ML19351A009

Amend 1 to License NPF-8,incorporating App a Tech Specs Re Radiological Environ Monitoring

ML19351A009
Person / Time
Site:	Farley
Issue date:	06/15/1981
From:	Youngblood B Office of Nuclear Reactor Regulation
To:
Shared Package
ML19351A010	List: ML19351A009 ML19351A011 ML19351A012
References
NUDOCS 8106240327
Download: ML19351A009 (39)

Text

I 3.n aseoq UNITED STATES

.' 8 t

f,j NUCLEAR REGULATORY COMMISSION r,

a wAsHWGTON, O. C. 20555

't,..... sd ALABAMA POWER COMPANY p)s

\\_

DOCKET NO. 50-364 JOSEPH M. FARLEY NUCLEAR PLANT, UNIT 2 FACILITY OPERATING LICENSE Amendment No. 1 License No. NPF-8 a

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Alabama Power Company (the licensee),

dated May 5,1981, complies with ti;e standards and requirements af the Atomic Energy Act of 1954, as amended (the Act) and the Commission's regulations set forth in 10 CFR Chap *,er I; B.

The facility will operate in conformity with the license, as amended, the provisions of the Act, and the regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance cf this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

9106 24 0j),'}f

c-0 . 2. Accordingly, the license is amended by enanges to the Technical Specifications as indicated in the attachment to this license amendment. Facility Operating License No. NPF-8 is hereby amended to read as follows: (2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No.1, are hereby incorporated into this license. The licensee shall operatt the facility in accordance with the Technical Specifications. 3. This license amendment was effective May 6,1981. FOR THE NUCLEAR REGULATORY COMMISSION [$0ttt" LW/ i i B. J Youngb ood, Chief Licensing Branch No.1 Division of Licensing Date of Issuance: JUN 151981 Enclusure: Revh ' pages to Appendix A Technical Specifications 9

4 ATTACHMENT TO LICENSE AMENDMENT NO. 1 FACILITY uPERATING LICENSE NPF-8 DOCKET NO. 50-364 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change. PAGE REVISIONS 3/4 8-4 3/4 8-5 PAGE CHANGES FOR TYP0 GRAPHICAL ERRORS XII 3/4 3-39 3/4 3-60a 3/4 4-13 3/4 4-17 3/4 4-34 3/4 7-3 3/4 7-13 3/a 7-52 3/4 8-20 3/4 8-22 3/4 8-24 3/4 8-25 3/4 8-26 3/4 8-28 3/4 8-31 3/4 9-16 6-22 f I I' L +

r. INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.11 RADIOACTIVE EFFLUENTS 3/4.11.1 LIQUID EFFLUENTS Concentration............................................ 3/4 11-1 0ose..................................................... 3/4 11-5 Liquid Wasta Treatment................................... 3/4 11-6 Liquid Holdup Tanks...................................... 3/4 11-7 3/4.11.2 GASEOUS EFFLUENTS Dose Rate................................................ 3/4 11-8 Dose-Noble Gases............. 3/4 11-12 Dose-Radioiodines, Particulate, and Radionuclides Other than Noble Gases................... 3/4 11-13 Gas eou s Radwas te Trea tment............................... 3/4 11-14 Explosive Gas Mixture....................ll.............. 3/4 11-15 Gas Storage Tanks........................................ 3/4 11-16 3/4.11.3 RA0 WASTE SOLIDIFICATION.................................. 3/4 11-17 3/4.11.4 TOTAL 00SE............................................... 3/4 11-19 3/4.12 RADIOLOGICAL ENVIRONMENTAL MONITORING 3/4.12.1 MONITORING PR0 GRAM...................................... 3/4 12-1 3/4.12.2 LAND USE CENSUS....................................... 3/4 12-10 3/4.12.3 INTERLABORATORY COMPARISON...................... 3/4 12-11 FARLEY-UNIT 2-XI

o'- INDEX BASES-SECTION PAGE 3/4.0 APPLICABILITY............................................... B 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTR0L......................................... B 3/4 1-1 3/4.1.2 B0 RATION SYSTEMS......................................... B 3/4 1-2 3/4.1.3 MOVABLE CONTROL ASSEMBLIES............................... B 3/4 1-3 3/4.2 POWER'0ISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX 0!FFERENCE.................................... B 3/4 2-1 3/4.2.2 and 3/4.2.3 HEAT FLl[X and NUCLEAR ENTHALPY HOT CHANNEL FACT 0RS................................................. B 3/4 2-2 3/4.2.4 QUADRANT POWER TILT RATI0.'............................... B 3/4 2-5 3/4.2.5 DNB PARAMETERS........................................... B 3/4 2-5 3/4.3 INSTRUMENTATION 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM and ENGINEERED SAFETY FEATURE . ACTUATION SYSTEM INSTRUMENTATION..................... B 3/4 3-1 3/4.3.3 MONITORING INSTRUMENTATION............................... B 3/4 3-2 1 3/4.3.4 TURBINE OVERSPEED PROTECTION............................. B 3/4 3-5 l 3/4.4 REACTOR COOLANT SYSTEM 1 l 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT C1^CULATION............ B 3/4 4-1 3/4.4.2 and 3/4.4.3 SAFETY VALVES.................................. B 3/4 4-2 3/4.4.4 PRESSURIZER.............................................. B 3/4 4-2 ' 3/4.4.5 RELIEF VALVES...................................... B 3/4 4-2 FARLEY-UNIT.2 XII Amendment No. 1

~. TABLE 3.3-6 RADIATION MONITORING INSTRUMENTATION 2$ MINIMUM C CHANNELS APPLICABLE ALARM / TRIP MEASUREMENT y INSTRUMENT OPERABLE MODES SETPOINT RANGE ACTION [ 1. AREA MONITORS a. Fuel Storage Pool 1 (a) $ 15 mR/hr 10-1 4 -10 mR/hr 23 Area (R-5) b. Containment Area (R-27A&B) 2 1,2,3,4 N/A 1 - 10 R/hr '27a 2. PROCESS MONITORS a. Fuel Storage Pool Area Gaseous Activity-Ventilation System -3 6 Isolation (R-25A&B) 1 (b) 1 8.73 x 10 Ci/cc(c) 10-10 cpm 25 b. Containment i' i. Gaseous Activity-U a) Purge & Exhaust Isolation (R-24A&B) 1 1,2,3 (d) 1 2.27 x 10.2 pCi/cc(c) 10-10 cpm 26 6 4,5,6 (d) 1 2.27 x 10_3 pd /cc(c). 26 1,2,3,4,5,6 (e) 1 4.54 x 10-3 pCi/cc(c) 26 1,2,3,4,5,6 (f) 1 2.27 x 10 pCi/cc(c) 26 6 b) RCS Leakage 1 1,2,3 & 4 N/A 10-10 cp, 24 y Detection (R-12) m R ii. Particulate Activity 6 2 RCS Leakage 1 1,2,3 & 4 N/A 10-10 cpm 24' 5 Detection (R-ll) z c. Control Room 6 Isolation (R35A&B) 1 1,2,3 & 4 and 1 800 cpm 10-10 cp, 27 during movement of irradiated fuel or movement of loads over irradiated fuel i

TABLE 3.3-12 FIRE DETECTION INSTRUMENTATION (Continued) - Auxiliary Building Total Minimum Room / Smoke of Operable Fire Zone Description Elevation Detectors Smoke Detectors 2401 Control Room 155'-0" 4 2 2452 Storage Area 155'0" .7 4 2462 Non-Radioactive Vent Equip. 155'-0" 5 3 Rm. 2466 West Cable Chase 155'-0" 7 4 - 2471 Control Rm. (Instrument 155'-0" 12 6 Racks) 2500 West Cable Chase 168'-2" 7 4 Containment

• 55 Containment Coolers 155'-9" 12/ Fan 6/ Fan 55 Containment 155'-0" 14 7

Scrvice Water Intake Structure 72 A Pump Room Area 188'-9" 12 6 4 72 A Strainer Bay 167'-0" 12 6 72 8 dwitchgear Room - Train B 188'-9" 2 1 72 C Foyer - Train B 188'-9" 1 1 72 0 Foyer - Train A 188'-9"- 1 1 72 E Switchgear Room - Train A 138'-9" 2 1 73 Battery Room - Train B 188'-9" 1 1 .74 Batt ry.~oun - Train A 188'-9" 1 1 Diesel Generator Building ~~ 56 A Switchgear Room - Train A 155'-0" 12 6 56 B Foyer 155'-0" 4 2 56 C Switchgear Room - Train B 155'-0" 12 6 71 Hallway 155'-0" 9 5 Diesel Generator Building (Heat Detectors) 57 Diesel Driven Generator 2C 155'-0" 5 3 59 Diesel Driven Generator 28 155'-0" 5 3 60 Diesel Driven Generator 1C 155'-0" 5 3 61 Diesel Driven Generator 1-2A 155'-0" 5 3 i 62 Day Tank Room 155'-0" 1 1 64 Day Tank Room 155'-0" 1 1 ~ 65 Day Tank Room 155'-0" 1 1 66 Day Tank Room 155'-0" 1 1 - ^The Fire Detection instruments located within the Containment are not required to be OPERABLE during the performance of Tyoe A Containment Leakage Rate Tests. FARLEY-UNIT 2 3/4 3-60a Amendment No.1

s REACTOR ' COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued) v ~ 9. Preservice Inspection means an inspection of the full length of ' each-tube in each steam generator performed by eddy-current - techniques prior to service to establish a baseline condition of the. tubing. This inspection shall be performed after the field' hydrostatic test and prior'to initial POWER OPERATION using the equipment _and techniques expected to be used during subsequent. . inservice inspections. b. The steam generator shall be determined OPERABLE after completing the corrasponding actions (plug all tubes exceeding the plugging limit and all tubes containing through-wall cracks) required by Table 4.4-2. 4.4.6.5 Reports Following each inservice inspection of steam generator tubes, the a. number of tubes plugged in each steam generator shall be reported to the Commission within 15 days. b. The complete results of the steam generator tube inservice inspection shall be submitted to the Commission in a Special Report pursuant to Soecification 6.9.2 within 12 months following the completion of the inspection. This Special Report shall include: 1. Number and extent of tubes inspected. 2. Location and percent of wall-thickness penetration for each indication of an imperfection. 3. Identification of tubes plugged. c. Results of steam generator tube inspections which fall into Category C-3 and require prompt notification of the Commission shall be repcrted pursuant to Specification 6.9.1 prior to resumption of plant operation. The written followup of this report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrence. FARLEY-UNIT 2 3/4 4-13 Amendment No. 1

TABLE 4.4-1 MINIMUM NUM8ER OE STEAM GENERATORS TO BE INSPECTED DURING INSERVICE INSPECTION No. of Steam Generators per Unit Three First Inservice Inspection Two Second & Subsequent Inservice Inspections One*

• The other steam generator not inspected during the first inservice inspection shall be reinspected. The third and subsequent inspections may be limited to one steam generator on a rotating schedule encompassing 3 N % of the tubes (where N is the number of steam generators in the plant) if-the results of the first or previous inspections indicate that all steam generators are performing in a like manner.

Note that under some circumstances, the operating conditions in one or more steam generators may be found to be more severe than those in other steam generators. Under such circumstances the same sequence shall be modified to inspect the most severe conditions. ~ e 4 e FARLEY-UNIT 2 3/4 4-14

REACTOR COOLANT SYSTEM OPERATIONAL LEAKAGE LIMITING CONDITION FOR OPERATION 3.4.7.2 Reactor Coolant System leakage shall be limited to: a. No PRESSURE BOUNDARY' LEAKAGE, b. 1 GPM UNIDENTIFIED LEAKAGE, c. 1 GPM total primary-to-secondary leakage through all steam generators and'500 gallons per day through any one steam generator, d. 10 GPM IDENTIFIED LEAKAGE from the Reactor Coolant System, and e. 31 GPM CONTROLLED LEAKAGE at a Reactor Coolant System pressure of 2235 20 psig. f. -1 GPM leakage from any Reactor Coolant System Pressure Isolation Valve specified in Table 3.4-1 at a Reactor Coolant System pressure of 2235 = 20 psig. APPLICABILITY: MODES 1, 2, 3 and 4 ACTION: a. With any PRESSURE BOUNDARY LEAKAGE, be in at least HOT STANDBY within 6 hours and in COLD SHUTDOWN within the following 30 hours. I b. With any Reactor Coolant System leakage greater than any one of the above limits, excluding PRESSURE BOUNDARY LEAKAGE, reduce the leakage rate to within limits within 4 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. c. With any Reactor Coolant System Pressure Isolation Valve leakage greater that the above limit, isolate the high pressure portion of the affected system from the low prSssure portion within 4 hours by use of at least two closed manual or deactivated automatic valves, or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.4.7.2.1 Reactor Coolant System leakages shall be demonstrated to be within each of the.above limits by; I a. Monitoring the containment atmosphere particulate radioactivity monitor at least once per 12 hours. b. Monitoring the containment air cooler condensate level system or containment atmosphere gaseous radioactivity monitor at least once per 12 hours. FARLEY-UNIT 2 3/4 4-17 4

REACTOR COOLANT SYSTEM ( t SURVEILLANCE REQUIREMENTS (Contiriued) ~ c. Measurement of the CONTROLLED LEAKAGE from the reactor coolant pump seals at least once per 31 days when the Reactor Coolant System pressure Is 2235 1 20 psig with the modulating valve fully open. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or 4. d. Perforrr.ance of a Reactor Coolant System water inventory balance at least once per 72 hours. e. Monitoring the reactor head flange leakoff system at least once per 24 hours. 4.4.7.2.2 Each Reactor Coolant System Pressure Isolation Valve specified in Table 3.4-1 shall be demonstrated OPERABLE pursuant to Specification 4.0.5 except that in lieu of any leakage testing required by Specification' 4.0.5, each valve should be demonstrated.0PERABLE by verifying leakage to be within 19.s limit. a. Every refueling outage during startup. b. Prior to returning the valve to service following maintenance, repair or replacement work on the valve affecting the seating capability of the valve. c. Following valve actuation due to automatic or nianual action or flow through the valve for valves identified in Table 3.4-1 by an asterisk. d. The provisions of Specification 4.0.4 are not applicable for entry into, MODE 3 or 4. i l ( FARLEY-UNIT 2 3/4 4-18

REACTOR COOLANT SYSTEM h SURVEILLANCE REQUIREMENTS 4.4.10.3.1 Each RHP relief valve shall be demonstrated OPERABLE by: Verifying the RHR relief valve isolation valves (8701a, 870lb, 8702a a. and 8702b) are open at least once per 72 hours when the RHR relief valve is being used for overpressure protection. b. Testing in pursuant to Specification 4.0.5. c. Verif*; cation of the RHR relief valve setpoint, of at least one RHR r211ef valve, at least once per 18 months on a rotating basis. 4.4.10.3.2 The RCS vent shall be verified to be open at least once per 12 hours

• when the vent is being used for overpressure protection.
• Except when the vent pathway is provided with a valve which is locked, sealed, or otherwise secured in the open position, then verify these valves.open at least once per 31 days.

FARLEY-UNIT 2 3/4 4-33

REACTOR COOLANT SYSTEM 3/4.4.11 STRUCTURAL INTEGRITY ASME CODE CLASS 1, 2 and 3 COMPONENTS LIMITING CONDITION FOR OPERATION 3.4.11 The structural integrity of ASME Code Class 1, 2 and 3 components i shall be maintained in accordance with Specification 4.4.11. I APPLICABILITY: All MODES ACTION: a. With the structural integrity of ar.y ASME Code Class 1 component (s) not conforming to the above requirements, restore the structural integrity of the affected component (s) to within its limit or isolate the affected component (s) prior to increasing the Raactor Coolant System temperature more than 50*F above the minimum temperature required by NDT considerations. b. With the structural integrity of any ASME Code Class 2 component (s) not conforming to the above requirements, restore the structural integrity of the affected component (s) to within its limit or isolate the affected component (s) prior to increasing the Reactor Coolant System temperature above 200 F. c. With the structural integrity of any ASME Code Class 3 component (s) not conforming to the above requirements, restore the structural integrity of the affected component (s) to within its limit or isolate the affected component (s) from service. d. The provisions of Specification 3.0.4 are not applicable. SURVEILLANCE REQUIREMENTS i 4.4.11.1 The structural integrity of ASME Code Class 1, 2 and 3 components shall be demonstrated; a. Per the requirements of Specification 4.0.5 and b. By the augmented program specified in Specifications 4.4.11.2 and l 4.4.11.3 l l FARLEY-UNIT 2 3/4 4-34 Amendment No. 1 i .e

a TABLE 3.7-3 STEAM LINE VALVES PER LOOP 5 l9 VALVE NUMBER LIFT SETTING (i 1%)* ORIFICE' SIZE (SQ. IN.) "1e a. Q2N11VO - 10A, 11A, 32A 1075 psig-16 5 -i b. Q2N11VO - 108, 118, 128 1088 psig 16 c. Q2N11VO - 10C, 11C, 12C 1102 psig 16 d. Q2N11VO - 100, 110, 12D 1115 psig 16 e. Q2N11VO - 10E, 11E, ITE 1129 psig A R + [

• The lif t setting pressure shall correspond to ambient conditions of the valve at nominal ~

operating temperature and pressure. 8o W e

PLANT SYSTEMS _ AUXILIARY FEE 0 WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater pumps and associated manual actuation switches in the control room and flow paths shall be OPERABLE with: a. Two auxiliary fe dwater pumps, each capable of being powered from separate emergensy busses, and b. One auxiliary feedwater pump capable of being powered from an OPERABLE steam supply system. APPLICABILITY: MODES 1, 2 and 3. ACTION: a. With one auxiliary feedwater pump inoperable, restore the required auxiliary feedwater pumps to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in HOT SHUTOOWN within the following 6 hours, b. With two auxiliary feedwater pumps inoperable be in at least HOT ( STANDBY within 6 hours and in HOT SHUT 00WN within the following 6 hours. c. With three auxiliary feedwater pumps inoperable, immediately initiate corrective action to restore at least one auxiliary feedwater pump to OPERABLE status as soon as possible. SURVEILLANCE REQUIREMENTS t 4.7.1.2.1 Each motor-driven and the turbine-driven auxiliary feedwater pump l shall be demonstrated OPERABLE pursuant to Specification 4.0.5. For the turbine-driven pump, the provisions of Specification 4.0.4 are not applicable for entry into MODE 3. l 4.7.1.2.2 Each auxiliary feedwater pump shall be demonstrated 1PERABLE: l l a. At least once per 31 days by: \\ 1. Verifying that each non-automatic valve in the flow path that is not locked, sealed, or othe Nise secured in position, is in its correct position. FARLEY-UNIT 2 3/4 7-4

jplANT SYSTEMS j 3/4.7.5' RIVER WATER SYSTEM e LIMITING CONDITION FOR OPERATION ,3.7.5 At least two independent river water loops shall be OPERABLE with at least two river water pumps per loop. APPLICABILITY: MODES 1, 2, 3 and 4. -ACTION: With only-one river water loop OPERABLE,. restore at least two loops to OPERABLE status within 72 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. SURVEILLANCE REQUIREMENTS 4.7.5 Each river water loop shall be demonstrated OPERABLE: a. At least once per 31 days by verifying that each valve (manual, power operated or automatic), in the flow path, servicing safety related equipment that is not locked, sealed, or otherwise secured in position, is in its correct position. b. At least once-per 18 months during shutdown, by: 1. Verifying that each automatic valve servicing safety related equipment actuates to its correct position on a low pond < level signal. 2. Verifying that the buried piping is leak tight.by a visual inspection of the ground area. 1 1 FARLEY-UNIT 2 3/4 7-13 Amendment No. 1

F PLANT SYSTEMS 3/4.7.6 ULTIMAT_E HEAT SINK s RIVER LIMITING CONDITION FOR OPERATION 3.7.6.1 The ultimate heat sink (river) shall be OPERABLE with a minimum water level at or above 70'-0" Mean Sea Level, USGS datum, and a maximum water level at or below 127' Mean Sea Level. APPLICABILITY: MODES 1, 2, 3 and 4. ACTION: With the requirements of the above specification not satisfied, be in at least HOT STAND 8Y within 6 hours and in COLD SHUTDOWN within the following 20 hours. SURVEILLANCE REQUIREMENTS 4.7.6.1 The ultimate heat sink shall be determined OPERABLE at least once per 24 hours by verifying the water level to be within limits. 6 6 l l FARLEY-UNIT 2 3/4 7-14 l

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 1. With a half-life greater than 30 days (excluding Hydrogen 3), and 2. In any form other than gas. b. Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous six months. Sealed sources and fission detectors transferred without a certificate indicating the last test date shall be tested prior to being placed into us.e. c. Startup sources and fission detectors - Each sealed startup source and fission detector shall be tested within 31 days prior to being subjected to core flux or installed in the core and following repair or maintenance to the source. 4.7.10.3 Reports - A report shall be prepared and submitted to the Commission oa an annual basis if sealed source or fission detector-leakage tests reveal the presence of greater than or equal to 0.005 microcuries of removable contamination. m 9 4 s FARLEY-UNIT 2 3/4 7-51 I J

PLANT-SYSTEMS 3/4.7.11 FIRE SUPPRESSION SYSTEMS -FIRE SUPPRESSION WATER SYSTEM LIM.VINGCONDI110NFOROPERATION 3.7.11.1 The. fire suppression water system shall be OPERABLE with: Two high pressure pumps, each with a capacity of 2500 gpm, with a. their discharge aligned to the fire suppression header, b. Separate water supplies, each with a minimum contained volume of 250,000 gallons, ant c. An OPERABLE flow path capable of taking suction from each tank and transferring the water through distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valves, the last valve ahead of the water flow alarm device on each sprinkler or hose standpipe, and the last valve ahead of the deluge valve on each deluge or spray system required to be OPERABLE per Specifications 3.7.11.2, 3.7.11.4 and 3.7.11.5. APPLICABILITY: At all tic.es. ACTION: With one of the above required pumps and/or water supplies inoperable, a. restore the inoperable equipment to OPERABLE status within 7 days or, in lieu of any other report required by Specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specifica-tion 6.9.2 within the next 30 days outlining the plans and procedures to be used to provide for the loss of redundancy in this system. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable. b. With the fire suppression water system otherwise inoperable: 1. Establish a backup fire suppression water system within 24 hours, and 2. In lieu of any other report required by Specification 6.9.1, submit a Special Report in accordance with Specification 6.9.2: a) By telephone within 24 hours, b) Confirmed by telegraph, mailgram or facsimile transmission no later than the first working day following the event, and c) In writing within 14 days following the event, outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status. i FARLEY-UNIT 2 3/4 7-52 Amendment No. 1 l

' ELECTRICAL POWER SYSTEMS l l ACTION: (Continued) ) e. With both of the above required diesel generator sets inoperable, demonstrate the OPERABILITY of two offsite A.C. circuits by performing Surveillance Requirement 4.8.1.1.1.a within I hour and at least once per 8 hours thereafter; restore at least one of the inoperable diesel generator sets to OPERABLE status within 2 hours or be in at least HOT STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours. Restore both diesel generator sets to OPERABLE status within 72 hours from time of initial loss or be in least HOT STANDBY within the next 6 hours and in COLD SHUT 00WN within the following 30 hours. SURVEILLANCE REQUIREMENTS

4. I,. l. l.1 Each of the above required independent circuits between the offsite transmission network and the onsite Class 1E distribution system shall be:

a. Determined OPERABLE at least once per 7 days by verifying correct breaker alignments, indicated power availability, and b. Demonstrateo OPERABLE at least once per 18 months during shutdown by transferring unit power supply from the normal circuit to the alternate circuit. 4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE: a. In accordance with the frequency specified in Table 4.8-1 on a STAGGERED TEST BASIS by: 1. Verifying the fuel level in the day tank, 2. Verifying the fuel level in the fuel storage tanks, 3. Verifying the fuel transfer pump can be started and transfers fuel from the storage system to the day tank, 4. Verifying the diesel starts from ambient condition and accelerates to at least 900 rpm, for the 2850 kw generator and 514 rpm for the 4075 kw generators, in less than or equal to 10 seconds. The generator voltage and frequency shall be > 3952 volts and > 57 Hz within 10 seconds after the st et signal. 5. Verifying the generator is synchronized, loa'aed to greater than or equal to its continuous rating, and opera tes for greater than or equal to 60 minutes, FARLEY-UNIT 2 3/4 8-3

ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 6. Verifying the diesel generator is aligned to provide standby power to the associated emergency busses. b. At least once per 92 days by verifying that a sample of diesel fuel from the. fuel storage tank obtained in accordance with ASTM-D270-65 is within-the acceptable Ifmits specified in Table 1 of ASTM-0975-74 when checked for viscosity, water and sediment. c. At least once per 18 months by: 1. Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service, 2. Verifying the capability to reject a load of greater than or equal to the largest single load associated with that diesel generator, while maintaining voltage between 3120 and 4910 volts and speed less than or equal to 75% of the difference between nominal speed and the overspeed trip setpoint and verifying recovery to 4160 t 420 volts and 60 1.2 Hz within 2 seconds. 3. Verifying the generator capability to reject a load equal to its. continuous rating without tripping. The generator voltage shall not exceed 120% during and following the load rejection. 4. Simulating a loss of of fsite power by i~tself, and: a) Verifying de-energization of the emergency busses and load shedding from the emergency busses. b) Verifying the diesel starts on the auto-start signal, energizes the emergency busses with permanently connected loads within 10 seconds,* energizes the auto-connected l shutdown loads through the load sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown loads. After energization of all loads, the steady state voltage and frequency of the emer-gency busses shall be maintained at 4160 + 420 volts and 60 + 1.2 Hz during this test. 5. Verifying that on an Safety Injection test signal (without loss of offsite power) the diesel generator starts on the auto start signal and operates on standby for greater than or equal to 5 minees. The generator voltage and frequency shall be > 3952 volts and > 57 Hz within 10 seconds after the auto-star: signal; the steady state generator voltage and frequency shall be main-tained between 4160 1 420 volts and 60* 1.2 Hz during this test.

• Energization of the Unit 2 emergency bus for diesel 2C is achieved within 24 seconds.

FARLEY-UNIT 2 3/4 8-4 Amendment No. I t l~

ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continue'd) 6. Simulating a loss of offsite power in conjunction with a Safety Injection test signal, and a) Verifying de energization of the emergency busses and load shedding from the emergency busses. b) Verifying the diesel starts from ambient condition on the auto-start signal, energizes the emergency busses with permanently connected loads within 10 seconds,** energizes the auto-connected emergency (accident) loads through the load sequencer and operates foi-greater than or equal to 5 minutes while its generator is loaded with t4e emergency loads. Af ter energization, the steady state voltage and frequency of the emergency busses shall be maintained at 4160 1 420 volts and 60 1.2 Hz during this test. c) Verifying that all automatic diesel generator trips, except engine overspeed and generator differential and low lube oil pressure, are automatically bypassed upon loss of voltage on the emergency bus and/or a safety injection test signal. 7. Verifying the diesel generator operates for at least 24 hours. During the first 2 hours of this test, the diesel generator shall be loaded to greater than or equal to 4474 kw for the 4075 kw diesels and 3250 for the 2850 diesels and during the remaining 22 hours of this test, the diesel generator shall be loaded to greater than or equal to 4075 kw for the 4075 kw diesels and 2850 kw for the 2850 k.I diesels. Immediately after completing this 24 hour test, perform Specification 4.8.1.1.2.c.4. The generator voltage and frequency shall be 1 3952 volts and 2 57 Hz within 10 seconds after the start signal; the generator voltage and frequency shall be maintained between 3120 and 4910 volts l and 57 and 61.2 Hz during this test.* 8. Verifying that the auto-connected loads to each diesel generator do not exceed the 2000 hour rating of 4353 kw for the 4075 kw generator and 3100 kw for the 2850 kw generator. "This surveillance is not required for MODE 3 or 4. This is a one time change ' to plant operations prior to initial criticality.

• • Energization of the Unit 2 emergency bus for diesel 2C is achieved within 24 seconds.

l FARLEY-UNIT 2 3/4 8-5 Amendment No. I

ELECTRICAL POWER SYSTEMS ( SURVEILLANCE REQUIREMENTS (Continued)

10. Verifying that with the diesel generator operating in a test mode (connected to its bus), a simulated safety injection signal overrides the test mode by returning the diesel generator to standby operation.

11. Verifying that the automatic load sequence timer is OPERABLE with each load sequence time within i 10% of its required value or 0.5 seconds whichever is greater. 12. Verifying that the following diesel generator lockout fea'"ves prevent diesel generator starting only when*rbquired; a) Oil Temperature High (OTH) b) Coolant Temperature High (CTH) c) Coolanc Pressure Low (CPL) d) trankcase Pressure High (CCPH) d. At least once per 10 years or after any modifications which could f affect diesel generator interdependence by starting the diesel s generators simultaneously, and verifying that the diesel generators accelerate to at least 900 rpm, for the 2850 kw generator and 514 rpm for the 4075 kw generator, in less than or equal to 10 seconds. 4.8.1.1.3 Reports - All diesel generator failurec, valid or non-valid, shall be reported to the Commission pursuant to Specification 6.9.1. Reports of diesel generator failures shall include the information recommended in Regulatory Posittin C.3.b of Regulatory Guide 1.108, Revision 1, August 1977. If the number of failures in the last 100 valid tests (on a per diesel type basis) is greater than or equal to 7, the report shall be supplemented to include the additional information recommended in Reculatory Position C.3.b of Regulatory Caide 1.108, Revision 1, August 1977. i I i k (' .FARLEY-UNIT 2 3/4 8-6

E ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) (c) For each circuit breaker found inoperable during these functional tests, an additional representative sample of at least one of the circuit breakers of the inoperable type shall a Lo be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested. 2. By selecting and functionally testing a representative sample of at least 10%'of each type of lower voltage circuit breakers. Circuit breakers selected for functional testing shall be < elected on a rotating basis. The functional test shall consist of injecting a current input at the specified setpoint to each selected circuit breaker and verifying that each circuit breaker functions as Cesigned. For each circuit breaker found inoperable during these functional tests, an ad ;nal repre-sentative sample of at least 10% of all the circ-. breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested. 3. By selecting and functionally testing a representative sample of each type of fuse on a rotating basis. Each representative sample of fuses shall include at least 10% of all fuses of that type. The functional test shall cons 6ist of a non-destructive resistance measurement test which demonstrates that the fuse meets its manufacturer's design criteria. For each fuse found inoperable during these functional tests, an additional repre-sentative sample of at least 10% of all fuses of that type shall be functionally tested until no more failures are found or all fuses of that type have been functionally tested, b. At least once per 60 months by subjecting each circuit breaker to an inspection and preventive maintenance in accordance with procedures prepared in conjunction with its manufacturer's reccmmendations. t. 8. 3. 2 Power sources feeding circuits indicated by an asterisk (*) in Table 3.8-1 shall be verified to be interrupted by an open breaker or removed fuse at least once every 31 days. FARLEY-UNIT 2 3/4 8-19

TABLE 3.8-1 CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES Trip

Response

Device Number Setpoint Time System and Location (Ampere) (Seconds) -Powered 1. 4160VAC Switchgears DA04 9600 .01.08 Reactor Coolant Pump 2A' 0B03 9600 .01.08 Reactor Coolant Pump 2B DC03 9600 .01.08 Reactor Coolant Pump 2C 2. 600VAC Load Centers EA04*'# 1000 1 10% .07.18 Reactor Polar Crane EA10 1800 10% .01.05 Containment Cooler 2A (Normal; EB05 1800 10% .01.05 Containment Cooler 2B (Normal: EB06 18C0 10% .01.05 Containment Cooler 2C (Normal: EC12 1800 10% .01.05 Containment Cooler 20 (Normal: E011 1200 1 10% .01.05 CROM Cooler Fan 2A E015-1500 1 10% .01.05 Containment Cooler 2A (Emergency) E016 1500 t 10% .01.05 Containment Cooler 28 (Emergency) EE08 1500 + 10% .01.05 Containment Cooler 2C (Emergency) EE13 1200 i 10% .01.05 CROM Cooler Fan 2B EE16 1500 1 10% .01.05 Containment Cooler 20 (Emergency) 3. 600VAC Motor Control Centers FA-F7 210 (INST) .01.016 Reactor Cavity Clg Fan Mtr. 2/ FA-I6 10 (INST) .01.016 Reactor Cavity Cool Fan Mov FA-15 105 (INST) .01.016 CTMT Post LOCA Air Mixing Fan 20 FA-J5 105 (INST) .01.016 CTMT Post LOCA Air Mixing Fan 2C FB-I3 105 (INST) .01.016 CTMT Post LOCA Air Mixing Fan 2B FB-I4 105 (INST) .01.016 CTMT Post LOCA Air Mixing Fan 2A FO-H7R*'# 400-700 .01.016 CTMT G1B Crane (N2T31K005-N) FB-J7 210 (INST) .01.016 Reactor Cavity Clg Fan Mtr. 2/ FB-A4R*', 400-700 .01.016 CTMT Elevator No. 3 Controllet FC-P3 105 (INST) .01.016 CTMT Dome Recirc. Fan 2A 1 FC-P4 105 (INST) .01.016 CTMT Dome Recire. Fan 2B FC-12*'g 400-700 .01.016 RCP Motor Space Heaters FC-I4 125 (INST) .01.016 RCP BRG Oil Lif t Pump FC-N3 125 (INST) .01.016 RCP BRG Oil Lift Pump FC-J3* 210 (INST) .01.016 Refueling Wtr Surface Supply FC-MS* 630 (INST) .01.016 ' Refueling Wtr Surface Exhaust FC-J5 330 (INST) .01.016 CTMT Pre-Access Fan Motors FC-N4*'g 400-700 .01.016 RCP Mtr Space Heaters 2C FARLEY-UNIT 2 3/4 8-20 Amendment No. 1

I L TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES Device Number Trip Setpoint Response Time System and location (Ampere) (Seconds) Powered FC-J6L*'# 600-1000 .01.016 Receptacles Term. Box 2A FC-J6R" 400-700 .01.016 Reactor Cavity Filter Pmp Recep. FC-53L*, 400-700 .01.016 Up Ending Frame Winch Mtr FC-M4L*', 400-700 .01.016 CTMT GIB Crane (N2T31K004-N) FC-N2L*' 400-700 .01.016 Reactor Cavity Manipulator Crane FC-53R*', 400-700 .01 016 .CTMT GIB Crane (N2T31K006-N) FC-C5R*', 400-700 .01.016 SW Port Orain Pump Recept. FO-06 125 (INST) .01.016 RCP BRG 011 Lift Pump FO-E3 105 (INST) .01.016 CTMT Dome Recirculation Fan 20 FD-B4 330 (INST), .01.016 Reactor Cool Orain Tank Pump 2B FO-C2 125 (INST) .01.016 ..CTMT Sump Pump Mtr 2A FO 02 125 (INST) .01.016 CTMT Sump Pump Mtr 2B FO-C4 330 (INST) .01.016 CTMT Pre-Access Fan Mtrs FO-G3*',, 400-700 .01 016 RCP Mtr Space Heaters 2B FD-A3L*' 600-1000 .01.016 Receptacles Term Box 2C FE-A6 330 (INST) .01 016 Reactor Cool Orain Tank, Pump 2A FE-A4L*', 600-1000 .01.016 Receptacles Term Box 2B l FE-C3L 600-100C .01.016 Incore Det. Drive & Cont. Pnl. FE-HS 105 (INST) .01.016 CTMT Dome Recirc. Fan 2C FU-G2 29 (INST) .01.016 RHR Pumps Inlet Mov FU-H2 12 (INST) .01.016 CTMT Air Cooling Fan Mov FU-H3 12 (INST) .01.016 CTMT Air Cooling Fan Mov FU-H4 10 (!:;ST) .01.016 RCP Motor Cooler Disch Mov FU-J4 10 (INST) .01.016 CTMT To Atmos Diff Press Mov FU-K4 22 (INST) .01 016 Pressuruer to Relief Tank MOV FU-K6 10 (INST) .01.016 CTMT Cooler Disch MOV FU-L4 12 (IN(T) .01.016 Post ACOT Air Sampler From CTMT Mov FU-L5 12 (INST) .01.016 Post ACOT Air Sampler From CTMT Mov FU-T4 22 (INST) .01.016 RCP Seal Water Return Isol. FU-M4 12 (INST) .01.016 Post ACOT Air Sampler Return Mov FU-RS 16 (INST) .01.016 CTMT Air Sampler Mov. FU-V4 12 (INST) .01.016 CROM Cool Fan Dampers Mov. FU-W2 16 (INST) .01.016 CTMT Air Cooler Disch Mov. Dilution FU-W4 29 (INST) .01.016 Reactor Cavity H2 Faa VLV 2A FARLEY - UNIT 2 3/4 8-21

TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES Device Number Trip Setpoint Response Time System and Location (Ampere) (Seconds) Powered FU-T5 45 (INST) .01.016 RHR System Inlet Isol. Viv. FU-Z2 400 (INST) .01.016 Accumulator 2A Disch. Viv. FU-Z3 400 (INST) .01.016 Accumulator 2C Disch. Viv. FV-M3 12 (INST) .01.016 Post ACOT Air Sampler Return Mov. FV-H4 12 (INST) .01.016 Post ACOT Air Sampler From CTMT Mov FV-H5 12 (INST) .01.016 Post ACOT Air Sampler From CTMT Mov FV-Y4 12 (INST) .01.016 Post LOCA CTMT Vent Mov FV-Y5 29 (INST) .01.016 Instr. Air Line Disch. Mov. FV-12 12 (INST) .01 016 CROM Cool Fan Damper FV-J4 16 (INST) .01.016 CTMT Air Cooler Disch. Mov. FV-J5 16 (INST) .01.016 CTMT Air Cooler Disch. Mov. FV-N2 29 (INST) .01.016 Reac. Cavity H2 Dilution Fan Viv. 28 FV-52 400 (INST) .01.016 RHRSysteminletIsol.Vlv.l Accumulator 28 Disch. Viv. FV-V3 45 (INST) .01.016 FV-W4 22 (INST) .01.016 Pressurizer to Relief Isol. Mov. FV-V2 45 (INST) .01.0)S RHR System Outlet Isol Viv. FV-C3 22 (INST) .01.016 RCP CCW Return from Oil Cool FV-F2 12 (INST) .01.016 CTMT Air Cooling Fan Mov. FV-F3 12 (INST) .01.016 CTMT Air Cooling Fan MOV. 4. 208 VAC Motor Control Centers HA-03 105 (INST) .01.016 Reac. Cavity H2 Dilution Fan 2A HB-N7 150 (INST) .01.016 Reac. Cavity H2 Dilution Fan 28 5. 600VAC Pressurizer l Distr. Pnl 2A l BKR #1 750-1600 .J1.016 Pressurizer Htr Group 2A I BKR #2 750-1600 .01.016 Terminal Box N2TB010 l BKR #3 750-1600 .01.016 BKR #4 750-1600 .01.016 BKR #5 750-1600 .01.016 i FARLEY-UNIT 2 3/4 8-22 Amendment No. 1 o

l i i 7 TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES Device Number Trip Setpoint Response Time System and Location (Ampere) (Seconds) Powered 6. 600VAC Pressurizer 01str. Pnl 2B BKR #1 750-1600 .01.-016 Pressurizer Htr Group 2B BKR #2 750-1600 .01.-016 Terminal Box N2TB011 BKR #3 750-1600 .01.-016 BKR #4 750-1600 .01.-016 BKR #5 750-1600 .01.-016 7. 600VAC Pressurizer Htr. Distr. Pn1 2C Circuit Bkrs. BKR #1 750-1600 .01.016 Pressurizer Htr Group 2C BKR #2 750-1600 .01.016 Terminal Box N2TB008 BKR #3 750-1600 .01.016 BKR #4 750-1600 .01.016 BKR #4 750-1600 .01.016 BKR #5 750-1600 .01.016 BKR #6 750-1600 .01.016 BKR #7 750-1600 .01.016 8. 600VAC Pressurizer Htr. Distr. Pn1 20 Circuit Bkrs. BKR #1 750-1600 .01.016 Pressurizer Htr Group 20 BKR #2 750-1600 .01.016 Terminal Box N2TB007 BKR #3 750-1600 .01.015 BKR #4 750-1600 .01.016 9. 600VAC Pressurizer HTR. Distr. Pn1 2E Circuit Bkrs. BKR #1 750-1600 .01.016 Pressurizer Htr Group 26 SKR #2 750-1600 .01.016 Terminal Box N2T8009 BKR #3 750-1600 .01.016 BKR #4 750-1600 .01.016 BKR f5 750-1600 .01.016 -FARLEY - UNIT 2 3/4 8-23

TABLE 3.8-1 (Continued)- CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT-PROTECTIVE DEVICES -Device Number Trip Setpoint Response Time System and Location (Ampere) (Seconds) Powered 10. 125VDC Scl. V1vs. ~ Power Fuses FBI (TC-05A) 3 N.A. PRZR PWR Relief VLV (445A) 2A FBI (TC-25A) 3 N.A. PRZR PWR Relief VLV (4448) 2B FB5 (TC-06A) 3 N.A. Letdown Line Isol. Viv. (459) FB6 (TC-06A) 3 N.A. Letdown Line Isol. Viv. (460) F85 (TC-05A) 3 N.A. Reac. Cool Orn Tank Pump Disci Viv (1003A) l FB6 (TC-05A, 3 N.A. Reac. Cool Orn Tank Vent Isol Viv (7126) l FB3 (TC-06A) 3 N.A. RMW to F.CP-Standpipe Fill (8168C) FB4 (TC-258) 3 N.A. PRZR Rel. Tnk to RMW Isol. l Viv. (B030) FB5 (TC-25B) 3 N.A. PRZR Rel. Tnk Drn to WPS Drn Tnk (8031) l FBG (TC-278) 3 N.A. Excess Letdown Isol. Viv. (815?) FB5 (TC-278) 3 N.A. RCS PRZR Aux. Spray Viv. r (8145) FB7 (TC-27B) 3 N.A. Excess Letdown Isol. Viv. (4154) FB2 (TC-278) 3 N.A. Rtw to RCP Standpipe Fill (8168A) FB3 (TC-278) 3 N.A. RMW to RCP Standpipe Fill (81688) FB2 (TC-08A) 3 N.A. Accum. N2 Supply & Vent Isol-(8875A) FB6 (TC-08A) 3 N.A. Accum. N Supply & Vent Isol 2 (8875C) FB4 (TC-08A) 3 N.A. Accum. Line Test Isol. (8877A) FB8 (TC-08A) 3 N.A. Accum. Line Test Isol. (8877C) FB3 (TC-08A) 3 N.A. Accum. Fill Line Isol. l (8878A) I FB7 (TC-08A) 3 N.A. Accum Fill Line Isol. (8878C) FB5 (TC-08A) 3 N.A. Accum. Inject Test Line Isol. (8879A) l FB9 (TC-08A) 3 N.A. Accum. Inject. Test Line Isol. (8879C) FB2 (TC-298) 3 N.A. Accum. N2 Supply & Ve.it Isol (88758) FARLEY-UNIT 2 3/4 8-24 Amendment No. 1

~ g.. TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES Device Number Trip Setpoint Response Time System and Location-(Ampere) (Seconds) Powered FB4 (TC-298) 3 N.A. Accum. Test Line Isol. I (88778) FB3 (TC-298) 3 N.A. Accum. Fill Line Iso' (88788) FB5 (TC-298) 3 N.A. Accum. Inject. Test Line Isol (88798) FB1 (TC-06A) 3 N. A. RCP Seal Leak Off Isol (8141A) FBI (~ 298). 3 N.A. Damper Sol. Vivs. CTMT Purge Isol (3196) FB9 (TC-06A) 3 N.A. Letdown Grifice Isol. Viv. (8149B) FB2 (TC-06A) 3 N.A. RCP Seal Leak Off Isol. (8141C) FB1 (TC-278) 3 N.A. RCP Seal Leak Off Isol. (81418) FBI (TC-06A) 3 N.A. RCS Alternate Charging Line (8147) FBI (TC-278) 3 N.A. RCS Normal Charging Line (8146) FB7 (TC-25B) 3 N.A. Reac. Vessel Leak.0ff Isol. (8032) FB2 (TC-258) 3 N.A. PRZR Rel. Tnk to RMW-Supply Isol (8047) FB8 (TC-278) 3 N.A. RCP Seals Wtr By pass Isol. Viv. (8142) FB5 (TC-278) 3 N.A. Excess L'Down to VLT or RC - Drn'Tk (8143) j FB10 (TC-06a)- 3 N.A. Letdown Orifice Isol. V1v. (8149A) FB8 (TC-06A) 3 N.A. Letdown Orifice Isol. Viv. (8149C) FBI (TC-08A) 3 N.A. Accum. Test Line Isol. Viv. (8871) FB4 (TC-318) 3 N.A. RCP Comp. Cool (3184) FBI (TC-09A) 3 N.A. Excess Letdown Hx Cool Disch (3443) FAN (NBL2702B-B) 3 N.A. SG2A Blowdown (3179C) 1 FAM (NBL27028-B) 3 N.A. SG2B Blowdown (3180C) FAL (NBL2702B-8) 3 N.A. SG2C Blowdown (3181C). l FAC (NBL27028-B) 3 N.A. SG2A Blowdown (39518) FAB (NBL27028-B) 3 N.A. SG2B Blowdown (39528) FAA (NBL27028-B) 3 N.A. SG2C Blowdown (39538) FAO (NBL27028-B) 3 N.A. CVCS Letdown Line Viv. (3950B) F0 (NBL2702A-A) 3 N.A. CVCS Letdown Line Viv. (3950A) FARLEY-UNIT-2 3/4 8-25 Amendment No. 1

TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES Device Number Trip Setpoint Response Time System and Location (Ampere) (Seconds) Powered FC (NBL2702A-A) 3 N.A. SG2A Blewdown (3951A) FB (NBL2702A-A) 3 N.A. SG2B Blowdcwn (3952A) FA (NBL2702A-A) 3 N.A. SG2C Blowdown (3953A) FK (NBL2702A-A) 3 N.A. SG2A Blowdown (7697A) FJ (NBL2702A-A) 3 N.A. SG2B Blowdown (7698A) FH (NBL2707A-A) 3 N.A. SG2C Blowdown (7699A) FAK (NBL2702B-B) 3 N.A. SG2A Blowdown (7697B) FAJ (NBL2702B-B) 3 N.A. SG2B Blowdown (76988) FAH (NBL27028-8) 3 N. A. SG2C Blowdown (76998) FAS (NBL27028-B) 3 N.A. Press. Stm Space Sampler (3880) FAR (NBL27028-B) 3 N.A. Press. Liq Space Sampler (3881) F/3766(NFSS2607A-A) 3 N.A. Accumulator Sampler (3766) F/3179A(NFSS2607A-A) 3 N.A. SG2A Blowdown Samplar (3179A) F/3179B(NFSS2607A-A) 3 N.A. SG2A Blowdown Sampler (31798) F/3180A(NFSS2607A-A) 3 N.A. SG2B Blowdown Sampler (3180A) F/3180B(NFSS2607A-A) 3 N.A. SG2B Blowdown Sampler (31808) F/3181A(NFSSZ607A-A) 3 N.A. SG2C Blowdown Sampler (3181A) F/3181B(NFSS2607A-A) 3 N.A. SG2C Blowdown Sampler (3181B) F/3162(NFSS2607A-A) 3 N.A. Accum. Tank 2A Sampler (3162) F/3163(NFSS2607A-A) 3 N.A. Accum. Tank 28 Sampler (3163) F/3164(NFSS2607A-A) 3 N.A. Accum. Tank 2C Sampler (3164) F/3101(NFSS26078-B) 3 N. A. Reac. Coolant Hot leg (3101) F/3102(NFSS26078-B) 3 N.A. Reac. Coolant Hot leg (3102) FA(NGB25040) 3 N.A. CTMT Sump Disch. (3376) FA(NGB25Q4) 3 N.A. CTMT Cooler Orains (3395A) - F0(NGB25Q4) 3 N.A. CTMT Cooler Drains (33958) FC(NGB25Q4) 3 N.A. CTMT Cooler Orains (3395C) FB(NGB25Q4) 3 N.A. CTMT Cooler Drains (33950) F/3103(NFSS26078-8) 3 N.A. PRZR Liquid Sampler (3103) F/3104(NFSS26078-B) 3 N.A. PRZR Liquid Sampler (3104) F/3765(NFSS26078-8) 3 N.A. Reac. Hot Leg Sampler (3765) 11. 120VAC Sol Vivs. Power Fuses FM(NGB2504M) 3 N.A. Reac. Cavity Cooling (3999A) FF(NGB25040) 3 N.A. Reac. Cavity Cooling (39998) l l l FARLEY-UNIT 2 3/4 8-26 Amendment No.1

4 TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONDUCTOR OVERC?tRRENT PROTECTIVE DEVICES Device Number Trip Setpoint Response Time System' and Location (Amoere) (Seconds) Powered

12. Variable O.C.

Voltage CRDM Fuses (125 V Max) FU13/A22 10 N.A. Mechanism #1 Sta. Gripper Group A FU14/A22 10 N.A. Mechanism #2 Sta. Gripper Group A FU15/A22 10 N.A. Mechanism #3 Sta. Gripper Group A FU16/A22 10 N.A. Mechanism #4 Sta. Gripper Group A FU25/A23 10 N.A. Mechanism #1 Sta. Gripper Group B FU26/A23 10 N.A. Mechanisa #2 Sta. Gripper Group B FU27/A23 10 H.A. .. Mechanism #3 Sta. Gripper Group B FU28/A23 10 N.A. Mechanism #4 Sta. Gripper Group B FU41/A24 10 N.A. Mechanism #1 Sta. Gripper Group C FU42/A24 10 N.A. Mechanism #2 Sta. Gripper Group C FU43/A24 10 N.A. Mechanism #3 Sta. Gripper Group C FU44/A24 10 N.A. Mechanism #4 Sta. Gripper Group C FU1/A51 50 N.A. Mechanism #1 Lift Group A FU2/A51 50 N.A. Mechanism #2 Lift Group A FU1/A52 50 N.A. Mechanism #3 Lift Group A FU2/A52 50 N.A. Mechanism #4 Lift Group A FU1/A53 50 ii. A. Mechanism #1 Lift Group A FU2/A53 50 N.A. Mechanisa #2 Lift Group B FU1/A54 50 N.A. Mechanism #3 Lift Group R FU2/A54 50 N.A. Mechanism #4 Lift Group d FU1/A55 50 N.A. Mechanism #1 Lift Group C FU2/A55 50 N.A. Mechanism #2 Lift Group C FU1/A56 50 N.A. Mechanism #3 Lift Group C FU2/A56 50 N.A. Mechanism #4 Lift Group C ] .FU21/A25 10 N.A. Mechanism #1 Moving Gripper Group A FU22/A25 10 N.A. Mechanism #2 Moving Gripper Group A FU23/A25 10 N.A. Mechanism #3 Moving Gripper Group A FARLEY - UNIT 2 3/4 8-27

TABLE 3.8-1 (Continued) CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES Devi:e' Number Trip Setpoint Response Time System and Location (Ampere) (Seconds) Powered FU24/A25 10 N.A. Mechanism #4 Moving Gripper Group A FU33/A26 10 N.A. Mechanism #1 Moving Gripper Group B FU34/A26 10 N.A. Mechanism #2 Moving Gripper Group B FU35/A26 10 N.A. Mechanism #3 Moving Gripper Group B FU36/A26 10 N.A. Mechanism #4 Moving Gripper Group 8 FU49/A27 10 N.A. Mechanism #1 Moving Gripper Group C FU50/A27 10 N.A. Mechanism #2 Moving Gripper Group C FU51/A27 10 N.A. Mechanism #3 Moving Gripper Group C FU52/A27 10 N.A. Mechanism #4 Moving Gripper Group C 13. 480/277 VAC Lighting Cables No Prot. Device N.A. N.A. Lighting Panel 2R(N2T51 LOO 1A-N No Prot. Device N.A. N.A. Lighting Panel 20(N2T51 LOO 10-N No Prot. Device N.A. N.A. Lighting Panel 2Q(N2T51 LOO 1B-N No Prot. Device N.A. N.A. Lighting Panel 2P(N2T51L001C-N No Prot. Device N.A. N.A. Receptacle Panel-2F(N2T51 LOO 2A-N) 14. 480 VAC, 30, H2 Recombiner Power Supply No Prot. Device N.A. N.A. H Recombiner HTRS 2 (Q2E17G001A-A). No Prot. Device N.A. N.A. H Recombiner HTRS 2 (Q2E17G0018-8)

• Circuits are to be deenergized except where allowed by note #.

1. May be energized under administrative controls when required for operational or maintenance activities.

1 FARLEY-UNIT 2 3/4 8-28 Amendment No. I

l TABLE 3.8-2 (Continued) MOTOR OPERATE 0 VALVES THERMAL OVERLOAD PROTECTION DEVICES" VALVE NUMBER FUNCTION BYPASS DEVICE MOV-8106. Charging Pump Mini Flow Isolation No MOV-8826A Containment Spray Suction from No Centainment Sump MOV-8826B Containment Spray Suction from No Containment Sump MOV-8827A Containment Spray Suction from No Containment Sump MOV-88278 Containment Spray Suction from No Containment Sump MOV-8817A Containment Spray Suction from RWST No MOV-88178 Containment Spray Suction from RWST No MOV-8836A Eductor Suction from Spray Additive No Tank MOV-8836B Eductor Suction from Spray Additive No Tank MOV-8820A Discharge to Spray Ring No MOV-88208 Discharge to Spray Ring No MOV-8803A BIT Inlet No MOV-8803B BIT Inlet No MOV-8801A BIT Outlet No MOV-8801B BIT Outlet No MOV-8886 Charging Pump Discharge to Hot Leg No MOV-8884 Charging Pump Discharge t0'Ho.t Leg No 4 MOV-8885 Charging Pump Discharge to Cold Leg No MOV-8808A SIS Accumulator Outlet No MOV-8808B SIS Accumulator Outlet No MOV-8808C SIS Accumulator Outlet No MOV-8811A RHR Suction from Containment Sump No MOV-88118 RHR Suction from Containment Sump No MOV-8812A RHR Suction from Containment Sump No MOV-88128 RHR Suction from Containment Sump No MOV-8809A RHR Suction from RWST No MOV-88098 RHR Suction from RWST No MOV-8887A RHR Discharge Crossconnect No MOV-88878 RHR Discharge Crossconnect No FCV-6028 RHR Pump Mini Flow No FCV-602A RHR Pump Mini Flow No MOV-8889 RHR Discharge to Hot Leg No MOV-8888A RHR Discharge to Cold Leg No MOV-88888 RHR Discharge to Cold leg No MOV-8706A RHR Discharge to Charging Pump Suction No MOV-87068 RHR Discharge to Charging Pump Suction No MOV-8112 Seal Water Return Containment No Isolation MOV-8100 Seal Water Return Containment No Isolation ^**"d**" "*I FARLEY-UNIT 2 3/4 8-31 a

4 5 g TABLE 3.8-2 (Continued) MOTOR OPERATE 0 VALVES THERMAL OVERLOAD ( PROTECTION DEVICES ^ ( VALVE NUMBER FUNCTIdN BYPASS DEVICE QSP25V513 RW to Pond Isolation No QSP25V514 RW to Pond Isolation No QSP25V517 RW to Wet Pit Isolation No QSP25V518 RW to Wet Pit Isolation No MOV-3536 CTMT Air Purge Isolation No MOV-3530 Post LOCA Vent Isolation No MOV-3740 Post LOCA Vent Isolation No MOV-3528A CTMT Air Sample Isolation No MOV-35288 CTMT Air Sample Isolation No MOV-3528C CTMT Air Sample Isolation No MOV-35280 CTMT Air Sample Isolation No MOV-3739A CTMT Air Sample Isolation No MOV-37398 CTMT Air Sample Isolation No MOV-3745A CTHT Air Sample Isolation No MOV-37458 CTMT Air Sample Isolation No MOV-3835A CTMT Air Sample Isolation No MOV-38358 CTMT Air Sample Isolation No MOV-3362A Pen Room Vent Damper No M0V-33628 Pen Room Vent Damper No MOV-3361A Pen Room Vent Damper No MOV-33618 Pen Room Vent Damper No MOV-3406 Turbine Trip and Throttle No MOV-3232A Feedwater Isolation No s MOV-32328 Feedwater Isolation No MOV-3232C Feedwater Isolation No Q2P16V514 Turbine Building Isolation No Q2P16V515 Turbine Building Isolation No Q2P16V516 Turbine Building Isolation No Q2P16V517 Turbine Building Isolation No Q2P16V538 Pond Recirculation No Q2P16V539 Pond Recirculation No LCV-115C Charging Pump Suction from VCT No LCV-115E Charging Pump Suction from VCT No LCV-1158 Charging Pump Suction from RWST No LCV-1150 Charging Pump Suction from RWST No MOV-8131A Charging Pump Suction Crossconnect No MOV-81318 Charging Pump Suction Crossconnect No MOV-8130A Charging Pump Suction Crossconnect No MOV-81308 Charging Pump Suction Crossconnect No MOV-8132A Charging Pump Discharge Crossconnect No MOV-8132B Charging Pump Discharge Crossconnect No MOV-8133A Charging Pump Discharge Crossconnect No M0V-81338 Charging Pump Discharge Crossconnet No MOV-8107 Charging Line Isolation No POV-8108 Charging Line Isolation No l MOV-8109A Charging Pump Mini Flow Isolation No MOV-81098 Charging Pump Mini Flow Isolation No i!0V-8109C Charging Pump Mini Flow Isolation No /

• Licensee may delete valves from this table provided the thermal overload protection devices are permanently bypassed.

FARLEY-UNIT 2 3/4 8-32

REFUELING OPERATIONS 7 ^ 3/4;9.13 STORAGE POOL VENTILATION (FUEL MOVEMENT) ' LIMITING CONDITION FOR OPERATION 3.9.13 Two independent penetration room filtration systems (Specification 3.7.8) shall be OPERABLE and aligned to the spent fuel pool room: APPLICABILITY: During crane operation with loads, over the fuel in the spent fuel pit and during fuel movement within the spent fuel pit. ACTION a. With one penetration room filtration system inoperable return both systems to OPERABLE status within 48 hours or suspend all movement of fuel and crane operation with loads over the spent fuel in the storage pool room. b. The provisions of Specification 3.0.3 and 3.0.4 are not applicable. SURVEILLANCE REQUIREMENTS 4.9.13.1 Two penetration room filtration systems shall be verified to be aligned to the spent fuel pool room within 12 hours prior to fuel handling or crane operations in the storage pool room and at least once per 24 hours thereafter until fuel movement operations in the storage pool room are suspended. 4.9.13.2 ' The penetration room filtration system shall be demonstrated ~~ OPERABLE per the reguirements of Specification 4.7.8. 4.9.13.3 At least csce per 18 months verify that the normal spent fuel pool system ventilation system will isolate upon receipt of either; a. The spent fuel pool ventilation low differential pressure test signal, or b. A spent fuel pool high radiation test signal. s FARLEY-UNIT 2 3/4 9-15

REFUELING OPERATIONS 3/4.9.14 CONTAINMENT PURGE EXHAUST FILTER LIMITING CONDITION FOR OPERATION 3.9.14 The containment purge exhaust filter shall be OPERABLE and valve N1P13V293 closed. APPLICABILITY: During CORE ALTERATIONS and Fuel Movement inside containment with any containment purge isolation valve open.* ACTION: With the ontainment purge exhaust filter. inoperable either: 1. Immediately clore the 48 inch containment purge isolation valves (CBV-HV-3196, 3197, 3198A and 31980) and the 18 inch containment mini purge isolation valves (CBV-HV-2866A, 28668, 2867A and 28678), or 2. Cease all CORE ALTERATIONS and fuel movement. SURVEILLANCE REQUIREMENTS 4.'J.14 The above required containment purge exhaust filter shall be demonstrated OPERABLE: a. At least once per 18 months or'(1) after any structural maintenance on the AEPA filter or charcoal adsorber housin'gs, or (2) following painting, fire or chemical release that could have contaminated the charcoal adsorbers or HEPA filter in any ventilation zone communicating with the system by: ~ "Not applicable during initial fuel loading. l f FARLEY-UNIT 2 3/4 9-16 ^**Ud**" l' ~

ADMINISTRATIVE CONTROLS ~J. Offsite releases of radioactive materials in liquid and gaseous effluents which exceed tN limits of Specification 3.11.1.1 or 3.11.2.1. k. Exceeding the limits in Specification 3.11.1.4 or 3.11.2.6 for the storage of radioactive materials in the listed tanks. The written follow-up report shall include a schedule and a description of activities planned and/or taken to reduce the contents to within the specified limits. THIRTY-0AY WRITTEN REPORTS 6.9.1.13 The types of events listed below shall be the subject of written reports to the Director of the Regional Office within 30 days of occurrence of the event. The written report chall include, as a minimum, a completed copy of a licensee event report form. Information provided on the licensee event report form shall be supplemented, as needed, by additional narrative material to provida complete explanation of the circumstances surrounding the event, Reactor protection system or engineered safety feature instrument a. settings which are found to be less conservative than those estab-lished by the Technical Specifications but which do not prevent the fulfillment of the functional requirements of affected systems, b. Conditions leading to operation in a degraded mode permitted by a Limiting Condition for Operation or plant shutdown required by a Limiting Condition for Operation. Observed inadequacies in the implementation of administrative or c. procedural controls which threaten to cause reduction of degree of redundancy provided in reactor protection systems or engineered safety feature systems. d. Abnormal tfegradation of systems other than those specified in 6.9.1.12.c above designed to contain radioactive material resulting from the fission process. An unplanned offsite release of 1) more than 1 curie of radioactive e. material in liquid effluents, 2) more than 150 curies of noble gas in gaseous effluents, or 3) more than 0.05 curies of radiciodine in gaseous effluents. The report of an unplanned offsite release of radioactive material shall include the following information: 1. A description of the event and equipment involved. 2. Cause(s) for the unplanned release. 3. Actions taken to prevent recurrence. 4. Consequences of the unplanned release. f. Measured levels of radioactivity in an environmental samplin0 medium c l determined to exceed the reporting level values of Table 3.12-2 when average over any calendar quarter sampling period. FARLEY-UNIT 2 6-21 i

ADMINISTRATIVE CONTROLS I RADIAL PEAKING FACTOR LIMIT REPORT limit for Rated Thermal Power (F,R ) shall be provided to 6.9.1.14 The Fxy the Director of the Regional Office of Inspection and Enforcement, with a copy to the Director, Nuclear Reactor Regulation, Attention Chief of the Core l Performance Branch, U.S. Nuclear Regulatory Commission, Washington, D.C. 20555 for all core planes containing bank "D" control rods and all unrodded core planes at least 60 days prior to cycle initial criticality. In the event that the limit would be submitted at some other time during core life, it will be submitted 60 days prior to the date the limit would become effective unless otherwise exempted by the Commission. 1 RTP Any information needed to support F need not be included in this report ? will be by request from the NRC and SPECIAL REPORTS 6.9.2 Special reports shall be submitted to the Director of the Office of Inspection and Enforcement Regional Office within the time period specified for each report. 6.10 RECORD RETENTION In addition to the applicable record retention require'ments of Title 10, Code of Federal Regulations, the following records shall be retained for at least the minimum period indicated. ~ 6.10.1 The following records shall be retained for at least five years: Records'and logs of unit operation covering time interval at each d. power level, b. Records and logs of principal maintenance activities, inspections, repair and replacement of principal items of equipment related to nuclear safety. c. All REPORTABLE OCCURRENCES submitted to the Commission. d. Records of surveillance activities, inspections and calibrations required by these Technical Specifications. e. Records of changes made to the procedures required by Specification 6.8.1. f. Records of radioactive shipments. i g. Records of sealed source and fission detector leak tests and i l results. Amendment No.1 l FARLEY-UNIT 2 6-22 .}}