ML19284B309

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Semiannual Rept,Jul-Dec 1975
ML19284B309
Person / Time
Site: Yankee Rowe
Issue date: 12/31/1975
From:
YANKEE ATOMIC ELECTRIC CO.
To:
Shared Package
ML19284B310 List:
References
FOIA-92-403 NUDOCS 8011100251
Download: ML19284B309 (69)
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SEMI-ANNUAL OPERATING REPORT JULY 1, 1975 TilRU DEC. 31, 1975 INDEX I. OPERATIONS SUM'!ARY A. Changes in Facility Design B. Performance Characteristics C. Changes in Operating Procedures D. Surveillance Tests and Inspections (Table I.D) E. Containment Leak Tests F. Tests and Experiments G. Staff Changes II. POWER GENERATION (Table and llistograms) III. SIIUTDOWNS (Table) IV. CORRECTIVE MAINTENANCE

SUMMARY

(Table) V. PRIMARY COOLANT CllEMISTRY (Table) VI. OCCUPATIONAL PERSONNEL RADIATION EXPOSURE (Table) VII. ABNORMAL OCCURENCES VIII. SPECIAL TOPICS IX. EFFLUENT AND WASTE DISPOSAL (Table)

I. Operations Summary A. Changes in Facility Design 1. The following changes requiring authorization from the Commission were made: a. PDCR 75-20, Reconnection of the Main Ceolant Flow (oP) Scram System, was completed during the report period. The old low MC Flow oP scram system was reconnected. This change was nade te provide a system whose reactor protective setpoiats can be equated in terms of flow and also provide a basis for the ! bin Coolant Flow rate for the 1.oss of Flow Accident. The elimination of the Low MC Flow Memory Light allows for electrical independence between the two diverse low flow trips. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. b. EDCR 75-28, Moo f4 cation Required to Meet PC No. 117 Supplement No. 3(b), 5 and 6, was completed during the report period. Changes were made to the ECCS system to meet the requirements of Proposed Change No. 117 Supplement Nos. 3(b), 5 and 6. This change looked at the ef fects of a single failure or operator error or spurious valve operation that could cause any manually-controlled, electrically-operated valve to move to a position adversely af fecting the ECCS performance. This change would eliminate the possibility of the ECCS becoming inoperative because of a single failure. PDCR 75-1, Plueging of ICI Thimble Tubes H-2 and K-6, c. was completed during the report period. The change consisted of cutting the flux tube as clor3 to the conoseal penetration as possible and installing a swagelok fitting with a plug on the end of the tube. This change was made to minimize the possibility of a Icak from the tube by reducing its length. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. 2. The following changes not requiring Commission approval were made: EDCR 75-4, Prevention of Flooding due to Non-Safety a. Related Equipment Failure, was completed during the report period. The interconnecting door between the PAB and the DGB was remounted so that it opens into the PAB. Casket material was installed on the

. door to make it watertight and a closed switch was mounted on it to initiate an alarn in the control room when the door is open greater than 30 seconds. Openings were provided in the PAR at ground icvel and these openings were equipped with louvers or screen mesh. Redundant alarms were inctalled in the ficor sump on the PAB. These changes were made to prevent a failure of any non-safety related systens or components from effecting, a safe shutdown of the plant. This change does not impose any unrei.cwed safety question in that the system will operate in the same manner as covered in the existing safety analysis

report, b.

EDCR 75-5, New Fuel Storage Rack Modification, was completed during the report period. Forty (40) new fuel storage racks were modified with aluminum channels which in turn was covered with neoprene to support the new design of fuel which will be employed for Core XII. This change was made to prevent possible distortion and/or damage of the new fuel assemblies. c. PDCR 75-2, Raising the Safety Injection Tank Low Level Alarm Setpoint, was completed during the report period. The low level, alarm switch (LLS 220 and HLA/LLA-SI-7) setpoint was raised from 20 feet to 25.5 feet. This change was made to provide an aid to the operator in maintaining the SI tank minimum level of 117,000 gallons. d. PDCR 75-3, Loop Seal Hich Level Alarm Alteration, was completed during the report period. HLS-313 was repiped to put it in parallel with LG-305. This change was made to allow the operation check of HLS-313 without cutting it out of the system. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. e. PDCR 75 6, Shutdown Cooling Instrumentation Piping Chgnaes, was completed during the report period. The 1/2" stainless steel tubing between the isolation root valve and FI-204 was replaced with 3/8" stain-less steel tubing, valves and fittings and a test valve was added. This change was made to minimize the leak potential of the oystem and allow the hydrostatic testing or the sensing line from the isolation root valve and the flow indicator. This change does not impoue any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis repoi

. f. PDCR 74-11, Incore Instrumentation Systen Modification, was completed during the report period. A leak test valve was installed in the leak censing line and four separate cables between terminal box 57670.A and B were replaced with one multiconducto. cable. The leak test valve was installed to allow checking for leaks by opening the valve and checking for liquid. The single cable was installed to facilitate removal of the Transfer Device Fran.e by disconnecting a single plug instead of remcving the four wires from the terminal blocks. This change does not impose any unreviewed nafety question in that the system will operate in the same manner as covered in the existing safety analysis report. g. PDCR 74-13, Guide Tube Hold-Down Plate and Upper Core Support Barrel Liftine Fixture Modification, was completed during the report period. The pneumatic cylinders were replaced with hydraulic cylinders containing glycerine. The change was made to reduce corrosion of the cylinders and to utilize a hydraulic hand pump which can be monitored and supply a sufficient pressure to free a stuck latch pin. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. h. PDCR 75-7, Relocation of Cavity Purification Line on the Primary Auxiliary Building, was completed during the report period. The Cavity Purification Line was rerouted on the Primary Auxiliary Building roof. The change was made to prevent interferences with the new building for the Primary Vent Stack Monitoring System. This change does r.ot impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. 1. PDCR 75-9, Dividing the Electrical Feeders to the the Main Coolant Cutout Valves, was completed during the repor* period. The electrical feed to the main loop valves (Tc, Th and Bypass) was split so that Loop 1 and 2 valves are fed from MCC 1, Bus 1 and Loop 3 and 4 valves are fed from MCC 1, Eus 2. This change was made to provide a redundant feed so that loss of one MCC Bus will not render all loop valves inoperable. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report.

4 5 j. PDCR 75-10, Emergency Diesel Generator DC Control Circuit UV Alarm Addition, was completed during the report period. An undervoltage relay was added to each emergency diesel generators' DC control circuit. The change was made to aliminate delay in the discovery of trouble by providing an annunciator alarm on the Safety Injection Panel in the Control Room. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. k. PDLR 75-4, VC Leak Monitoring and Pressure Sensing System, was completed during the report period. The change consisted of adding a 100" mercury manometer to the old closed bulb system. Various valves were removed from and added to the open and closed bulb systems. Tubing, fittings and valves were replaced with stainless steel ones. This change was made to allow for comparison of two separate pressure sensing sy.ctems of VC pressure as required by Proposed Change 116 to the FHSR 509.2. Replacing the brass valves and copper tubing with stainless steel will increase the reliability and integrity of the systems. This change does not impose any unreviewed safety question in that the system will operate in the same manner as covered in the existing safety analysis report. B. Performance Characteristics None C. Changes in Operating Procedures 1. The following Operating Procedures were prepared or changed as necessitated in I.A.2 and 2.b. OP-3610 Waste Disposal OP-3617 Safety Injection Tank Level OP-4616 Safety Injection Tank Electronic Level Indication Channel Calibration OP-6451 Calibration of the SI Tank High and Low Level Alarm Switches (HLS 219/LLS 220) OP-6559 Calibration of the Loop Seal Inlet High Level Switch OP-5000.31 Installation and Testing of Plate and Barrel Lifting Fixture Modification

, OP-6101 Nuclear Instrumentation and Reactor Protection System Precritical Check OP-6210 Maintenance of the Primary Plant Instrumentation OP-4608 Main Coolant Flow Primary Channel Calibration OP-2100 Plant Startup from Cold Shutdown OP-2104 Scheduled Plant Shutdown to Hot Standby or Hot Shutdown OP-2105 Plant Cooldown from Hot Shutdown, with the Main Condenser in Service OP-2106 Plant Cooldown from Hot Shutdown, with the Main Condenser Out of Service OP-2125 Filling and Venting of Main Coolant System OP-2151 Boric Acid Addition to the Main Coolant System OP-2168 Steam Generator Feed Via the Charging Pump OP-2176 Charging Line Removal from Service for Maintenance of Drain and Relief Valves OP-2652 Releasing Radioactive Waste Gases from the Waste Gas Surge Drum to Atmosphere OP-2653 Removal of the Safety Injection System from Service OP-3000 Emergency Shutdown from Power OP-3106 Loss of Main Coolant OP-3107 Steam Generator Tube Failure OP-3112 Failure of Regenerative Heat Exchanger OP-3114 Failure of Charging and Volume Control System OP-3119 Excessive Safety Injection Check Valve Leakage OP-3201 Main Steam Line Rupture ~ OP-4203 Weekly Valve Check OP-4204 Monthly Test or Special Operation of the Safety Injection Pumps OP-4609 Safety Injection Actuation Channels Calibration and Functional Check

. OP-4630 Main Coolant Pump and Main Coolant Stop Valve Interlock Surveillance Check OP-6455 Safety Injection Accumulator Level Switch Operational Check OP-2479 VC Atmosphere Control System Charging 2. The following Operating Procedures were prepared or changed as necessitated by an analysis of plant performance characteristics described in I.B. above: None 3. The following Operating Procedures were prepared or changed to improve the safety of plant operation: AP-0002 Abnormal Occurrnece Reports AP-0220 Surveillance Tests and Reports AP-0601 New Fuel Receiving Report OP-1213 Unloading Exxon Fuel OP-2167 Chemical Shutdown System, Boric Acid Preparation OP-2173 Flushing of the Chemical Injection Line OP-2256 Operating of the Ibin Steam System OP-2654 Safety Injection Tank Makeup OP-2703 Chemical Cleaning of Component Coolers OP-3014 Emergency Plant Shutdown and Cooldown Under Abnormal or Offnormal Circumstances OP-3107 Large or Partial Loss of Main Coolant OP-3311 Emergency Environmental Sample Collection OP-4517 Surveillance of Motor Operated Valves OP-4518 Travel Time of Motor Operated Valves - Master List AP-0210 Control of Special Processes AP-0212 Material Receipt AP-0218 Preoperational, Operational and Special Tests Material Receipt

. OP-5101 Maintenance cf Motor Operated Valve No. OP-5404 Inspection of the Steam Generator - Secondary Side No. OP-6250 No. Feedwater Plow Transmitter Calibration OP-6457 Repair and Adjustment of Accumulator Pressure Regulating Valves SI-PR-58 (SI-PR-59) OP-7200 New Fuel Inspection AP-8001 Energency Monitoring Training AP-80ll Health Physics Procedures for Extended Shutdown and Refueling Periods OP-8102 Radiation Dose Rate Surveys (Beta-Gamma) OP-8104 Airborne Radioactivity Surveys OP-8301 Radioactive Material Shipment OP-8405 Bioassay Program OP-8415 Radiation Work Permits OP-8419 Cleaning, Disinfection, Decontamination and Storage of Respirators OP-9247 Analyses of Radioactive Airborne Releases OP-9404 Split Sample Program OP-9406 Primary Plant Sample Points AP-0004 Plant Information Reports AP-0016 Distribution Lists AP-0202 Engineering Design Changes AP-0205 laintenance Requests AP-0208 In Plant Audits AP-0225 Plant Drawings OP-2100 Plant Startup from Cold Shutdown OP-2107 Changing Generator Load OP-2132 Cooldown of an Individual Main Coolant Loop

. OP-2162 Operation of the Shutdown Cooling System OP-3000 Emergency Shutdown from Power OP-3103 Partial or Total Loss of Main Ccolant Flow OP-3252 Emergency Operation of the Main Generator Hydrogen Vent Valve OP-3624 Main Coolant Loop Low Flow Alarm OP-3630 2400 Volt Motor Auto Trip Alarm OP-3631 2400 Volt Motcr Overload Alarm OP-3632 Main Coolant Pump High Temperature OP-4225 Throttle Valve Surveillance Test OP-4615 Safety In: action Tank Pneumatic Level Instrumentation, LIT-401, Calibration OP-4631 Waste Cas Instrument Leak Test OP-4801 Calibration Check of the Process Radiation Monitoring System OP-6104 Installation and Removal of the VC High Accuracy Pressure Indicator AP-7104 Core XI Operational Limits OP-9400 Ammoniation of the Main Coolant and Purification Systems OP-9416 Chemistry Control of Primary Auxiliary Systems AP-0018 Bypass of Safety Function and Jumper Control AP-0211 Material and Service Purchase AP-0215 Control of Measuring and Test Equipment AP-0400 General Organization for Security AP-0401 Responsibilities of Security Police Force AP-0404 Emergency Security Procedures AP-0406 Access Control and Intrusion Alarm System AP-0503 Fire Protection Training AP-2001 Responsibilities and Authorities of Operations Department Personnel

t OP-2108 Routine Power Operation OP-2250 Feedwater Line Isolation and Return to Service to Affect Repairs on Feedwater Line Components OP-2253 Steam Removal from Secondary Plant to Repair High Pressure Steam Line OP-2381 Concentrating and Drumming Evaporator Bottoms OP-2387 Test of NO. Gas Decay Drum and Safety Valve OP-2475 Vapor Container Access OP-2652 Preparation of the Safety Injection System for Normal Operation OP-2653 Removal of the Safety Injection System from Service OP-3002 Loss of Control Air Supply OP-3008 Plant Action in the Event of a Severe Wind Storm OP-3010 Fire or Forced Evacuation of the Control Room OP-3012 Large Volume Chemical Spill OP-3015 Plant Action in the Event of a Security Emergency Alert or Intrusion Alarm OP-3115 Loss of Component Cooling OP-3116 Loss of Control Rod Drive Breaker Trip Circuit OP-3610 Waste Disposal OP-3617 Safety Injection Tank Level OP-4201 Power Range Channel Calibration OP-4203 Weekly Valve Check OP-4213 Operational Tcst of the Vapor Container Recirculation System OP-4219 Pressurizer Spray System Operational Check OP-4226 Testing of Fuel Handling Equipment with the Dummy Fuel Assembly OP-4232 Vapor Container Inspection While Operating at Power OP-4505 Inspection and Testing of Fuel Handling Equipment OP-4605 Steam Generator NR Level Trip Channel Calibration No.

. OP-4611 HPSI Pump Discharge Header Pressure Instrument (PT-SI-7 and PI-SI-7) Calibration OP-4613 SI Accumulator Level Transmitter Calibration No. OP-4618 LPSI Header Flow Instrument FT-SI-10/FI-SI-10 Calibration OP-4619 HPSI Header Flow Inst? tent FT-SI-6 and FI-SI-6 Calibration OP-4634 Safety Injection Actuation Pressure Switches (PS-238 and PS-239) Monthly Surveillance Check AP-5006 Training of Maintenance Department Personnel Including Initial and Annual Review Training Requirements OP-6157 Core Vibracion Monitoring Using Nuclear Instrumentation Intermediate Power Range Detectors OP-6264 Maintenance of the Stean Generator NR Level Trip System No. OP-6451 Calibration of the SI Tank High and Low Level Alarm Switches (HLS-219/LLS-220) OP-6453 Primary Seal Tank Pressure Instrument (PT and PI-236) Calibration OP-6604 Calibration of the Radiation Monitoring System Electronics OP-8107 Neutron Surveys Using the PNR-4 Rem Counter OP-8409 Lost or Damaged Film Badge or TLD OP-9220 Determination of Gross Beta Radioactivity OP-9230 Determination of Chlorides in High Purity Water OP-9240 Tritium Analysis by Liquid Scintillation Counting AP-0002 Abnormal Occurrence Reports AP-0017 Switching and Tagging Rules for Plant Equipment AP-0208 In-Plant Audit AP-0220 Surveillance Tests and Records AP-0403 Security Responsibilities of Plant Personnel AP-0500 Yankee Rowe Operator Training Program

. OP-1100 Dismantling and Reassembly of the Reactor Systems for Core XII Refueling OP-1203 Filling of Shield Tank Cavity OP-2106 Transfer of Spent Fuel AssemSlies in Spent Fuel Pit Using Manual Tool OP-1209 Operation of the VC Manipulator Cranes, Handling Fixtures and Transfer Equipment OP-1214 Transfer of New Fuel from the New Fuel Vault to the Spent Fuel Pit OP-1221 Movement of Reactor Core Components Withia the Spent Fuel Pit OP-1500 Relaxing Reactor Head Studs OP-1502 Reactor Lower Core Support Structure Removal and Replacement OP-15031 Unitized Control Rod Shearing OP-1505 Removal Reactor Head Conoseals OP-1506 Removal, Handling and Inspection of Rod Drive and Indicating Light Coil Stacks and Cables OP-1507 Reactor Head - Removal, Handling and Storage OP-1508 Handling and Storage of Reactor Head Studs OP-1510 Reactor Upper Core Barrel and Plates Removal and Storage OP-1511 Installation of Rod Drive and Indicating Light Coil Stacks and Cables OP-1512 Tensioning Reactor Head Studs OP-1.c ' 3 Reactor Head - Replacement OT-1514 Reactor Upper Core Barrel and Plates - Replacement OP-1515 Installation of Reactor Head Conoseals OP-1516 Inspection of New Fuel Elevator and Air Hoist OP-1600 Protection Alarms for the Refueling Level and Pressure Detectors, Setup and Calibration OP-1601 Refueling Main Coolant Level Channel Calibration Operation OP-1602 Operation of Refueling Nuclear Channels

s . OP-1603 Low Range Loop Fill Pressure Channel Calibration and Operation OP-1604 Removal of the Protection Alarms for the Refueling Level and Pressure Detectors OP-1700 Core XII Reactor Refueling and Component Inspection OP-1701 Core XII BOL Zero Power Physics Test Procedure OP-1703 Core XI-XII Refueling, Shroud Tube Inspection AP-2002 Operations Department Personnel Shift Relief AP-2005 Operations Department Surveillance Schedule During Power Operation OP-2116 System / Component Pressure / Leak Test OP-2130 startup and Cut-in of an Isolated Loop AP-2476 Establishing and Maintcining Normal Vapor Container Pressure OP-2601 Operation of the PAB/SFP/WDB Ventilation Exhaust System OP-2000.21 Changeover to the New PAB/SPFB/WDB Exhaust and VC Purge System OP-2000.22 Preoperational and Acceptance Testing of the Filtered Ventilation Exhaust and VC Purge System OP-3254 Total Loss of AC - Plant in a Cold Shutdown Condition and Integrity of MC System not Established OP-3300 Local Emergency Procedure OP-3301 Site Emergency Procedure OP-3302 General Emergency Procedure OP-3303 Emergency Off-Site Radiation Monitoring OP-3770 Temporary Loop Seal Radiation Monitoring Channel OP-4210 Fire Pump Operability Test OP-4224 Control Valve Exercise OP-4515 Operating Test of Primary Protection Relays OP-4519 Station Battery Capacity Test Battery No. OP-4601 Nuclear Instrumentation Surveillance Check

. OP-4607 MC Flow Trip System Calibration OP-4608 Main Coolant Flow Channel Calibration Loop No. OP-4616 SI Tank Electronics Level Indication Channel Calibration LT-SI-7, LI-SI-7 and ELA/LLA-SI-7 OP-4617 SI Loop Pressure Instrument Calibration SI-PI-OP-4624 Control Rod Drive System Interlock Surveillance Check OP-4627 Pressurizer Narrow Range Level Calibration OP-4629 Pressurizer Pressure Channel Calibration OP-4633 Nuclear Instrumentation Surveillance During Extended Plant Shutdowns OP-4700 Vapor Container Continuous Leak Rate Monitoring OP-4703 Control Rod Drop Time Measurement OP-5201 Main Coolant Stop Valve Motor Operator Maintenance OP-5210 Inspection of Pressurizer Internals OP-5217 Closing of the Steam Generator Primary Manways (Welded Diaphragns) OP-5218 Opening of the Steam Generator Primary Manways (Welded Diaphragms) OP-5762 Checking and Setting Plant Protective Relaying OP-5000.25 Conoseal Gasket Cauging OP-5000.27 Installation of Indicating Fuses, Removal of Auto Tie Danction and Testing on No.1 and 2 Battery Chargers OP-6105 I & C Department Hydrostatic Pressure Test OP-6601 Calibration of Area Gamma Alarm Unit No. OP-6000.46 Installation and Testing of the Primary Auxiliary Systems Instrumentation Sensing Line Changes OP-6000.47 Installation and Testing of the Diesel Fuel Oil Level Control System Electrical Connection Change OP-6000.48 Reconnecting the D/P MC Flow Trip System

. OP-1504 dovement of Control and Shim Rods to VC OP-1514 Reactor Upper Core Barrel and Plates - Replacement OP-1605 Temporary Pressurizer Level Channel Calibration and Operation CP-1700 Core XII Reactor Refueling and Component Inspection OP-1000.17 Core XI-XII Refueling Core Unloading OP-2100 Plant Startup from Cold Shutdown OP-2101 Plant Startup from Hot Standby or Hot Shutdown OP-2103 Reactor Startup and Shutdown OP-2104 Scheduled Plant Shutdown to Hot Standby or Hot Shutdown OP-2158 Establishment of Hydrogen Blanket Gas on the Low Pressure Surge Tank OP-2169 Return of Charging and Bleed Line to Service After Maintenance OP-2380 Operation of the Waste Disposal Evaporator Syste a OP-2388 Degassing of the Waste Gas System for Valve Diaphragm Replacement CP-2478 Operation of the VC Purge System OP-2000.23 Ir.stallation and Operational Testing af the VC Booster Pan OP-3015 Plant Actions in the Event of a Security Emergency Alert or Instrusion Alarm OP-3117 Refueling Accidents OP-3304 Emergency Equipment Readiness Check OP-4200 Main Coolant System Leak / Hydro Test and Inspection OP-4214 Chemical Shutdown System Check OP-4225 Throttle valve Surveillance Test OP-4234 Low Pressure Surge Tank Safety Valve Testing AP-5000 Maintenance Department Surveillance Schedule OP-5108 Dissassembly and Inspection of Grinnell Hydraulic Suppressors OP-5000.28 Installation of the Emergency Diesel Generator Control Circuit Undervoltage Alarn OP-5000.29 Steam Generator Primary Manway Modification OP-5000.30 Removal and Replacement of Reactor Core Holddown Ring OP-5000.32 Dividing the Electrical Feeders to the Main Coolant Cutout Valves OP-5000.33 Shearing of Flux Tubeo H-2 and K-6 OP-5000.34 Special Inspection of MOV Wiring OP-5000.35 Installation of Hot Leg Injection System AP-6004 Evaluation of I 6 C Department Equipment Failures OP-6201 Calibration of Th NR Channels OP-6454 Safety Inj ection Tank (TK-28) Low Temperature Alarm Switch (LTS-223) Calibration OP-6559 Calibration of the Loop Seal Inlet High Level Switch (HLS-313) OP-7202 Handling and Inspection of New Control or Shim Rods OP-7000.9 Neutron Monitoring Test in SFP AP-8004 Self-F.aading Dosimeter Records OP-8305 Radioactive Source Inventory and Leak Testing OP-8000.2 Preparation Calibration and Testing of the Primary Vent Stack Monitor, (EDCR 74-11) OP-9406 Primary Plant Sample Points OP-9415 Radioactive Gas Sampling OP-9000.1 Chemical Flushing of Control Rod Drive Housings OP-6000.49 SI Accumulator Level Switch (LS-6) Replacement OP-6000.50 Installation and Testing of the Rod Position Indicating Light Change OP-7iO3 Eddy Current Examination and Repair of Steam Generator No. OP-7000.9 Neutron Monitoring Test in SFP

. OP-8600 Quality Assurance Prog. n for Contracted Radiological Environmental Analysis OP-9246 Radioactive Liquid Releases and Reports OP-6101 Nuclear Instrumentation and Reactor Protection System Precritical Check AP-8002 Control of Chemistry and Health Physics Incoming QA Documents OP-80CO.2 Preparational Calibration and Testing of the Primary Vent Stack Monitor, (EDCR 74-1) AP-9001 Primary Chemistry Test Frequencies and Specifications OP-9000.1 Chemical Flushing of Control Rod Drive Housings OP-0400.1 Pre-Acceptance Check of the Guard Alert Il Security Check OP-1202 Supplemental Locked Valve List for Refueling OP-1702 Core XII Zero to Full Power Physics Test Procelure OP-2101 Plant Startup from Hot Standby or Hot Shutdown OP-2171 Blended Makeup to the Low Pressure Surge Tank with the Safety Injection Tank out of Service OP-2375 Liquid Transfer from the LPST OP-2383 Burning of Solid Combustible Waste OP-2386 Re??asing Radioactive Waste Gases from the Waste Gas Surge Drum to Atmosphere OP-2000.22 Preoperational and Acceptance Testing of the Filtered Ventilation Exhaust and VC Purge System OP-3006 Environmental Flooding Conditions OP-3016 In Plant Flooding Condition OP-3105 Emergency Boron Injection OP-3308 Re-Entry and Recovery Plan OP-3755 Emergency Diesel Generator DC Control Circuit Loss of DC Supply OP-4606 Main Coolant Flow Trip System Surveillance Check OP-4703 Control Rod Drop Time Measurement

4 OP-4000.4 Type C Test of TV-212 (VC Mercury Manometer) OP-5002 Maintenance Department Corrective and Preventive Maintenance Program OP-5600 Maintenance of Waste cas Compressor C OP-5000.36 Installation of Modfifications to Prevent ECCS Single Failure OP-5000.37 Emergency Diesel Generator Intake Louvre and Auto-Fuel System Circuit Modifications AP-6005 I & C Department Unanticipated Mon-Routine Corrective Maintenance on Safety Related Equipment D. Surveillance Tests and Inspections required by the Technical Specifications were satisfactorily completed during the report period with the following exceptions: See attached table. E. Containment Leak Tests 1. The following Class "B" tests were performed according to procedure OP-4702, " Vapor Container Type B & C Penetration Tests", during the report period: a. Attachment "W" - VC Personnel Hatch, Test was satisfactorily completed 8/14/75. b. On November 24, 1975 the VC Purge System 30 inch Inlet Line, BV-4-1, was tested according to Attachment T. The line upstream of BV-4-1 was blank flanged and pressurized to 32 psig between the flange and BV-4-1. The pressure decay was monitored for one hour. The observed leakage satisfied the criterion of the nominal leakage rate. c. On November 24, 1975 the VC Air Purge System 30 inch Outlet Line, BV-4-2, was tested according to Attachment U. The line upstream of BV-4-2 was blank flanged and pressurized to 32 psig between the flange and BV-4-2. The pressure decay was monitored for one hour. The observed leakage satisfied the criterion of the nominal leakage rate. 2. On December 3, 1975, the Electrical Penetrations were tested in accordance with OP-4702, " Vapor Container Type B & C Penetration Tests" Attachment S.

. 3. The following Class "C" tests were performed according to procedure OP-4702, " Vapor Container Type B & C Penetration Tests", during the report period: a. Attachment "Q" - VC Drain Line Trip Valve (TV-209), Test was satisfactorily completed on 8/4/75. b. Attacament "J" - Main Coolant Vent Header Trip Valve (TV-203), Test was satisfactorily completed on 8/19/75. c. Attachment "V"- Eight Inch Air Purge Bypass (HCV-602), Test was satisfactorily completed on 8/19/75. d. On Novenber 21, 1975, the VC service water return isolation valve, TV-408, was tested according to Attachment C. The line upstream of TV-408 was isolated and pressurized to 32 psig. The pressure decay was monitored for 10 minutes. The observed leakage satisfied the criterion of the nominal leakage rate. e. On November 21, 1975, che VC Open Bulb Leak Monitoring System Trip Valve, TV-211, was tested according to Attachment H. The line upstream of TV-211 was isolated and pressurized to 32 psig. The pressure decay was monitored for 5 minutes. The observed leakage satisfied the criterion of the nominal leakage rate. f. On November 22, 1975, the Valve Stem Leak-off, TV-204, was tested according to Attachment I. The line upstream of TV-204 was isolated and pressurized to 32 psig. The pressure decay was monitored for 5 minutes. The observed leakage satisfied the criterion of the nominal leakage rate. g. On November 21, 1975, the Component Cooling Returns Header Trip Valve, TV-205, was tested according to Attachment O. The line upstream of TV-205 was isolated, drained, and pressurized to 32 psig. The pressure decay was monitored for 15 minutes. The observed leakage satisfied the criterion of the nominal leakage rate. h. On November 24, 975, the Low Pressure Surge Tank and Line, TV-213, was tested according Low Pressure Sat a to Attacht;..t :. The system upstream of TV-213 was isolated and pressurized to 32 psig. The pressure decay was monitored for 6 hours. The observed leakage satisfied the criterion of the nominal leakage rate.

.s . 1. On November 22, 1975, the ECCS Recirculation Header Isolation Valves, PU-MOV-543 and 544, were tested according to Attachmentt R. The line upstream of FU-MOV-543 and 544 was blank flanged and pressurized between the flange and valves to 32 psig. The pressure decay was monitored for 30 minutes. The observed leakage satisfied the criterion of the nominal rate. j. On November 26, 1975, the Post Accident Hydrogen Vent System Solenoid Operated Valves, HC-SOV-1 and 2, were tested according to Attachment Y. The line upstream UC-SOV-1 and 2 was isolated and pressurized to 32 psig. The pressure decay was monitored and observed leakage was satisfactory. k. On November 29, 1975, the VC Heating System Trip Valve, TV-409, was tested according to Attachment K. The line upstream of TV-409 was isolated and pressurized to 32 psig. The pressure decay was monitored for one hour. The observed leakage did not satisfy the nominal leakage and the valve was in the process of repair at the end of the report period. 1. On December 1, 1975, the VC Heating System Trip Valve, TV-409, was retested according to Attachment K. The line upstream of TV-409 was isolated and pressurized to 32 psig. The wessure decay was monitored for one hour. The observed leakage satisfied the criterion of the nominal leakage rate. m. On December 2, 1975, the Vapor Container Open Bulb Leak Monitoring Trip Valve, TV-211, was tested according to Attachment H. The line upstream and downstream of TV-211 was solated and pressurized to 32 psig. The pressure decay was monitored for 5 minutes. The observed leakage satisfied the criterion of the nominal leakage rate. n. On December 2, 1975, the Vapor Container Service Water Return Isolation Valve, TV-408, was tested according to Attachment C. The system upstream of TV-408 was isolated and pressurized to 32 psig. The pressure decay was monitored for 10 minutes. The observed leakage satisfied the criterion of the nominal leakage rate.

. o. On December 3, 1975, the Steam Generator Blowdown Line Trip Valves TV-401A, 401B, 401C and 401D, were tested according to Attachment N. The lines to the blowdown tank were isolated and the sample valves lined up to the sample sink. When flow vas established the trip valves were shut and the leakage was collected for one hour. The observed leakage satisfied the criterion of the nominal leakage rate. p. On December 3, 1975, the VC Drain Line Trip Valve. TV-209 was tested according to Attachment Q. The line between VD-V-755 and TV-209 was isolated, drained and pressurized to 32 psig. The pressure decay was monitored for 5 minutes. The observed leakage satisfied the criterion of the nominal leakage rate. F. Tests and Experiments 1. The following Tests or experiments requiring authorization from the Commission were performed: None 2. The following tests or experiments not requiring authorization from the Commission were performed: Core XII BOL Physics Testing was completed during the a. report period. The purpose of this testing was to measure various coefficients and parameters at low power level to verify nuclear design calculations utilized for analyzing plant transient and accidents and to provide such coefficients and parameters for routine plant operation. G. The following plant key staff changes were made during the report period: Effective December 1,1975, Norman N. St.Laurent is the Assistant Plant Superintendent and James L. Staub is the Technical Assistant to the Plant Superintendent. II. Power Generation See attached table and six month histogram. III. Shutdowns See attached table. IV. Corrective Maintenance Summary See attached table.

. V. Primary Coolant Chemistry See attached table. VI. Occupational Personnel Radiation Exposure Sce attached table. VII Abnormal Occurrences A. Report Number 50-29/75-6

Title:

Failure of the Vapor Container Drain Line Trip Valve to Fully Close Occurrence Date: July 25, 1975 Description of Occurrence: At approximately 1300 on July 25, 1975, during preparations for a Class C leak test in the Vapor Container Drain Line Trip Valve, TV-209, the valve failed to fully close. B. Report Number 50-29/75-7

Title:

Weld Crack in No.3 Charging Pump Relief Valve l'azzle Occurrence Date: August 7, 1975 Description of Occurrence: On August 7, 1975, at approximately 1930 the auxiliary operator observed that a crack had developed in the No. 3 charging pump relief talve nozzle just above the flange connection to the charging p,- discharge line. No. 1 charging pump was put on service and No. 3 charging pump was shutdown and isolated. C. Report Number 50-29/75-8

Title:

Vapor Container Leakage Occurrence Date: August 15, 1975 Description of Occurrence: During normal operation Containment Leakage Monitoring Data indicated vapor container leakage in excess of the calculated allowable limits. Leak was located on a blind flange in the upper pipe chase connected to the Low Pressure Vent Header.

. D. Report Number: 50-29/75-09

Title:

No. 1 Emergency Diesel Generator Contrcl Circuit Failure Occurrence Date: September 6, 1975 Description of Occurrence: At 0720 on September 6, 1975, the Control Room Operator noted that the supervisory light for No. 1 Emergency Diesel Generator Starting Circuit was out. The operator attempted to start the No. 1 Emergency Diesel but was unsuccessful. Iurther investigation revealed that the DC Control Circuitry Supervisoty light outside the No. 1 Diesel Generator Cubicle had failed and was fused to its socket. E.

Title:

Abnormal Degradation of No. 1 and 4 Steam Generator Tubes Occurrence Date: November 7, 1975 Desc.ription of Occurrence: During evaluation of data collected by Eddy Current Examination of No. 1 and 4 Steam Generator tubes, degradation in excess of the acceptance limits of Regulatory Guide 1.83, June 1974, Inservice Inspection of Pressurized Water Reactor Steam Generator Tubes, was found. F. Report Number: 50-29/75-11

Title:

Failure of Vapor Container Trip Valve Solenoids SOV-432 and SOV-433 to Operate Occurrence Date: November 8, 1975 Description of Occurrence: During a routine refut1_ ig surveillance test, two apparatus Service Company Model WPX-8310bF Solenoid operated valves failed to operate upon receiving containment isolation signal. G. Report Number 50-29/75-12

Title:

Pressurizer Wide Range Level Scram Instrument Se*. point Drift Occurrence Date: November 13, 1975 Description of Occurrence: During the performance of OP-4626, " Pressurizer Wide Range Level Calibration", the high level scram bistable setpoint was found to be greater than the Technical Specification Limit of 200 inches by an Instrument and Control Technician. The I & C Supervisor was notifiedd and the bistable readj usted. H. Report Number 50-29/75-13

Title:

Failure of Safety Injection Accumulator Solenoid Pilot Valve (SPV-56) to Operate Occurrence Date: November 20, 1975 Description of Occurrence: During the performance of OP-6455,

. " Safety Inj ection Accumulator Level Switch Operational Check", it was noted that SPV-56 did not operate, by an Instrumentation and Control Technician. The I & C Supervisor was notified and an open solenoid was found in the valve. I. Report Namber 50/29-75-14

Title:

Vapor Container Electrical Penetration Excessive Leakage Occurrence Date: November 24, 1975 Description of Occurrence: During the routine Type B penetration testing excessive outward leakage was detected from penetration No. 14 in blister 1.o. 10 of the Vapor Container. The leakage was traced to a cracked MI cable gland nut. J, Report Number: 50-29/75-15

Title:

Failure of Hydraulic Shock Suppressors to Pass Surveillance Test occurrence Date: November 25, 1975 Description of Occurrence: During routine surveillance testing or the hydraulic shock suppressors by the uanufacturer for proper stroke, lock-up and bleed, a number of suppressors failed to meet the manufacturer's acceptance criteria. K. Report Number: 50-29/75-16

Title:

Excessive Leakage from the Vapor Container Trip Valve, TV-409 Occurrence Date: November 29, 1975 Description of Occurrence: During the routine Type C Containment Isolation Valve Surveillance testing excessive leakage was detected from isolation valve TV-409, Vapor Container Heating System Return Header Isolation Trip Valve. Further investigation revealed that the valve seating surface had degraded. L. Report Number: 50-20/75-17

Title:

Loop No. 1 Main Coolant Valve Interlock Instrument Setpoint Drift Occurrence Date: December 4, 1975 Description of Occurrence: During a routine calibration check o f t he "o. 1 loop wide range cold leg temperature indicator, the bistable setruint was found to exceed the Technical Specification limit. The bistable was readjusted to a more conservative point to preclude exceeding the limit should the instrument drift again.

. M. Report Number 50-29/75-18

Title:

Nuclear Instrumentation, Channel 5 Cabling Occurrence Date: December 15, 1975 Description of Occurrence: During EOL Physics Testing Channel 5 Intermediate Range Detector was co!.nected to Channel 3 Intermediate Range Channel which was connected te the Reactivity Computer. As the power level was increased the indication decreased. At this time, the rods were dropped into the core to bring the reactor subcritical. Further investigation revealed that the positive and negative leads from the detector were reversed at the junction box. VIII. Special A. Surveillance 1. No. 1 startup rate Bistable lamp was found to be burnt out during the Nuclear Instrumentation surveillance check. The bulb was replaced and the surveillance check was repeated with satisfactory results. 2. During thc calibration check of tb Process Radiation Monitor, the instrument failed to properly source check. The monitor required electronic parts replacement after trouble shooting. The radiation monitor performed satisfactorily during its retect. 3. TV-209, Vapor Container Drain Line Trip Valve, failed to close during preparations to perform Attachment Q of the Class C containment test. A corrosion buildup was discovered and removed from between the valve disc linkage and the pin hinging the linkage to the valve body. During the retest TV-209 operated satisfactorily. 4. No. 1 Steam Generator's Low Level Alarm Indication was found to be defective during the S/G NR Level trip System surveillance check. At the end of this report period, proper plant conditions have not existed to allow the bulb replacement. 5. No.1 Steam Generator's Low Level Alarm Indication was reported to have failed its surveillance test in the last report. During this report period, the proper plant conditions were met repeated with satisfactory results. 6. A blank flange on a line on the Low Pressure Vent Header was found to be loose resulting in a higher than normal leak rate during VC continuous leak rate monitoring. The flange was tightened and a satisfactory leak rate risulted. 7. During the Nuclear Instrumentation Surveillance Check, a faulty light bulb was found and replaced. The retest of the Nuclear Instrumentation System

  • i satisfactory.

. 8. The S/G NR Level Trip system railed to function properly during its surveillance check. Troubleshooting disclosed a faulty photo-diode and when it was replaced the resulting retest was satisfactory. 9. The weekly inspection of the station batteries indicated low cell specific gravities because a discharge capacity test had recently been conducted. After sufficient charging time had elapsed all the cell specific gravities had returned to normal. 10. During the performance of OP-4533, "NI Check During Extended Plant Shutdowns", the 60 Hz check of the Channel 2 indicated low. The channel was adjusted to the correct value and the surveillance check was continued with satisfactory results. 11. During the VC class C tests TV-409 failed to seat properly. Subsequent investigation revealed erosion of the seating surfaces. At the end of this report period, repair of the valve is in progress. 12. TV-409 was reported to have failed its leakage surveillance test in the last report. During this report period, the valve was repaired and the surveillance test was rerur. with satisfactory results. IX. EFFLUENT AND WASTE DISPOSAL See attached Table

s SURVEILLMiCE TEST AND INSPECTION DISCREPANCIES TABLE 1.D

SURVEILLANCE TESTS AND INSPECTIONS DISCREPANCIES TABLE 1.D DATE TEST DESCRIPTION DISCREPANCY AOR NO. RESOLUTION 7/21/75 Nuclear Instrumentation Surveillance

  1. 1 Startup Rate B/S Lamp Replaced light bulb and reper-Check Defective formed surveillance check with l

satisfactory results. 7/21/75 S/G NR Level Trip System Surveillance #1 S/G Low Level Alana Awaiting proper plant condi-Check Indication Defective tions to perform light bulb replacement. 7/23/75 Calibration Check of Process Radia-Failed to Source Check Trouble Shot and repairs made. tion Monitor Performed surveillance check with satisfactory res ilts. 7/25/75 Vapor Container Class "C" Test TV-209 Failed to Close 50-29/75-06 Repaired TV-209 and re-ran Attachment Q. Attachment Q of surveillance with satisfactory results. 8/15/ 75 Vapor Container Continuous Leak Rate Leak on blank flange on a 50-29/75-8 Tightened blank flange. Monitoring low pressure vent header line 8/20/75 Nuclear Instrumentation Su'rycillance Burnt out light bulb Replaced light bulb. Check 8/20/75 S/G NR Level Trip System Surveillance Photo-diode defective Replaced photo-diode. Check i 10/30/75 Weekly Inspection of the Station Low specifig gravities Gravities returned to proper Batteries values after sufficient charging time. 10/30/75 NI Check During Extended Plant Low reading 'on 60 Ifz test Adjusted 6011z adjustment. Shutdowns

SURVEILLANCE TESTS AND INSPECTIONS DISCREPANCIES TABLE 1.D DATE TEST DESCRIPTION DISCREPANCY AOR NO. RESOLUTION 11/1/75 IIPS1 Pump Discharge Pressure Instru-As Found indication and Ma Adjusted during calibration ment Calibration out of tolerance 11/1/75 LPSI Ileader Flow Instrument Calibra-As Found indication out of Adjusted during calibration tion tolerance 11/3/75 SI Accumulator Pressure Instrument As Found indication oct of Adjusted during calibration Calibration tolerance 11/11/75 V.C. Trip Valve Valves failed to close 75-11 Repaired valves 11/12/75 BC Pressure Channel Calibration As Found scran and SI B/S Adjusted during calibration were high 11/14/75 SI Loop Flow Inst. Calibration As Found data out of Adjusted during calibration tolerance 'i/17-18/75 Main Coolant Flow Primary Channel Loops 1, 2 and 3 As Found Adjusted during calibration Calibration Data out of tolerance 11/17-18/75 S/G NR Level irip System Calibration As Found data out of Adjucted during calibration tolerance 11/20/75 Removal and Test of Pressuri cr Code As Found relief setting too Adjasted setting Safety Valves high 11/24/75 Pressurizer h'R Level Channel Calibra-As Found high lever scram 75-12 Adjusted during calibration tion B/S set too aigh 11/25/75 Pressuri:er NR Level As Found readings out of Adjusted during calibration tolerance 11/29/75 IIPSI Pump Ammeter Calibration

  1. 1 As Found Data out of Adjusted during calibration tolerance

SURVEILLANCE TESTS AND INSPECTIONS DISCREPANCIES TABLE 1.D DATE TEST DESCRIPTION DISCREPANCY AOR NO. RESOLUTION 11/29/75 Vapor Container Class C Test - TV-409 failed to seat 75-16 Repairs in progress Attachmenc K properly 12/3/75 Safety Injection Loop Flow Instru-Loop #3 and 4 As Found Readjusted during calibration ment Calit'ation indication out of tolerance 12/5/75 Nuclear Instrumentation Surveillance Intermediate range alana Readjusted during calibration Check bistable out of tolerance 12/10/75 Nuclear Instrumentation and Reactor Channel 2 Scram, Channel 3 Readjusted during calibration. Protection System Precritical Check SUR alarm and Channel 8 Low Power Scram Setpoints out of tolerance

5 0 POWER GENERATION TABLE II

j POWER GENER\\ TION TABLE II July Auaus t s-tr+n r October thvembe r % ne'cr T01AL Gross Thermal I'wer Generated (MWh) 437,041.300 474,170,7g} 367.377.63u 192,490.090 0 12 E S,1 4 an 4.020.82 U 19 _ Gross Electrical Power Generated (MWh) 137,724,600 137,949,60L 113,752,000 59,438.0 0 39.041,300 T,771,105,300 Nunber of flours Reactor Critical 744 744 720 419.c8 0 473.50 7,392.48 Nur.her of !!ours Generator on Line 744 744 720 415.08 0 319.75 7,214.13 Net Electrical Power Generated (MWh) 129,5S0.653 124,850.699 106,233.706-55,277.13 0 35,926,546 1,193.419,764 t 'l 1 S i i l I C

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2 PLANT SHUTDOWNS TABLE III

PLANT SilUTDOWNS TABLE III F1ETi!0D OF PLANT DURATION SilUTTING STA1US DATE (110URS) CAUSE OF OUTAGE DOWN REACTOR DURING CORRECTIVE ACTION OUTAGE 10/18/75 1,458.12 The plant was shutdown for scheduled blanually controlled Cooled down and None Core XI-XII refueling. deliberate shutdown de-pressurized condition 12/18/75 7.23 T-1 Air Break overheated due to hfanual llot Standby Cleaned air break improper contact. 12/25/75 1.92 Excessive Valve Steam Leak-off from blanua l ifot Standby Plugged steam leak PR-F10V-191 - off line 12/27/75 3.65 Line fault on Z-126 Line F!anual Reactor Scram liot Shutdown None 12/28/75 3.25 Line fault on 2-126 Line Auto Reactor Scram liot Shutdown None (Low S/G Level

CORRECTIVE MAINTENANCE

SUMMARY

TABLE IV

CORRECTIVE tRI!TILNANCE SGM\\RY TABLE IV.1 MAINTENANCE DEPARTMENT e I EFFECT ON CORRECTIVE ACTION TAKEN SYSTBf CmPONE?R CAUSE RESULT SAFE OPERATION E PREVFAT REPETITION Charging Charging Pump Bad plug Minute leak flone None Flow Transmitte - Aux. Steam TV-405 Deteriorated valve Leaked None None Charging CH-V-611 Deteriorated Seat Leaked by None None Safety CS-V-668 Insufficiently Minute leak None Ncne Injection seated bonnet. Safety CS-V-621 Bad gasket Minute leak None None Injection Safety

  1. 3 LPSI Pump Worn packing Excessive packing None None Injection leakage Safety S I-SV-55 Deteriorated seatin(I Leaks by None None Injection surfaces 4ain Coolant MC-M0V-302 Limit switch out of Valve would not close None None adjustment all the way afety
  2. 1 LPSI pump Worn packing Excessive packing None None njection leaking team
  3. 2 Steam loose u-bolt clamps Noisy None Torqued new u-bolt nuts to 200't enerating Generator lbs and tack welded nuts ressurizer PR-MOV-191 Shorted contacts Damaged Operator None None team 43 Steam Loose u-bo? t clamps Noisy None Torqued new u-bolt nuts to enerating Generator 200 ft-lbs and tack welded nuts.

team

  1. 1 Steam Loose u-bolt clamps Noisy None Torqued new u-bolt nuts to enerating Generator 2001,f t-lbs and tack welded nuts.
  2. 89% 89O

CORRECTIVE MAIhTENANCE S13 NARY TABLE IV.2 MAINTENANCE DEPARTMENT IO.N e EFFECT ON CORREGIVE AGION TAKEN SYSITN Ca!PONENI' CAUSE RESlJi,T SAFE OPERATION TD PREVENT REPETITION Steam

  1. 4 Steam Loose u-bolt clamps Noisy None Torqued new u-bolt nuts to Generating Generator 200 f t-lbs and tack welded nut!

Chemical CS-bOV-540 Unknown Restricted flow None None Shutdown Main Cool' ant MC-M0V-326 Hard grease buildup Increased drag while None None opening Pressurizer Surge Line Pipe Not centered Uneven stresses None None Hanger Charging CH-M0V-523 Bad Bearing Would not close None None electrically. Charging CH-MOV-526 Improper fitting Would 'not close 'None None gate electrically Safety

  1. 1 HPSI Pump Worn Seal Gland leaked None None Injection Pressuri zer PR-MOV-191 Deteriorated gasket Gasket leaked

. None None Safety

  1. 1 HPSI Pump Loose elbow Leaked None None Injection Gland Seal Cooler Outlet Line Auxili ary AS 'l-6 38 Worn packing Leaked None None Steam Feed B F-V-659 Nut galled to stud Damaged Stud None None Safety
  2. 1 LPSI Pump Worn packing Excessive leak-off None None Injection 9

e #ee 8_e

00RRFLTIVE MARTENANCE Sh41ARY TAI;LE IV.3 MAltlTENANCE DEPARTMENT ION EFFECT ON CORRECTIVE ACTION TAKEN SYSTEM CatPONENT CAUSE RESULT SAFE OPERATION 'ID PREVENT REPETITION Safety Inject-MOV-309, 507 & Worn and insuffi-Leaked Ilone None ion & Loop 538 ciently compmssed Drain packing Nitrogen ilS-V-16, SI-V-Deteriorated seats Leaked by None None Safety Inject-74, SI-V-620, and discs ion & Chehical 621 and 77 Shutdown SC-V-660 Safety Inject-S I-V-22 Insufficiently Leaked None None ion seated bonnet Vent & Drain VD-V-732 Deteriorated seat Leaked by None None and disc Vent & Drain VD-MOV-508 Deteriorated seat Leaked by None None and disc Vent & Drain VD-MOV-505 Deteriorated seat & Leaked None None disc & packing Main Steam NR-405B Unknown - Damaged stud None None Feed & Bleed Vari-ori fice Deteriorated in-Improper operation None None ternals ECCS Auto T/0 SwitchVSRI Relay Noisy operation None None

  1. 2 deteriorated Charging CH-SV-214 Deteriorated Leaked None None gasket Main Steam MS-V-625V Deteriorated Leaked None None Valve

~ Charging CH-SV-209 Deteriorated seat Leaked by None None and disc O-4 8 es.

CORRECTIVE MAI.,4ENANCE

SUMMARY

TABLE IV.4 MAlfNENANCEDEPARTMENT MALFUNCTION EFFECT ON CORRECTIVE ACTION TAKEN SYSTEM COMPONENT CAUSE i RESULT SAFE 0'PERATION TO PREVENT REPETITION 'ress ui rzer Pressuri zer Insufficient seal Minute oil leak None None Code S.V. Line between vent & body Shock Absorbers threads HSS-23 & 24 'ress uri zer MOV-509 Insufficient packinc Stem Leak None None compression s )iesel Generator Diesel Starting Shorted light bulb Blown fuse in None None Ci rcuit starting circuit Charging 43 Charging Pump Crack in flange Leak None None itelief Valve weld Electrical AC B-BT3B Overload Burnt out None None Distribution overload device Electrical Vital Bus Faulty thyrite Low readings .None None Distribution Control Cab. resistor and zener diode Charging

  1. 1 Charging Foreign object Damaged windings None None Pump I

l i 6/?~r

i, CORRECTIVE MAUTTENANCE SlM!ARY TABLE IV.5 MAINTENANCE DE'ARTMENT m GION EFFECT ON CORRECTIVE ACTION TAKDi SYSTDI COMPONDir CAUSE RESULT SAFE OPEPATION 'ID PREVEYr REPETITION Electrical Blister #10 Cracked gland nut Leaks None None Penetration #14 Charging

  1. 3 Charging Worn valves and Leaks None None Pump packing Feed
  2. 4 Feedwater Deteriorated pipe Leaked None None Line Vent J Drain VD-V-750B Worn packing Leaked None None Control Rod
  3. 17 Control Ro<l Deteriorated coil Grounded None None Lift Coil Charging
  4. 1 Charging Deteriorated "0" Lea,ked None None Pump Ring 4

6 0 r.191 / K1

CORREC TIVE MAIN rENANCE SU! NARY TABLE IV,6 I&C MALFUNCTION EFFECT CN CORRECTIVE ACTION TAK3N SYSTEM COMPONENT CAUSE RESULT SAFE OPERK/ ION TO PREVENT REPETITICN Safety Injectio 1 SI Tk Low Alarm set too high Alarm actuated None None Level Alarm at. normal level Safety Injectiol #3 Diesel Defective gauge Oscillations of None t'one Generator Oil gauge Gauge Reactor

  1. 1 S/G NR Burned out light Los Level Alarm None None Protection Level Alarm Continuous Vapor Container TV-209 Defective packing Valve leaked by None None and dirty disc and seat Reactor
  2. 4 S/G NR Defective Alarm Low Alarm Light None None Protection Level Trip Light On System Signal Safety Injection SI-V-82 Sample Dirt on seat Leaked by None None Valve 6''

CORRECTIVE MAINTENANCE

SUMMARY

TABLE IV.7 I G C Department MALFUNCTION EFFECT ON CORRECTIVE ACTION TAKEN SYSTEM COMPONENT CAUSE RESULT SAFE OPERATION TO PREVENT REPETITION Safety

  1. 2 Loop SI Defective Ampli-Incorrect None None Inj ect ion Flow Trans-fier PC Board Operation mitter G Strain Gage Primary Charging Defective Improper None None Auxiliary Pump Disch.

Bourdon Tube _ Operation Pressure Linkage Transmitter Vapor TV-209 Stuck Plug Valve Would None None Container Not Close Safety LPSI Accumu-Misadjusted Erratic High/ None None Inj ection lator High/ Pressure Low Pressure Low Press. Regulator Alarm Alarm Reactor S/G NR Level Defective Photo No fligh Alarm None None Protection Trip System Diode Operation No. 3 Safety SI-V-82 Sample Dirt on Seat Valve 1 caked by None None Injection Valve / 6/7'/7/.

CORRECTIVE 3'._NTENANCE

SUMMARY

r TABLE IV.8 ISC DEPARTMENT MALFUNCTION SY'JTEM COMPONENT CAUSE i RESULT SAFE OPERATION TO PREVENT REPETITION EFFECT ON CORRECTIVE ACTION TAKEN afety Injection

  1. 1 Loop Fitting insufficient. Leak Pressure ly seated.'

None None Transmi tter afety Injection S P-V- 56 Open Coil Valve failed to None None operate

uclear Thintle #1 Defective cable Noisy None None ns trumentation luclear Nuclear Recorder Dirty Slide wire Pen failed to None None ns trumentation operate

'ri ma ry Pzr. WR Level Defective comp. Pos;ible cause None None ' switch of scram ' rima ry Pzr. Pressure Out of calibration hcorrect None None MC Pressure indication Ind. MCB teactor S/B NR Level Defective feedback No response None None 'rotection Trip Sys. #1 link Transmi tter Indication Cont. 'rimary Th NR 4 amp High Pot defective Erratic operation None None 1 (,/ 7 ' ! ? ?

CORRECTIVE MuhTENANCE SlNMARY TABl.E IV. 9 I & C DEPARTMENT ION EFFECT ON CORRECTIVE ACTION TAKEN SYSTF14 OMMENT CAUSE RESULT SAFE OPERATION TO PRE'MNT REPETIT'ON Main Steam TV-404 Deteriorated plug Leaked by None None and seat Main Steam TV-410 Deteriorated plug Leaked by .None None and seat Nuclear inst. Thimble #7 Defective cables Channel 5 erratic None None Feedwater

  1. 2 & 3 WR Dirty Slidewire S ticks None None Level brush & follower sleeve Feed & Bleed Vari-ori fice Out of calibration Improper operation None None Nuclear Inst.

Channel #2 Defectiva electron Improper operation None None tube Component TV-205 Defective gasket Leaked None None Cooling Main Steam TV-411 Deteriorated plug Leaked by None None and seat Nuclear Inst. Thintle #3 Defective detector Improper oper& tion None None and cables Nuclear Inst. Channel #5 Unknown Drops in level Ncne None indication Nuclear Inst. Thimble #6 Defective Cables Improper operation None None Main Coolant

  1. 3 Loop AP cell Defective Tee Leaked None None Service Water TV-408 Deteriorated plug Leaked by None None and seat Nitrogen Piping Tee defective Tee Minute leak None None 6/11 7.a

' CORRECTIVE MAINTD4ANCE SIDNARY TAllLE IV.10 I&C DI:PARTMENT ON EFFECT ON CORRECTIVE ACTION TAKEN s SYSTBI CQ4PONENT CAUSE RESULT SAFE OPERATION 'IU PREVENT REPETITION Feedwater

  1. 3 Feedwater worn packing Leaked excessi ve'.y.

None None reg. valve Safety N2 Regulator Out of adjustment Maintained pressure None None Injection too high i Main Coolant Press arizer WR Insuffi cient. Thread Minute leak None None Level Transmit-Seal ter Steam G2nera-TV-401B Deteriorated plug Leaked by None None tor and seat VC Pressure TV-ill Worn plug and seat Leaked by None None Sensing VC Drain TV-209 Deteriorated plug Leaked by None None and seat Charging Flow Meter Cracked weld Minute leak None None Heating & TV-409 Deteriorated plug Leaked by None None Cooli ng and seat Nuclear Inst Channel 1 Defective tubes Could not calibrate Nor,e None Incore IC T/C D-8 Broken Connector Improper operation None None ICI K-6 Thimble Cracked transition Leaked None None weld ICI i!-2 Thimble Cracked transition Leaked None None lj weld { Safety

  1. 2 Loop Flow AP Defective Threads Minute leak None None i

Injection Cell Isolation Valve

c. r,, r,

PRIMARY C00UA'T CllEMISTRY TABL? V

I 8 l l l l 1 i, l i i l I I ll4 l' + + _ - - +. ~ _~ _.+_._ i ~ } l Il l ll,

i..

3 ~! I i l l i I l. l r l' i 'j l l t i 1 ! l l ll l r l I l,' l i l! i1 i i i i I l I l il E l 1 ! ,i _.! -_ .L i l i l . ' f l s 4 s. j l l m- ~ l ll l fll I .d E W 555l :0881 8 5 8; '5 5 8. M I" ! n~~ 555 ' d go l !kk.k 'Skb kkk kkki.Nkk kkk lEk i k.

k k!

,4 ~ ~. mnn = = ame m o ~j any 4

77; 7;

llll -~ --o !!I il l ll l fI l lll l l ll l l' ul ll' i l lc og I i i ul . "u EGE OE G{ to8 $ 0%25& SOE ! 'E U ' 7, 'IS ~~~ 1 h g g.kbk kN,h, Nk$ kkk f'" 5 =: -my .J 4 = Jwy ;yl gq; -f m- "9l[ lulI! lllJ l! l ,l f li* i9 :

=

I ! f'_l_.1' { ll l l! l lII !l l ll l

  • 55Y 555 l555 !555 l l55' l'553 dl !

j5 8 5 5 5 5' 5 5 5 8 8;8: l l 3 * ' 9 9 5 e.,b M

"
R9. 9 99 999 99 9'

.B ": ~. *, ;99 9. M ":9 ' 9." 9 : ~- e-m-m, m.,

- ~. ; u m, ~

.m 3.- ;,--- v

== ~ lll l! l l ll l l l { l l lll ' 8 l l O l l 'i,. ,l !!IiI i;i I l f tEGO 553 ;555 "o 5 0'o l 00 c. ooo ---. --- ooo Saaa laaa Id44 :44 4 44 s @@@, E i-M@d @@Q Ysi !ocg $h -j yMa ta!2 :~.as ps,s.,.e -.cIll,s4 li Ill!! iill! j M.-.,7 ;./ 7;,, l l: ai d.l ~ 9 it lli lill ill !i y l l Illll: li!il I il ll l'l!'!li!!'1! l - 2 5,55 l350'558 SE E :55 5.-- .? a '-- 555 o I ,hkkk kkk kkkn kkk {k9k I.O.k sk l 0.gMk. ikk k kkk; gggM99l e o t - -- ; aa m ,u m - muu t-llllI ' i ! !~! l I l l l I l l n-w~ uml nl 1lI l)D)!))) l'lj l i o, R$ b!$ 'NS$ ; EB Ej 00 ;E E 55,,55.5 3.l l5 E:2 BEE EE E i $ $ $! $ $ dl $ $ $, !8M8 ,A '88k ;SE N; N ESE 5: he 555 88'8 f O,,a M I H W Rl ry ;;4 L q... u.a _a _ _._,~ 4 4 p y fj p " # '4l4 e W4s d3 f.l.l ) I. ]. a .l. e :l: =:

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s.

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r E

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m i

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aj a

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aiimi, i ii i

u I ' {' g ~= h. ' ! c' '..s. l 8I W i i L ij6 i t e l j3i 1 ~,,P !, l l c. - 7 I ,d . i. i, pLI E,, lSI h =,' il I 3o l D, l)a {, !b f ( !. I Y*- I.+. r i i .e m {m' t; 3 j a' 8 }- i 15 '2 0 !a {. :3 ,9 i.- i g,,, 4 ! ! il Iw i4;!F, Ie i l, ;. ! P l ! i s i l Pi ! j R '. er Dff D 90 W k ) E"R. A j]

OCCUPATI01\\L PERSONNEL RADIATION EXPOSURE TABL.E VI 4 ma ma LJ % La u Q J UQ

a TABLE VI.a OCCUPATIO4AL RADIATION EXPOSURE

SUMMARY

eJ 100-250-500-750-Personnel N.H.E. <100 250 500 750 1000 1-2 2-3 3-4 4-5 5-6 >6 Category mrem mrem mrem mrem mrem Rem Rem Rem Rem Rem Rem Permanent 21 6 7 17 12 8 23 3 0 0 0 0 Temporary 878 57 13 14 7 9 21 13 0 0 0 0

  • No Measurable Exposure A tabulation is attached listing the number of personnel receiving more than 3 Rem in the calendar year and the major cause(s) thereof.

All exposures in excess of 500 mrem during the six month period are tabulated on the attached page(s). A table of reference symbols for the major duty functions of the tabulation is as follows: Symbol Duty Function A I Routine surveillance and inspection (normal operation) B Routine maintenance C Special maintenance (describe below**) D i Routine refueling operation E Special refueling operatici. (describe below) F Other job relat'ed activities (describe below**)

    • Additional Description of Duty Functions C.1 Primary Ccolant Pump Repairs l
2. Core Hold Down Spring Replacement
3. Steam Generator Feed Ring Repairs F.1, Waste Processing i

EXPOSURES IN EXCESS OF 500 Mrem TABLE VI.b Total mrem per duty function

  • Personnel Exposure Number Job Assignment (in Ren)

A B C D E F 1. Training Coord. 1.531 92 2 0 8 0 0 2. Tech. Asst. 1.488. 97 0 0 3 0 0 3. Tech. Ass t. 1.093 94 0 0 6 0 0 4. Tes ter .615 34 8 0 53 0 5 5. Eng. Ass t. .653 55 10 0 22 0 13 6. Plant H.P. .818 92 0 0 8 0 0 7. I&C Tech. .799 1 95 0 4 0 0 8. I&C Tech. .736 5 88 6 1 0 0 9. I&C Tech. .876 18 68 13 1 0 0 10. I&C Tech 1.014 6 91 0 3 0 0 11. Tes ter 1.193 58 3 10 22 0 8 12. Eng. Asst. 1.642 59 22 5 14 0 0 13. Elec. Supv. .65' 49 6 16 29 0 0 14. Mech. Supv. .937 51 12 21 17 0 2 15. Plant Mechanic 1. 30 2 60 21 7 12 0 0 16. Plant Electrician .560 41 25 29 5 0 0 17. Plant Mechanic 1.783 7 40 29 23 0 5 18. Eng. Asst. 1.695 15 39 4 44 0 0 19. Plant Mechanir .805 2 49 30 19 0 0 20. Plant Mechanic 2.387 2 14 63 17 0 3

21. -

Plant Electrician 1.400 1 29 67 4 0 0 22. Plant Mechanic 2.024 57 17 24 2 0 0 23. 1 Plant Mechanic 1.137 17 74 2 6 0 1 24. Plant Mechanic 2.467 37 25 20 14 0 4 ( Described on previous page

5j3j7,

i EXPOSURES IN EXCESS OF 500 Mrem TABLE VI.b Total Personnel mrem per duty function

  • Exposure Number Job Assignment (in Rem)

A B C D E F 25. Plant Mechanic 1.475 1 42 41 16 0 1 26. Plant Mechanic 1.841 58 17 17 6 0 3 27. Plant Electrician .694 7 8 84 1 0 0 28. Aux. Oper. 1.115 26 2 3 28 0 42 29. Cont. Rm. Oper. .614 55 5 0 38 0 2 30. Aux. Oper. .594 25 2 0 ~6 0 68 31. Aux. Oper. 1.054 37 2 4 27 0 30 1 32. Aux. Oper. 1.136 50 4 0 38 0 8 33. Aux. Oper. .5/4 46 8 0 25 0 21 34. Con t. Rm. Oper. 1.008 40 6 0 38 0 15 35. Shift Supv. 1.180 45 19 0 18 0 18 36. Aux. Oper. .848 48 5 1 29 0 17 37. Shif t Supv. .587 64 0 0 36 0 1 38. Cont. Rm. Oper. 1.239 27 9 3 60 0 1 1 39. Cont. Rn. Oper. .761 39 26 0 24 0 16 ~ 40. Cont. Rm. Oper. .582 75 13 0 10 0 2 41. Cont. Rm. Oper. .500 59 2 0 7 0 32 42. Cont. Rm. Oper. 1.017 49 1 13 26 0 11 43. Aux. Oper. .684 13 6 0 35 0 46 44. Reactor Eng. 1.726 94 2 0 4 0 45. Tech. Ass t. - 1.083 88 7 1 3 0 1 46. Tech. Asst. 1.610 88 7 0 5 0 0 t 47. Contractor 1.733 100 0 0 0 0 0 48. Contracter .636 0 100 0 0 0 0 Described on previous page 4/3/7J

1 EXPOSURES IN EXCt!SS OF 500 Mrem TABLE VI.b u Total mrem per duty function

  • Personnel Exposure Number Job Assignment (in Rem)

A B C D E F . 49. Contractor .674 1 00 0 0 0 0 0 50. Contractor .808 0 142 0 93 0 5 51. Contractor .890 11 0 0 89 0 0 52. Con tractor 1.184 31 0 0 69 0 0 53. Contractor .626 18 0 5 77 0 0 54. Contractor .925 14 0 3 83 0 0 55. Contractor 1.599 39 0 0 61 0 l 0 56. Contractor 1.136 18 0 0 82 0 0 I 57. Con tractor .665 1 99 0 0 0 0 58. Contractor 1.956 1 0 0 6 0 92 59. Contractor .803 0 11 0 8 0 81 60. Con tractor .665 2 0 0 0 0 98 61. Contractor 1.326 0 0 0 0 0 100 62. Contractor .6 30 88 2 0 10 0 0 63. Contractor .773 67 2 0 41 0 0 64. Contractor .710 64 8 0 28 0 0 65. Contractor 2.128 89 2 3 8 0 0 65. Contractor 2.235 47 53 5 0 0 0 67. Contractor

1. 800 64 28 0

8 0 0 68. Contractor 1.849 79 9 5 7 0 0 69. Contractor 1.747 42 26 13 18 0 0 70. Contractor 2.163 72 1 17 10 0 0 71. Contractor 2.133 90 5 0 2 0 3 t 7.2. Contractor 2.194 43 14 21 18 0 3 Described on previous page

EXPOSURES IN EXCESS OF 500 Mrem TABLE VI.o Total mrem per duty function

  • Personnel Exposure Number Job Assignment (in Reml A

B C D E F 73. Contractor 1.923 26 30 21 20 0 0 74. Contractor

1. 730 62 18 13 2

0 5 75. Contractor 1.055 53 47 0 4 0 0 76. Contractor .6 86 0 49 49 2 0 0 77. Contractor 2.111 70 15 10 4 0 0 78. Contractor 2.260 58 38 5 0 0 4 79. Contractor 2.004 34 48 0 17 0 1 80. Contractor

1. 86 3 25 31 29 13 0

3 81. Contractor 1. 809 27 27 26 19 0 2 82. Contractor 2.202 74 13 0 8 0 5 83. Contractor 2.020 53 19 0 22 0 0 84. Contractor 1.511 51 16 1 31 0 3 85. Contractor 2.174 59 23 0 15 0 3 86. Contractor 2.132 23 71 3 4 0 0 i 87. Con tracto:- 2.205 36 16 27 21 0 0 f 88. Contractor .651 14 24 54 2 0 0 89. Contractor 1.307 68 26 2 4 0 0 90. Contractor .735 14 29 55 1 0 0 91. Con tractor 1.218 61 2d 1 15 0 1 92. Contractor

1. 280 3

22 79 3 0 0 3, 9 3. - Contractor 1.904 61 18 11 9 0 1 t 94. Cont'ractor 1.796 55 28 3 14 0 1 95. Contractor 1.366 72 25 12 1 0 0 96. Contractor .790 1 99 0 1 0 0 Described on previous page 4/3/_e,

ANNUAL EXPOSURE TABULATION No. Number of Personnel whose annual exposur is 2 2.5 REM for the calendar year 1975 2 Major Causes: 1. Refueling Outage. 2. Inservice Inspection Program

EFFLUENT AND WASTE DISPOSAL Table IX

Yankee Atomic Electric Company, Rowe, Mass. Effluent and Waste Disposal Supplemental Information 1. Technical Specifications Limits a. Fission and Activation Annual average <1000 times ?@C Gases: as described in 10 CFR 20, Appendix B, Table 2, Column 1. b. Iodines: Annual average <1.43 times MPC as described in 10 CFR 20, c. Particulates Appendix B, Table 2, Column 1. (T 1/2 >8 Days) Annual average <l.43 times !!PC as described in 10 CFR 20, Appendiy B, Table 2, Column 1. d. Liquids Isoto'>ic limits found in 10 CFR 20, Appendix B, Table 2, Column 2. 2. Maximum Permissible Concentrations 4 a. Fission 6 Activation No MPC Limit Reporting Limits as Gases Specified in 10 CFR 20 (20.403) and (20.405) b. Iodines c. Particulates (T 1/2 >8 Days) d. Liquid Effluents 10 CFR 20, App. B, Table II, Col. 2

3. Average Energy of Fission and Activation Cases Releases. (3rd) quarter E8 = 0.25 Mev., EV = 0.23 Mev. (4th) quarter ES = 0.17 Mev., Ey = 0.05 Mev. 4. Measurements and approximations of total act ivity. a. Fission and Activation Gases " Continuous Discharges" - Indirect Measurement Primary gas samples are taken neriodically and analyzed. Assumptions: That in primary '.o secondary leakage all gases are ejected through the air ejector. In primary coolant charging pump leakage all gases are ejected to the primary vent stack either during flashing or liquid wa te,rocessing. " Batch Discharges" - Direct Measurement. b. Iodines: Continuous monitoring, sample draen from the primary vent stack through a particulate filter and charcoal cartridge, the filter and charcoal cartridge are removed weckly. c. Particulates: The particulate filter as described in (b) above is analyzed weekly. d. Liquid effluents - Direct Measurement Compositing for Sr 89, 90; Alpha and Carbon-14 Analysis. No compositing for Beta, Tritium and Dissolved Gases. y isotopic analysis (Resin Method) - compositing for continuous discharges and no compositing for batch discharges. 5. Additional Information: 1. Refueling outage Oct. 18 - Dec. 18, 1975 2. New Vent Stack Ventilation System Operational Nov. 12, 1975.

i SUPPLEMENTAL INFORMATION ERROR ESTIMATIONS - LIQUIDS I - Errors Associated with Volumes Discharge a. Blowdown = 130% b. Test Tank = 13% II.* Errors Associated with Counting a. Isotopic Analysis Maximum = ! 20'. (Resin Method) b. Tritium = 1 10's c. Dissolve Fission Gases = ! 15% d. Alpha Analysis = 1 10'. Maximum counting error was deternined by co'::parison of cross check sample data with that of Teledyne, N.R.C. and E.P. A. results. l Fission + Activation Products About equal amounts discharge = via blowdown + test tanks E= (30)2. (3)2 + (20)2 = 1309 = i N 3 6 *. Tritium

95's discharge via test tanks (3)2 E

(10) 110. 9'a 109 + = = Dis,olve Fission Gases = About equal amounts discharge via blowdown and test tanks. E= (30)2 + (3)2 + (15)2 1234 = ! 35% = Apha = About equal amounts discharge via blowdown and test tanks. E= (30)2 + 3) + (10) 1009 = 1 32% = I

i SUPPLEMENTAL INFORR\\ TION ERROR ESTIMATION - GASES I. Errors Associated with volumes discharge Charging pump Icakage = 1 10% a. b. Primary to secondary leak race = ! 30'. Sample volume for batch discharges = ! 25% c. d. For Iodines and particulates volume fluctuation at primary vent stack = ! IOS. Error of uncertainty that gases at sampling is at equilibrium c. during the entire period = ! 50% f. Fluctuation of volume at tritiura samples = ! 25'. II.* Errors associated with counting Fission and activation gases - isotopic analysis = 1 15% a. b. Iodines analysis = ! 20'. Particulates - isotopic analysis = ! 25% c. d. Tritium analysis = + 10'.

  • Maximum counting error was determined by comparison of cross check sample data from that of Teledyne, and NRC results.

Fission + Actuation Cases = About 95*. discharge via charging pump leakage (50)2 + (19)2 + (15) E= 2825 =

  • 53's

= Iodine] E= (10) + (20) 500 = _+ 22.5% = Particulates E= (10)2 + (25) 725 = + 27% =

1 SUPPLEMENTAL INFORMATION ERROR ESTIMATION - GASES (CONTINUED) Tritium E= (25)2 + (10)2 725 =I 2 7'. =

TABLE lA EFFLUENT AND WASTE DISPOSAL SEMIANNUAL REPORT 1975 GASEOUS EFFLUE.\\TS - SUSDIATION OF ALL RELEASES YANKEE RONE Unit Quarter l Quarter Est. Total 3rd [ 4th

Error, S.

A. Fission 6 activation gases 1. Total release Ci 5.96E00 8.60E00 5.5E01

2. Average celease rate for period pCi 'sec 7.67E-01 1.07E00 3.

Percent of technical specification limit 96 1.12E-01 3.85E-02 B. Iodines

1. Total iodi ne-131 Ci 7.05E-04 1.15E-03 2.5E01
2. Averare release rate for period pCi/sec 9.06E-05 1.43E-04
3. Percent of technical specification lirait 96 3.81E00 9.17E00 C. Particulates
1. Particulates with half-lives >8 days Ci 9.39E-05 7.82E-03 3.0E01
2. Average release rate for period pCi/sec 1.21E-05 9.74E-04 3.

Percent of technical specification limit 96 3.36E-01 8.96E00

4. fiross alpha radioactiv'ity Ci 9.06E-06 4.63E-05 D. Tritium
1. Total release Ci 1.83E-01 8.54E-01 3.0E01
2. Average release rate for period pLi/sec 2.35E-02 1.06E-01 C Percent of technical specification limit

?e 1.61E-03 4.76E-03 4

TABLE IB liFFLUlXI A:,0 L'ASI E DI SI'0".Al. SL:.:1 A.,t UAL Imi' ORT 9M m a .g p GASFOUS EFFEUENTS w w au o IM 3 (all gaseous effluents are considered as ground level release by Tech. Spec.) CO.'UINUQUS :.:JDE BATCil !:0DE fiuclides Eeleased Unit Qua rt er Quarter Quarter Quarter 3rd 4th 3rd 4th

1. Fir.sion gases k rypt on - S5 Ci 1.97E-02 6.0SE-03 4.49E-03 2.66E00 k ryy_t ca-2.5:a C1
4. 511.-62 S. 54E 03 6.60F nz 157L L L ryp t oit-S 7

(: t 3. 4 2 E - O i' __ _!. 41E-02

6. 3 8h0.3__

1.551L-03_ k rypt on - S b I Ci (;. o h E - 0. 1,43p_02 1,jyg __gy_ _,,_3,;;;;_ p, - yenon-133 Ci 3.72E00 1.29E00 ' 76r-02 ,___ L 3g g gq____ xenon - 1.i5 C2 6.b7E-01 1.35F-01 ?.141!-02 5.77E-02 xenon-13En Ci 6.llE-01 9.36E-02 1.S3E-03 a.89E 04 Aenon-l.E Ci

1. 3.Ili- 0 2 3.65} -03 2.61E-03 5.805-04 5.46E-0.

3.19E-02 1.23E-03 8.36E 03 Xenon-133;f ri ~ j.T4fi-05 y.16E-04 6.19fi-03 5.24E-01 Arron - 37 r; Arcon-11 ci 2.98E-01 5.09E-02 7.21E-02 .6tE-03 Carbon-14 I CL,LL_1.g_p3 1.63E-03 1.0SE-03 ___1.56E00 Rubidium-89 C 1 _j 2.02E-01 18.94E-02 1.62E-O' d.64E-03 unident ) fi(d Ci l l 'J a t.a l 101 period Cl] 5.73E00 1.74E00 2.29E-01

6. 831iO O_

7, inainne E) dine-131 C-_ l 6'L-U4 -1. 6 0 E - 0 4 5.77E-06 6.90E-04 i odj nd-133 Ci 4.0bE-04 i3.92F-05 3.04E-05 5J8F-05 iodine-I h Ci 7.50E-05

12. 96 E -O f>

1,53E-06 4.4!F-06 'J otal fer period Ci 0.67E-01 '!5.02E-04 3.77E-05 7.50E-04

3. l' art.iculates stront i u a-S9 Ci 9.11E-07 1.78E-06 1.86E-09 2.66E-06 s t ronti t -90 C1 4.77EJ'R

,2.22E-07 9J.4-10 3 ;;F 07 c e r. i u.:'- 13 d Ci < 3. 52E-07 I4.72E 06 < S 00F-09 7_ DP -0; ceritN l M Ci 2.44E 06 < 8.31F-09 3_._6.61i- 0 6 Ci_t'e 4. 03E-07 < 7.2SE-07 < 1.34E-07 < LjP.lli-R6._-- barium i uithanuu-140 l l< 9.02E-07 Ti6!ill-53 6 Ci I 1.37E-06 5.16E 04 .L_S_0ji- 03_._.J. 74 E.01_ Cobalt-60 [ Ci 7.01E-05 1.19E 03 1.43U-06 . _. _1,] 9_E - 91__ 1ron-50 Ci < S.44 E-07

1. 651_QJ

< 1.12E- 0_L_ _.__2, 4 7 F - 01 Chronian-31 Ci Ll.82E-05 9.2sE-04 _ _L ] 2Ji-E _ __ L I L g1__ _ lir_coniup.-}'iobiun 95 Ci 7__._7_7_]i- 0 7 .LO31:. - 04 _L 5 9" - 07 -__L 521E _0 L_. ___L. 65 E- 09._.. -_521EdM--.) Se1eniun-75 Ci _._.l. 2PJi.0 Z___ LCLO6 Si1ver.I10'f Ci 4_. 41 E_- Os__. < L 52E D6 0 14E-fF- _s.6.33L O '.-. Antincav-124 Ci < 8, 8_2E - 0 7 2J L O; - __1_. 6 L OS__ _ _ LaLOS.- .\\ianvanese,54 ___. C i _ L 20F-0; L 626_f_4 _7 16F 07 ._ ' M F _ 0.L__. J" C1 Ci } C uni &ntified C1 I [_ - _-] 4 l j 1.0fE-01 {f..#[f. - 01 {3T231-03 _ { 4. 91 E-({l ] Witiua ~ ~ ~ ~Ci

TABLE 2A EFFLUENT AND WASTE DISPOSAL SEMIANNUAL REPORT 1975 LIQUID EFFLUENTS - SU.\\MATION OF ALL RELEASES YANKEE RONE Unit Quarter Quarter Est. Total 3rd 4th Error, % A. Fission and activation products

1. Total relecse (not including tritium, gases, alyha)

Ci 3.49E-03 3.94E-03 4.0E01

2. Average diluted concentration during period LCi/ml 5.09E-11 1.53E.10
3. Percent of applicable limit 1.51E-03 1.44E-02 B. Tritium
1. Total release Ci 7.81E01 5.43E01 1.0E01
2. Average diluted concentration during

~ period pCi/ml 1.14E-06 2.11E-06

3. Percent of applicable limit 3.80E-02 7.03E-02 C. Dissolved and entrained gases
1. Total release Ci 9.40E-02 9.86E-02 3.5E01
2. Average diluted concentration during period pCi/ml 1.37E-09 3.84E-09
3. Percent of applicable limit 4.5/b-UZ 1.28E-01 D. Gross alpha radioactivity
1. Total release Ci 2.97E-06

<1.63E-06 3.0E01 E. Volume of waste released (prior to dilution) liters 3.96E06 3.03E06 3.0E01 F. Volume of dilution water used during period liters 6.85E10 2.57E10 5.0E00

e TABLE 2B EFFLUENT AND h'ASTE DISTOSAL SD11L'NUAL REPORr 1975 LIQUID EFFLUENTS YANKEE R0h'E CON Flh'UQUS >RJE BATCil MODE Nuclides Released Unit Quarter Qu <ter Quarter Quarter 3rd 4th 3rd 4th strontium-89 Ci <l.02E-03 <1.67E-04 <1.65E-04 <1.60E-04 strontiuu-90 Ci <6.81E-05 <2.33E-05 <l.10E-05 <l.60E-05 cesiun-134 Ci 1.23E-07 1.69E-04 8.06E-05 3.48E-04 cesium-137 C1 1.7oE-Ob 1.58E-01 h.48E-05

3..'3 E- 04 iodine-131 Ci 1.52E-05 1.18E-04 S.80E-05 8.38E-04 cobalt-58 Ci 5.67E-04 1.77E-06 2.41E-06 7.39E-05 cobalt-60 Ci 5.81E-06 4.61F-06 1.60E-05 1.48E-04 iroa-59 Ci 2.53E-07 2.57E-06 1.76E-06 4.07E-05 zinc-65 Ci

<2.07E-06 <l.37E-06 <4.77E-06 <l.81E-05 nanfanese-54 Ci 2.91E-08 3.23E-07 1.83E-05 2.02E-04 chromium-51 Ci '4.09E-06 4.66E-06 1.10E-05 2.35E-04 zirconium-niobium-95 Ci 1.01E-07 5.66E-06 1.8SE-06 4.63E-05 nolybdenun-n Ci <4.28E-06 '3.6_7E-06 2.06F-05 '4.74E-05 technetium-99m Ci 1.09E-07 '4.20E-07 <1.34E-06 <5.96E-06 barium-lanthanum-140 Ci 2.36E-07 <2.39E-06 <8.18E-06 3.66E-05 cerium-141 C1 3.52E-07 <9.17E-07 <2.29E-06 1.99E-06 Other (specify) Ci Iodine-133 Ci i 2.05E-06 3.09E-05 1.77E-06 5.24E-06 Selenium-75 Ci 2.15E-07 <6.81t-07 <2.30E-06 <8.45E-06 Silver-110M Ci 1.15E-07 ' 5. 94 ti - 07 <9.66E-06 1.20E-05 Antimony-124 Ci 2.15E-07 <7.74E-07 <4.48E-06 3.03E-05 ~ Carbon-14 Ci 1.82E-05 5.08E-00 2.55E-03 1.12E-03 Cerium-144 Ci 4.03E-07 <2.12E-06 <9.43E-06 6.00E-06 unidcatified j Ci 1.53E-06 <7.80E-co Total for period (above) Ci 6.14E-04 4.70E-04 2.88E-03 3.47E-03 xenon-133 Ci <l.60E-03 <3.66E-04 9.35E-02 9.86E-02 xenon-13a Ci '7*03U-"' 'l#-" 7 0 L - "

  • dE-03
Tritin, Ci 2.83E-01 7.99E-02 7.79E+01 5.42E+01

a TABLE 3 EFFLUEN1 AND liASTE DISPOSAL SE;tIAN';U.\\L PEPORT 1975 SOLID liASTE AND IlutADIATED FUEL Si!INENTS YANKEE RCWE A. SOLID h'ASTE.S!!IPPED OFFSITE FOR EURIAL CR DISPOSAL (Not irradiated fuel) 6-month Est. Total 1. Type of waste Unit l'e riod Error, 6

a. Spent resins, filter sludges, evaporator n3 4.7E01 bottons, etc.

Ci 1.0E00 3.0E01 b.Drycohiressibicwaste,contaninated 3 1.52E02 ~ n equip, etc. Ci 2.0E-01

c. Irradiated components, control 3

n one rods, etc. 01 m 7.lE00 a 3.0E01

d. Other (describe)

Ci 7.lE-01 m3 3.8E00 8'OE01 + c. Contaminated Soil Ci 1.6E-2

2. Estimate of major nuclide composition (by type of waste)

^ a. Evaporator Bottoms - Cesium-134 8.6E00 Cesium-137 's 8.0E00 Cobalt-58 1.3E01 Cobalt-60 t 3.lE01 Iron-59 5.8E00 Manganese-54 g 2.lE01 Chronmium-51 g. /.9tuu b. Dry Waste Cobalt-58 '6 2.2E01 Coba11-60 t 3.1E01 Silver-110M i 4.7E01 c. Decontaminated Sol.- Cobalt-58 1.6E01 a; Cobalt-60 6.3E01 Manganese-54 5.7E00 g d. Contaminated Soil - Cobalt-60 8.0E01 'e 6

3. Solid Waste Disposition 1lunber of Shipments Mode of Transportation Destination 6

Truck Moorhead, Ky. B. IRRADIATED FilEL S!!IPMENTS (Disposition) Number of Shipments Mode of Transportation Destination None ---}}

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