 4, 03-21-80 The test was changed to reflect completion of a modification request which installs rails to permit efficient movement of the screens. This change included the equipment necessary to lift the screens. (Permanent) 3.5.81 ORT #5 (Unit 2), Sump "B" to Residual Heat Removal Pump l

Suction Valves' Hydro, Revision 5, 03-21-80 l

The test was changed to reflect completion of a mc tion which installs rails to permit efficient movement of the > .ns.

This change included incorporation of the equipment necessary to lift the screens. (Permanent)

3.5.82 ORT #6 (Unit 1). Containment Spray Sequence Test, Revision 3, 08-24-79 (performed 12-18-80)

A step was added to verify alarms for ventilation and containment isolation. A ctep was also added to complete a table required in order to respond to IE Bulletin No. 80-06 requirements. New Step 2.4 was added to ensure proper I & C interfacing during performance of the test. (Temporary) 3.5.83 ORT #6 (Unit 1), Containment Spray Sequence Test, Revision 4, 12-26-80 New Step 3.3.4 was added to verify alarms for ventilation and ,

containment isolation. Step 2.4 was added to ensure proper I & C interfacing during performance of the test. (Permanent) 3.5.84 ORT #6 (Unit 2), Containment Spray Sequence Test, Revision 3, 09-12-79 (performed 05-03-80)

Step 3.4.1 and Table 1 were added to verify the breakers remain closed and the valves do not reposition. These steps were added for preparation of an IE Bul}etin No. 80-06 response.

(Temporary) 3.5.85 ORT #7 (Unit 1), Operation of Backdraft Dampers, Revision 4, 02-28-80_

The procedu. e was rewritten to better document backdraft damper operability. (Permanent) 3.5.86 ORT #8 (Unit 2), Visual Check of Residual Heat Removal System, Revision 1, 02-02-76 (performed during Unit 2 Refueling 6)

The procedure was changed to qualify this visual inspection as an inservice operational pressure test. (Temporary) 3.5.87 ORT #65 (Unit 2), IVLT, R11 and R12 Return Piping, Penetration X2, Revision 5, 01-30-79 (performed 04-25-80)

The page 5 drawing was updated to reflect actual system configuration. (Temporary) 1 3.5.88 ORT #65 (Unit 2), IVLT, R11 and R12 Return Piping, Penetration l X2, Revision 6, 05-09-80 The page 5 drawing was updated to reflect actual system configuration. (Permanent) 3.5.89 OI-23, Changing Boric Acid Feed Filters IF8 (2F8), Revision 0, 39-05-78 The operating instruction was canceled because it was superseded by OI-22G of the same title. (Canceled) 3.5.90 ICP 2.1 (Unit 1), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV, Revision 14, 12-03-79 (conducted 02-20-80)

In Step 5.5 a caution note was added to tag out the crane to prevent spurious trips from steam line low pressure. In Steps 6.8C 6.168 and 6.330 "inc" was changed to "dec" because the steam flow signal is simulated constant at 30.00 ma while feed flow is decreased to 22.00 ma to check the setpoint. In Steps 6.43, 6.128, 6.301 and 6.209, the low pressure trip was changed to be greater than or equal to 15.00 decreasing because the setpoint had been changed. (Temporary) 3.5.91 ICP 2.1 (Unit 1), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV. Revision 15, 02-19-80 0

In Step 5.5 a caution note was added to tag out the crane to prevent spurious trips from steam line low pressure. In Step 6.80, 6.168, and 6.330 "inc" was changed to "dec" because the steam flow signal is simulated constant at 30.00 ma while feed flow is decreased to 22.00 ma to check the setpoint. In Steps 6.43, 6.128, 6.301, and 6.209, the low pressure trip was changed to be greater than or equal to 15.00 decreasing because the setpoint had been changed. (Permanent) 3.5.92 ICP 2.1 (Unit 1), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV, Revision 16, 06-25-80 In Steps 6.22, 6.107, 6.188 and 6.280, the lower tolerance for f(Tavg) at 515 F of -0.00 ma was inadvertently omitted in Revision 15 and was replaced appropriately in this revision.

(Permanent) 3.5.93 ICP 2.1 (Unit 1), Periodic Test, Reactor Protection and Safeguards Analog Channels I through IV, Revision 16, 06-25-80 (performed 10-28-80)

In Steps 6.140 and 6.222 turbine power first stage steam pressure setpoint was changed from $13.38 inc. to $13.22 inc. because the setpoint had been previously changed for P7 unblocking at 9.5% to permit setpoint drift. (Temporary) 3.5.94 ICP 2.1 (Unit 1), Periodic Test, Reactor Protection and Safecuards Analog Channels I through IV, Revision 17, 11-06-80 In Steps 6.140 and 6.222 turbine power first stage steam pressure setpoint was changed from 113.38 inc. to 113.22 inc. because the setpoint had been previously changed for P7 unblocking at 9.5% to parmit setpoint drift. (Permanent) l 29-

3.5.95 ICP 2.1 (Unit 2), Periodic Test, Reactor Protection and Safeguards Avalog Charnels I through IV, Revision 12, 09-26-79 (performed 05-09-80)

Revision 12 was used in lieu of Revision 13 because the new revision'was not available at the time of the test. The changes for Revision 13 were pen and ink incorporated into Revision 12.

A temporary change was made to Step 6.38 to recalibrate ATspl based upon 2000 psia ope ra t.\on . Step 6.123, 6.204 and 6.296 checkpoints were changed for 2000 psia operation. In Steps 6.43 and 6.128 the low pressure trip was changed from 119.25 to 15.00 dec. because the trip setpoint was changed to 1800 psi. In Steps 6.209 and 6.301 a step was added to reset the low pressure alarm .

to 21.75 ma on a temporary basis. In Steps 6.39, 6.124, 6.205 and 6.297 pressure value was set to some value greater than 50%

versus 75% because of the new alignment of ATspl. In Step 6.260 ,

a typographical correction was made; and throughout the procedure

" initials" was changed to " checkoff" (Temporary) 3.5.96 ICP 2.1 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV, Revision 13, 02-19-80 Revision 12 was used in lieu of Revision 13 because the new revision was not available at the time of the test. The changes for Revision 13 were pen and ink incorporated into Revision 12. A change was made to Step 6.38 to recalibrate ATspl based upon 2000 psia operation. Step 6.123, 6.204, and 6.296 checkpoints were changed for 2000 psia operation. In Steps 6.43 and 6.128 the low pressure trip was changed from 119.25 to 15.00 dec. because the trip setpoint was changed to 1800 psi. In Steps 6.209 and 6.301 a step was added to reset the low pressure alarm to 21.75 ma. In Steps 6.39, 6.124, 6.205, and 6.297 pressure value was set to some value greater than 50% versus 75% because of the new alignment of ATspl. In Step 6.260 a typographical correction was made; and throughout the procedure " initials" was changed to

" checkoff" (Permanent) 3.5.97 ICP 2.1 (Unit 2), Periodic Test, Reactor Protection and Safeauards Analog Channels I through IV, Revision 13, 02-19-80 (performed 03-26-80)

Steps 6.22-6.29, 6.107-6.109, 6.188-6.190, and 6.280-6.282 were revised to reflect changed temperature range resistors for l operation until the refueling outage. Steps 6.26, 6.111, 6.192 and 6.289 were revised to reflect the necessary setpoint adjustment for the range change. Steps 6.38, 6.123, 6.204 and 6.296 provided new ATspl curve limits for the reduced temperature operation. (Temporary) 3.5.98 ICP 2.1 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog Channels I through IV, Revision 14, 05-09-80 Steps 6.123, 6.504 and 6.296 were revised to change the checkpoints for 2000 psia operation. In Steps 6.43 and 6.128 the low pressure trip was changed from >19.25 to 15.00 dec. because the reactor trip setpoint was changed to 1800 psi. In Steps 6.39, 6.124, 6.205 and 6.297 pressurizer pressure value was set to some value greater than 50% versus 75% because of the new alignment of ATspl. In Step 6.260 a typographical correction was made: end throughout the procedure "initiais" was replaced by "checkofr'

. (Permanent)

3.5.99 ICP 2.1 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog Channels I through IV, Revision 14, 05-09-80 (performed 11-04-80)

In Steps 6.140 and 6.222 turbine power first stage steam pressure setpoint was changed from 113.38 inc. to 113.22 inc. because the setpoint had been previously changed for P7 unblocking at 9.5% to permit setpoint drift. (Temporary) 3.5.100 ICP 2.1 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog Channels I through IV, Revision 15, 11-06-80 In Steps 6.140 and 6.222 turbine power first stage steam pressure setpoint was changed from $13.38 inc. to- <13.22 inc. because the setpoint had been previously changed for P7 unblocking at 9.5% to

. permit setpoint drift. (Permanent) 3.5.101 ICP 2.2 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV, Revision 11, 02-18-80 All. of the greater' or less than symbols .were missing the underscored u '! equals to" sign and these symbols were inserted.

(Permanent) 3.5.102 ICP 2.2 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV, Revision 11, 02-18-80 (performed 03-11-80)

~

Steps 6.16-6.18, 6.59-6.62, 6.100-6.102, and 6.141-6.144 were revised ;to reflect changed temperature- range rE+istors for 6.- operation until the refueling outage. Steps 6.23, 6.63, 6.104, and 6.145 were revised- to reflect the range change necessary setpoint correction. (Temporary)'

3.5.103~ ICP 2.2 (Unit-2)',-Periodic Test, Reactor Protection and Safeguards Analog,~ Channels I through IV, Revision 11, 02-18-80 (performed 06-03-80)

Steps 6.35, ~6.75, - 6.116, and 6.157 were revised for 2000 psia

- operation . requirin9 revision 'to the _ ATspl calibration curve.

Because ' the c calibration 1 curve - was revised, Steps 6.36, 6.76,-

-6.117 Land.6.158 were also modified. (Temporary) 4

, ; g .

3.5.104 ICP 2.2 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog, Channels I through IV, Revision 12, 06-13-80 Steps 6.35, 6.75, 6.116, and 6.157 were revised for 2000 psia operation requiring revision to the ATsp1 calibration cu rve .

Because the calibration curve was revised, Steps 6.36, 6.76, 6.117, and 6.158 were also modified. (Permanent) 3.5.105 ICP 2.2 (Unit 2), Periodic Test, Reactor Protection and Safeguards Analog Channels I through IV, Revision 13, 08-19-80 Tolerance values, which had been missing because of clerical error, were added. (Permanent) .

3.5.106 ICP 2.5 (Unit 1), Periodic Test, Safeguards System Logic, Revision 11, 09-20-79 (performed 03-17-80)

Steps 6.2.5.a and 6.4.5.a changed containment spray Testpoint 11 to 300 ohms. St.,.t 6.2.8.c and 6.4.8.c changed safety injection sequence Testpoint 17 to 625 ohms. New Steps 6.2.8.e and 6.4.8.e were added to note Testpoint 21 should read approximately 1900 ohms. These changes were necessary during performance of modification requect IC-204. (Temporary) 3.5.107 ICP 2.5 (Unit 1), Periodic Test, Safeguards System Logic, Revision 12, 04-03-30 The temporary changes noted above which were made to Revision 11 on 03-17-80 were incorporated into this revised procedure which reflects completion of modification request IC-204. (Permanent) 3.5.108 ICP 2.5 (Unit 1), Periodic Test, Safeguards System Logic, Revision 12, 04-03-80 (performed 09-30-80)

Notes were added to Steps 6.1.2 and 6.2.2 to clarify testing of main steam line isolation logic when high steam flow and low Tavg signals are present. (Temporary) 3.5.109 ICP 2.5 (Unit 1), Periodic Test, Safeguards System Logic, Revision 13, 10-07-80 .

Notes were added to Steps 6.1.2 and 6.2.2 to clarify testing of main steam line isolation logic when high steam flow and low Tavg ,

signals are present. (Permanent) 3.5.110 ICP 2.5 (Unit 2), Periodic Test, Safeguards System Logic, Revision 9, 09-20-79 (performed 05-08-80)

Steps 6.2.5.a, 6.2 8.c, 6.2.8.e, 6.4.5.a, 6.4.8.c and 6.4.8.e were changed to reflect completion of modification request IC-205. (Temporary) 3.5.111 ICP 2.5 (Unit 2), Periodic Test, Safeguards System Logic, Revision 10, 05-09-80 Steps 6.2.5.a, 6.2.8.c, 6.2.8.e, 6.4.5.a. 6.4.8.c, and 6.4.8.e were changed to reflect completion of modification request IC-205. (Permanent) 3.5.112 ICP 2.5 (Unit 2), Periodic Test, Safeguards System Logic, Revision 11, 10-07-80 Notes were added to Steps 6.1.2 and 6.2.2 to clarify testing of main steam line isolation logic when high steam flow and Tavg

. signals are present. (Permanent) 3.5.113 ICP 2.7 (Unit 1), Periodic Test, Nuclear Instrumentation Power Range Channels N41, N42, N43, and N44, Revision 7, 12-18-79 (performed 01-09-80)

In Steps 6.31.1 and 6.31.2 current value was reduced from 100% to 85% and in 6.31.3 voltage was reduced from 8.33 to 7 08 V; all three changes made to permit testing at reduced reactor trip setpoints. (Temporary)

~3.5.114 ICP 2.7 (Unit 1), Periodic Test, Nuclear Instrumentation Power Range Channels N41, N42, N43 and N44, Revision 8, 01-21-80 In Steps'6.31.1 and 6.31.2 current value was reduced from 100% to

. 85% and in 6.31.3 ~ voltage was reduced from 8.33 to 7.08 V; all three changes made to permit testing at the reduced reactor trip setpoints. (Permanent) 3.5.115 ICP 2.7 (Unit 2), Periodic Test Nuclear Instrumentation Power Range Channe]s N41, N42, N43, and 44, Revision 6, 11-20-79 (performed 03-27-80)

In Step _6.31.2 Detector "B" current value was increased from 105%

to 120%, and in Step 6.31.3 ion chamber current voltage level ideal settings were increased to 10.00 V. These gain adjustments were required by Tavg increase-caused detector currents.

(Temporary) 3.5.116 ICP 2.7 (Unit 2), Periodic Test, Nuclear Instrumentatio11 Power Range Channels N41, N42, N43, and N44, Revision 6 11-20-79 (performed 05-08-80)

In. Step 6.25-a note was added to change the overpower trip to 80%

following refueling; this being standard procedure. In Step 6.31 a note - was added that allows current values other then those listed to be utilized .in the test if' conditions warrant.

(Temporary)

^

3.5.117 ICP 2.7 (Unit 2), Periodic Test, Nuclear Instrumentation System Power Range Channels N41, N42, N43, and 44, Revision 6, 11-20-79 (performed 05-22-80)

In Steps 6.22 and 6.25 setpoints for overpower trip and overpower rod stop were reduced to maintain administrative conservatism in controlling Fg. (Temporary) 3.5.118 ICP 2.7 (Unit 2), Periodic Test, Nuclear Instrumentation Power Range Channels N41, N42, N43, and N44, Revision 7. 05-09-80 In Step 6.25 a note was added to change the overpower trip to 80%

following refueling; this being standard procedure. In Step 6.31 .

a note was added that allows current values other than those listed to be utilized if conditions warrant. (Permanent) 3.5.119 ICP 2.8, Periodic Test, Nuclear Instrumentation System Power Range Channels - Axial Offset Calibration, Revision 2, 10-25-78 (performed 08-13-80)

The procedure was revised to reflect the low power operation of Unit 1. (Temporary) 3.5.120 ICP 2.8, Periodic Test, Nuclear Instrumentation System Power Range Channels - Axial Offset Calibration, Revision 3, 08-19-80 The procedure was revised to reflect the low power operation of Unit 1. (Permanent) 3.5.121 'ICP 2.12 (Unit 1), Periodic Tests, Independent Overspeed Protection System, Revision 5, 09-04-80 Steps 6.2.1 through 6.2.13 and 6.3.1 through 6.3.13 were renumbered to perform the single channel test only after the 2/3 test is performed.~ This ensures that no relay is hung up after the 2/3 test. Step 6.1 was revised to formalize the defeat of i the opposite unit's IOPS. Step 6.10 was revised to include addition of the turbine first-out alarm in the control room.

(Permanent) .

3.5.122 ICP 2.12 (Unit 2), Periodic Test, Independent Overspeed Protection System, Revision 5, 09-04-80 Steps 6.2.1 through 6.2.13 and 6.3.1 through 6.3.13 were renumbered to perform the single. channel test only after the 2/3 test is performed. This ensures that no relay is hung up after the 2/3 - test. Step 6.1 was revised to formalize' the defeat of the opposite unit's IOPS. Step 6.10 was revised to . include addition of the turbine first-out alarm in the control room.

.(Permanent) l 3.5.123 ICP 2.15 Periodic Test, Reactor Protection System Logic I I

Periodic Test, Revision 1, 01-03-79 (performed 04-11-80, Unit 2)

Step 2.4 was changed to provide an inclusive description of the items checked during the test. In Step 6.6 the note was changed to read: "This test can be performed only if condenser pressure is greater than 22" water and a circulating water pump is operating. This condition will be indicated by relays P9 1&2 being energized". This change clarified the original note. In Step 6.6.1.a. "S8" was added because it is required to be operated under certain conditions. (Temporary) 3.5.124 ICP 2.15, Periodic Test Reactor Protection System Logic

: - Periodic Test, Revision 2, 04-24-80 Step 2.4 was changed 'to provide an inclusive description of the

- items checked during the test. In Step 6.6 the note was changed to read: "This test can be performed only if condenser pressure is greater than 22" water and a circulating water pump is operating. This condition will be indicated by relays P9 1&2 being energized". This change clarifies the original note. In Step 6.6.1.a, "S8" was added because it is required to be operated under certain conditions. (Permanent) 3.5.125 '

ICP 2.16, Periodic Test, Overpressurization Hitigating System,

. Revision 1, 09-08-80 In Steps 6.3, 6.5, 6.12, 6.15, and 6.16 bistable setpoints were changed from 425 to 515 psig to permit some drift of the bistable without . incurring a Technical Specification violation.

(Permanent)-

3.5.126 ICP-4.1 (Unit-1), Calibration Procedure, Reactor Protection and Safeguards Analog Racks, Revision 2, 11-20-79 (performed 12-01-80)

- StepsL were changed throughout the procedure to reflect low temperature / low pressure operation _of. the unit. Severt.1 typographical errors were corrected, and computer inputs were added. . (Temporary) 3.S.127 .ICP 4.1 (Unit 1), Calibration Procedure, Reactor Protection and Safeguards Analog Racks, Revision 3, 12-22-80

=

- Steps were- changed throughout' the procedure- to reflect low temperature / low pressure' operation .of .the unit. Several typographical errors ;were corrected, and computer inputs _were added. (Permanent).

'3.5.'128 I ICP 4.1 (Unit 2), Calibration Procedure,' Reactor Protection and Safeguards Analog Racks, Revision 3, 09-05-80

0n -70. pages " ideal"' data was filled in and/or other instr-checks were ladded. .On five pages the testpoint , location .

On spage. 8, - calibration. of; TI-405B '. was deleteu.

corrected.

-(Permanent) .

E

3.5.129 ICP 4.3 (Unit 1), Calibration Procedure, Pressurizer Level Transmitters, Revision 5, 11-20-79 (performed 03-18-80)

Step 6.6 was revised to indicate 2000 psia operation for Unit I as well as 2250 psia operation of Unit 2. The data sheets were revised accordingly for Unit I low pressure operation.

(Permanent) 3.5.130 ICP 4.3, Calibration Procedure, Pressurizer Level Transmitters, Revision 6, 03-19-80 (performed 05-09-80, Unit 2)

Step 6.6 and the data sheets were revised to reflect 'Init 2 operation at 2000 psia. Steps 5.3 and 6.9 were added to provide '

instructions for performance of the procedure when the 4

pressurizer is solid. (Temporary) 3.5.131 ICP 4.3, Calibration Procedure, Pressurizer Level Transmitters, -

Revision 7, 05-09-80 Step 6.6 and the data sheets were revised to reflect Unit 2 operation at 2000 psia. Steps 5.3 and 6.9 were added to provide instructions for performance of the procedure when the pressurizer is solid. (Permanent) 3.5.132 ICP 4.5, Calibration Procedure, Steam Generator Level Transmitters, Revision 2, 02-03-77 (performed 03-21-80, Unit 1)

Calibration data on the data sheets was revised for Unit 1 only to reflect steam generator operation at 600 psia. (Temporary) 3.5.133 ICP 4.5, Calibration Procedure, Steam Generator Level Transmitters, Revision 2, 02-03-77 (performed 12-08-80, Unit 1)

The Unit I data sheet input and ideal values for LT-461-463 and LT-471-473 -were revised for operation at reduced Tavg.

(Temporary) 3.5.134 ICP 4.5, Calibration Procedure, Steam Generator Level Transmitters, Revision 3, 12-22-80

~

The Unit 1 data sheet input and ideal values for LT-461-463 and LT-471-473 were revised for operation at reduced Tavg.

(Permanent) .

3.5.135- ICP 4.7', Calibration Procedure, Feedwater Flow Transmitters, Revision 1, 02-18-77 (performed 04-19-80, Unit 2)

In Step 2.1 flow transmitters FI-466 and FI-476 were added. These indicators.had been previously calibrated but had not been listed

~

in the procedure. (Temporary) 3.5.136 ICP 4.7, Calibration Procedure, Feedwater Flow Transmitters, Revision 2, 05-09-80 In Step 2.1 flow transmitters FI-466 and FI-476 were added.

(Permanent) 3.5.137 ICP 4.11, Calibration Procedure, Accumulator Level Transmitters, Revision 1, 02-18-77 (performed 12-02-80, Unit 1)

The data sheets for Unit I were corrected to reflect the actual transmitter numbers; i.e., ILT-936 to ILT-938, and ILT-937 to ILT-939. (Temporary) 3.5.138 ICP 4.11, Calibration Procedure, Accumulator Level Transmitters, Revision 2, 12-22-80 The data sheets for Unit I were corrected to reflect the actual transmitter numbers; i.e., ILT-936 to ILT-938, and ILT-937 to 1LT-939. (Permanent) 3.5.139 ICP 4.13, Calibration Procedure, Accumulator Level and Pressure Rack Calibration, Revision 2, 06-12-79 (performed 12-02-80, Unit 1)

On the L-935 data sheet a typographical error was corrected.

(Temporary) 3.5.140 ICP 4.13, Calibration Procedure, Accumulator Level and Pressure Rack Calibration, Revision 3, 12-22-80 On the L-935 data sheet a typographical error was corrected.

(Permanent) 3.5.141 ICP 4.14, Calibration Procedure, Boric Acid Control System, Revision 3, 11-20-79 (performed 12-09-80, Unit 1)

Signoff spaces were modified to require checkoff in lieu of

' initials and valve stroke data . sheets for F110 and F111 were revised to include data for FCV-110A and .FCV-111, respectively.

- '(Temporary)

-3.5.142 ICP 4.14, Calibration Procedure, Boric Acid Control System, Revision 4, 12-22-80 Signoff spaces. were modified to require checkoff in lieu . of initials and valve stroke data sheets for _F110 and F111, respectively. .(Permanent) 3.5.143 ICP 4.15, Calibration Procedure, Boric Acid Tank Level Transmitters, Revision 0, 09-18-72 (performed 04-17-80, Unit 2)

In ' Step l2.1 a note' was added to indicate that L-171, L-102 and L-189 need 'only be calibrated . during Unit I refueling

. calibrations. (Temporary)

- 3 7-W . .L ____:_------

3.5.144 ICP 4.15, Calibration Procedure, Boric Acid Tank Level Transmitters, Revision 1, 05-09-80 In Step 2.1 a note was added to indicate that L-171, L-102 and L-189 need only be calibrated during Unit 1 refueling calibrations. (Permanent) 3.5.145 ICP 4.18, Calibration Procedure, Volume Control Tank Rack, j Revision 4, 06-14-79 (performed 12-06-80, Unit 1)

Signoff spaces were modified to require checkoff in lieu of initials. .The data sheet was revised for L112 to add computer input information. On the sheet for L141 a typographical error -

was corrected, and LI-141A was deleted because it is contained in another procedure. (Temporary) 3.5.146 ICP 4.18, Calibration Procedure, Volume Control Tank Rack, Revision 5, 12-22-80 Signoff spaces were modified to require checkoff in lieu of initials. The data sheet was revised for L112 to add computer input information. On the sheet for L141 a typographical error was' corrected, and LI-141A was deleted because it is contained in another procedure. (Permanent) 3.5.147 ICP 4.19, Calibration Procedure, Refueling Water Tank Level Indication, Revision 1, 09-20-77 (performed 04-16-80, Unit 2)

Terminal strip test point locations were added to the data sheet for information. (Temporary) 3.5.148 ICP-4.19, Calibration Procedure, Refueling Water Tank Level Indication, Revision 2, 05-09-80 Terminal strip test point locations were added to the data sheet for information. (Permanent) 3.5.149 ICP 4.20, Calibration Procedure, Residual Heat Removal Pump Flow, Revision 0, 09-18-72 (performed 12-03-80, Unit 1)

.A computer data block was added on the F626. data sheet.

~(Temporary) 3.5.150 .ICP 4.20, Calibration Procedure, Residual Heat Removal Pump Flow, Revision 1, 12-22-80 A computer' data.' block was added on the F626 ~ data sheet.

(Permanent).

3.5.151 ICP 4.21, Calibration Procedure, Charging Flow, Revision 1, 11-20-79 (performed 12-18-80, Unit 1).

A computer. data. block was added to:the data sheet. (Temporary) 3.5.152 TCP 4.21, Calibration Procedure - Charging Flow, Revision 2, 12-22-80 A computer data block was added to the data sheet. (Permanent) 3.5.153 ICP 4.23, Calibration Procedure, Radiation Monitoring System (Electronic), Revision 3, 11-20-79 (performed 04-80, Unit 2)

In Attachments "A" and "B", the applicable units were listed; a note was added that R22 is source-calibrated only; and that RISHL CR7&8 are not used. In Appendix "A", Section 9 0 the title was expanded to include PM detectors with high background, which permits running of the high voltage curve for the detectors.

, (Temporary) 3.5.154 ICD 4.23, Calibration Procedure, Radiation Monitoring System (Electronic), Revision 4, 05-09-80 In Attachments "A" and "B", the applicable units were listed; a note was added that R22 is source-calibrated only; and that RISH'.

,- CR7 & 8 are not used. In Appendix "A", Section 9.0, the title was expanded to include PM detectors with high background, which permits running of the high voltage curve for the detectors.

(Permanent) 3.5.155 ICP 4.23, Calibration Procedure, Radiation Monitoring System (Electronic), Revision 5, 11-12-80 A note was- added to notify the Radicchemist of the date and time certain. channels- were calibrated for release accounting considerations. In Appendix "A", Steps 2.1.1 through 2.1.3, voltage tolerances were added, as was a note in Step 3.1 to remove the detector input cable from the drawer for R207 calibration. On page 4 _of the same appendix, the voltage chart range was ' increased. In Appendix "C", a note was added to Step 2.2.2 to set input. at 30 my for calibration of readout electronics EC-7 for channel R20. (Permanent) 3.5.156 ICP 4.23A, Calibration Procedure, Victoreen Radiation Log Ratemeters, Revision 2, 03-21-77 (performed 04-80, Unit 2)

In Step 2.1 CR7&8 were deleted because they are not-used. In Step 7.1.6-instructions were provided to,run the high voltage plateau, attach the graph, : and record the high voltage setting. These

checks were not previously included in the manufacturer's procedure; however, high voltage settings were found to have changed. (Temporary)'

3.5.157 ICP-4.23A, Calibration Procedure, Victoreen Radiation Log Ratemeters, Revision 3, 05-09-80 In Step 2.1 CR7&8 were deleted because they are not used. In Step 7.1.6 instructions were provided.to run the high voltage plateau,-

attach the graph -and record '. the high voltage setting. These Echecks-. - were . . not previously- included in -the manufacturer's procedure; however, high voltage settings were found to have

- changed.- Thus, the settings will - be checked in the future.

-(Permanent)'

y [

2- ..__.t _ _ _ _ _ _ . _ _ _ _ _ _ 1 __ ____ __ , _ _ _ _ _ _ _ , , , _ _ _ _ _ _ _3

3.5.158 ICP 4.24, Calibration Procedure, Nuclear Instrumentation Source Range Channels, Revision 3, 11-02-78 (performed 12-01-80, Unit 1)

Computer data blocks were added where appropriate. (Temporary) 3.5.159 ICP 4.24, Calibration Procedure, Nuclear Instrumentation Source Range Channels, Revision 4, 12-22-80 Computer data blocks were added where appropriate. Typographical errors were corrected and notes were added to enhance calibration per Westinghouse data letter 78-4. (Permanent) ,

3.5.160 ICP 4.25, Calibration Procedure, Nuclear Instrumentation Intermediate Range Channels, Revision 5, 11-20-79 (performed 12-04-80, Unit 1)

Data blocks for computer data were added. High level rod stop and trip setpoints were revised as a result of low temperature operation on Unit 1. A typographical error was corrected in Step 6.7.3 for the Unit 2 high level trip setpoint. Step 6.6.4 was changed to increase accuracy of 10 a indication. (Temporary) 3.5.161 ICP 4.25, Calibration Procedure - Nuclear Instrumentation Intermediate Range Channels, Revision 6, 12-22-80 Data blocks for computer data were added. High level rod stop and trip setpoints were revised as a result of low temperature operation on Unit 1. A typographical error was corrected in Step 6.7.3 for the Unit 2 high level trip setpoint. Step 6.6.4 was changed to increase accuracy of 10 3 indication. (Permanent) 3.5.162 ICP 4.26, Calibration Procedure, Nuclear Instrumentation Power Range Channels, Revision 3, 11-27-78 (performed 04-80, Unit 2)

The procedure was revised to include a calibration check of the NR45 recorder, the NR41-44 recorders, and the NR46 and 47 recorders. (Temporary) .

3.5.163 ICP 4.26, Calibration Procedure, Nuclear Instrumentation Power Range Channels, Revision 4, 05-09-80 .

The procedure was revised to include a calibration check of the NR45 recorder, the NR41-44 recorders, and the NR46 and 47 recorders. (Permanent) 3.5.164 ICP 4.26, Calibration Procedure, Nuclear Instrumentation Power Range Channels, Revision 4, 05-09-80 (performed 12-06-80, Unit 1)

Data blocks were added for computer data; channel voltages were revised to reflect detector efficiency; and channel setpoints were revised to reflect reduced power level operation.

(Temporary)

3.5.165 ICP 4.27 (Unit 2), Calibration Precedure, Nuclear Instrumentation Power Range Channels, Revision 5, 12-22-80 The procedure was unitized to reflect different operating

'; conditions between units. Blocks were added for computer data.

(Permanent) 3.5.166 ICP 4.26 (Unit 1), Calibration Procedure, Nuclear Instrumentption Power Range Channels, Revision 0, 12-22-80 This procedure was unitized to reflect different operating 4 conditions between the PBNP units. Blocks were added for 4

computer data; channel voltages were revised to reflect detector efficiency; and channel setpoints were revised to reflect reduced power level operation. (Permanent)

. - 3.5.167 ICP 4.27, Calibration Procedure, Nuclear Instrumentation Auxiliary Channels, Revision 1, 11-20-79 (performed 12-11-80, Unit 1)

Step 6.2 was deleted in its entirety because the calibrations noted therein are accomplished during conduct of ICP 4.26.

(Temporary) 3.5.168 ICP 4.27, Calibration Procedure, Nuclear Instrumentation Auxiliary Channels, Revision 2, 12-22-80 Step 6.2 was deleted in its entirety because the calibrations noted therein are accomplished during conduct of ICP 4.26.

t (Permanent)

'3.5.169 ICP 4.28, Calibration Procedure, IOPS, Revisicn 1, 11-20-79 (performed 05-01-80, Unit 2)

A data sheet was added to the procedure. Section 6.0 was revised to incorporate steps required to perform the procedure, including opening and closing of sliders. (Temporary) 3.5.170. 'ICP 4.28, Calibration Procedure, IOPS, Revision 2, 05-09-80

- A data sheet was added to the procedure. Section 6.0 was revised to incorporate steps required to perform the procedure, including opening and' closing of sliders. '(Permanent)

ICP 4.29, Calibration Procedure, Analog Rod Position,

.3.5.171 Revision 1, 11-20-79 (performed 04-02-80, Unit 2)

The' data sheets were revised to reflect checkpoints listed in the technical ~ manual l procedure and calibration curve points for actual rod position. The technical manual required spanning the instrument using 3.45 V at 144" while the calibration curve required 3.32'V at 142.5". (Temporary)

---..v_---_- A..-------- ..--._!-,_.-.-'..--.-

3.5.172 ICP 4.29, Calibration Procedure, Analog Rod Position, Revision 2, 05-09-80 The data sheets were revised to reflect the checkpoints listed in the technical manual procedure and calibration curve points for actual rod position. The technical manual required spanning the instrument using 3.45 V at 144" while the calibration curve requires 3.32 V at 142.5" (Permanent) 3.5.173 ICP 6.24, Calibration Procedure, Emergency Diesel, Revision 3, 06-22-80 (performed 10-13-80)

Step 5.10.6 was added to open the Whitey valve to complete the ,

raw water switch check. Data sheets were added to document calibrations. (Temporary) 3.5.174 ICP 6.24, Calibration Procedure, Emergency Diesel, Revision 4, 10-23-E0 Data sheets were added to document calibration of some pressure gauges. Steps were added to call out these calibrations.

(Permanent) 3.5.175 Emergency PInn. Fevision 13, 09-15-80 The changes - consisted of revisions to the Emergency Call List (Section 8). (Permanent) 3.5.176 FOP 1.2, Foaming Agent Sampling, Revision 1, 11-05-79 This minor procedure was canceled because foaming agent is changed out on an annual basis. (Canceled)

FOP 1.3, Fire Brigade Training Record, Revision 0, 04-07-80

~

3.5.177 This minor procedure was canceled and made into form FP-02.

(Canceled) 3.5.178 FOP 1.4, Fire Brigade Member Training Record, Revision 0, 04-07-80

~

This minor procedure was canceled and made into form FP-04.

(Canceled) 3.5.179 TS-7, Monthly Diesel Fire Pump Functional Test, Revision 5, -

04-10-80 The ' test .was revised to include instructions to remove the red lock and shut PS-3713 (the isolation to cause the pump to start) with later reopening and red locking of the valve (with documentation of the lock number). In addition, minor clerical changes were made. (Permanent) 3.5.180 TS-12, Monthly Fire Equipment Surveillance, PAB, Units 1 and 2 Facades, Revision 2, 04-10-80 New hose reels were added and. Technical Specification requirements were flagged. (Permanent) 3.5.181 TS-13, Monthly Fire Equipment Surveillance, Unit 2 Turbine Room, Revision 4, 06-01-79 (performed 05-29-80)

Operating personnel utilized a superseded test form (Revision 5, 04-10-80 was current); however, temporary changes were marked on the test in Steps 2, 42 and 46 to correct redesignated and renumbered hose reels. (Temporary) 3.5.182 TS-13, Monthly Fire Equipment Surveillance, Unit 2 Turbine Room, Revision 5, 04-10-80 New hose reels were added and several existing hose reels were renumbered to incorporate completed modification requests. In addition, Technical Specification requirements were flagged.

(Permanent).

3.5.183 TS-13, Monthly Fire Equipment Surveillance, Unit 2 Turbine Room, Revision 6, 09-05-80

- In Steps 49 and 50 cable spreading room fire extinguisher numbers were corrected. (Permanent) 3.5.184 TS-14, Monthly Fire Equipment Surveillance, Outside Areas, Maintenance and Portable Welding Carts, Revision 5, 12-20-79 In Step .9.g the correct number of fire axes at FH-26 was changed to be one. In Step 24 a truck identification was corrected.

(Permanent) 3.5.185 TS-14, Monthly Fire Equipment Surveillance , Outside Aret s, Maintenance and Portable Welding Carts, Revision 6, 04-10-80 Technical Specification requirements were flagged. (Permanent)

. 3.5'.186 TS-14, Monthly Fire Equipment Surveillance, Outside Areas, Maintenance and Portable Welding Carts, Revision 7, 07-17-80 On page 8, Item 25, the- vehicle number for a new truck, 1003B, was added. (Permanent) 3.5.187 TS-14, Monthly Fire Equipment Surveillance, Outside Areas, Maintenance and Portable Welding Carts, Revision 8, 11-20-80

-The test was modified L to comply with 10 CFR 50 Appendix R for fire hydrant stations. (Permanent)

- - -, _ . - . - - . ,_ . . ,.s

3.5.188 TS-15, Monthly Fire Equipment Surveillance, Unit 1 Turbine Room and Service Building, Revision 6, 04-10-80 A new hose reel was added and several existing hose reel numbers were revised to incorporate completion of modification requests.

Technical Specification requirements were also flagged.

(Permanent) 3.5.189 TS-15, Monthly Fire Equipment Surveillance, Unit 1 Turbine Building, Service Building, Revision 7, 08-25-80 Page 11 was added to update the list of spare extinguishers to include newly installed units. (Perman.nt) .

3.5.190 TS-15, Monthly Fire Equipment Surveillance, Unit 1 Turbine Room, Service Building, Revision 8, 11-03-80 Page 11 was revised to include addition of six more spare pressurized water extinguishers; three of which were required for trailers being utilized by site contractor organizations.

(Permanent) 3.5.191 TS-18, Annual Pressure Test of Fire Hose, Revision 4, 01-28-80 Typographical errors were corrected. The inventory for FH-26 was i'

corrected to show one fire axe instead of two. Vehicle numbers were corrected as appropriate. (Permanent) 3.5.192 TS-18, Annual Pressure Testing of Fire Hose, Revision 4, 01-28-80 (performed 08-25-80)

A note was added following Step 3.5 to inform the operator that each of the six test header valves has a one quarter inch hole drilled in its disc to act as a thrust limiter should one of the hoses fai1~ during the test. Steps 5.1-5.4 were revised to utilize fire water supply from a hose reel versus rigging to the test connection and providing an additional hose section. On page 8, hose number 25-525 was added and 25-520 was deleted.

(Temporary) l 3.5.193

~~

TS-18, Annual Pressure Testing of Fire Hose, Revision 5, 08-29-80 -

A note was added following Step 3.5 to inform the operator that each of the six test header valves has a one quarter inch hole ,

drilled in its disc to act as a thrust limiter should one of the i

hoses fail during the test. Steps 5.1-5.4 were revised to utilize fire water supply from a hose reel versus rigging to the test connection and providing an additional hose section. On page ' 8, hose number 25-525 was added and 25-520 was deleted.

(Permanent) 3.5.194 TS-18, Annual Pressure Testing of Fire Hose, Revision 6, 11-03-80 Page 5 was added to include the new containment fire hoses in the hydrostatic test program. (Permanent)

?

3.5.195 TS-18, Annual Pressure Testing of Fire Hose, Revision 7, 12-02-80 The drawing of the fire hose hydro manifold was revised to reflect changes to the manifold. It was mounted on a cart so associated piping was altered te fit. (Permanent) 3.5.196 TS-20, Annual Fire System Automatic System and Valve Actuation, Revision 2, 08-25-80 Step 2.3 was revised for deluge valve tripping within 45 seconds; a more realistic period than the 15 seconds previously specified.

In Steps 8.3 and 8.4, fuel oil tank east DV-3727 and west DV-3728 were changed to west and east, respectively, to conform to as-built conditions. (Permanent) 3.5.197 TS-23, Monthly Valve Lineup Verification, Revision 3, 09 23-80 The procedure was changed for those sprinkler system valves not yet in service because downstream piping was not installed. Upon completion of piping installation, the procedure will be revised.

(Permanent) 3.5.198 TS-23, Monthly Valve Lineup Verification, Revision 2, 04-10-80 As a result of an insurance inspection, ten valves which are required to be verified open were added to the list. (Permanent) 3.3.199 TS-23, Monthly Valve Lineup Verification, Revision 2, 04-10-80 (performed 06-13-80)

In Step 2.1 valves FP-270, FP-269, FP-253, FP-267, FP-250, and FP-249 were in the shut rather than the open position. These are all sprinkler system valves which are in place; however, the associated piping was not installed. (Temporary)

~3.5.200 TS-23, Monthly Valve Lineup Verification, Revision 2, 04-10-80 (performed 07-16-80)

The procedure was changed noting six valves were in the shut position -since the modification to . the fire system requiring these valves to be shut was not completed. (Temporary)

~

3.5.201 TS-23, Monthly Valve Lineup Verification, Revision 2, 04-10-8,0,

. (peformed 08-16-80)

The procedure was changed ' to identify shut and flanged valves since new fire protection piping work was not completed.

(Temporary) 3.5.202 TS-23, Monthly Valve Lineup Verification, Revision 2, 04-10-80 (performed 09-18-80)

The. position -. for valves 249, 250, 253 269, and 270 was shut because the downstream piping . was not installed. (Temporary)

3.5.203 TS-23, Monthly Valve Lineup Verification, Revision 3, 09-23-80 The procedure was revised to denote valves in the closed position because downstream fire protection piping installation was iot completed. (Permanent) 3.5.204 TS-23, Monthly Valve Lineup Verification, Revision 3,09-23-8}

(performed 11-14-80)

FP-51 was removed per modification request M-550 and therefore was deleted from the test. (Temporary) 3.5.205 TS-23. Monthly Valve Lineup Verification, Revision 4, 11-20-80 FP-51. was removed per modification request M-550 and therefore was deleted from the test. (Permanent) 3.5.206 TS-24, Annual Cycling of Flow Path Valves, Revision 2, 11-20-80 FP-51 was deleted from the procedure because it was removed from service per modification request M-550. (Permanent) 3.5.207 TS-25, Alarm Valve Tests, Drain Tests and Miscellaneous, Revision 1, 11-20-80 NPFA Standard 24 for outside protection was referenced and provisions of that standard were incorporated into the test procedure. _( Permanent) 3.5.208 TS-27, Quarterly Sampling of Emergency Fuel Oil Tank, Revision 5, 07-17-80 The title was revised to denote the sampling frequency.

(Permanent) 3.5.209 TS-28, Monthly Auxiliary Building Crane Interlock Checks, Revision 0,-05-21-79 (performed 02-25-80)

The : test was revised to . prevent crane operation over the north

. spent fuel pool. (Temporary)

.3.5.210 TS-28, Monthly ~ Auxiliary Building Crane Interlock Checks, Revision 1, 02-26-80 The j test was rewritten to prevent crane operation over the north

-spent fuel' pool. (Permanent)'-

~3.5.211 .TS-29, Sodium Hydroxide Addition Valves, Revision 0, 09-26-80 (performed 09-26-80, Unit 1)

The - test was revised to add lock numbers for valves which are normally locked but are ' repositioned for the test. ~(Temporary)

.~ - .. ,. . , ., , , . ..

3.5.212 TS-29, Sodium Hydroxide Addition Valves, Revision 0, 09-26-80 (performed 09-26-80, Unit 2)

The test was revised to add lock numbers for valves which are normally locked but are repositioned for the test. (Temporary) 3.5.213 TS-29, Technical Specification Surveillance Testing, Sodium Hydroxide Addition Valves, .tevision 1, 10-06 80 The test was revised to add lock numbers for valves which are normally locked but are repositioned for the test. (Permanent) 3.5.214 HP 1.0, Radiation Protection Standards, Revision 1, 08-29-80 In Section 2.2 ALARA objectives covering supervisory

. responsibilities were added. In Section 2.3 the title of the Manager - Nuclear Operations Section was corrected to reflect organizational title changes. (Permanent) 3.5.215 HP 1.1, Maximum Permissible Exposure, Revision 1, 07-25-80 The revision clarified allowable exposure limits for 18-year old individuals; i.e., a person in his eighteenth year shall be limited to 1.25 Rem per calendar quarter whole body dose. An additional clarification was inserted relating to females of child-bearing capacity being limited to 300 mR per calendar quarter. (Permanent) 3.5.216 HP 1.5, Exposure Limits for Non-Plant Personnel, Revision 3, 07-25-80 The procedure was changed to provide 18-year old and female exposure limits as noted for Revision 1 of HP 1.1. (Permanent) 3.5.217 HP 1.5, Exposure Limits for Non-Plant Personnel, Revision 3, 07-25-80 (changed 12-17-80)

Sections 3.1.5 and 3.2 concerning medical reqd rements for extended exposure were deleted for Hyt o-Nuclear Services

- personnel only. These steps were waived under the authority of the WE Medical Director with the provision that followup lab work on blood analysis be completed. (Temporary) 3.5.218 HP 2.7, Radiation Work Permits, Revision 3, 11-21-80 The procedure was revised to provide accountability for entries into locked gate areas and to clarify an individual's responsi-bilities in utilizing radiation work permits. Several general items were further clarified to enable better understanding.

(Permanent)

_ _ _ _ . _ _ _ ~ - - __

i 3.5.219 HP 2.8, General Rules for Work in the controlled Zone, Revision 1, 12-26-80 Typographical corrections were made and Section 7.0 was revised to clarify monitoring requirements in areas where radiation level could suddenly increase. (Permanent) 3.5.220 HP 2.9, Personnel Decontamination, Revision 0, 08-11-75 The procedure was cancelled because its provisions are contained in HP 9.1. (Canceled) 3.5.221 HP 4.2, Licensed Radioactive Sources, Revision 1, 08-29-80 .

In Section 1.0 Chemistry & Health Physics supervision was ,

delineated for supervising the handling of sealed sources. In

Section 2.0 a clerical word omission was corrected. (Permanent) 3.5.222 HP 5.0, Radiological Surveys and Records, Revision 1, 09-26-80 Typographical errors were corrected and several word clarifications were made. (Permanent) 3.5.223 HP 6.1, Solid Radioactive Waste, Revision 1, 09-26-80 The procedure was revised and editorially upgraded to reflect present practices. (Permanent) 3.5.224 HP 6.2, Liquid Radioactive Waste, Revision 1, 09-26-80 A general editorial upgrade of the procedure was made including specific directions for notifying the Duty Shift Supervisor and Duty &. Call Superintendent if any uncontrolled or unplanned release occurs. (Permanent) 3.5.225 HP 6.3, Gaseous Radioactive Waste, Revision 1. 09-26-80 A general editorial upgrade of the procedure was made including

, specific directions for notifying the Duty Shift Supervisor and l Duty & Call Superintendent if any uncontrolled or unplanned ,

release occurs. (Permanent) 3.5.226 HP 7.2, State of Wisconsin, Revision 0, 08-11-75 The major procedure was canceled because' State of Wisconsin interfacing is contained in the Emergency Plan. (Canceled) 3.5.227 HP 8.4,- Health Physics Survey Schedule, Revision 3, 02-15-79 The minor procedure was canceled because the survey schedule was

- republished as Health Physics Informational Data Sheet HPID 10.

(Canceled) 3.5.228 HP 9.2, Decontamination of Reactor Cavity, Revision 0, 08-11-75 This minor procedure was canceled because guidelines for decon of the cavity are issued on a case-by-case basis as circumstances dictate. (Canceled) 3.5.229 HP 11.2 Appendix A, Packaging and Labeling Requirements for Radioactive Material Shipments, Revision 0, 09-10-79 This minor procedure was canceled and replaced by a new HP 11.2 series which provides detailed guidance for handling of radioactive waste. (Canceled) 3.5.230 HP 11.2 Appendix B, Radioactive Waste Processing and Shipment Procedure, Revision 0, 09-10-79

This minor procedure was canceled and replaced by a new HP 11.2 '

series which provides detailed guidance for handling of radioactive waste. (Canceled) 3.5.231 HP 11.2 Appendix C, Shipment of Non-Waste Radioactive Material, Revision 0,'09-10-79 This. minor procedure was canceled and replaced by a new HP 11.2 series which provides guidance for handling of radioactive waste.

(Canceled) 3.5.232 HP 13.1.1, Monthly operational Test of the Radiation Monitoring System (Area and Process Subsystems), Revision 5, 04-25-80 Step 5.10 was added to fulfill Technical Specification requirements for visual verification that monitors whose alarms

' initiate automatic responses perform satisfactorily. (Permanent) 3.5.233. HP 13.1.1, Monthly Operational Test of the Radiation Monitoring System (Area and Process Subsystems), Revision 6, 06-27-80

,The. changes-consisted of minor typographical errors. (Permanent)

HP 13.1.1, Monthly Operational Test of the Radiation.

~

3.5.234 Monitoring System (Area and Process Subsystems), Revision 7, 09-26-80

- The procedure was . revised in Sections 5.10 and 5.11 to add the provision of monthly indicating light observation for monitors whose alarms initiate. automatic responses. (Permanent) 3.5.235 - HP' 13.5.2, LHonthly Check of Emergency Monitoring Equipment Located at Site Boundary Control Center, Revision 3, 11-21-80 ALreference was - added to identify the. form utilized to check _ the equipment monthly and the semi-annual complete inventory form was

' listed.' ( A Esection 'was added to ' include the battery-powered air

sampler and its operational check. . (Permanent)

~49-t ,

3.5.236 HP 16.1, Radiation Protection Personnel Training, Revision 2,

12-26-80

, The procedure was rewritten +o include changes in the health physics orientation, advanced health physics training, retraining, and Auxiliary Operator Trainee health physics training. (Pe rmanent) 3.5.237 WMTP1 2.1 (Refueling 8), Core Refueling, Revision 0, 12-01-80

(performed 12-07-80)

-Steps 18A-F were added because assembly M08 was found in the manipulator instead of M07 and additional steps were necessary to ,

~ transfer the assembly back to the spent fuel pit and to properly load M07. (Temporary) 3.5.238 WMTP1 4.1 (Refueling 8), Cycle 9 Initial Criticality, All Rods

Out Flux Map, Endpoint and Temperature Coefficient, Revision 0, 11-05-80 (performed 12-28-80)

Step 5.6 was modified to lower the temperature range from 520*F to 540*F -to 515*F to 530'F to reflect Unit 1 operating temperatures. A temperature swing of 10*F was also specified to clarify the actual. intent of the original statement. (Temporary) 3.5.239 WMTP1 4.2 (Refueling 8), Control Bank "A" Worth and Endpoint Measurement and Temperature coefficient Measurements with Bank "A" Inserted, Revision 0, 11-05-80 (performed 12-29-80)

Step 5.2 was modified to lower the temperature range from 520*F to 540*F to 515*F_ to 530*F to reflect Unit 1 operating temperatures. A temperature swing of 10 F was also specified to clarify the actual intent of the original statement. A heatup and cooldown rate of 20 F/ hour was deleted because this would unduly prolong' testing time. (Temporary) 3.5.240 . WMTP1 6.1, Unit 1 End of Cycle 8 Physics Tests, Revision 0, 11-05-80 (performed 11-27-80)

Because of the ' unscheduled termination of Unit 1 Cycle 8, an end-of-life flux map was not taken, xenon follow measurements

.were not ' performed .and a power defect measurement could not be performed. (Temporary) 3.5.241 WMTP2 3.2 (Refueling 6), Primary System Tests - Hot, Revision 0,

' 04-08-80 (performed 05-12-80)

Step 5.8 requiring a flux map was deleted because NRC IE Bulletin Nos. 79-02 and 79-14 work was being - performed in containment.

Rods were not exercised ~per previous Manager's Supervisory Staff

-decisions not.to do'so. '(Temporary) 3.5.242 WMTP2 4.2 (Refueling 6, Control Bank "A" Worth and Endpoint Measurement and Temperature Coefficient Measurement with Bank "A" Inserted Revision 0, 04-08-80 (performed 05-12-80)

Step 5.2 regarding a temperature coefficient measurement utilizing MITF 9.6 was not done because of time considerations.

(Temporary) 3.5.243 WMTP2 4.4 (Refueling 6), Physics Testing During Boration to All Rods Out, Revision 0, 04-08 80 (performed 05-13-80)

Step 5.1 was omitted because operating personnel were controlling reactor coolant system temperature via the auxiliary feedwater pump and blowdown, and requested the reactor not be tripped unless absolutely necessary. Since there was no heat input from the reactor, it therefore did not make a difference whether the a reactor was critical. (Temporary) 3.5.244 WMTP2 5.3 (Refueling 6), Power Level Increase to Full Load, Revision 0, 04-08-80 (performed 05-23-80)

Step 5.3 calling for a calorimetric measurement to be performed at approximately 905 power level was deleted since calorimetric testing was performed along with the flux map taken prior to attaining 905 power. (Permanent) 3.5.245 WMTP2 5.3 (Refueling 6), Power Level Increase to Full Load, Revision 0, 04-08-80 (performed 05-23-80)

In Step 5.1 proper operation of the arming circuit for the crossover steam dump system was not verified at 755 power; it being noted an error in the procedure existed because the system does not arm until 82*s power. Operation of the system is an operations Division responsibility and therefore, can be deleted from Reactor Engineering test procedures. In Step 5.11 on 05-23-80, power level was not varied 12% prior to conducting the power coefficient measurements because of time constraints. In Step 5.9 power was not reduced to 90% prior to performing the power coefficient measurement because of time constraints and the fact that power would have had to be maintained at 90% for

- several hours to allow xenon to approach its equilibirum value.

The power coefficient was performed beginning at 97% power.

(Temporary) 3.5.246 WMTP 9.1, Rod Cortrol Mechanism Timing Rod Drop and Rod Position Calibration, Revision 7, 11-05-80 The procedure was changed to specify a time interval during and after reactor coolant system heatup in which the rods should not be moved. Oscillograph setup was changed tc, provide improved rod drop trace format. A method was specified to verify when a rod is fully withdrawn. Several minor typographical changes, rephrasing and other clarificatiot.s were made which did not change standing practice. (Permanent) 3.5.247 WMTP 9.2, Power Range Calibration, Quarterly Axial Offset Test, Revision 8, 08-31-78 (performed 11-05-80)

Since Unit 2 calorimetrics were unreliable, core AT's were used for power level determination in Step 5.4 in accordance with REI 1.0. In Step 5.5 it was not necessary to withdraw Bank D to the bite limit or above to obtain the desired positive flux difference. (Temporary) 3.5.248 WMTP 9.2, Power Range Calibration, Quarterly Axial Offset Test, Revision 9, 11-13-80 Step 5.4 was revised to determine reactor thermal output by either a calorimetric or in accordance with REI 1.0 by utilizing -

AT. Step 5.5 was revised to borate to obtain the positive flux difference instead of the bite limit or above since boration to that limit is not necessarily required. (Permanent) .

3.5.249 WMTP 9.4, Initial Criticality for a Cycle, Revision 4, 01-29-78 (performed 12-28-80)

For Unit 1 Cycle 9, the following changes were made: (1) In Step 3.2, the limit on boron concentration dilution was changed from 1100 ppm to 900 ppm because predicted all rods out critical boron concentration is 989 ppm. (2) Because Unit 1 is being operated at reduced temperature for steam generator considerations, the permissible temperature range for initial criticality was lowered from 525'F-545 F to 515'F-535*F. (3) Step 4.4 was changed to specify only. that condenser atmospheric stemn dtmp be available for reactor coolant system temperature control rather than state it must be used (to clarify the eriginal intent of the statement).

(Temporary) 3.5.250- WMTP 9.5A, Control Rod Worth, Boron Worth and Endpoint Measurement, Revision 4, 08-17-76 (performed 12-28-80, Unit 1)

For Unit 1 Cycle 9 startup tests the following changes were made:

(1) Because Unit 1 'is operating at reduced temperature for steam generator considerations, Step 4.1 was revised to lower the permissible testing temperature range to 515'F-535 F. (2) Step 4.2 was revised to specify only that condenser atmospheric steam .

dump be available for reactor coolant system temperature control rather than state it must be used (to clarify the original intent of the statement). (Temporary) ,

3.5.251 WMTP 9.6, Low Power Temperature Coefficient Measurement, Revision 3, 08-17-80 (performed 11-18-80, Unit 2)

In Steps 4.3 =and 5.5, a two pen recorder was used instead of an

X-Y recorder ' because an X-Y recorder was not readily available.

~

In -Step 4.6, pressurizer level was' kept constant between 30% and 35% instead of 20% and 25% - as ,specified because Operations -

preferred that- level' for- operational convenience. Their preference was' accommodated because it would have no effect upon the. conduct nor the results of the test. (Temporary) 3.5.252 WMTP 9.8, Xenon Follow Measurement, Revision 4, 04-08-80 The requirement to sample boron at one-hour intervals was deleted because it was deemed unnecessary to sample at that interval for a known 0 ppm boron concentration. (Permanent) 3.5.253 WMTP 9.8, Xenon Follow Measurement, Revision 5, 11-05-80 Steps were added to obtain reactor coolant system and pressurizer boron samples at the beginning and end of the measurement of the test. (Permanent) 3.5.254 WMTP 9.10, Reactor Coolant System Flow Tests, Revision 3,

- 02-06-80 A section was added to the Discussion clarifying the basis for the calculations which verifies sufficient primary coolant flow.

The method for data reduction was explained and review criteria were included. Procedural steps were reorganized so checkoffs were more clear and more logical. Several typographical errors and editorial changes were made. (Permanent) 3.5.255 WMTP 9.13, Pressurizer Tests, Revision 2, 01-04-80 Precaution 3.9 was added to exercise care during manipulation of the spray bypass valves. Various other steps were reworded to provide better clarification. (Permanent) 3.5.256 WMTP 11.19. Steam Generator Crevice Cleaning, Revision 1, 03-17-80 The procedure was revised to (1) reduce the number of samples to be taken during this evolution based upon past experience; (2) eliminate injection of water prior to depressurizing for subcooling of the top of the tubesheet; and (3) incorporate two additional depressurizations during the first cycle only with cooldown to identify chemicals readily removed from the top of the tubesheet versus chemicals resident within the deep crevice area

. 3.5.257 WM1F 11.19, Steau Generator Crevice Cleaning, Revision 1, 03-17-80 (performed 05-09-80 Unit 2)_

In Step 5.4 a sentence was added to notify Chemistry to collect sample "H" before stopping the reactor coolant pumps. A portion of Step 5.7.3 and all of Step 5.7.4 were deleted because in Cycle 1 only two depressurizations were performed instead of the three originally scheduled. (Temporary) 3.5.258 WMTP 11.19, Steam Generator Crevice Cleaning, Revision 1, 03-17-80 (performed 08-08-80, Unit 1)

The procedure was modified to delete all sampling points except the drain sample and delete the use of the special handhole sampling apparatus because multiple cycles were not possible within the limited time schedule. (Temporary)

3.:2.259 WMTP 11.19, Steam Generator Crevice Cleaning, Revision 2, 12-22-80 The procedure was revised to allow crevice flushing with less extensive sampling requirements because experience has denonstrated the final draindown sample to be most relevant.

(Permanent) 3.5.260 WMTP 11.19, Steam Generator Crevice Cleaning, Revision 2, 12-22-80 (performed 12-26-80, Unit 1)

Step 5.7 was modified because only one instead of both reactor coolant pumps was used for cooldown. (Temporary) .

3.5.261 WMTP 11.23 (Unit 2), Test for Evaluating High Pressure Glands, Revision 0, 03-18-80 (conducted 03-25-80)

Step 4.2 was changed to shut the manual dump valve bypass and Step 4.4 was changed to open the bypass prior to cutting in cylinder heating steam. The changes were required to return gland steam to normal operation for the test. (Temporary) 3.5.262 WMTP 11.24, Emergency Diesel Generator Room Ventilation Reversed Flow (Modification Request M-685), Revision 0, 09-16-80 (performed 10-22-80)

Section 5.1, Preliminary Testing, was not performed because the fan was tagged out for-the modification prior to the start of the normal work day when testing was to be performed. This section was prepared for information purposes only and its deletion was considered acceptable. The flow rate measurement prior to reversing the fan was to be taken for comparison to the design

' flow values. (Temporary) 3.5.263 WMTP 12.6, Piping Inspection Procedure for NRC IE Bulletin No. 79-14, Revision 1, 04-10-80 The procedure was revised to add the use of indirect measurement of piping when such ' piping is inaccessible, and provide

. qualification criteria for accomplishing the measurements. Table 1 was deleted becaur.e it was unnecessary. Appendix "A" was -

upgraded to reflect actual conditions. Appendix "C" was added to provide guidance for the processing of mechanical changes.

(Permanent) 3.5.264 TMI-02', High Pressure-Safety Injection System Leakage Test, Revision 1, 12-17-80 The procedure was rewritten to provide detailed instructions for observing, , measuring,- and calculating system _ leakage , including valve lineup ' lists. Specific acceptance criteria were included.

1(Permanent) 3.5.265 TMI-02, High Pressure Safety Injection System Leakage Test, Revision 1, 12-17-80 (performed 12-19-80, Unit 1)

Phase 3 was not performed in conjunction with Phases 1 and 2 because this phase could be done when the unit is at power. The-valve lineup sheets attached to the procedures were modified to assure proper residual heat removal lineup. (Temporary) 3.5.266 TMI-04, Containment Spray System Leakage Test, Revision 1, 12-17-80 The procedure was rewritten to provide detailed instructions for observing, measuring, and calculating system leakage, including valve lineup lists. Specific acceptance criteria were included.

(Permanent)

'

3.5.267 THI-04, Containment Spray System Leakage Test, Revision 1, 12-17-80 (performed 12-19-80, Unit 1)

A typographical error was corrected in Step 3.5.7. Steps were not performed because valve through-leakage 4.1.5-4.1.9 would not permit same; this situation also being true for Steps 4.2.9-4.2.20. A portion of Step 4.2.23 was omitted because containment spray pump flow and amps were not available for readout. (Temporary) 3.5.268 Setpoint change: Low Pressurizer Pressure Reactors Trip, 02-04-80, Unit 1 and 05-09-80, Unit 2

Present: -11865 psig New: 11790 psig

-(Bistable change from 1885 to 1800 psig).

Reason: Needed to improve margin to trip while operating at low pressure condition. -(Permanent) 3.5.269 Setpoint Changes: Stretch operation, 03-10-80, Unit 2 Temperature range resistors for temperature channels: T401A&B,

T402A&B, T403A&B, T404A&B.

Present: 540*F-615 F

-- -Null resistance for temperature 521.25 F New: 515 F-590*F Null resistance for temperature 496.25 F No-Load Tref: Preser_t: 547*F,_TM401P; no change required *

-New: 522 F-Tref Limit: Present: '570*F, HC401C; no change _ required *

' Pressurizer Level Program:

Present: 20% at 547 F Tavg 45.8% at_570 F Tavg; no change. required

New: 20% 'at 522 F Tavg

-45.8% at 545 F Tavg Steam Dump Controllers:

Turbine Trip Present: 547 F Tavg, TC40]G New: 522 F Tavg; no change required

Load Rejection Present based on Tref, TC4011 New _setpoint- see no-load Tref and Tref limit; no change required

Steam Dump Valve Actuation Bistables Present: 556 F Tavg; no change required *

(positioner arm) New: 531 F Tavg TC401E Present: 560 F; no change required

Open 4 valves New: 535*F TC401J Present: Tref +9 F; no changes required *

(positioner arm) New: See no-load Tref and Tref limit TC4010 Present: Tref +13 F: no change required

Open 4 valves New: See no-load Tref and Tref limit Feedwater Valve Interlocks TC401T Present: 5F4 F 4 Tavg New: $29 F 4 Tavg; no change required

TC401F Present: 554 F t Tavg New: 529 F t Tavg; no change required

ATspl: Bias shift 26.2 F TM401B TM402B Lowers ATspl to keep the set TM403B point on instrument scale TM404B Conservative action ATsp2: Present setpoint 60.98 F below 574.2 F Tavg TM401V decreasing to-58.17 F at 615 F Tavg TM402V TM403V New setpoint 60.98*F below 549.2*F Tavg TM404V .

decreasing to 58.17*F at 590 F Tavg No change reqd.*

' No change lof controller or bistable setpoint was recuired ,

because the range change ' of Tavg or- the master controller setpoint change causes the setpoint change.

Reason: Required to permit Unit 2 stretch operation to Refueling 6. Setpoints- were returned to normal values per 05-09-80 approval prior to Cycle 7 startup. (Temporary)

3.5.270 Setpoint Change: Stretch Operation, 03-19-80, Unit 2 Tref: . Adjust bias: of TM401P to run program from 532 F-555*F.

Turbine Trip: Adjust TC401G from 522 F-532 F.

Feedwater Valve Interlocks: Adjust TC401T from 529 F-539 F t and TC-401F from 529 F-539 F t.

Reason: Permitted unit the capability of achieving more core energy such that 95-97% power level could be realized. Setpoints were returned to normal values per 05-09-80 approval prior to Cycle 7 startup. (Temporary) 3.5.271 Setpoint Changes: Pressurizer Pressure Control, 05-09-80, Unit 2

. Pressure Controller PC431K:

Present: 223S; no change required

Few: 1985 PC431E Backup Heaters:

Present: 2210; no change required

New: 1960 PC431C&H Spray Valve Controls Present: 2260; no change required

New: 2010 PC430C, PC449D, PC429D Low Pressure Alarms Present: 2185 New: 1935 PC431E High Pressure Alarm Present: 2310;-no change required

New: 2060 PC431L Variable Heater Controller Present: 2220; no change required *

< New: 1970~

. PC431B PORV-431C Setpoint Presen- 2335; no change required

New: 2085

- Noichar.ge of. controller or. bistable setpoint was required because of the range change of Tavg or the master controller setpoint change.causes the_ listed setpoint to change.

s Reason: Required to operate Unit 2 at a reduced primary system pressure of 2000' psia. (Permanent)

~

\

3.5.272 Setpoint Change: Overpover Trip / Overpower Rod Stop 05-23-80, Unit 2 1

Present: 107/105 New: 104/102 Reason: Administrative conservatism to control F within Technical Specification' limit. (Temporary) 3.5.273 Setpoint change: Spray Line Temperature Low Alarm, 06-12-80, Unit 1 Present: 475*F New: 450 F ,

Reason: Reduced primary system temperature caused numerous alarms. .Because of minimal flow provided by bypass needle valves, water from cold leg cools off to 460*F-470 F.

(Permanent).

3.5.274 -Setpoint Change: PC-485A and PC-486A, First Stage Pressure, P7, Units 1 and 2 The previous setpoint ~was unblocked at 10%; the Technical

/ Specification requiring it to be unblocked at >10%. Any drift in the upward direction'of,this bistable would result in a Technical Specification violation. . Unblocking at 9.5% allows for bistable drift. (Permanent) 3.5.275 Setpoint Chance: Overpressure Mitigating Circuit-(PC493A and

.PC420B&C), 10-08-80, Units 1 and 2 F The -setpoint. for the subject ~c ircuits was lowered to 415 psig from 425 psig -(Technical 1 Specification limit) to allow for bistable drift. '(Permanent) 3.5.276 -STPT 3.0,-Reactor Trip Interlocks, Revision 1, 10-08-80 In Steps 3.2.1 and 3.2.2 rated power setpoints were clarified. A Ttypographical'. error was corrected in Step 3.5.1. In Step 3.2.2 first stage turbine prersure was' reduced to unblock at 9.5% to ~

allow for -upward: bistable ' drift. In Step 3.3.1 direction of bistable ' action was added.' In Step 3.4.2 bistable. direction was

. clarified as: was condenser vacuum measurements in inches of '-

x- mercury absolute. (Permanent)

^* o. ,

I' l

l l

l l-l

! 4.0 - NineEP. OF PERSONNEL AND MhN-REM BY WORK CIOUP AND JOB FINCTION

-4.1. 1980 JOB FUNCTION NUSER TOTAL REM REACTOR PERSONNEL PER WORK OPERATIONS & ROUTINE INSPECTION SPECIAL WASE SURVEILLANCE MAINENANCE ACTIVITIES MAINTENANCE PROCESSING REFUELING

>100 m9em GROUP I .-1. Company Encloyees 58 67.302 45.703 0 8.912' 5.9 34 5.045 1.700 Operations l

i f Peak Maintenance 25.295 and Maintenance 75 78.619 0 15.416 18.904 19.004 0 g

r . e I'- ' Chemistry & Health 17 18.317 11.621 0 0 0 4.127 0.569 i Physics I 0 2.250 0 0 0.250 Reactor Engineering 3 2.500 0 I

4.680 0 2.340 1.872 0 0 0.468 l

Instrument & Control 11 3.558 0 0 3.558 0 0 0

. Administration 5

- 2. Contract Workers and 0 Othe rs 307 412.975 0 0 298.746 114.229 0 476 587.951 59.324 17.756 334.242 139.167 9.172 28.290 1DTALS

(

l k.

I 1

9 5.0 STEAM GENERATOR TUBE INSERVICE INSPECTION i 5.1 Unit 1 03-06-80 Outage on_03-06-80, Unit 1 was placed in cold shutdown for the 60 effective full power day steam generator testing program required by the

, Confirmatory Order of 11-30-79. When taken off line, the unit had a

- primary-to-secondary leakage of approximately 30 gallons per day.

During the cooldown, a 2000 psi primary-to-secondary differential pressure condition was established.

An 800 psi secondary-to-primary leak check was performed prior to the .

eddy current inspection. No leaks were identified in the "A" steam generator; however, in the "B" steam generator one tube (R23C44) was observed to be leaking approximately three drops per minute. Another ,

tube . (R08C37) _ appeared to be wet, but no water was dripping from the tube. Also'in the "B" steam generator an existing explosive plug was identified as having a wet end, but no water was dripping from the

. plug.

.The , eddy current inspection program which was mutually agreed upon with. the Nuclear Regulatory Commission consisted of inspecting approximately 1,000 tubes in each steam - generator through the first tube support: and an additional three per cent of the total tubes for the full length. The 1,000 tubes were located in the region where

' deep crevice tube defects have been found in the past. The full length tube inspections . were randomly located throughout the steam generator including the wedge area.

Of the tubes' inspected in the "A" steam generator, 24 were identified E as having indications in the hot leg crevice region. Included in the 24 tubes - are six. tubes with undefinable indications which were plugged as -a conservative measure. No eddy current indications were found at or -above the . hot leg tubesheet and no degraded tubes were found on'the-cold leg side.

f Of the tubes inspected in' the "B" steam ' generator, 26 were identified

~

-as_having; indications in the hot leg crevice region, and one tube had

'a' defect one-half inch above the_tubesheet. Included in the 26 tubes ,

dre 'three tubes with undefinable indications which were plugged as a conservative measure. No degraded tube indications were found on the cold leg side. ,

Three tubes were pulled during'the' outage'for laboratory examin'ation.

The . three- tubes pulled were 'R19C37, .R30C41, and R26C53. After pulling the. tubes, the tube holes were. manually weld plugged.

Four-tubes located near~ tube' R30C41 were plugged a 's a precautionary-l measure because ~ R30C41 had.'not been completely cut prior to pulling it down about five inches. Plugging of these ft.,ur tubes' removed from

~

service all adjacent tubes which may have been damaged.

i During the outage and during sWasequent secondary-to-primary leak tests, four additional ' leaking tubes and three additional leaking plugs were identified besides the two tubes and one plug identified during the initial hydro. All the leaking tubes were plugged and the leaking plugs (excluding wet end plugs) were weld repaired.

The unit returned to line on 04-06-80, with a primary-to-secondary leakage rate of approximately ten gallons per day.

Extent of Eddy Current Inspection "A" SG Inlet 936 tubes inspected through first support; multifrequency 167 tubes inspected for full length; multifrequency

~'

"A" SG Outlet 167 tubes inspected from hot leg "B" SG Inlet 797 tubes inspected through first support; multifrequency "B" SG Outlet 141. tubes inspected for full length; multifrequency o 141 tubes inspected from hot leg Results of Eddy Current Inspection Indications Identified "A" SG "B" SG Undefinable 6 3 l' <20% (Cold Leg) 1 0 20-29% 1** 0 30-39% 0 0 40-49% 1 2 50-59% 0 2 60-69% 3 3 70-79% 2 7 80-89%- 7 7*

90-99% 5** 3 100% 0 1*

-One tube contained both a 89% and a 100% defect.

- One tube contained both a 29% and a 96% defect.

"A" Steam Generator Hot Leg Column Origin Location Plugged Row cti 12 19 0.D. 19-21" above tube end Yes 7 22 25 0.D. 12/17" above tube end Yes

- 18 22 2 6t . 0.D. 20" above tube end Yes 10 l 23_ - 41% 0.D. 20" above tube end Yes

. 7 '24_ 83% 0.D. 17-20" above tube end Yes

'8 24 79% 0.D. 17-21" above tube end Yes 25' 45 69% 'O.D. 12-20" above tube end Yes 20 48 85% 0.D. 21" above tube end Yes 9 49' 90%' O.D. 21" above tube end Yes-17- 50- 185%1 0.D. 19" abbve tube end Yes

.19 50 97% 0.D. 11" above tube end Yes

-50 97%- 0.D. 11" above tube end Yes 20 12- 59L 87% 0.D. 21" above tube end Yes i .

During the outage and during sWasequent secondary-to-primary leak tests, four additional leakir.g tubes and three additional leak plugs were identified besides the two tubes and one plug identified during the initial hydro. All the leaking tubes were plugged and the leaking plugs (excluding wet end plugs) were weld repaired.

The unit returned to line on April 6, 1980, with a primary-to-secondary leakage rate of approximately ten gallons per day.

'1 Extent of Eddy Current Inspection

'" A" SG Inlet 936 tubes inspected through first support; multifrequency 167 tubes inspected for full lenath; multifrequency "A"-SG Outlet 167 tubes inspected from hot leg-

"B" SG. Inlet 797 tubes inspected through first support; multifrequency r "B" SG Outlet 141 tubes inspected for full length; multifrequency 141 tubes inspected from hot leg -

Results of Eddy Current Inspection Indications' Identified "A" SG "B" SG Undefinable 6 3

<20% (Cold Leg) 1 0 20-29% 1** 0 j, 30-39% 0 0 40-49% 1 2 50-59% 0- 2 i 60-69% 3 3 70-79% .2 7 80-89% 7 7*

90-99% 5** 3 100% 0- 1*

No Defects Detected 4

One-tube contained both'a 89% and a 100% defect.

- One tube contained both a'29% and a 96% defect.

"A" STEAM GENERATOR FOT LEG Row; 'Cblumn' Defect Origin Location .Pluqqed -

L12 I19 80%- 0.D. 19-21" above tube end Yes 7 r22, 29/96% 0.D. 12/17" above tube end Yes .

- 181 22 -66%: -0.D. 20" above tube end Yes 20' 23 .41% 0.D. 20" above tube end Yes-i 7; s24- 83%. -0.D. 17-20",above tube end Yes

'8- 24 :79%- 0.D. 17-21" above tube end

~

Yes J25 =45' 1 69% 0.D. 12-20" above tube end Yes

'20

~

- 48 > -85% 0.D. 21" above tube end Yes

9 49 290% 0.D. 21" above' tube Jend Yes J17' '50c ' 85% LO.D. 19" above tube end Yes

19 ~50 '97% 0.D. 11" above tube end Yes

!20. 50: 97% 0.D. 11" above tube end Yes i . 12L.: ;59- 87% 0.D. ;21" above tube end 'Yes

' ~-

"A" Steam Generator Hot Leg, continued . . .

Row Column Defect Origin Location Flugged 12 61 83% 0.D. 17" above tube end Yes 14 63 83% 0.D. 19" above tube end Yes 15 66 60% 0.D. 18" above tube end Yes 20 41 91% 0.D. 19" above tube end Yes 25- 43 73% 0.D. 17" above tube end Yes 15 28 Undefinable Indication O.D. 21" above tube end Yes 28 34 Undefinable Indication O.D. 18-20" above tube end Yes 28- 35 Undefinable Indication O.D. 17" above tube end Yes

11. 46 Undefinable Indication- O.D. 12-21" above tube end Yes 29 52 Undefinable Indication O.D. 14" above tube end Yes 8 27 Undefinable Indication O.D. 15-20" above tube end Yes

"A" Steam Generator Cold Leg Ro,_w Column Defect Origin Location Plugged 19 :25 <

.20%- 0.D. 2" above tubesheet No "B" Steam Generator Hot Leg how - Column Defect Origin Location Plugged '

18 26 75% 0.D. 18" above tube end Yes 26 73% 0.D. 21" above tube end Yes

.13 33 71% 0.D. 20" above tube end Yes 6 34 91%- 0.D. 11" above tube end Yes 20 13 5 68% 0.D. 21" above-tube end Yes S 37_ 89/100% 0.D. _10-17"/3-6" above tube end Yes 0.D. Yes 19- 37 -58% 1/2" above tubesheet 10 41; 70%- 0.D. 21" above tube end Yes

30 141 '47% 0.D. 21" above tube end. Yes-30 42- 48% 0.D. 21" above' tube end Yes 22' 46 76% 0.D. 15" above tube end Yes

'22' -48 :84% 0.D. 12" above tube end Yes 30' 48 85% 0.D. 21" above-tube end Yes

' 2.5 49- 84% .O.D. 5" above tube end. Yes

' 20- 51 99% 0.D. 16" above. tube end Yes 23 54 86%- O.D. 4-21" above tube end Yes

-- ; 23 57. 56%- -O.D. 17" above tube end Yes 21 '58~ :83% 0 . D .~ 21" above tube end Yes L2- :72 92%. O.D. 3" above tube end- Yes-

-14 59 75% 0.D. 21" aboveLtube end- Yes-21' 63 62% 0.D. - 21" above tube end- Yes.

12 ' 67 ' 66%- -O.D. 121" above tube end

'Yes 55 74%- O.D. 15".above tube end- Yes 25:

26 ~53- '86% 0.D. 18" above tube end- Yes-Yes 30 . _43 - Undefinable Indication- 0 . D ~. 21" above_ tube end 22- 63 ' Undefinable Indication' 'O.D. 21" above tube end Yes 22% 64 Undefinable ' Indication O.D. 20" above' tube end u a___--_-_=_--.__:___- --,___:--

) -lB"

' Steam Generator Hot Leg, continued ...

Row Column Defect Origin Plugged 1

23 .44 Leaking tube; no defect identified O.D. Yes 25 48 . Leaking tube; no defect identified O.D. Yes 23 55 Leaking tube; no defect identified O.D. Yes 26 52 Leaking tube;'no. defect identified O.D. Yes 29 53 Leaking tube; not inspected- 0.D. Yes 1 29 42 Plugged as a precautionary measure; possibly damaged during tube pulling 0.D. Yes 31 42 . Plugged as a precautionary measure; .

-possibly damaged during tube pulling O.D. Yes 28 '40 Plugged as a precautionary measure; ,

possibly damaged during-tube pulling: 0.D. Yes Plugged as a piecautionary meast're; 4

. 30 40-3-

possibly damaged during tube pulling 0.D. Yes "B" Steam Generator Cold Leg

-No indications identified I- Explosive Plugs Repaired ,-

L R23C50 (Hot Leg) -R25C53 (Hot Leg)

R29C41 (Hot Leg)- R22C48 (Cold Leg)

.07-25-80 Outage-

. In accordance - with the' Nuclear Regulatory Commission's modification of the 11-30-79 Order. dated 04-04-80, Unit 1 was taken out-of-service on 07-25-80 for _ hydrostatic . tests and eddy - current . examinations ~ of the steam generator tubes.

~

A. 2000 . psi' primary-to-secondary . differential pressure condition war

' established during the cooldown and an 800 psi secondary-to-primar_ .

' leak. check was ~ conducted following ' draindown. In - the "A" s teu.

_~ generator, - two dripping explosive plugs (R31C44 and R29C54) and two

~

wet end plugs (R24C37Jand R21C49) were identified in the hot leg with '

rio leaks detected in the cold leg. ._In the "B'.' steam generator, _one

!. wet end explosive plug (R23C53) and one dripping' tube (R21C48) were

' identified < in - the c hot' leg with no leak f detected in the cold leg.

The eddy - currentL inspection program consisted of an examination of y

' 100% of the tubes - to. the' first support plate on the hot leg side and ~

-3% of the. tubes: inspected over their entire length. In.the "A" steam leg,. 30' - tubes were identified with eddy _ current generator-~ hot

indications. ~ Twenty _eight :(28) indications 1.were Lin: the tubesheet

- - crevice region and ;two.. tubes had indications _ at the ' top of the tubesheet L and one-half inch above. The' 28 = tubes-' with indications

,withinLthe tubesheet region were plugged along with three tubes.which -

>; s.

--S 4- -

were plugged inadvertently. The two leaking plugs were weld repaired. Only six indications, all below the plugging limit, were found in the cold leg during the full length inspection of over three per cent of the tubes.

In the "B" steam generator hot leg, 22 tubes were identified with tubesheet crevice indications. No indications were found in the cold leg during the full length inspection of over three per cent of the tubes. The 22 tubes with indications in the tubesheet crevice region, including the leaking tube, were plugged.

Following plugging and weld repair, an 800 psi secondary-to-primary hydrostatic leak check was performed.

O %~ ~

Extent of Eddy Current Inspection "A" SG Inlet 2,639 tubes inspected through first support; multifrequency 109 tubes inspected for full length; multifrequency "A" SG Outlet 109 tubes. inspected from hot leg "B" SG. Inlet 2,736 tubes inspected through first support; multifrequency 153 tubes inspected for full length; multifrequency "B" SG Outlet 153 tubes inspected from hot leg i Results of Eddy Current Inspection Indications Identified "A" SG "B" SG Undefinable 1 0

<20% 4/2* 0 20-29% 1/2* O 30-39% 4 0 40-49% 2 4 50-59% 5 4 60-69% 1 4 70-79% 4 5**

80-89% 8 5-90-99% 1 1 100% 0 0

Hot leg / cold leg

- One tube contained both a 70% and 76% indication.

>- "A" Steam Generator Hot Leg

-Row Column Defect. Origin Location Plugged 22: 18 -73%L O . D .~ ~6" above tube.end Yes' 28- 26 123/<20% -0.D. 5"/20".above tube.end Yes

7. 36: 53% 0.D. 3" above tube end' Yes 33 37- 82% 0.D. 8" above tube.end Yes 30 42 31% 0 '. D . 15-17" above tube end Yes 24 46 -79%. 0.D. 20"labove tube end Yes

'8 <20% -0.D. 8"'above tube end .Yes 9 z50 85%- 0.D. 20" above tube end Yes 12 :50 .<20% 0.D. 17".above tube end Yes

- - - - - - - - - ---a-- -----=_,,,_._,__,_,,__-_,,,,__,,,,_____,,___,,,_y

"A" Steam Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged

~ 26 53 83% 0.D. 21" above tube end Yes 33 54 '

34% 0.D. " above tubesheet No 10 54 34% 0.D. Top of tubesheet No 22 55 81% 0.D. 7-15" above tube end Yes 24 55 88% 0.D. 18-21" above tube end' Yes 12 56 <20% 0.D. 11" above tube end Yes 8 58 54% 0.D. 15" above tube end Yes 17 58 42% 0.D. 20" above tube end Yes

?.7 59 69% 0.D. 8" above tube end Yes 5 61' 92% 0.D. 10" above tube end Yes -

23 61 80% 0.D. 10" above tube end Yes

'18 62 .59% 0 D. 10-15" above tube end Yes 27 62 84% 0.D. 15-20" above tube end Yes .

-15 64 36% 0.D. 13" above tube end Yes

27. 64 '51% 0.D. 3" above tube end Yes 8 66 78% 0.D. 2%-6" above tube end Yes

'10 68 47% 0.D. 10-20" above tube end Yes 8 70 47% 0.D. 20" above tube end Yes 9 72 76% 0.D. 20" above tube end Yes 8' 75 89% 0.D. 20' above tube end Yes 8 76 Undefinable 0.D. 15-20" above tube end Yes Indication, "A" Steam Generator Cold Leg Row Column Defect Origin Location Plugged-28 ,4 8 . 29% 0.D. " above.tubesheet No 24 52 <20% 0.D. 1" above tubesheet No 20 56' <20% 0.D. 1" above tubesheet No-24 56 <20% 0.D. 2" above tubesheet' No

20 - 60. 21% 0.D. 2" above tubesheet No 20 24 <20% 0.D. -2" above.tubesheet No Inadvertently Plugged Tubes R07C58- .

R07C59 R07C51 (Hot. Leg Side Only)

Explosive Plugs Repaired

.R31C44 (Hot Leg)

R29C54 (Hot Leg)-

<6-

.-__.2.__-_______-_ . _ _ - _ . _ . . . = _ _ _ -

"B" Steam Generator Hot Leg i Row Column Defect Origin Location Plugged

.9 20 65% 0.D. 21" above tube end Yes 10 25 57% 0.D. 19" above tube er.d Yes 14 27 42% 0.D. 20" above tube end Yes 8 31 64% 0.D. 10" above tube end Yes 12 31 79% 0.D. 12-17" above tube end Yes 25 37 54% 0.D. 15-20" above tube end Yes 27 38 48% 0.D. 20" above tube end Yes 26 43 56% 0.D. 21" above tube end Yes

, 21 48 46% 0.D. 3" above tube end Yes 24 49 85% 0.D. 2 -5" above tube end Yes 20 50 67% 0.D. 17" above tube end Yes 28 51 82% 0.D. 2 -7" above tube end Yes 27 53 75% 0.D. 5" above tube end Yes 24 54 80% 0.D. 11" above tube end Yes 29 62 75% 0.D. 2%-11" above tube end Yes 13 69 49% 0.D. 21" above tube end Yes 13 71 83% 0.D. 20" above tube end Yes 2 74 90% 0.D. 2 -10" above tube end Yes 10 76 59% 0.D. 14-17" above tube end Yes 10 78 76/70% 0.D. 5"/8" above tube end Yes 2 80 82% 0.D. 5" above tube end Yes 4 46 61% 0.D. 10-17" above tube end Yes "B" Steam Generator Cold Leg No indications identified Unit 1 Refueling 8 Outage Inservice Inspection The . refueling outage steam generator inspection program was designed to meet the requirementt of the Confirmatory Order and to satisfy inservice inspection- requirements. The eddy current inspection program perfonned' consisted of examination of 100% of the tubes up to the first support plate on the hot leg side and greater than 3% of the tubes plus all previously degraded ' tubes in the cold leg were inspected over their. entire length.

Prior-to the eddy current inspection, a 2000 psi primary-to-secondary differential pressure condition was established during cooldown. An

'800- psi ' secondary-to-pr'imary hydrostatic leak check -was also

_ performed. A detailad inspection of the tubesheet during the secondary-to primary hydrostatic leak check showed no evidence of any leakage- from the steam generator tubes. Although, two previously plugged tubes in - the "A" steam generator 'and two previously plugged tubes in the~"B" steam generator hot legs were observed to have " wet" plug ends.

6 -

A . total of ten indications were found in the "A" steam generator hot leg. The ten indications consisted of eight indications within the tubesheet crevice region, including five undefinable indications, and two indications at or above the top of the tubesheet. In the "A" steam generator cold leg a total of 32 indications were detected; however, only. one of the indications was greater than 20S o (but still less than the plugging limit).

In the "B" steam generator, a total of eight indications were detected, all within the hot leg. The eight indications consisted of seven' indications within the tubesheet crevice region, including two undefinable indications, and one indication one-half inch above the tubesheet.

-A total of 11 tube ends and 55 first tube support restrictions were encountered with a 0.720" probe. All except one tube end and eight .

first support restrictions passed a 0.700" probe, however. Only ten restrictions at various cold leg supports were encountered while performing the full tube length tube inspection.

All of the tubes.with indications within the tubesheet crevice region except for the undefinable indications in the "A" steam generator were plugged. The tubes with undefinable indications in the "A" steam generator were left unplugged as potential sleeving candidates for a demonstration program planned for the spring of 1981. The unit returned to line ' December 31, 1980, with a primary-to-secondary leakage of'approximately five gallons per day.

Based on the results of the refueling outage inspection and the

' inspections conducted in 07-80 and 03-80, it appears that the rate of corrosion of the steam generator tubes in the tubesheet crevice region has been substantially reduced. A total of 58 tubes in the "A" steam generator and 65 tubes in the "B" steam generator were plugged -in 1980, raising ~ the f total of plugged tubes to 407 ~ (12.5S.)

and 399 . (12.2S.), respectively. In comparison, a total of 161 tubes in the "A" steam generator and 129 tubes in the "B" steam generator were plugged in 1979.

1 Extent of Eddy Current Inspection

' '. A" SG Inlet 2,690-tubes inspected through first support; multifrequency

'165 tubes inspected for full length; multifrequency "A" SG Outlet ~165 tubes: inspected from' hot leg' .

"B" SG Inlet ~2,7277 tubes inspected through first. support; multifrequency 126 tubes inspected for. full length;.multifrequency

'"B".SG Outlet: 126 tubes _ inspected from hot. leg

Results of Eddy Current Inspection Indications Identified "A" SG "B" SG Undefinable 5 2

<20% 1/31* O 20-29% 1/1* 1 30-39% 0 0 40-49% 0 0 50-59% 0 0 60-69% 2 1 70-79% 1 1 80-89% 0 3 90-99% 0 0 100% 0 0 e

Hot Leg / Cold Leg "A" Steam Generator Hot Leg Row- Column Defect Origin Location Pluqqed

~24 33 71% 0.D. 11" above tube end Yes 11 35 63% 0.D. 13" above tube end Yes 29 53 65% 0.D. 11-13" above tube end Yes cl1 ~43 Undefinable 0.0. 19-20" above tube end No R25 44 . Undefinable 0.D. 13-15" above tube end ' No

'25 47- Undefinable 0.D. 13-18" above tube end No 8- '55 Undefinable 0.D. 17" above tube end No

- 10 54- <20% 0.D. Top of tubesheet No E33- . 5<4 22% 0.D. .\" above tubesheet No 15- 60 Undefinable 0.D. 14-18" above tube end No

." A" Steam Generator Cold Leg Row Column Defect Origin' Location Plugged 13 24 < 20% 0.D 2" above tubesheet No

'19' E28 L<20% 0.D. 2" above tubesheeti No

'21- 30 . <20%1 0.D. 2" above tubesheet No 22: 33 <20% 0.D. 2" above tubesheet No 21 35: <20%- 0.D. .2'! above tubesheet No-

. 19 ~36 ~<20% 0.D. 2"Labove tubesheet No-

23 36 L<20%- 10. D .~ 2\" above tubesheet No

25 37 <20% 0.D. 2 " above:tubesheet No 19 -31 <20%- 0.D. 2\" above tubesheet No

'28 -38! '.<20% 0.D. 2" above tubesheet- No-27 ~38 . <20%- 0.D. 2"'above tubesheet- No-

23: 38 -<20%-

2 0.D. 2" above tubesheet No 26 42 <20%~ -0.D. 1\".above tubesheet No 2" above tubesheet

~

23 14 2 <20%- 0 . D .' .No-

'24 43 <20% 0.D. 2" above-tubesheet No' E25 '44 .<20% 0.D. -2" above tubesheet- No 2

.9 - . 44 ' . <20%f 0.D. 1" above tubesheet- No 2".above tubesheet -No

-19, 66L <20%' 'O.D.

"A" Steam Generator Cold Leg, continued . .

Row Column Defect Origin Location Plugged 21 66 <20% 0.D. 2" above tubesheet No 23 66 <20% 0.D. 2" above tubesheet No 19 64 <20% 0.D. 2" above tubesheet No 21 62 <20% 0.D. 2" above tubesheet No 20 60 <20% 0.D. 2" above tubesheet No 23 54 <20% 0.D. 2" above tubesheet No 25 54 <20% 0.D. 2" above tubesheet No 26 54 <20% 0.D. 2" above tubesheet No 27 52 <20% 0.D. 2" above tubesheet No 25 52 <20% 0.D. 2" above tubesheet No 23 48 (20% 0.D. 1" above tubesheet No 28 48 28% 0.D. 1" above tubesheet No

'll 48 <20% 0.D. 1" above tubesheet No .

24 53 <20% 0.D. 2" above tubesheet No "B" Steam Generator Hot Leg Row Column De fect Origin Location Plugged 14 28 62% 0.D. 21" above tube end Yes 19 30 Undefinable O.D. 20" above tube end Yes 26 37 Undefinable O.D. 12" above tube.end Yes 24 52 80% 0.D. 5" above tube end Yes 3 60 80% 0.D. 1" above tube end Yes 20 60 87% 0.D. 19" above tube end Yes 21 62 74% 0.D. 20-21 " above tube end Yes 27 30 29% 0.D. h" above tubesheet No "B" Steam Generator Cold Leg-1 No indications identified 5.2 Unit 2 02-28-80 Outage Inservice Inspection The unit was taken off line on 02-28-80 following confirmation of primary-to-secondary . leakage of 1,420 gallons per day in the "A" steam generator. The leak had begun as a slight indication about

' noon the previous day and increased slowly until just before the unit ,

was shutdown when a significant ' increase was noted. A static head leak check identified the leaking tube at position R18C37 and a subsequent eddy current inspection placed the defect at eight to ten inches above the tube end. The previously scheduled refueling outage i

steam generator eddy current inspection was performed during the outage. 'The inspection program was setup to satisfy the inservice

' inspection requirements. It included a random 3% inspection over the U-bend plus the inspection of all previously degraded tubes. The cold leg degraded tubes were inspected either by inspecting the full length of .the tube from the hot leg side or by going into the cold leg. It was discovered later that one cold leg degraded tube in the

"A" steam generator was missed, however. The program also included an inspection of both the hot and cold leg wedge areas. The extent of the inspection was expanded during the outage; however, as six tubes with greater than 50% through-wall indications, in addition to the leaking tube, were discovered in the "A" steam generator. Eighteen tubes with indications between 40% and 49% were also found. The "A" steam generator hot leg program was first expanded by a 25 sample, then to 100% as required by the Technical Specificat.on for inservice inspection.

The 25 defective or degraded tubes in the "A" steam generator were explosively plugged. The leaking tube was mechanically plugged on the hot leg side until the refueling outage in 04-80 when the tube was pulled for examination and the tube hole weld plugged. Eight tubes with 39% indications were also explosively plugged as a conservative measure. Two tubes, R22C62 and R09C54, also with 39%

-indications were plugged on the cold leg only. These two tubes were left unplugged on the hot leg as potential candidates for pulling during the refueling outage. However, they were not pulled and were mechanically plugged during the refueling outage.

An 800 psi secondary-to-primary hydrostatic leak check of the "B" steam generator revealed no leaking tubes or plugs. Approximately 700 tubes in each of the hot and cold legs of the "B" steam generator were examined and only one pluggable indication was found. This was a.41% indication located in the cold leg.

Following a- satisfactory hydrostatic leak check, the unit was returned to line on 03-13-80 with an undetectable primary-to-secondary leakage.

Extent of Eddy Current Inspection "A"-SG Inlet' 149 tubes inspected for full length; multifrequency 233 tubes inspected through sixth support; multifrequency 122 tubes inspected through U-bend; multifrequency 2,634 tubes inspected through first support; multifrequency.

"A" SG Outlet .149 tubes inspected from hot leg side "B" SG Inlet :331 tubes inspected through first support; multifrequency 209 tubes inspected through sixth support; multifrequency 177 tubes inspected through U-bend; multifrequency "B" SG Outlet 536' tubes inspected through first support; multifrequency 149 tubes inspected through sixth support; multifrequency o

Results of Eddy Current Inspection "A" SG "A" SG "B" SG "B" SG Indications Identified Hot Leg Cold Leg Hot Leg Cold Leg

<20% 253 S 48 406 20-29% 118 0 23 28 30-39% 80 0 8 4 40-49% 18 0 0 1 50-59%. 6 0 0 0 60-69% 1 0 0 0 70-79% 0 0 0 0 80-89% 0 0 0 0 t 90-99% 0 0 0 0 100% 1 0 0 0 "A" Steam Generator Hot Leg Row Column Defect' Origin Location Plugged

18. 37 100% (Leaker) 0.D. 8-10" above tube end Yes 14 34 57% 0.D. Top of tubesheet Yes 13 41. 56% 0.D. Top of tubesheet Yes 10 SEL 52% 0.D. Top of tubesheet Yes 20- 63- 51% 0.D. Top of tubesheet Yes 21 63- 56% 0.D. Top of tubesheet Yes 19 65 51% 0.D. Top of tubesheet Yes 13 19 40% 0.D. Top of tubesheet Yes 12 31 41% 0.D. Top of tubesheet Yes 13 34 43% 0.D. Top of tubesheet Yes 14- 35 42% 0.D. Top of tubesheet Yes 15 35 44% 0.D. Top of.tubesheet Yes 13 .36 42% 0 D. Top of tubesheet Yes 10- 39 45% 0 D. Top of tubesheet Yes 28- 42 45% 0.D. Top of tubesheet Yes 12 44. 41% 0.D. Top of tubesheet Yes 21 ~57 43% 0.D. Top of tubesheet Yes 22 157 42% iO.D. Top of.tubesheet Yes 21 58 42% 0.D. Top of tubesheet Yes 20 59 .41% 0.D. Top of~tubesheet Yes .

10 a61, 42% 0.D. Top of.tubesheet Yes 10- 64' 42%- 0.D. Top of tubesheet. Yes 21 64 46% 0.D. Top of tubesheet Yes ,.

12 73- -43% 0.D. Top of.tubesheet Yes 34 -73 .43% 0.D. First support Yes~

7 21' 39%. O.D. Top of tubesheet Yes 14- 36 39%. 0.D. -Top of tubesheet Yes 20 o43 39% 0.D. Top of tubesheet -Yes 120 .47 39% .O.D. Top of tubesheet Yes 9 54. 39% 0.D. Top of tubesheet Yes

- 10' 59' 39%. 0.D. Top'of tubesheet Yes 121: 59 39% 0.D. Top'of tubesheet. Yes 22 ~62 39%. 0.D. Top of'tubesheet Yes

.18 ' 68 39% 0 . D .' Top of tubesheet 'Yes J11' 74- 39% 0.D. Top of tubesheet Yes 120 6' 32 . O.D. Top of tubesheet _No

,11 ' 19: 33% 'O.D. Top of tubesheet No

"A" Steam Generator Hot Leg, continued ..

Row Column Defect Origin Location Plugged 5 20 30% 0.D. Top of tubesheet No 12 22 35% 0.D. Top of tubesheet No 20 23 35% 0.D. Top of tubesheet No 10 24 37% 0.D. Top of tubesheet No 13 24 30% 0.D. Top of tubesheet No 6' 25 33% 0.D. Top of tubesheet No 13 25 33% 0.D. Top of tubesheet No 18 ~25 33% 0.D. Top of tubesheet No 20' 25 -32% 0.D. Top of tubesheet No 17 26 34% 0.D. Top of tubesheet No 18 26 37% 0.D. Top of tubesheet No

19 26 30% 0.D. Top of tubesheet No 20 26 31% 0.D. Top of tubesheet No 16' 27 34% ,

O.D. Top of tubesheet No 17 27 37% 0.D. Top of tubesheet No 18 27 33% 0.D. Top of tubesheet No 19 27 32% 0.D. Top of tubesheet No 20 27 34% 0.D. Top of tubesheet No

'6 28 36% 0.D. Top of tubesheet No 20 28 33% 0.D. Top of tubesheet No 20 '29 37% 0.D. Top of-tubesheet No 19 30 36% 0.D. Top of tubesheet No 12 34 32%- 0.D. Top of-tubesheet No 12 35 36% 0.D. Top of tubesheet. No 13 35 35% 0.D. Top of tubesheet No 12- -38 35% 0.D. Top of tubesheet No 9 39- 34% -0.D. Top:of tubesheet No 17 39 36% 0.D. Top of tubesheet. No 12, -41 35% 0.D. Top of tubesheet No 19 41~ -30% 0.D. Top of tubesheet No

-41 Top of tubesheet 23 '31% 0.D. No 20 42. '34%'

O.D. Top of tubesheet No 12: 43' 35%. 0.D. Top of tubesheet No Top of tubesheet

~

~19 43 34% 0.D. No

-22 . 43 36%. 0.D. Top of-tubesheet No

~*

13' 44. 32% 0.D. Top of tubesheet No 19 44' ~ ~ 34% ' O.D. -Top of tubesheet .No 21 44- 33% 0.D. Top of tubesheet No

-- 31- 44 30% 0.D. Top of tubesheet No

~10 45^ i34% 0.D. Top.of:tubesheet- .No

' 12. 45 32%- 0.D. Top of tubesheet No

.10 .46 32% 0.D. . Top of tubesheet No

-21: 46L 37%' O.D. Top.of tubesheet -No 21 47 .37%: 0.D. Top of tubesheet No-

9 48. 34%. :0.D. : Top of tubesheet No 20' f48 -34% 0.D. Top of tubesheet. No-13: :49 32% -0.D. Top of tubesheet No

.33: 49. 36% 0.D. Top of tubesheet No

12 51' 32%. 0.D. Top of tubesheet. No 21 55: '36% 0.D. -Top of tubesheet No 24- 55; ;32%- 0.D. Top of tubesheet No 21 -56 30% 0.D. Top'of tubesheet. No

"A" Steam Generator' Hot Leg, continued . . .

-Row- Column Defect Origin Location Plugged 12 57 30% 0.D. Top of tubesheet No 23 57 - 31% 0.D. Top of tubesheet No 20 58 36% 0.D. Top of tubesheet No 22 58 32% 0 D. Top of tubesheet No 20 60 32% 0.D. Top of tubesheet No 21- 60 30% 0.D. Top of tubesheet No 10 62 35% 0.D. Top of tubesheet No 20 62 35% 0.D. Top of tubesheet No 21 62 35% 0.D. Top of tubesheet No 9 64 36% 0.D. -Top of tubesheet No 20 65. 31% 0.D. Top of tubesheet No 21 65 36% 0.D. Top of tubesheet No 12 71 31% 0.D. Top of tubesheet No 17 71 32% 0.D. Top of tubesheet No 15 73 36% 0.D. Top of tubesheet No 12 74 36% 0.D. Top of tubesheet No 11 18 22% 0.D. Top of tubesheet No 13 20 25% 0.D. Top of tubesheet No 18 21 25% 0.D. Top of tubesheet No 18 22 21% 0.D. Top of tubesheet No 11 23 22% 0.D. Top of tubesheet No 12 23 21% 0.D. Top of tubesheet No 19 '23 21% 0.D. Top of tubesheet No 21 23 22% 0.D. Top of tubesheet No 11 24 25% 0.D. Top of tubesheet No 18 24' 22%- 0.D. Top of tubesheet No

'19 24 22% 0.D. Top of tubesheet No 21 24. 22% 0.D. Top of tubesheet No 9 25 27% 0.D. Top'of tubesheet No 11 25 21% 0.D. Top of tubesheet No 12 25 22% 0.D. Top of tubesheet No

~17 25 25% 0.D. Top.of tubesheet No 19 25 ~25% 0.D. Top of tubesheet No 6 26 22% 0.D. Top of tubesheet No

-9 26 25% -- 0.D. Top of tubesheet No

11. .26 25%. O.D. Top of tubesheet No

~

13 26- .29%. O . D .- Top of tubesheet No 16- 26 22% 0.D. Top of tubesheet No 21 :26 21% 0.D. Top of tubesheet No 4 27. 22% 0.D. Top of tubesheet No -

-12~ 27 27% 0.D. Top of tubesheet No 13~ -27 24% 0.D. . Top of tubesheet. No 14 27 22% 0.D. Top of tubesheet_ No~

0.D. Top of tubesheet No

'15 27 -21%

- 21 27 -27% 0.D. Top of tubesheet. No 26 27 ' 24% 'O.D. . Top of tubesheet No 17' 28 '. 21% 0.D. Top of tubesheet No 0.D. Top of tubesheet .No

-8' l28- 27%

0.D. -~ Top'of tubesheet -No

16' . 28 25%

_O.D. Top of tubesheet 'No 17' 28 26%

O . D .' Top of tubesheet No.

~19 28 =21%'

"A" Steam Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged 21 28 21% 0.D. Top of tubesheet No 10 29 25% 0.D. Top of tubesheet No 18 29 21% 0.D. Top of tubesheet Fa 19 29 25% 0.D. Top of tubesheet No 22 29 21% 0.D. Top of tubesheet No 12 30 28% 0.D. Top of tubesherit No 15 30 27% 0.D. Top of tubesheet No 18 31 29% 0.D. Top of tubesheet No 12 32 22% 0.D. Top of tubesheet No 27 34 27% 0.D. Top of tubesheet No 9 36 21% 0.D. Top of tubesheet No 10 36 21% 0.D. Top of tubesheet No

- 16 38 26% 0.D. Top of tubesheet No 20 41 25% 0.D. Top of tubesheet No 24 41 27% 0.D. Top of tubesheet No 25 41 27% 0.D. Top of tubesheet No 12 42 27% 0.D. Top of tubesheet No 13 42 27% 0.D. Top of tubesheet No 24 42 26% 0.D. Top of tubesheet No 10 44 25% 0.D. Top of tubesheet No 20 44 21% 0.D. Top of tubesheet No 28 44 21% 0.D. Top of tubesheet No 29 44 23% 0.D. Top of tubesheet No 23 45 26% 0.D. Top of tubesheet No 26 45 21% 0.D. Top of tubesheet No 20 46 29% 0.D. Top of tubesheet No 7 48 23% 0.D. Top of tubesheet No 32 48 27% 0.D. Top of tubesheet No 12 49 25% 0.D. Top of tubesheet No 11 50 26% 0.D. Top of tubesheet No 12 -52 26% 0.D. Top of tubesheet No 13 52 22% 0.D. Top of tubesheet No 21 52 22% 0.D. Top of tubesheet No 22 52 22% 0.D. Top of tubesheet No 23 52 22% 0.D. Top of tubesheet No 19 53 21% 0.D. Top of tubesheet No 22 53 22% 0.D. Top of tubesheet No 24 53 25% 0.D. Top of tubesheet No 12 54 26% 0.D. Top of tubesheet No

. 19 54 23% 0.D. Top of tubesheet No R20 54 27% 0.D. Top of tubesheet No 21 54 26% 0.D. Top of tubesheet No 22 54 26% 0.D. Top of tubesheet No 24 54 24% 0.D. Top of tubesheet No 30 54 23% 0.D. Top of tubesheet Ne 19 55 26% 0.D. Top of tubesheet No 20 55 22% 0.D. Top of tubesheet No 22 55 26% 0.D. Top of tubesheet No 23 55 24% 0.D. Top of tubesheet No 25 55 26% 0.D. Top of tubesheet No 19 56 21% 0.D. Top of tubesheet No "A" Steam Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged 22 56 26% 0.D. Top of tubesheet No 9 57 25% 0.D. Top of tubesheet No 20 57 26% 0.D. Top of tubesheet No 24 57 22%- 0.D. Top of tubesheet No 19 58 27% 0.D. Top of tubesheet No 23 58 25% 0.D. Top of tubesheet No 13 59 22% 0.D. Top of tubesheet No 22 59 25% 0.D. Top of tubesheet No 19 60 28% 0.D. Top of tubesheet No 22 60 21% 0.D. Top of tubesheet No 10 61 28% 0.D. Top of tubesheet No 21 61 29% 0.D. Top of tubesheet No 17 62 22% 0.D. Top of tubesheet No -

18 62 27% 0.D. Top of tubesheet No

-19 62 22% 0.D. Top of tubesheet No 20 64 25% 0.D. Top of tube' sheet No 12 66 22% 0.D. Top of tubesheet No 19- 66 21% 0.D. Top of tubesheet No 20 66 25% 0.D. Top of tubesheet No 17 69 ~22% 0.D. Top of tubesheet No 12 70 21% 0.D. Top of tubesheet No

17. 70' 21% 0.D. Top of tubesheet No 18 70 21% 0.D. Top of tubesheet No 13 73 26% 0.D. Top of tubesheet No 14 73 23% 0 . D .- Top of tubesheet No 5 75 22% 0.D. Top of tubesheet- No 10 75 28% 0.D. Top of tubesheet No

- 1.2- 75 21% 0.3. Top of tubesheet No 7 76 22% 0.D. Top of tubesheet No 13 76 21% 0.D. Top of tubesheet No 5 L77 27%- 0.D. Top of tubesheet No 9 77 :27% 0.D. Top of tubesheet' No 8 ~16 <20% HO.D. Top of tubesheet No 4 17 <20% 0.D. Top of tubesheet. No 8 17 -<20% 0.D. Top of tubesheet No 9 17- <20% 0.D. Top-of tubesheet No 8 18 <20% 0.D. Top of tubesheet No -

9 19 <20% 0.D. Top of tubesheet No

'10. 19 <20%- 0.D. Top of.tubesheet No 12- 19 <20% 0.D. Top of tubesheet No .

4 20 <20% 0.D. Top of tubesheet- No 6 20 <20% 0.D. Top of tubesheet No 9 20 .<20% 0.D. . Top of tubesheet No 10 .20 <20%. 0.D. Top of tubesheet No 11: 20 <20% 0.D. Top of tubesheet. No 6 21 <20% 0.D. ' Top of tubesheet No

'8 21 . <20% 0.D. Top of tubesheet. No.

12- <20%. 0.D. Top of tubesheet No

-16 211 <20% 0.D. Top of tubesheet No 17 21 < 20%. 0.D. Top of tubesheet RNo 3 22 <20% 0.D. Top of tubesheet .No "A" Steam Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged 8 22 <20% 0.D. Top of tubesheet No 9 22 <20% 0.D. Top of tubesheet No 17 22 <20% 0.D. Top of tubesheet No 20 22 <20% 0.D. Top of tubesheet No 26 22 <20%. O.D. Top of tubesheet No 5 23 <20% 0.D. Top of tubesheet No 10 23 <20% 0.D. Top of tubesheet No 13 23 <20% 0.D. Top of tubesheet No 16 23 <20% 0.D. Top of tubesheet No

.y 18 23 <20% 9.D. Top of tubesheet No 23 23 <20% 0.D. Top of tubesheet No 9 24 <20% 0.D. Top of tubesheet No 12 24 <20% 0.D. Top of tubesheet No 16 24 <20% 0.D. Top of tubesheet No 17 24 <20% 0.D. Top of tubesheet No 20 24 <20% 0.D. Top of tubesheet No 7 25 <20% 0.D. Top of tubesheet No 8 25 <20% 0.D. Top of tubesheet No 10- 25 <20% 0.D. Top of tubesheet No 14 25 <20% 0.D. Top of tubesheet No 15 25 <20% 0.D. Top of tubesheet No 21 25 <20% 0.D. Top of tubesheet No 10- 26. <20% 0.D. Top of tubesheet No li 26 <20% 0.D. Top of tubesheet No E14 .26 <20% 0.D. Top of tubesheet No 15 26 <20% 0.D. Top of tubesheet No 22 26 <20% 0.D. Top of tubesheet No 5 27 <20% 0.D. Top of tubesheet No 7 27 <20% 0.D. Top of tubesheet No 9 27 <20% 0.D. Top of tubesheet No 10- 27- <20% 0.D. Top of tubesheet No 11 27 <20% 0.D. Top of'tubesheet No 22 27 '<20% 0.D. Top of tubesheet No 5 28 <20% 0.D. Top of tubesheet No 10 28 <20% 0.D. ' Top of tubesheet No 14 28 <20% 0.D. Top of tubesheet No 15 28 <20% 0.D. Top of tubesheet No 18 28 <20% 0.D. Top of tubesheet No 23 '28 <20% 0.D. Top of tubesheet No 21- _29 <20% 0.D. Top of tubesheet No 23 129 <20% ' O.D. Top of tubesheet No 6 -30 <20%' O.D. Top of tubesheet No 8' 30 <20%~ 0.D. Top of tubesheet- No

'16 - 30 <20% 0.D. Top of tubesheet No

8. 31 <20% 0.D. Top of tubesheet: No 17 31 - <20% - 0.D. . Top of tubesheet No 8 32 -(20% 0.D. . Top of tubesheet No 13, 13 2 < 20%. 0.D. . Top of tubesheet No-

14. 32 -<20% 0.D. Top of tubesheet No 6- -33 .<20% 0.D. -Top of tubesheet No 11: 33 <20%

4 0.D. Top of tubesheet No 1

u-

"A" Steam. Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged 13 33 <20% 0.D. Top of tubesheet No 17 33 <20% 0.D. %" above tubesheet No 19 33 <20% 0.D. %" above tubesheet No 18 34 <20% 0.D. %" above tubesheet No 20 34 <20% 0.D. 1" above tubesheet No 21 34 <20% 0.D. %" above tubesheet No 17 35 <20% 0.D. Top of tubesheet No 22- 35 <20%. 0.D. " above tubesheet No 26 35 <20% 0.D. Top of tubesheet No 12 36 <20% 0.D. Top of tubesheet No 110 37 <20% 0.D. Top of tubesheet No 11 37 <20% 0.D. Top of tubesheet No

.12 37 <20% 0.D. Top of tubesheet No -

13 37 <20% 0.D. Top of tubesheet No 14 37 <20% 0.D. Top of tubesheet No 9 38 <20% 0.D. Top of tubesheet No 18 38 <20% 0.D. 1" above tubesheet No 19 38- <20% 0.D. 2" above tubesheet No 20 38 <20% 0.D. 1" above tubesheet No 11 39 <20% 0.D. Top of tubesheet No 16- . 39 <20% 0.D. Top of tubesheet No 11 .40 <20% 'O.D. Top of tubesheet No 18' 40 <20% 0.D. 1" above tubesheet No 25 40 <20%. 0.D. Top of tubesheet No 16 41 . <20% 0.D. Top of tubesheet No 6- 42- <20% 0.D. Top of tubesheet No 17 42 <20% 0.D. " above'tubesheet No

.18. 42 <20%' O.D. It' above tubesheet No 26 42 <20% 0.D. Top of tubesheet No

-18 43 <20% 0.D. 1" above tubesheet No

.25 '43 . <20% 0.D. Top of tubesheet No 26 43~ <20% 0.D. Top of tubesheet No

' 27 43 <20% 0.D. . Top of tubesheet No 28 43 _< 20% .0.D. Top of tubesheet No i~ ,29 - 43 <20% 0.D. Top of tubesheet No

.8 44 <20% 0.D. Top of tubesheet No

.9 44 <20%- 0.D. Top of tubesheet No -

, '22 44 <20% 0.D. Top of tubesheet No i

27- 44 <20%. 0.D. Top of tubesheet No 7~ 45 <20%; 'O.D. Top of tubesheet No .

9 45 <20%. O.D. Top of tubesheet- No 5: 46~ <20% 0.D. Tcp of tubesheet- No 6 46 <20%. O.D. ' Top of tubesheet No 9 46 <20% .0.D. Top of tubesheet No 11- .46 :<20% 0.D. Top of tubesheet No

'20 46. <20% J0.D. %"Labove tubesheeti No

'8- .47 <20%' . 0 . D .' .1op of tubesheet No.

14 47. <20% 0.D. Top of tubesheet No 15 47 <20%- 0.D. It' above tubesheet No-17 47 <20% -0.D. 1"labove tubesheet- No 47 .<20%. ,0.D. 1" above tubesheet No

.78-

{

"A" Steam Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged 19 47 <20% 0.D. 5" above tubesheet No 32 47 <20% 0.D. Top of tubesheet No 2 48 <20% 0.D. Top of tubesheet No 15 48 <20% 0.D. %" above tubesheet No 6 49 <20% 0.D. Top of tubesheet No 14 49 <20% 0.D. Top of tubesheet No 5 50 <20% 0.D. Top of tubesheet No 6 50 .<20% 0.D. Top of tubesheet No

o. - 9 50 <20% 0.D. Top of tubesheet No 10 50 <20% 0.D. Top of tubesheet No 12 50 <20% 0.D. Top of tubesheet No 13 50 <20% 0.D. h" above tubesheet No 14 50 <20% 0.D. h" above tubesheet No 18 50 <20% 0.D. " above tubesheet No

.10 51 <20% 0.D. Top of tubesheet No 13 51 <20%~ 0.D. Top of tubesheet No 20 51 <20% 0.D. Top of tubesheet No 22 - 51 <20% 0.D. Top of tubesheet No 23 51 <20% 0.D. Top of tubesheet No 24 51 .<20% 0.D. Top of tubesheet No 11 52 <20% 0.D. Top of tubesheet No 20 52 <20% 0.D. Top of tubesheet No 6~ 53 <20% 0.D. Top of tubesheet No 10 53 <20% 0.D. Top of tubesheet No 11' 53 <20% 0.D. Top of tubesheet No 12 53- <20% 0.D. Top of tubesheet No 13- 53 <20% 0.D. %" above tubesheet No 23 -. 53. <20% 0.D. Top of tubesheet No 30' 53 <20% 0 D. Top of tubesheet No 31' 53 <20% 0.D. Top of tubesheet No 32 53 <20% 0.D. Top of tubesheet No 6 54 .<20% 0.D. Top of tubesheet No 10 54 <20% 0.D. Top of tubesheet .No 17 54 ~ <20% 0.D. Top of tubesheet .No 12 55 <20% 0.D. Top of tubesheet No 26 ~55 . <20% 0.D. Top of tubesheet- No 9 56 .<20% 0.D. Top _of tubesheet No 10 56 <20% 0.D. Top of tubesheet No 12 56 <20% 0.D. Top of-tubesheet No 18 .56 <20% 0.D. Top of tubesheet No 20 56 <20% 0.D. Top of tubesheet -No 23 56 <20% 0.D. Top of tubesheet No 24 56 <20% 0.D. -Top of tubesheet No 25 56 -' <20%. 0.D. Top of tubesheet No 11' 57 <20% 0.D. " above tubesheet No 19 57 -- <20%- 0.D. Top of tubesheet No

'9

- 58 <20% 0.D. Top.of tubesheet

~

No 12_ 58 ' <20% 0.D. Top of.tubesheet No 26 58~ <20% 0.D. Top of tubesheet_ No

9. 59- <20% 'O.D. Top'of tubesheet No 12~ 59 < 20%; .0.D. Top of tubesheet No "A" Steam Generator Hot Leg, continued ...

' Row Column Defect Origin Location Plugged 17 ~59 <20% 0.D. Top of tubesheet No 18 59 <20% 0.D. Top of tubesheet No

'19 59 <20% 0.D. Top of tubesheet No

23 59 <20% 0.D. Top of tubesheet No i 16 60 <20% 0.D. Top of tubesheet No 17 60 <20% 0.D. Top of tubesheet No c 23 60 <20% 0.D. Top of tubesheet No 26 60 <20% 0.D. Top of tubesheet No 11 61 <20% 0.D. %" above tubesheet No 12 61 <20% 0.D. Top of tubesheet No -

17 61 <20% 0.D. Top of tubesheet No

. 22' 61 <20% 0.D. Top of tubesheet No Top of tubesheet

~

23 61 <20% 0.D. No -

25 61 <20% 0.D. Top of tubesheet No 26 61 < 20% 0.D. Top of tubesheet No 11 62 <20% 0.D. Top of '6ubesheet No 12 62' <20% 0.D. Top of tubesheet No 15 '62 <20%. O.D. Top of tubesheet No 16 .62 <20% 0.D. Top of tubesheet No 9 63 <20% 0.D. Top of tubesheet No 10 63- <20% 0.D. Top of tubesheet No 12 63 <20% 0.D. Top of-tubesheet No 16 16 3 <20% 0.D. Top of tubesheet No 17 63 <20% 0.D. Top of tubesheet No

, 18 63 <20%' O.D. Top of tubesheet No 22: 63 <20%- O.D. Top of tubesheet No 23 63 '<20% 0.D. Top of tubesheet No 12 :64 <20% 0.D. Top of tubesheet No 13 64 <20% 0.D. Top of tubesheet No 22 64 <20%_ O.D. Top of tubesheet No 10 65- <20%- O.D. Top of tubesheet No 11 65 <20% 0.D. . Top of tubesheet No 12 '65 .<20% 0.D. Top of tubesheet No 13 65 <20% 0.D. . Top of tubesheet No

15. 65 <20%- O.D. . Top of tubesheet No 16- 65- 1<20%' O.D. Top of tubesheet No

22 65 <20% _O.D. Top of tubesheet No -

'll 66 <20% 0.D. Top of tubesheet No

'13 66' ' < 2 0"5 - 0.D. Top of tubesheet No-

14- 66 <20%- 0.D. Top of tubesheet No .

16 66 <20% 0.E. -Top.of tubesheet No 17- -66 .20%

< J0.D. Top of tubesheet .No

-21 .66 <20% -OiD. Top of tubesheet No Top of tubesheet

12 ~67 <20% 0.D. No 13 67. <20% .O.D. Top of tubesheet No Top of tubesheet

~

.14 67 <20% 10.D. .No 15 67 <20%. .O.D. Top.of tubesheet No 20 16 7 - :<20%- oO.D. Top'of tubesheet No

6. 68 . <20% 0.D. Top of-tubesheet. No

_12 l 68 -<20%~ .O.D. . Top of tubesheet. No 13 .68 <20%- O.D. Top _of tubesheet No

_ ~

I "A" Steam Generator Hot Leg, continued ...

Row Column Defect Origin Location Plugged 14 68 <20% 0.D. Top of tubesheet No 16 68 <20% 0.D. Top of tubesheet No 19 68 <20% 0.D. Top of tubesheet No 20

68 <20% 0.D. Top of tubesheet No 7 69 <20% 0.D. Top of tubesheet No 12 69 <20% 0.D. Top of tubesheet No 18 69 (20% 0.D. Top of tubesheet No 19 69 <20% 0.D. Top of tubesheet No 11 70 <20% 0.D. Top of tubesheet No 13 70 <20% 0.D. Top of tubesheet No 12 .72 <20% 0.D. Top of tubesheet No

- 13 72 <20% 0.D. Top of tubesheet No 14 72 <20% 0.D. Top of tubesheet No 16 72 .<20% 0.D. Top of tubesheet No 17 72 <20% 0.D. Top of tubesheet No 9 73 <20% 0.D. Top of tubesheet No 9 74 <20% 0.D. Top of tubesheet No 10 74 <20% 0.D. Top of tubesheet No 13 74 <20% 0.D. Top of tubesheet No 9' 75 <20% -O.D. Top of tubesheet No 4- 76 <20% 0.D. Top of tubesheet No 5- 76 <20% 0.D. Top of tubesheet No 61 -76~ <20% 0.D. Top of tubesheet No 8- 76 <20% 0.D. Top of tubesheet No 10 76 <20% 0.D. -Top of tubesheet No

.11 76 <20%- O.D. Top of tubesheet No 10 77- <20% 0.D. Top of tubesheet No 4: '

-<20%. 0.D. Top of tubesheet- No

-10 - <20% 0.P. . Top of tubesheet No 9 <20%- O.D. Top of tubesheet No "B" Steam Generator Cold Leg Row Column' - Defect Origin. ' Location Plugged 19 33- <20% - 0.D. " above tubesheet No

~20 34- ~ <20% -0.D. 1" above tubesheet No 18 .- 35' ~<20% 0.D. -%" above tubesheet- No

, 21; 35- <20%1 0 . D .~ %"~above tubesheet. No 10 .40- <20% 0.D. 1" above tubesheet No 40 , .<20% 0.D. ~ " above tubesheet No 12 l42. - <20%. .O.D. -Top of tubesheet No 9 '4 . <20% .

0.D. - " above tubesheet No-21 -46 <20% 0.D. 1" above tubesheet No.

+

a

, ._u_

"B" Steam Generator Hot Leg Row Column Defect Origin Location Plugged 22 25 36% 0.D. Top of tubesheet No 22 30 , 30/26% 0.D. 1" above tubesheet/ No Top of tubesheet 21 34 30% 0.D. Top of tubesheet No 32 40 36% 0.D. 1" above tubesheet No 32 42 30% 0.D. Top of tubesheet No 21 43 37% 0.D. Tcp of tubesheet No 22 45 30% 0.D. Top of tubesheet No 22 50 32% 0.D. Top of tubesheet No Top of tubesheet 21 31 26% 0.D. No 15 32 22% 0.D. Top of tubesheet No 21 32 22% 0.D. Top of tubesheet No 18 33 22% 0.D. Top of tubesheet No -

14 38 29% 0.D. Top of tubesheet No 13 40 23% 0.D. Top of tubesheet No 26 41 24% 0.D. Top of tubesheet No 33 41 27% 0.D. \" above tubesheet No 19 42 29% 0.D. h" above tubesheet No 19 43 28% 0.D. Top of tubesheet No 19 44 23% 0.D. Top of tubesheet No 21 44 27% 0.D. Top of tubesheet No 22 44 22% 0.D. Top of tubesheet No 22 46 24% 0.D. Top of tubesheet No 28 49 22% 0.D. Top of tubcsheet No 25 51 27% 0.D. Top of tubesheet No 21 57 25% 0.D. Top of tubesheet No 22- 57 21% 0.D. Top of tubesheet No 15 58 25% 0.D. Top of tubesheet No 21 58' 27% 0.D. Top of tubesheet No 23 58 23% 0.D. " above tubesheet No 43 58 22% 0.D. 2" above tubesheet No

< 23 59 26% 0.D. 4" above tubesheet No 14 22 <20% 0 D. Top of tubesheet No 14 23 <20% 0.D. -Top of tubesheet No 18 23 <20% 0.D. Top of tubesheet No 17- 24 <20% 0.D. Top of tubesheet No 25 25 <20% 0.D. Top of tubesheet No -

18 27 <20%- .U.D. Top of tubesheet No 19 27 <20% 0.D. Top of tubesheet No

.21 27 <20% 0.D. Top of tubesheet No .

14 28 <20% 0.D. . Top of tubesheet No 13 -29 _ <20% 0.D. Top of tubesheet No 18_ 29 . <20%- 0.D. . Top of tubesheet No 19 31 <20% 0.D. Top of tubesheet No 16 33 <20%. 0.D. Top of tubesheet No 20 33 <20% 0.D. Top of tubesheet No 20- 38 <20% 0.D. Top of tubeshe.et .No

<20%- 0.D. \" above tubesheet No 15 -39;

.40 < 0.D. .%" above tubesheet No

-14 _20%

28 40 <20%. 0.D. Top of tubesheet No 31 40 '<20% 0.D. Top of tubesheet No I '

"B" Steam Generator Hot Leg, continued . .

Row Column Defect Origin Location Plugged i 18 41 <20% 0.D. 1" above tubesheet No 15 42 <20% 0.D. \" above tubesheet No 13 43 <20% 0.D. Top of tubesheet No i 14 43 <20% 0.D. " above tubesheet No 16 43 <20% 0.D. " above tubesheet No 15 45 <209 0.D. h" above tubesheet No 31 46 <20% 0.D. Top of tubesheet No 13 47 <20% 0.D. \" above tubesheet No

. 14 4) <20% 0.D. h" above tubesheet No 16 47 <20% 0.D. 1" above tubesheet No i 21 47 <20% 0.D. \" above tubesheet No 22 47 <20% 0.D. " above tubesheet No 13 48 <20% 0.D. Top of tubesheet No r 14 48 <20% 0.D. h" above tubesheet No ,

15 48 <20% 0.D. \" above tubesheet No 18 48 .<20% 0.D. I " above tubesheet No 13 49 <20% 0.D. \" above tubesheet No 0.D. \" above tubesheet 14 49 <20% No 21 49 <20% 0.D. \" above tubesheet No ,

22 49 <20% 0.D. Top of tubesheet No 13 50 <20% 0.D. \" above tubesheet No 13 52 <20% 0.D. " above tub ^ sheet No 22 52 <20% 0.D. Top of tubesheet No 29' 54 <20% 0.D. Top of tubesheet No 28 55 <20% 0.D. Top of tubesheet No 21 60 .<20% 0.D. Top of tubesheet No 18 63 <20% 0.D. Top of tubesheet No 10 67 <20% 0.D. h" above tubesheet No 10 70 <20% 0 . D .' \" above tubesheet No "B" Steam Generator Cold Leg 4

' Row: Column Defect Origin ' Location Pluqqed 7 ~36 41% 0.D. I " above.tubesheet Yes

, , 18 '29 32% 0.D. " above'tubesheet No

.184 '32 32% 0.D. " above tubesheet No 7 37' 31% 0.D. \" above tubesheet No 223- -54 32% 0.D. " above tubesheet No

-5 28 24% 0.D. -\" above tubesheet No 9 '28 29% 0.D. \" above tubesheet No r

-7 30 27%. 0.D. " above tubesheet No'

> 7, '32 27% 0.D. . ha above tubesheet No 7 35- 22% 0.D. \" aboveLtubesheet .No 12= 35" 22%- 0.D. \" above tubesheet- No 12 .37 22% 0.D. " above tubesheet No

8 38 22%; 0.D. 1\" above-tubesheet No-7 39. ~27% 0.D. Ih above tubesheet No 7 43f .21%" -0.D. \" above tubesheet No

, 10, 43' 21%- 0.D. .1\".above tubesheet No

7: 23% 0.D. .1\" above-tubesheet No 47L "B" Steam Generator Cold Leg, continued ...

Row Column Defect Origin Location Plugged 7 38 . <20% 0.D. 1" above tubesheet No 9 38 <20% 0.D. 1\" above tubesheet No 10 38 <20% 0.D. 1" above tubesheet No 12 38 <20% 0.D. 1 " above tubesheet No 13 38 <20% 0.D. Ih" above tubesheet No 14 38 <20% 0.D. 1\" above tubesheet No 15 38 <20% 0.D. I " above tubesheet No 16 38 <20% 0.D. I " above tubesheet No '

21 38 <20% 0.D. 1\" above tubesheet No 4 39 <20% 0.D. 1\" above tubesheet No 6 39 <20% 0.D. Ih" above tubesheet No 8 39 <20% 0.D. 1 " above tubesheet No 9 39 <20% 0.D. " above tubesheet No 10 39 <20% 0.D. I " above tubesheet No 11 39 <20% 0.D. I " above tubesheet No 12 39 <20% 0.D. 1\" hbove tubesheet No 13 39 <20% 0.D. I " above tubesheet No 14 39 <20% 0.D. I " above tubesheet No 15 39 <20% 0.D. 1\" above tubesheet No 16 39 <20% 0.D. 1\" above tubesheet No 7 40 <20% 0.D. 1 " above tubesheet No 8 40 <20% 0.D. 1\" above tubesheet No 9 40 <20% 0.D. 1 " above tubesheet No 10 40 <20% 0.D. 1\" above tubesheet No 11 40 <20% 0.D. 1 " above tubesheet No 12 40 <20% 0.D. 1 " above tubesheet No 13 40 <20% 0.D. 1\" above tubesheet No 6 41 <20% 0.D. " above tubesheet No 7 41 <20% 0.D. \" above tubesheet No 8 41 <20% 0.D. 1" above tubesheet No 9 41 <20% 0.D. 2" above tubesheet No 10 41 <20% 0.D. 2" above tubesheet No 11 41 <20% 0 D. \" above tubesheet No 12 41 <20% 0.D. 2" above tubesheet No 13 41 <20% 0.D. 1\" above tubesheet No 7 42 <20% 0.D. 1\" above tubesheet ?!o 9 42 <20% 0.D. h" above tubesheet No 10 42 <20% 0.D. 1" above tubesheet No

'll 42 <20% 0.D. 1" above tubesneet Ne 12 42 <20% 0.D. 1" above tubesheet No

'13 42 <20% 0.D. 1" above tubesheet No 6 43 <20% 0.D. " above tubesheet No 9 _43 <20% 0.D. 1" above tubesheet No 11 43- _<20% 0.D. 1" above tubesheet No 12 ;43 <20%L .0.D. 1"_above tubesheet No 13 43 <20% 0.D. 1" above tubesheet No 8 44 <20% 0.D. 1\" above tubesheet No 9 44 <20% 0.D. 1" above tubesheet No

'10 44 <20% .0.D. 1" above tubesheet No 11 _44 <20% 0.D. 1" above tubesheet No 13 44 <20%- 0.D. 1" above tubesheet No "B" Steam Generator Cold Leg, continued ..

Row Column De fect Origin Location Plugged 8 32 <20% 0.D. \" above tubesheet No 9 32 <20% 0.D. h" above tubesheet No 11 32 <20% 0.D. \" above tubesheet No 12 32 <20% 0.D. \" above tubesheet No 13 32 <20% 0.D. \" above tubesheet No 14 32 <20% 0.D. h" above tubesheet No 15 32 <20% 0.D. \" above tubesheet No 5 33 <20% 0.D. h" above tubesheet No 6 33 <20% 0.D. \" above tubesheet No 7 33 <20% 0.D. \" above tubesheet No 9 33 <20% 0.D. \" above tubesheet No 10 33 <20% 0.D. h" above tubesheet No 12 33 <20% 0.D. " above tubesheet No 13 33 <20% 0.D. " above tubesheet No 14 33 <20% 0.D. \" above tubesheet No 15 33 <20% 0.D. \" above tubesheet No 16 33 <20% 0.D. " above tubesheet No 18 33 <20% 0.D.

above tubesheet No 6 34 <20% 0.D. \" above tubesheet No

'7 34 <20% 0.D. \" above tubesheet No 6 34 <20% 0.D. \" above tubesheet No 9 34 <20% 0.D. \" above tubesheet No 10 34 <20% 0.D. h" above tubesheet No 11 34 <20% 0.D. \" above tubesheet No 12 34 <20% 0.D. h" above tubesheet No 13 34 <20% 0.D. 1" above tubesheet No 14 34 <20% 0.D. \" above tubesheet No 15 34 <20% 0.D. " above tubesheet No 16 34 <20% 0.D. " above tubesheet No 8 35 <20% 0.D. \" above tubesheet No 10 35 <20% 0.D. " above tubesheet- No 13 35 <20% 0.D. \" above tubesheet No 14 35 <20% 0.D. \" above tubesheet No 15 35 <20% 0.D. 1" above~tubesheet No 16 35 . <20% 0.D. " above tubesheet No 9 36 <20% 0.D. \" above tubesheet No 10 36- .<20% 0.D. h" above tubesheet No 11 36 <20% 0.D. \" above tubesheet No 12 36 <20% 0.D. \" above tubesheet No

~

13 36 <20% 0.D. \" above tubesheet No 14 36 <20% 0.D. \"'above.tubesheet No 15 36 <20% 0.D. " above tubesheet No

.16. 36 <20% 0.D. \" above tubesheet No 6 37 <20% 0.D. " above tubesheet No 8 37 <20%- 0.D. " above tubesheet No 9- 37 <20% 0.D. \" above tubesheet No 11 . 37 . <20%- 0.D. " above tubesheet No

'13 37 <20% 0.D. \"~above tubesheet No 14 37. < 20%' 0.D. - " above tubesheet No 0.D. \" above tub (sheet No

15. 37, -<20%

37 <20% 0.D. \" above tubesheet No 16

"B" Steam Generator Cold Leg, continued ...

Row Column Defect Origin Locationi Plugged 7 38 <20% 0.D. 1" above tubesheet No 9 38 <20% 0.D. 1\" above tubesheet No 10 38 <20% 0.D. 1" above tubesheet No 12 38 <20% 0.D. 1\" above tubesheet No 13 38 <20% 0.D. Ih" above tubesheet No 14 38 <20% 0.D. Ih" above tubesheet No 15 38 <20% 0.D. I " above tubesheet No 16 38 <20% 0.D. 1\" above tubesheet No 21 38 <20% 0.D. 1 " above tubesheet No 4 39 <20% 0.D. 1 " above tubesheet No -

6 39 <20% 0.D. 1 " above tubesheet No 8 39 <20% 0.D. Ih" above tubesheet No 9 39 <20% 0.D. " above tubesheet No e 10 39 <20% 0.D. 1\" above tubesheet No 11 39 <20% 0.D. Ih" above tubesheet No 12 39 <20% 0.D. 14" above tubesheet No 13 39 <20% 0.D. 1 " above tubesheet No 14 39 <20% 0.D. 1\" above tubesheet No 15 39 <20% 0.D. 1\" above tubesheet No 16 39 <20% 0.D. 1\" above tubesheet No 7 40 <20% 0.D. 1\" above tunesheet No E 40 <20% 0.D. 1\" above tubesheet No 9 40 <20% 0.D. 1\" above tubesheet No 10 40 <20% 0.D. 1 " above tubesheet No 11 40 <20% 0.D. 1\" above tubesheet No 12 40 <20% 0.D. 1\" above tubesheet No 13 40 <20% 0.D. 1 " above tubesheet No 6 41 <20% 0.D. \" above tubesheet No 7 41 <20% 0.D. \" above tubesheet No 8 41 <20% 0.D. 1" above tubesheet No 9 41 <20% 0.D. 2" above tubesheet No 10 41 <20% 0.D. 2" above tubesheet No 11 41 <20% 0.D. " above tubesheet No 12 41 <20% 0.D. 2" above tubesheet No 13 41 <20% 0.D. 1\" above tubesheet No 7 42 <20% 0.D. Ih" above tubesheet No 9 42 <20% 0.D. \" above tubesheet No .

10 42 <20% 0.D. 1" above tubesheet No 11 42 <20% 0.D. 1" above tubesheet No 12 42 <20% 0.D. 1" above tubesheet No .

13 42 <20% 0.D. 1" above tubesheet No 6 43 <20% 0.D. " above tubesheet No 9 43 <20% 0.D. 1" above tubesheet No 11 43 <20% 0.D. 1" above tubesheet No 12 43 <20% 0.D. 1" above tubesheet No 13 43 <20% 0.D. 1" above tubesheet No 8 44 <20% 0.D. 1\" above tubesheet No 9 44 <20% 0.D. 1" above tubesheet No 10 44 <20% 0.D. 1" above tubesheet No 11 44 <20% 0.D. 1" above tubesheet No 13 44 <20% 0.D. 1" above tubesheet No "B" Steam Generator Cold Leg, continuad ..

Row Column Defect Origin Lccation Plugged 8 45 <20% 0.D. 1" above tubesheet No 9 45 <20% 0.D. 1" above tubesheet No 10 45 <20% 0.D. I " above tubesheet No 11 45 <20% 0.D. 1" above tubesheet No 7 46 <20% 0.D. 1" above tubesheet No 8 46 <20% 0.D. 1" above tubesheet No 10 46 <20% 0.D. 1" above tubesheet No 11 46 <20% 0.D. 1" above tubesheet No 8 47 <20% 0.D. 1" above tubesheet No

, 9 47 <20% 0.D. 1" above tubesheet No 10 47 <20% 0.D. 1" above tubesheet No 12 47 <20% 0.D. 1" above tubesheet No

, 13 47 <20% 0.D. \" abuve tubesheet No 14 47 <20% 0.D. " above tubesheet No 15 47 <20% 0.D. 1" above tubesheet No 8 48 <20% 0.D. 1" above tubesheet No 10 48 <20% 0.D. 1" above tubesheet No 11 48 <20% 0.D. 1" above tubesheet No 12 48 <20% 0.D. 1" above tubesheet No 14 48 <20% 0.D. \" above tubesheet No 15 48 <20% 0.D. 1" above tubesheet No 7 49 <20% 0.D. I " above tubesheet No 8 49 <20% 0.D. 1" above tubesheet No 10 49 <20% 0.D. 1" above tubesheet No 11 49 <20% 0.D. 1" above tubesheet No 12 49 <20% 0.D. 1" above tubesheet No 13 49 <20% 0.D. 1" above tubesheet No 14 49 <20% 0.D. 1" above tubesheet No 15 49 <20% 0.D. 1" above tubesheet No 16 49 <20% 0.D. 1" above tubesheet No 18 49 <20% 0.D. 1" above tubesheet No 6 50 <20% 0.D. " above tubesheet No 9 50 <20% 0.D. 1" above tubesheet No 11 50 <20% 0.D. \" above tubesheet No 12 50 <20t 0.D. 1" above tubesheet No 13 50 <20% 0.D. 1" above tubesheet No

. 14 50 <20% 0.D. 1" above tubesheet No 15 50 <20% 0.D. 1" above tubesheet No 16 50 <20% 0.D. " above tubesheet No

,. 17 50 <20% 0.D. \" above tubesheet No 8 51 <20% 0.D. h" above tubesheet No 9 51 <20% 0.D. \" above tubesheet No 10 51 <20% 0.D. h" above tubesheet No 11 51 <20% 0.D. 1" above tubesheet No 13 51 <20% 0.D. 1" above tubesheet No 14 51 <20% 0.D. \" above tubesheet No 15 51 <20% 0.D. " above tubesheet No 16 51 <20% 0.D. " above tubesheet No 19 51- <20% 0.D. " above tubesheet No 20 51 <209 0.D. " above tubesheet No 21 51 <20% 0.D. " above tubesheet No

" B" Steam Generator Cold Leg, continued ...

Row Column Defect origin Location Plugged 22 51 <20% 0.D. " above tubesheet No 6 52 <20% 0.D. 1" above tubesheet No 7 52 <20% 0.D. I " above tubesheet No 8 52 <20% 0.D. 1\" above tubesheet No 10 52 <20% 0.D. 1" above tubesheet No 11 52 <20% 0.D. 1" above tubesheet No '

12 52 <20% 0.D. 1" above tubesheet No l 13 52 <20% 0.D. 1" above tubesheet No 14 52 <20% 0.D. 1" above tubesheet No 15 52 (20% 0.D. 1" above tubesheet No '

16 52 <20% 0.D. \" above tubesheet No 17 52 <20% 0.D. \" above tubesheet No 18 52 <20% 0.D. \" above tubesheet No -

19 52 <20% 0.D. " above tubesheet No

, 21 52 <20% 0.D. h" above tubesheet No 23 52 <20% 0.D. \" above tubesheet No 6 53 <20% 0.D. 1" above tubesheet No 7 53 <20% 0.D. 1 " above tubesheet No 8 53 <20% 0.D. 1" above tubesheet No 9 53 ' <20% 0.D. 1" above tubesheet No 11 53 <20% 0.D. \" above tubesheet No 13 53 <20% 0.D. 1" above tubesheet No 14 53 <20% 0.D. \" above tubesheet No 15 53 <20% 0.D. " above tubesheet No 16 53 <20% 0.D. \" above tubesheet. No 17 '53 <20% 0.D. \" above tubesheet No 18 53 <20% 0.D. " above tubesheet No 22 53- <20% 0.D. \" above tubesheet No 23 53 <20% 0.D. No h",above tubesheet 24 53 <20% 0.D. \" above tubesheet No

6. 54 <20% 0.D. 1" above tubesheet No 7 54 <20%- 0.D. 1" above tubesheet- No 8 54 <20% 0.D. 1" above tubesheet- No

. 10 54 - <20% 0.D. 1" above tubesheet No 11 ~54 <20% 0.D. 1" above tubesheet No 14 54 <20% 0.D. 1" above tubesheet No

'16 54 <20% 0.D. '1" above tubesheet No .

17 54 <20% 0.D. 1" above tubesheet No 18 54 <20% 0.D. 1" above tubesheet No 19 54 <20% 0.D. \" above tubesheet No ,

21 54 <20% 0.D. " above tubesheet No 24 54 <20%. 0.D. " above tubesheet No 7 55- <20% 0.D. '1\" above tubesheet No

.8. 55 <20% 0.D. '1" above tubeshetc No 9 5

.5 <20%4 0.D. ~1\" above tubesheet No 10 55: <20%' O.D. la above tubesheet: No.

11 55 <20% 0.D. 1" above-tubesheet No

'12 55. <20% 0.D. 1" aboveTtubesheet No

.13 55 <20% 0.D. 1" above tubesheet No 14 55 _ <20% 0.D. 1" above tubesheet .No 15: 55 L<20% :0.D. 1" above tubesheet .No 88-4

_-_m,_m_L...

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

i "B" Steam Generator Cold Leg, continued ...

4 Row Column Defect Origin Location Plugged 16 55 <20% 0.D. 1" above tubesheet No 17 55 <20% 0.D. 1" above tubesheet No 18 55 <20% 0.D. 1" above tubesheet No 19 55 <20% 0.D. Ih" above tubesheet No 20 55 <20% 0.D. 1" above tubesheet No 21 55 <20% 0.D. 1" above tubesheet No 22 55 <20% 0.D. 1" above tubesheet No i 23 55 <20% 0.D. h" above tubcsheet No 24 55 <20% 0.D. h" above tubesheet No a 7 56 <20% 0.D. 1" above tubesheet No 9 56 <20% 0.D. Ih" above tubesheet No 10 56 <20% 0.D. I " above tubesheet NJ q- 11 56 <20% 0.D. 1 " above tubesheet No 4

12 56 <20% 0.D. Ih" above tubesheet No 13 56 <20% 0.D. Ih" above tubesheet No 14 56 <20% 0.D. 1" above tubesheet No 15 56 <20% 0.D. 1" above tubesheet No 16 56 <20% 0.D. 1" above tubesheet No 18 ~56 <20% 0.D. 1" above tubesheet No 19 56 <20% 0.D. h" above tubesheet No 20 56 <20% 0.D. 1" above tubesheet No 21 56 <20% 0.D. 1" above tubesheet No 22 56 <20% 0.D. 1" above tubesheet No 23 56 <20% 0.D. " above tubesheet No 24 56 <20% 0.D. h" ab ve tubesheet No 25 56 <20% 0.D. " above tubesheet No 6 57 <20% 0.D. Ih" abose tubesheet No

7 57 <20% 0.D. Ih" above tubeshi,et No 8- 57 <20% 0.D. Ih" above tubesheet No 9 57 <20% 0.D. 1 " above tubesheet No

10

. 57 <20% 0.D. I " above tubesheet No 11 57 <20% 0.D. 1 " above tubesheet No 12 57. <20% 0.D. 1" above tubesheet No 14 57 <20% 0.D. 1" above tubesheet No-16 57 <20% 0.D. 1" above tubesheet No 17 57 <20% 0.D. 1" above tubesheet No d 18 57 <20% 0.D. 1" above tubesheet No 19 57 <20% 0.D. h" above tubesheet No j 20- 57, <20% 0.D. h" above tubesheet No e1 . 21 57. <20% 0.D. h" above tubesheet No 22 57 -

<20% 0.D. No

.23 57

<20% 0.D. h".above tubesheet h" abone tubesheet Mo

-24 57* <20% 0.D. h" above tubesheet No 7- 58 <20% 0.D. 1" above tubesheet No

'8 58 <20% 0.D. 1" above tubesheet' No-4

-10 58 <20% 0.D. 1" above tubesheet No 11 SS <20% 0.D. '1" above tubesheet. No 14 -58 <20% 0.D. :1" above tubesheet No-

, 15 ? 58- <20% 'O.D. 1" above tubesheet No

,18L 58 . <20% 0.D. "~above tubesheet No 19 58 <20% 0.D. " above tubesheet No

"B" Steam Generator Cold Leg, continued ...

Row ' Column Defect Origin Location Plugged 21 58 <20% 0.D. \" above tubesheet No 22 58 <20% 0.D. " above tubesheet No 23 50 <20% 0.D. h" above tubesheet No 24 58 <20% 0.D. " above tubesheet No 6 59 <20% 0.D. " above tubesheet No 7 59 <20% 0.D. 1 " above tubesheet No 8 59 <20% 0.D. 1" above tubesheet No 9 59 <20% 0.D. h" above tubesheet No 10 59 <20% 0.D. " above tubesheet No

'11 59 <20% 0.D. \" above tubesheet No 12 59 <20% 0.D. 1 ' above tubesheet No 13 59 <20% 0.D. 1" above tubesheet No '

14 59 <20% 0.D. 1" above tubesheet No 15 59 <20% 0.D. 1" above tubesheet No 16 59 <20% 0.D. 1" above tubesheet No 17 59 <20% 0.D. \" above tubesheet No 18 59 <20% 0.D. 1" above tubesheet No 19 59 <20% 0.D. " above tubesheet No ..

6 60 <20% 0.D. " above tubesheet No' 7 60 <20% 0.D. " above tubesheet No 8 60 <20%- 0.D. 1" above tubesheet No 9 60 <20% .0.D. 1\" above tubesheet No 10 60 <20% 0.D. 1" above tubesheet No 11 60 <20% 0.D. 1" above tubesheet No 12' 60 <20% 0.D. 1\" above tubesheet No 13 60 <20% 0.D. 1" above tubesheet No 14 60 <20% 0.D. 1" above tubesheet No 15' 60 <20%_ 0.D. 1" above tubesheet No 16- 60 <20%' O.D. 1" above tubesheet No 18 60 <20% 0.D. 1" above tubesheet No 19 60 <20% 0.D. \" above tubesheet No 6 61 -<20% 0.D. \" above tubesheet No 7 61 ' <20%. 0.D. 1 " above tubesheet No 8 61 <20% 0.D. 1" above tubesheet No 9 61 <20% 0.D. la above tubesheet No 10 61 <20% 0.D. 1" above tubesheet No -

11 61 <20% 0.D. la above tubesheet No 13 61 <20% 0.D. 1\" above tubesheet No 14 61 <20% 0.D. 1" above tubesheet No a 15 61 <20% 0.D. 1" above tubesheet No 16 _61 <20% 0.D. 1" above tubesheet No

~ 18 61- -<20% 0.D. \" above tubesheet No 19 '61 <20% 0.D. " above tubesheet No 6 62 <20%. :0.D. h" above tubesheet No 7 62 <20%- 'O.D. la above tubesheet No' 8 62. <20%. .O.D. 1"'above tubesheet No

'9 ~62 <20% 0.D. la above tubesheet No 10 62 <20%' O.D. '1" above tubesheet No 11 -62 <20% 0.D. 1" above tubesheet No

.12 62- <20% 0.D. 1" above tubesheet No 13, 62 . <20% - a0.D. 1" above tubesheet No "B" Steam Generator Cold Leg, continued ..

Row Column Defect Origin Location Plugged

14. 62 <20% 0.D. 1" above tubesheet No 15 62 <20% 0.D. 1" above tubesheet No 17 62 <20% 0.D. h" above tubesheet No 18 62 <20% 0.D. h" above tubesheet No 19 62 <20% 0.D. 'i' above tubesheet No 6 63 <20% 0.D. 1" above tubesheet No 7 63 <20% 0.D. 1" above tubesheet No 8 63 <20% 0.D. 1" above tubesheet No 9 63 <20% 0.D. h" above tubesheet No 11 63 <20% 0.D. " above tubesheet No 13 63 <20% 0 D. 1" above tubesheet No 14 63 <20% 0.D. h" above tubesheet No 9 16 63 0.D.

<20% h" above tubesheet No 17 63 <20% 0.D. h" above tubesheet No 18 63 <20% 0.D. h",above tubesheet No 19 63 <20% 0.D. h" above tubesheet No t -

6 64 <20% 0.D. 1" above tubesheet No 7 64 <20% 0.D. 1" above tubesheet No 8 64- <20% 0.D. 1" above tubesheet No 9 64 <20% 0.D. Ih" above tubesheet No 10 64 <20% 0.D. Ih" above tubesheet No

12. 64 <20% 0.D. 1" above tubesheet No 13 64 <20% 0.D. 1" above tubesheet No 14 64 <20% 0.D. 1" above tubesheet No 15 64 <20% 0.D. 1" above tubesheet No

'6 65 <20% 0.D. h" above tubesheet No 7 65 <20% 0.D. 1" above tubesheet No 8 65 <20% 0.D. " above tubesheet No 9 65 <20% 0.D. 1" above tubesheet No 10 65 <20%; 0.D. 1" above tubesheet No 11 65 <20% 0.D. 1" above tubesheet No 13 65 <20% 0.D. 1" above tubesheet No 14 65 <20% 0.D. \" above tubesheet No 15 65- <20% 0.D. \" above tubesheet No 23 65 <20% 0.D. h" above tubesheet No 6 66 <20% 0.D. h" above tubesheet No

'66 7 <20% 0.D. \" above tubesheet No 8 66 <20% 0.D. " above tubesheet No 9 66 <20% 0.D. " above tubesheet - No

10 66 ~ <20%- 0.D. 1" above tubesheet- No 12 66. <20% 0 D. 1" above tubesheet- No 13 66 <20% 0.D. 1" above tubesheet No

.14 .66 <20% 0.D. " above tubesheet No

'15 '66- <

'20% 0.D. 1":above tubesheet No 7 67 <20%. 0.D. 1" above tubesheet No L8 67 <20%- 0.D. 1" above tubesheet No 9 67- <20% 0.D. " above tubesheet- No 10 67. <20% 0.D. \" above tubesheet No 11 67 !<20% 0.D. \" above tubesheet No 11 2 67c <20% , 0.D. .\" above tubesheet. No' 14- 67J < 20%. 0.D. \" above tubesheet No I

1

"B" Steam Generator Cold Leg, continued ...

Rme Column Defect Origin Location Plugged 15 67 <20% 0.D. la above tubesheet No 19 67- <20% 0.D. la above tubesheet No 7 68 <20% 0.D. " above tubesheet No 9 68 <20%- 0.D. \" above tubesheet No 10- 68 <20% 0.D. \" above tubesheet No 11 68 (20% 0.D. " above tubesheet No 12 '68 <20% 0.D. \" above tubesheet No 13- 68 <20% 0.D. " above tubesheet No 14 68 <20% 0.D. h" above tubesheet No 15 68 <20% 0.D. \" above tubesheet No 8 19 68 -<20% 0.D. 1" above tubesheet No 7 69 <20% 0.D. \" above tubesheet No i

-10 70 <20% 0.D. \" above tubesheet No r 9 72. <20% 0.D. " above tubesheet No f

92-

ML19347C916

Text

1.0 INTRODUCTION

1.0 INTRODUCTION

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