ML20072U516
| ML20072U516 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 04/07/1983 |
| From: | MISSISSIPPI POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML20072U465 | List: |
| References | |
| NUDOCS 8304110335 | |
| Download: ML20072U516 (34) | |
Text
{{#Wiki_filter:- - _ _ I.CGGNS-13) ADMINISTRATIVE CONTROLS PROMPT NOTIFICATION WITH WRITTEN FOLLOWUP (Continued)
- d. Reactivity anomalies involving disagreement with the predicted value of reactivity balance under steady state conditions during power opera-tion greater than or equal to 1% delta k/k; a calculated reactivity balance indicating a SHUTDOWN MARGIN less conservative than specified in the technical specifications; short-term reactivity increases that correspond to a reactor period of less than 5 seconds or, if subcritical, an unplanned reactivity insertion of more than 0.5% delta k/k; or occurrence of any unplanned criticality. .
- e. Failure or malfunction of one or more components which prevents or could prevent, by itself, the fulfillment of the functional require-ments of system (s) used to cope with accidents analyzed in the SAR.
f. Personnel error or procedural inadequacy which prevents or could prevent, by itself, the fulfillment of the functional requirements of systems required to cope with accidents analyzed in the SAR.
- g. Conditions arising from natural or man-made events that, as a direct result of the event, require unit shutdown, operation of safety systems, or other protective measures required by technical specifications.
wh . Errors discovered in the transient or accident analyses or in the methods used for such analyses as described in the safety analysis f report or in the bases for the technical specifications that have or
- could have permitted reactor operation in a manner less conservative than assumed in the analyses.
- 1. Performance of structures, systems, or components that requires remedial action or corrective measures to prevent operation in a manner less conservative than assured in the accident analyses in the safety analysis report or technical specifications bases; or discovery during unit life of conditions not specifically considered in the safety analysis report or technical specifications that require remedial action or corrective measures to prevent the existence or development of an unsafe condition. .
J. Offsite releases of radioactive materials in liquid and gaseous effluents which exceed the limits of Specification 3.11.1.1 or 3.11.2.1. i
- k. Exceeding the limits in Specification 3.11.X.4 er-*-*_*dM for the storage of radioactive materials in the listed tanks. The written follow-up report shall include a schedule and a description of actiyities planned and/or taken to reduce the contents to within the specified limits.
GRAND GULF-UNIT 1 6-20 , 8304110335 830407 PDR ADOCK 05000416 P, PDR
n TABLE 4.3.1.1-1 , REACTOR PROTECTION SYSTEM INSTRiiMENTATION SURVEILLANCE REQlllREMENTS h* m
- CHANNEL CilANNEL FUNCil0NAL , CllANNEL OPERATIONAL CON 0!TIONS FOR WillCll CALIllRATIONI ")
- ' FUNCTIONAL UNIT CllECK TEST SURVEILLANCE REQUIRED E q 1. Intermediate Range Monitors: S/U(c) ,W , g a. Neutron Flux - liigh S/U.S.(b) R 2 ! S , W R 3, 4, 5 ! b. Inoperative NA W NA 2,3,4,5 j 2. Average Power Range Monitor: I}
- a. Neutron Flux - liigh, S/U.S.(b) S/U(c) ,W SA 2 Seldown S W SA 3, 5 I
- b. Flow Biased Simulated
. Thermal Power - High S. D(h) 3fg(c),y g(d)(e), SA, R III 1 s
- c. Neutron Flux - liigh S S/UICI, W W(d) , 34 g %
9 0 N l
- d. Inoperative NA W NA 1, 2, 3, 5. p
- 3. Reactor Vessel Steam Dome Z E Pressure - High S M R IU} 1, 2 } D T 1
- 4. . Reactor Vessel Water Level -
Low, Level 3 S M Rg g) 1, 2 h4 g j 1
- 5. Reactor Vessel Water Level -
High, Level 8 , 5 M R(g) 1 pD
. m 1 6. Main. Steam Line Isolation Valve - Closure ,, MA M R 1 1
- 7. Main Steam Line Radiation - m
+ liigh S M R 1, 2 V
- 8. Drywell Pressure - liigh S M R IUI 1, 2 1
^
I g TAlllE 4.3.1.81-1 (Continued) REACTOR PROTECTION SYSTIM INSTRUMENTATION SURVEILLANCE REQUIREMENTS , E CilANNEL OPERATIONAL 5 CHANNEL FUNCil0NAL CilANNEL CON 01TIONS FOR WlilCll
; e FUNCTIONAL UNIT CllECK TEST CAllllRATION SURVEILLANCE R[ QUIRED e
- ' 5 9. Scram Discharge Volume Water Level - liigh 5 M R IU) 1, 2, 5
[ R IU)
- 10. Turbine Stop Valve - Closure 5 M I f'
- 11. Turbine Control Valve Fast Closure Valve Trip System 011 g9)
Pressure - Low 5 M R 1 i 12. Reactor Mode Switch i Shutdown Position NA R NA 1,2,3,4,5 { 13. Manual Scram NA M NA 1,2,3,4,5
- T
! (a) Neutron detectors may be excluded from CllANNEL CAllBRATION. (b) The IRM and SRM channels shall be determined to overlap for at least 1/2 decade during each startup after entering OPERAIIONAL CONDITION 2 and the IRM and APRM channels shall be deter-mined to overlap for at least 1/2 decade during each controlled shutdown, if not performed within the previous 7 days. (c) Within 24 hours prior to startup, if not performed within the previous 7 days. P (d) This calibration shall consist of the adjustment of the APRM channel to conform to the power values = calculated by a heat balance during OPERAT10NAL CONDITION I when TillRMAL POWI.R > 25% of RATED. O
; THERMAL POWER. reater tiian 2% of RATED O TilERMAL POWER. Adjust Any APRM thechannel APRMgain channh1 adjustment if the madeabsolute difference in compliance wi is g'th Specification 3.2.2 O shall not he included in determining the absolute difference. 2 (e) This calibration shaII consist of the adjustment of the APRM flow biased channel to conform to a (/l calihrated flow signal. l (f) The LPRMs shall be calibrated at least once per 1000 ef fective full power hours (EfPil) using the q TIP system. Not.s u red Core f/sco f6 be. less naAs of- D VtM [y's estin.b/
,, (g) Calibrate trip unit at least once per 31. days.
(h) ^.,,,i, . . . _ m.,,c ; ; ,, ^ ,, ,.. eftml f
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d C8Fe flon.* ad /Ae ex/sf/q
, .s.f/,As cMr.g New. posi W, M
p (i) This calibration shall consist of verifying the 6 .t I second simulated thermal power time constant. t
- 3. (66N S -137)p,1 REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued) 4.4.6.1.2 The reactor coolant system temperature and pressure shall be deter-mined to be to the right of the criticality limit line of Figure 3.4.6.1-1 curves C and C' within 15 minutes prior to the withdrawal of control rods to bring
, the reactor to criticality and'at least once per 30 minutes during system-heatup. 4.'4.6.1.3 The reactor vessel material specimens shall be removed and examined to determine reactor. pressure vessel fluence as a function of time and THERMAL POWER as required by 10 CFR 50, Appendix H in accordance with the schedule in Table 4.4.6.1.3-1. The results of these fluence determinations shall be used to update the curves of Figure 3.4.6.1-1. The adjusted reference temperature resulting from neutron irradiation shall be calculated based on the greater of the following:
- a. Actual shift in the RT NDT f r materials in the capsules as defined by the CVN impact test.
53 2AZ7 AE
- b. Predicted shift in RT for plate C2594-2 and weld 627260/99fWMH%E l (heat / lot) as determib by Regulatory Guide 1.99, " Effects of Residual Elements on Predicted Radiation Damage to Reactor Vessel-Materials".
4.4.6.1.4. The reactor vessel flange and head flange temperature shall be verified to be greater than or~ equal to 70*F: ' I
- a. In OPERATIONAL CONDITION 4 when reactor coolant system temperature is:
- 1. $ 100*F, at least once per 12 hours.
- 2. 1 80*F, at least once per 30 minutes.
I b. Within 30 minutes prior to and at least once per 30 minutes during tensioning of the reactor vessel head bolting studs. _ l l GRAND GULF-UNIT 1 3/4 4-18 l
TABLE 4.4.6.1.3-1 o j REAC10R VESSEL MATERIAL SURVEILLANCE PROGRAM-WITH0RAWAL SCHEDULE O h ^ VESSEL LEAD WITHDRAWAL TIME LOCATION FACTOR (EFPN) NU h 1. 131C8981G1-N01 3a 0.46 # 10
- 2. 131C8981G1-N02 177 0.46 [M s 0.46 Spare
- 3. 131C8981G1-NO3 183a
- i. R.
B i i O A 2
- M I
M
, ol 4
V 3 P
h, (GGNS-150) TABLE 3.7.8-1 AREA TEMPERATURE MONITORING AREA TEMPERATURE LIMIT (*F) EQUIPMENT EQUIPMENT NOT OPERATING OPERATING
- a. Containment Inside Drywell 135 150 CRD Cavity 135 185 Outside Drywell -ee 60 ase- f or l Steam Tunnel 125 . 125
- b. Auxiliary Building General 104 104 ECCS Rooms 105 150 104 104 ESF Electrical Rooms
- c. Control Building E5F Switchgear and Battery Rooms 104 104 77 77 Control Room 125 125
- d. Diesel Generator Rooms SSW Pumphouse 104* 104* ,
. e.
"For this area, the limit shall be the greater of 104*F or outside ambient temperature plus 20*F, not to exceed 122*F for greater than one hour.
9 GRAND GULF-UNIT 1 3/4 7-43
l
- 5. Gc NS 4 5' hi.
PLANT SYSTEMS 3/4.7.2 CONTROL ROOM EMERGENCY FILTRATION SYSTEM LIMITING CONDITION FOR OPERATION 3.'7.2 ' Two independent control room emergency filtration system subsystems shall be OPERABLE. APPLICABILITY: All OPERATIONAL CONDITIONS and *. ACTION:
- a. In OPERATIONAL CONDITION 1, 2 or 3 with one control room emergency filtration subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days or be in at least HOT SHUIDOWN within the next 12 hours and in COLD SHUTDOWN within the following 24 hours.
- b. In OPERATIONAL CONDITION 4, 5 or *:
- 1. With one control room emergency filtration subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 7 days or initiate and maintain operation of the OPERABLE subsystem in the isolation mode of operation.
- 2. With both control room emergency filtration subsystems inoperable, suspend CORE ALTERATIONS, handling of irradiated fuel in the secondary containment and operations with a potential for draining the reactor vessel. e
, c. The provisions of Specification 3.0.3 are not applicable in Operational Condition *.
SURVEILLANCE REQUIREMENTS i 4.7.2 Each control room emergency filtration subsystem shall be demonstrated OPERABLE: 3
- a. At least once per 31 days on a STAGGERED TEST BASIS by initiating, from the control room, flow through the HEPA filters and charcoal l
adsorbers and verifying that the subsystem operates for at least i 10 hours with the heaters OPERABLE.
- b. At least once per 18 months or (1) after any structural maintenance on the HEPA filter or charcoal adsorber housings, er (2) following painting, fire or chemical release in any ventilation zone communicating with the subsystem by: _
with the subsystem operating at e of
- 1. Ver) 4000 cfm i 10% an 'n thro filters and charcoal adsorbers, t low of the system to the ess than or equal to subsystem is facilit by admitting cold DOP at the system intake. _
R When irradiated fuel is being handled in the secondary containment. I GRAND GULF-UNIT 1 3/4 7-5 O
5,(GGN$-15Gby,2. PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) Verifying that the subsystem satisfies the in place testing l
} [ acceptance criteria and uses the test procedures of Regulatory Positions C.S.a, C.5.c and C.S.d of Regulatory Guide 1.52, Revision 2, March 1978, and the system flow rate is 4000 cfm i 10%. '
2,g. Verifying within 31 days after removal that a laboratory analysis of a representative carbon sample obtained in accordance with l Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978.
.3. M Verifying a subsystem flow rate of 4000 cfm i 10% during subsystem operation when tested in accordance with ANSI N510-1975.
- c. After every 720 hours of charcoal adsorber operation by verifying within 31 days after removal that a laboratory analysis of a repre-sentative carbon sample obtained in accordance with Regulatory Positon C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a
. of Regulatory Guide 1.52, Revision 2, March 1978.
- d. At least once per 18 months by:
- 1. Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 7.2 inches Water Gauge while operating the subsystem at a flow rate of 4000 cfm i 10%.
- 2. Verifying that on each of the below isolation mode actuation l- test signals, the subsystem automatically switches to the isola-tion mode of operation and the isolation valves close within 4 seconds:
a) High radiation in the outside air intake duct, b) High chlorine concentration in the outside air intake duct, c) High drywell pressure, and d) Low reactor water level.
- 3. Verifying that the heaters dissipate 20.7 1 2.1 kW when tested' in accordance with ANSI N510-1975.
- e. After each complete or partial replacement of a HEPA filter bank by verifying that the HEPA filter banks remove greater thar or equal to 99.95% of the DOP when they are tested in place in accordance with ANSI H510-1975 while operating the system at a flow rate of 4000 cfm i 10%.
- f. After each complete or partial replacement of a charcoal adsorber bank by verifying that the charcoal adsorbers remove 99.95% of a halogenated hydrocarbon refrigerant test gas when they are tested in place in accordance with ANSI N510-1975 while operating the system at a flow rate of 4000 cfm i 10%.
GRAND GULF-UNIT 1 3/4 7-6 .
6(GG A/S-187)g1 N. Cwmacs Ts.s Swee r CONTAINMENT SYSTEMS 3/4.6.5 DRYWELL POST-LOCA VACUUM BREAKERS . LIMITING CONDITION FOR OPERATION 3.6.5 All drywell post-LOCA vacuum breakers shal1 be OPERABLE and closed.. APPLICABILITY: OPERATIONAL CONDlTIONS 1, 2 and 3. ACTION:
- a. With one drywell post-LOCA vacuum breaker inoperable for opening but known to be closed, restore the inoperable vacuum breaker to OPERABLE status within 72 hours or be in at least HOT SHUTDOWN within the neyt 12 hours and in COLD SHUTDOWN within the following 24 hours.
- b. With one drywell post-LOCA vacuum breaker open.. restore the open vacuum breaker to the closed position within I hour or be in at least HOT SHUT-OfAIN within the next 12 hours and in C3LD SHUTE 0'<.R within tne following
. 24 hours.
- c. With the position indicator of an OPERABLE drywell post-LOCA vacu'um breaker inoperable, verify the vacuum breaker to be closed at least once per 24
# hours by local indication. Otherwise declare the vacuum breaker inoperable.
(See Note 1) l
~
SURVEILLAt;CE REOUIREMENTS j l-4.6.5 Each drywell post-LOCA vacuum breaker 'shall be:
- a. Verified closed at least once per 7 days.
- b. Demonstrated OPERABLE:
- 1. At least 'nce o per 31 days by:
a) Cycling the vacuum breaker and isolation valve (s) through at least one complete cycle of full travel. b) Verifying the position indicater OPERA'BLE by observing expected l valve movement during the cycling test. (See Note 1) !
- 2. At least once per 18 months by:
I a) Verifying the pressure differential required to open the vacuum breaker, from the closed position, to be less than g or equal to 1.0 psid, and (See Note 1) l l b) Verifying the position indicator OPERABLE by performance of a l CHAlit<EL CALIBRATION. (See Note 1) 1 l G:tA';D GULF-UNIT 1 3/4 6-45 Amendment No. 4 [ _ _
6, (GG N S - 18 7)P. 2. CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- 3. By verifying the OPERABILITY of the vacuum breaker isolation valve differential pressure actuation instrumentation with the opening setpoint 1.0 psid by performance of a:
a) CHANNEL CHECK at least once per 24 hours, b) CHANNEL FUNCTIONAL TEST at least once per 31 days, and c) CHANNEL CALIBRATION at least once per 18 months. Note 1: Until restart after the first refueling outage, the following requirements shall apply: 3.6.5
- c. With the position indicator of an OPERABLE drywell post-LOCA isolation valve for a vacuum breaker inoperable, verify the isolation valve to be closed at least once per 24 hours by local indication. Otherwise declare the isolation valve inoperable.
4.6.5.b.1
- b. Verifying the position indicator for the vacuum breaker isolation valve OPERABLE by observing expected valve movement during the" cycling test.
4.6.5.b.2 At least once per 18 months by:
~
a) Verifying the pressure differential required to open the vacuum breaker, from the closed position, to be less than or equal to 1.0 psid,by u:: ef an equivaltnt t::t weight :nd lever :r er the v uum brc:L r, and b) Verifying the position indicator for the vacuum breaker isolation valve OPERABLE by performance of a CHANNEL CALIBRATION. i i l t i GRAND GULF-UNIT 1 3/4 6-45a Amendment No. 4 MAEC-82/259 November 18, 1982
TABLE 3.3.3-2 y EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS ALLOWABLE i 5 TRIP SETPOINT VALUE
- c7 TRIP FUNCTION .
E A. DIVISION 1 TRIP SYSTEM
- [ 1. RHR-A (LPCI MODE) AND LPCS SYSTEM
- a. Reactor Vessel Water Level - Low Low low, level 1 1 -150.3 inches
- 1 -152.5 inches h b. Drywell Pressure - High 5 1.89 psig i 1.94 psig LPCI Pump A Start Time Delay Relay i 5 seconds 5 5 seconds
- c. NA
- d. Manual Initiation NA
}
- 2. AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "A" > -152.5 inches
- a. Reactor Vessel Water Level - Low Low Low, Level 1 1 -150.3 inches *
- b. Drywell Pressure - High 5 1.89 psig $ 1.94 psig
< 115 seconds < 117 seconds
- c. ADS Timer I 10.8 inches
- d. Reactor Vessel Water Level-Low, level 3 5 11.4 inches *
- e. LPCS Pump Discharge Pressure-High [145psig, increasing [140psig, increasing LPCI Pump A Discharge Pressure-High 1 125 psig, increasing 1 122 psig, increasing i f.
NA NA
- g. Manual Initiation
- B. DIVISION 2 TRIP SYSTEM g 1. RHR B AND C (LPCI MODE)
- a. Reactor Vessel Water Level - Low Low Low, Level 1 1 -150.3 inches" 1 -152.5 inches
) [ 5 1.89 psig $ 1.94 psig a
- 4, b. Drywell Pressure - High 5 seconds m c. LPCI Pump B Start Time Delay Relay 5 5 seconds 5 l NA NA
- d. Manual Initiation * ! 2. AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "B" > -152.5 inches
- a. Reactor Vessel Water Level - Low Low Low, Level 1 > -150.3 inches *
- b. Drywell Pressure - High 31.89psig 51.94psig l < 115 seconds < 117 seconds
- c. ADS Timer i 10.8 inches
- d. Reactor Vessel Water Level-Low, level 3 i 11.4 inches *
- e. LPCI Pump B and C Discharge Pressure-High [125psig, increasing [122psig, increasing NA NA i f. Manual Initiation
! C. DIVISION 3 TRIP SYSTEM
- 1. HPCS SYSTEM <-43.8 inches hQ
- a. Reactor Vessel Water Level - Low Low, Level 2 >-41.6 inches *
- b. Drywell Pressure - High i 1.89 psig i 1.94 psig 2 j
- c. Reactor Vessel Water Ldvel - High, level 8 353.5 inches
- 555'.7 inches y l
- d. Condensate Storage Tank Level - Low 1 0 inches 1 -3 inches m j < 6.5 inches u i e. Suppression Pool Water Level - High < 5.9 inches ~*
AA RA
- f. Manual Initiation P I
V'
- 8. (GG N S- 28Q INSTRUMENTATION TABLE 3.3.4.2-1 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION MINIMUMOPERABLECHANg5PER TRIP SYSTEM TRIP FUNCTION CD) 2
- 1. Turbine Stop Valve - Closure 2(b)
- 2. Turbine Control Valve - Fast Closure (a) A trip system may be placed in an inoperable status for up to 2 hours for required surveillance provided that the other trip system is OPERABLE.
(b) This function shall be au o_atically Dypassed when turbine first stage l
- pressure is less than 30% o the value of turbine first stage pressure, in psia, at valves wide open (WO) steam flow, equivalent to THERMAL POWER less than 40% of RATED THERMAL POWER.
e i i l l l As. ra:hJ se_treid . I;NJ setpo,gt % be de\erM ka ael-{k.s clur:wg l shr%p P :~t t est skpregem a g ,s u. A . %q d rego;reh to h w ,,coh a5e. m m:K:a 5d . 9 0 d m-y 5 e4 ie=,t CompleY.04.
- GRAND GULF-UNIT 1 3/4 3-40 l
- 9,(GG NS-301,306,348)p.i ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS 4.8.1.1.1 Each of the above required independent circuits between,the offsite transmission network and the onsite Class 1E distribution system shall be:
- 4. Determined OPERABLE at least once per 7 days by verifying correct breaker alignments and indicsted power availability, and
- b. Demonstrated OPERABLE at least once per 18 months during shutdown by transferring, manually and automatically, unit power supply from the normal circuit to the alternate circuit.
4.8.1.1.2 Each of the above required diesel generators shall be demonstrated OPERABLE:
- a. In accordance with the frequency specified in Table 4.8.1.1.2-1 on a STAGGERED TEST BASIS by:
- 1. Verifying the fuel level in the day tank.
- 2. Verifying the fuel level in the fuel storage tank.
- 3. Verifying the fu*1 transfer pump starts and transfers fuel from the storage system to the day tank.
- 4. Verifying the diesel starts from ambient condition and accelerates to at least 441 rpm for diesel generators 11 and 12 and 882 rpm for diesel generator 13 in less than or equal to 10 seconds. The generator voltage and frequency shall be 4160 1 416 volts and l 60 t 1.2 Hz within M seconds after the start signal. The diesel l g 7 generator shall be' started for this test by using one of the #
following signals: a) Manual. b) Simulated loss of offsite power by itself. c) Simulated loss of offsite power in conjunction with an ESF actuation test signal. d) An ESF actuation test signal by itself.
- 5. Verifying the diesel generator is synchronized, loaded to greater l than or equal to 3500 kW for diesel generators 11 and 12 and 1650 kW for diesel generator 13 in less than or equal to 60 seconds, and operates with these loads for at least 60 minutes.
- 6. Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.
- 7. Verifying the pressure in all diesel generator air start receivers
! to be greater than or equal to: a) 160 psig for diesel generator 11 and 12, and b) 175 psig for diesel generator 13. (
- b. At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to I hour by checking for and removing accumulated water from the day fuel tanks.
E GRAND GULF-UNIT 1 3/4 8-3
' 9.[GG NS-301,306,3+8)p.2, ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- c. At least once per 92 days and from new oil prior to addition to the storage tanks by verifying that a sample obtained in accordance with ASTM-D270-1975 has a water and sediment content of less than or equal to .05 volume percent and a kinematic viscosity 9 40*C of greater than or equal to 1.9 but less than or equal to 4.1 when tested in accordance with ASTM-D975-77, and an impurity-level of less than 2 mg. of insolubles per 100 al. when tested in accordance with ASTM-D2274-70, except that the test of new fuel for impurity level shall be performed within 7 days j after addition of the new fuel to the storage tank. j
- d. At least once per 18 months, during shutdown, by: l l 1. Subjecting the diesel to an inspection in accordance with pro-
' cedures prepared in conjunction with its manufacturer's recom- l mendations for this class of standby service.
- 2. Verifying the diesel generator capability to reject a load of greater than or equal to 1735 kW for diesel generator 11, greater than or equal to 890 kW for diesel generator 12, and greater than or equal to 2780 kW for diesel generator 13 while maintaining less than or equal to 75% of the difference between nominal speed and the overspeed trip setpoint, or 15% above nominal, whichever is less.
- 3. Verifying the diesel generator capability to reject a load of 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13 without tripping. The generator voltage shall not exceed 5000 volts during and following the load rejection.
- 4. Simulating a loss of offsite power by itself, and:
a) For Divisions 1 and 2:
- 1) Verifying deenergization of the emergency busses and load shedding from the emergency busses.
- 2) Verifying the diesel generator starts on the auto-start signal, energizes the emergency busses with permanently g g t connected loads withia K seconds, energizes the auto- l
~
connect.eo shutdown lodds through the load sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown loads. After ener-gization, the steady state voltage and frequency of the emergency busses shall be maintained at 4160 1 416 volts and 60 1 1.2 Hz during this test. b) For Division 3:
- 1) Verifying de-energization of the emergency bus.
- 2) Verifying the diesel generator starts on the auto-start signal, energizes the emergency bus with the loads within X seconds and operates for greater than or equal to , l 5 minutes while its generator is loaded with the shutdown loads. After energization, the steady state voltage and frequency of the emergency bus shall be maintained at 4160 1 416 volts and 60 1 1.2 Hz during this test.
GRAND GULF-UNIT 1 3/4 8-4 s
- . - . . -- - - - . _ . - . - - , , _ _ . _ - , . . ~ , . . _ - _ - . ___
m
l ..
- 9. (GGNS-3o1,306 3 5+8)p.3 ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- 5. Verifying that on an ECCS actuation 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 minutes. The generator voltage and frequency shall be 4160 i Og 416 volts and 60 1 1.2 Hz_ within X seconds after the auto-start signal; the steady state generator voltage and frequency shall be maintained within these limits during this test.
- 6. Verifying that on a simulated loss of the diesel generator, with offsite power not available, the loads are shed from the emergency busses and that subsequent loading of the diesel generator is in accordance with design requirements.
- 7. Simulating a loss of offsite power in conjunction with an ECCS actuation test signal, and:
a) For Divisions 1 and 2:
- 1) Verifying deenergization of the emergency busses and load shedding from the emergency busses.
2)' Verifying the diesel generator starts on the auto-start signal, energizes the emergency busses with permanently
/0 -
connected loads within X seconds, energizes the auto-connected shutdown lo~ ads through the load sequencer
- and operates for greater than or equal to 5 minutes while its generator is loaded with the emergency loads.
After energization, the steady state voltage and frequency of the emergency busses shall be maintained '- at 4160 1 416 volts and 60 1 1.2 Hz during this test. b) For Division 3.
- 1) Verifying de-energization of the emergency bus.
- 2) Verifying the diesel generator starts on the auto-start signal, energizes the emergency bus with the permanently
/0 connected loads withig X seconds and the autoconnected l emergency loads witnih 20 seconds and operates for j
i greater than or equal to 5 minutes while its generator is loaded with the emergency loads. After energization, the steady state voltage and frequency of the emergency bus shall be maintained at 4160 1 416 volts and 60 1 1.2 Hz during this test.
- 8. Verifying that all automatic diesel generator trips are automatically bypassed upon an ECCS actuation signal except
a) For Divisions I and 2, engine overspeed, generator l differential current, low lube oil pressure, and generator ground overcurrent. b) For Division 3. engine overspeed and generator differential current. 2 GRAND GULF-UNIT 1 3/4 8-5
~_ .- _ . _ _ ._.. _ _. .__ ,_ -_ . _ .
9.(ans-w.,30s,uO,,+ ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- 9. 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 7700 kW for diesel gen-erators 11 and 12 and 3630 kW for diesel generator 13 and during the remaining 22 hours of this test, the diesel generator shall be loaded to 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13. The generator voltage and frequency shall be 4160 416 volts and 60 t 1.2 Hz withi % econds after I the start signal; the steady state generator voltage and frequency shall be maintained within these limits during this test. Within 5 minutes after completing this 24-hour test, perform Surveillance Requirement 4.8.1.1.2.d.4.a).2) and b).2)*.
- 10. Verifying that the auto-connected loads to each diesel generator do not exceed the continuous rating of 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generatar 13.
- 11. Verifying the diesel generator's c6pability to:
a) Synchronize with the offsite power source while the generator is loaded with its emergency loads upon a simulated restoration of offsite power, b) Transfer its loads to the offsite power source, and c) Be restored to its standby status. f 12. Verifying that with the diesel generator operating in a test mode and connected to its bus that a simulated ECC6 actuation signal: a) For Divisions 1 and 2, overrides the test mode by return-
'ing the diesel generator to standby operation.
b) For Division 3, overrides the test mode by bypassing the diesel generator automatic trips per Surveillance Require-ment 4.8.1.1.2.d.8.b). l l 13. Verifying that with all diesel generator air start receivers pressurized to less than or equal to 256 psig and the compres-sors secured, the diesel generator starts at least 5 times from ambient conditions and accelerates to at least 441 rpm for diesel generators 11 and 12 and 882 rpm for diesel generator 13 in less than or equal to K seconds.
/0 A
If Surveillance Requirement 4.8.1.1.2.d.4.a)2) or b)2) are not satisfactorily completed, it is not necessary to repeat the preceding 24 hour test. Instead, the diesel generator may be operated at rated load for one hour or until operating temperatures have stabilized. GRAND GULF-UNIT 1 3/4 8-6 l
7.(cos-soi, s*, as)e. s ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued t j 14. Verifying that the fuel transfer pump transfers fue'l from each fuel storage tank to the day tank of each diesel via the installed lines.
- 15. Verifying that the automatic load sequence timer is OPERABLE with the interval between each load block within i 10% of its design interval for diesel generators 11 and 12.
- 16. Verifying that the following diesel generator lockout features prevent diesel generator starting and/or trip the diesel generator only when required:
a) Generator loss of excitation. b) Generator reverse power. c) High jacket water temperature. d) Generator overcurrent with voltage restraint. e) Bus underfrequency (11 and 12 only). f) Generator bearing temperature high (11 and 12 only). g) Low turbo charger oil pressure (11 and 12 only). h) High vibration (11 and 12 only). i) High lube oil temperature (11 and 12 only). j) Low lube oil pressure. k) High crankcase pressure.
- e. At least once per 10 years or after any modifications which could affect diesel generator interdependence by starting all three diesel generators simultaneously, during shutdown, and verifying that the three diesel generators accelerate to at least 441 rpm for diesel generators 11 and 12 and 882 rpm for diesel generator 13 in less than or equal to K seconds. l
- f. At least onc/0e per 10 years by:.
- 1. Draining each fuel oil storage tank, removing the accumulated sediment and cleaning the tank using a sodium hypochlorite or equivalent solution, and i
l ! 2. Performing a pressure test of those portions of the diesel fuel oil system designed to Section III, subsection ND of the ASME Code in accordance with ASME Code Section 11, Article IWD-5000. 4.8.111.3 Reports - All diesel generator failures, 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 Regu-l latory Position 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 nuclear unit l basis, is greater than or equal to 7, the report shall be supplemented to include the additional information recommended in Regulatory Position C.3.b l of Regulatory Guide 1.108, Revision 1, August 1977. GRAND GULF-UNIT 1 3/4 8-7
- 10. @cn s - 30s) e.1 TABLE 3.3.2-3 ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME RESPONSE TIME (Seconds)#
TRIP FUNCTION
- 1. PRIMARY CONTAINMENT ISOLATION
< 13I ")
- a. Reactor Vessel Water Level - Low Low, Level 2 Drywell Pressure - High 513(a) b.
- c. Containment and g ell Ventilation Exhaust < 1.0*/< 13(,)**
Radiation - High WA
~
- d. Manual Initiation .
- 2. MAIN STEAM LINE ISOLATION
- a. Reactor Vessel Water Level - Low Low Low, < 1.0*/< 13(*)**
Level 1 7 1.0*/7 13((a) ,
- b. Main Steam Line Radiation - High(b) a I 1.0*/7 13I "))**,
- c. Main Steam Line Pressure - Low 30.5*/513
- d. Main Steam Line Flow - High NA
- e. Condenser VacLum - Low NA f.
Main Steam Line Tunnel Temperature - High NA
- g. Main Steam Line Tunnel a Temp. - High NA
- h. Manual Initiation
- 3. SECONDARY CONTAINMENT ISOLATION
< 13(*)
- a. Reactor Vessel Water Level - Low Low, Level 2 Drywell Pressure - High 313(*) #
~
b.
- c. Fuel Handling Area Ventilation Exhaust I Radiation - High High(b) $ 13 ")
- d. Fuel Handling Area Pool Sweep Exhaust i 13(,)
Radiation - High High(b) NA
- e. Manual Initiation
- 4. REACTOR WATER CLEANUP SYSTEM ISOLATION N
- a. 3 a Flow - High NA
- b. a Flow. Timer NA
- c. Equipment Area Temperature - High NA Equipment Area a Temp. - High g)
- d. < 13
- e. Reactor Vessel Water Level - Low Low, level 2 -
- f. Main Steam Line Tunnel Ambient NA Temperature - High NA
- g. Main Steam Line Tunnel a Temp. - High NA
- h. SLCS Initiation NA
- 1. Manual Initiation 3/4 3-18 GRAND GULF-UNIT 1
IO. hG NS -308) g g INSTRUMENTATION TABLE 3.3.2-3 (Continued) ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION RESPONSE TIME (Seconds)#
- 5. REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION
- a. RCIC Steam Line Flow - High
- b. RCIC Steam Supply Pressure - Low < 13(I 513")
- c. RCIC Turbine Exhaust Diaphragm Pressure - High NA
- d. RCIC Equipment Room Ambient Temperature - High NA
- e. RCIC Equipment Room a Temp. - High NA ,
- f. Main Steam Line Tunnel Ambient Temp. - High NA
- g. Main Steam Line Tunnel a Temp. - High NA
- h. Main Steam Line Tunnel Temperature Timer NA
- i. RHR Equipment Room Ambient Temperature - High NA
- j. RHR Equipment Room a Temp. - High NA
- k. RHR/RCIC Steam Line Flow - High NA
- 1. Manual Initiation NA
- 6. RHR SYSTEM ISOLATION
- a. RHR Equipment Room Ambient Temperature - High NA
- b. RHR Equipment Room a Temp. - High NA g)
- c. Reactor Vessel Water Level - Low, Level 3 < 13
- d. Reactor Vessel (RHR Cut-in Permissive)
Pressure - High NA
- e. Drywell Pressure - High NA ,
- f. Manual Initiation NA la) The isolation system instrumentation response time shall be measured and recorded as a part of the ISOLATION SYSTEM RESPONSE TIME. Isolation system instrumentation response time specified includes the delay for diesel generator starting assumed in the accident analysis.
(b) Radiation detectors are exempt from response time testing. Response time shall be measured from detector output or the input of the first electronic component in the channel.
- Isolation system instrumentation response time for MSIVs only. No diesel generator delays assumed.
** Isolation system instrumentation response time for associated valves except MSIVs.
# Isolation system instrumentation response time specified for the Trip Function actuating each valve group shall be added to isolation time shown in Tables 3.6.4-1 and 3.6.5.2-1 for valves in each valve group to obtain ISOLATION SYSTEM RESPONSE TIME for each valve.
Or'ithe,.; ", x : = d tint d:1:7
###Without 13 second time delay. 8 CRAND GULF-UNIT 1 3/4 3-19
-n. _, _ ._ _ _
I . i TABLE 3.3.7.1-1 (Continued) , i RADIATION MONITORING INSTRUMENTATION j h
) G APPLICABLE ALARM / TRIP MEASUREMENT MINIMUM CHANNELS ACTION .; e CONDITIONS SETPOINT RANGE OPERABLE E INSTRUMENTATION i 7' j E 10. Area Monitors Q a. Fuel Handling Area j Monitors ,
10
-2 to 103mR/hr 72
- 1) New Fuel 1 (e) 12.5 mR/hr/NA Storage Vault l
(f) <2.5 mR/hr/NA 10
~2 to 103mR/hr 72
- 2) Spent Fuel 1 ~
2 6mg/kr/gA io t mR[hr 72
- 3) St. c. A A (d 10 to 10 mR/hr 72
- b. Control Room 1 At all times 10.5 mR/hr/NA Radiation Monitor w
Y " With RHR heat exchangers in operation. l
- !G
** When irradiated fuel is being handled in the secondary containment. , Any required change to
# Initial setpoint. Final Setpoint to be determined during startup test program.
l this setpoint shall be submitted to Commission within 90 days after test completion. l (a) Trips system with 2 channels upscale-high high, or one channel upscale and one channel inoperative, or g 2 channels inoperative. . i l (b) Isolates containment /drywell purge penetrations. (c) With irradiated fuel in spent fuel storage pool. gp I (d) Also isolates the secondary containment penetrations. g (e) With fuel in the new fuel storage vault. 9 e (f) With fuel in the spent fuel storage pool. i (g) W:4k fu\ W 4ke Dryee s+orge 4*em . (A N H v
)
s o
i TABLE 4.3.7.1-1 ) o j R RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS
! o -
i OPERATIONAL S CHANNEL CONDITIONS FOR
; Gi WHICH SURVEILLANCE CHANNEL FUNCTIONAL CHANNEL INSTRUMENTATION CHECK _ TEST CALIBRATION REQUIRED l
- 1. Component Cooling Water Radiation W Monitor S M R At all times
- 2. Standby Service Water System
! Radiation Monitor S M R 1, 2, 3, and*
Offgas Pre-treatment Radiation Monitor 5 M R 1, 2
- 3. 1, 2 Offgas Post-treatment Radiation Monitor S M R 2 4 M R 1, 2
- 5. Carbon Bed Vault Radiation Monitor S
- 6. Control Room Ventilation Radiation 1, 2, 3, 5 and**
i Monitor S M(a) R
, 7. Containment and Drywell Ventilation Exhaust Radiation Monitor S M At all times
.Y R
=
w 8. Fuel Handling Area Ventilation 1, 2, 3, 5 and** l M R
- J. Radiation Monitor S i
- 9. Fuel Handling Area Pool Sweep Exhaust Radiation Monitor S M R (b)
- 10. Area Monitors
; a. Fuel Handling Area Monitors
- 1) New Fuel Storage Vault 5 M R (c) l m2) Spent Fuel Storage Pool S M R (d) l
- b. " Control Room Radiation Monitor S M R At all times l 31 Dever 54erge hee' .
s r4 g (c_) q
" With RHR heat exchangers in operation, g
** When irradiated fuel is being handledgin the secondary containment.
(a) The CHANNEL FUNCTIONAL TEST shall demonstrate that control room annunciation occurs if any of the follow
- conditions exist.
Instrument indicates measured levels above the alarm / trip setpoint.
- 1. 9
- 2. Circuit failure. w N
- 3. Instrument indicates a downscale failure.
Instrument controls not in Operate mode. D. 4. (b) With irradiated fuel in the spent fuel storage pool, y 0 (c) With fuel in the new fuel storage vault.- (d) With fuel in the spent fuel storage pool.
@) W:E(veA W oar. defe" 5 4 *raje area .
- 12. (ccNs-34c)
CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) By measuring the leakage rate:
- 1. As *t of the overall integrated leaka e test required
~
by Speci i n 3.6.1.2, or
- 2. By measuring the leaka- . of the system outside of the containment iso o valves a 1.5 psig, on the schedule wired by Specificatio8 4. .
and including the m ed leakage as a part of the leakage de ' ed in
- accordance with Specification 4.6.1.2.
i GRAND GULF-UNIT 1 3/4 6-57
.I3. (GG NS-350) l l
)
ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)
- 9. Verifying the diesel generator operates for at least 24 hours. J During the first 2 hours of this test, the diesel generator shall be loaded to greater than or equal to 7700 kW for diesel gen-erators 11 and 12 and 3630 kW for diesel generator 13 and during the remaining 22 hours of this test, the diesel generator shall be loaded to 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13. The generator voltage and frequency shall be 4160 1 416 volts and 60 1 1.2 Hz within 13 seconds after the start signal; the steady state generator voltage and frequency shall be maintained within these limits during this test. Within 5 minutes after completin this 24-hour test, perform Surveillance Requirement 4.8.',1.2.d. a).2) and b).2)*.
- 10. Verifying that the auto- onnected loads to each diesel generator do not exceed the continuous rating of 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel generator 13.
- 11. Verifying the diesel generator's capability to:
a) Synchronize with the offsite power source while the generator is loaded with its emergency loads upon a simulated
' restoration of offsite power, b) Transfer its loads to the offsite power source, and c) Be restored to its standby status.
- 12. Verifying that with the diesel generator operating in a test mode and connected to its bus that a simulated ECCS actuation signal:
a) For Divisions 1 and 2, overrides the test mode by return-ing the diesel generator to standby operation.
'b) For Division 3, overrides the test mode by bypassing the diesel generator automatic trips per Surveillance Require-ment 4.8.1.1.2.d.8.b).
- 13. Verifying that with all diesel generator air start receivers pressurized to less than or equal to 256 psig and the compres-sors secured, the diesel generator starts at least 5 times from ambient conditions and accelerates to at least 441 rpm for diesel generators 11 and 12 and 882 rps for diesel generator 13 in less than or equal to 13 seconds, a
If Surveillance Requirement 4.8.1.1.2.d.4.a)2) or b)2) are not satisfactorily Instead, completed, it is not necessary to repeat the preceding 24 hour test. the diesel generator may be operated at rated load for one hour or until operating temperatures have stabilized. 3/4 8-6 . GRAND GULF-UNIT 1
4 4 9 L4. (GG Ns- 351) Dsterea l l l I I l l l t l 3/4- B-5 1
% Cwwass hs PAse 1.s. Ges- stO 7,1 l
ELECTRICAL POWER SYSTEMS l SURVEILLANCE REOUIREMENTS 4.8.1.1.1 Each of th'e 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 and indicated power availability, and
- b. Demonstrated OPERABLE at least once per 18 months during shutdown by
. transferring, manually and automatically, unit power supply from the normal circuit to the alternate circuit. 4.8.1.1.2 Each of the above required diesel generators shall be demonstrated - OPERABLE:
- a. In accordance with the frequency specified in Table 4.8.1.1.2-1 on a STAGGERED TEST BASIS by:
-1. Verifying the fuel level in the day tank.
- 2. Verifying the fuel level in the fuel storage tank.
. 3. Verifying the fuel transfer pump starts and transfers fuel from the storage system to the day tank.
- 4. Verifying the diesel starts from ambient condition and accelerates to at least 441 rpm for diesel generators 11 and 12 and 882 rpm for diesel generator 13 in less than or equal to 10 seccads. The generator voltzge and frequency shall be 4160 2 416 volts and 60 1 1.2 Hz within 13 seconds after the start signal. The diesel generator shall be started for this test by using one of the ,
following signals: a) Manual. b) Simulated loss of offsite power by itself. c) Simulated loss of offsite power in conjunction with an ESF actuation test signal.
. d)' An ESF actuation test signal by itself.
5*. Verifying the diesel generator is synchronized, loaded to greater than'or equal to 3500 kW for diesel generators 11 and 12 and 1650 kW for diesel generator 13 in less than or equal to 60 seconds, and operates with these loads for at least 60 minutes.
- 6. Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.
- 7. Verifying the pressure in all diesel generator air start receivers to be greater than or equal to:
a) 160 psig for oiesel generator 11 and 12, and b) 175 psig for diesel generator 13.
- b. At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to 1 hour by checking for and removing accumulated water from the day fuel tanks.
f GRAND GULF-UNIT 1 3/4 8-3 9 - - - --e, ---.---,-,e - .,,,- ~ , - , - - - -r-- -, -,,m -- - - . , , - -
is.GGM-W)p.2. ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) c.- At least once per 92 days and from new oil prior to addition to the storage tanks by verifying that a sample obtained in accordance with ASTM-D270-1975 has a water and sediment content of less than or equal to .05 volume percent and a kinematic viscosity 9 40*C of greater than or equal to 1.9 but less than or equal to 4.1 when tested in accordance with ASTM-D975-77, and an impurity level of less than 2 mg. of insolubles per 100 ml. when tested in accordance with ASTM-D2274-70, except that the test of new fuel for impurity level shall be performed within 7 days after addition of the new fuel to the stora2e tank.
- d. At least once per 18 months, during shutdown, by:
- 1. Subjecting the diesel to an inspection in accordance with pro-cedures prepared in conjunction with its manufacturer's recom-sendations fo g i{ g ss o g ag by sergcg.
gg Verifyingtheaieseigeneratorcapa(iNtytorejecta1 d of flew of
- 2. for diesel generator 11, greater 7tifgM greater than or equal to
& feaJ (Fem a- than or equal tol4904W for diesel generator 12, and greater than Sie le. tPcr pung or equal to y43644 W for diesel generator 13 while maintaining less e wyn, Sc. than or equil to 75% of the difference between nominal speed and y or 15% above nominal whichever is less. .4 Ysm 9 orebJq g the overspepd e.trio &s t oin us - m.+., w%i, m Verifying the diesel gener orcapabilftytoreje:taloadof r %
a+. Med (1w 3. 7000 kW for diesel generators 11 and 12 and 3300 kW for diesel ,f.g g 1 of W50 83Pm. generator 13 without tripping. The generator voltage shall not
< exceed 5000 volts during and following the load rejection.
- 4. Simulating a loss of offsite power by itself, and:
a) For Divisions 1 and 2:
- 1) Verifying deenergization of the emergency busses and load shedding from the emergency busses. ,
- 2) Verifying the diesel generator starts on the auto-start l
signal, energizes the emergency busses with permanently connected loads within 13 seconds, energizes the auto-connected 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 ener-gization, the steady state voltage and frequency of the emergency busses shall be maintained at 4160 1 416 volts' and 60 1 1.2 Hz during this test. b) For Division 3:
- 1) Verifying de-energization of the emergency bus.
- 2) Verifying the diesel generator starts on the auto-start signal, energizes the emergency bus with the loads within 13 seconds and operates for greater than or equal to ,
5 minutes while its generator is loaded with the shutdown loads. After energization, the steady state voltage and frequency of the emergency bus shall be maintained at 4160 1 416 volts and 60 1 1.2 Hz during this test. GRAND GULF-UNIT 1 3/4 8-4
. _ _ . _ _ _ . _ . __ _ _ _ _ _ ~ . _ _ _ _ _ _ _ - . _ _ .
' s TABLE 4.3.7.12-1 (Continued)
Q RA010 ACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILL g CHANNEL MODES IN WHICH FUNCTIONAL SURVEILLANCE
!;; CHANNEL SOURCE CHANNEL TEST REQUIRED
& CHECK CHECK CAllBRATION INSTRUMENT
" 6. OFFGAS PRE-TREATMENT MONITOR ***
# Q(2)
Noble Gas Activity Monitor 0 M R(3)## a.
- 7. OFFGAS POST-TREATMENT MONITOR
- a. Noble Gas Activity Monitor g Providing Alarm and Auto- **
D M R(3)# Q(1) l w matic Termination of Release k' w f s 0% 4 n 2. M l
+
04
' b b
t'
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^ _ 17. (GGas-4%) J
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= = = =
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- th E-EW M E U e -
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>= > <
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.:< s m s
to E mb W e3 C E == C U C
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~ CE & *= ti 5 >= E 3 > 3
-- W - W -
- .- % O %
.J % %
O W >= W W - E
> > >= W W W -
- 0- C es E ed 4
> e.- E e W e C U >Q S E 4 4 b
- v4
=
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=
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-z = 0 = .u CC = W - .C C 3 >- 3 W EE & C & W E - m - -
>= mC .J .J E e-A g 25 o
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=
r E . . em M M GRAND GULF-UNIT 1 3/4 3-85
- L6. (GGNS-503)
CONTAINMENT SYSTEMS BASES 4 3/
-_J'.6.1.5 FEEDWATER LEAKAGE CONTROL SYSTEM i The feedwater leakage control system consists of two independent subsystems designed to eliminate through-line leakage in the feedwater piping by pres-surizing the feedwater lines to a higher pressure than the containment and drywell pressure. This ensures that no release of radioactivity through the feedwater line isolation valves will occur following a loss of all of fsite power coincident with the postulated design basis loss-of-coolant accident.
4 3/g.6.1.6 CONTAINMENT STRUCTURAL INTEGRITY This limitation ensures that the structural integrity of the containment will be maintained comparable to the original design standards for the life of the unit. Structural integrity is required to ensure that the containment will withstand the maximum pressure of 11.5 psig in the event of a LOCA. A visual inspection in conjunction with Type A leakage tests is sufficient to demonstrate this capability. 3/4.6.1.7 CONTAINMENT INTERNAL PRESSURE The limitations on containment-to-Auxiliary Building and Enclosure Building dif ferential pressure ensure that the containment peak pressure of 11.5 psig
' does not exceed the design pressure of 15.0 psig during LOCA conditions or that the external pressure differential does not exceed the design maximum external pressure differential of 3.0 psid. The limit of -2.0 to 0.0 psid for initial containment-to-Auxiliary Building and Enclosure Building differential pressure #
will limit the containment pressure to 11.5 psid which is less than the design pressure-and is consistent with the safety analysis. 3/4.6.1.8 CONTAINMENT AVERAGE AIR TEMPERATURE The limitation on containment average air temperature ensures that the containment peak air temperature does not exceed the design temperature of 185'F during LOCA conditions and is consistent with the safety analysis. 3/4.6.1.9 CONTAINMEN7 PURGE SYSTEM The continuous use of the containment purge Ifnes during all operational conditions is restricted to the 6-inch purge supply and exhaust isolation valves; whereas, continuous containment purge using the 20-inch purge system is limited to only OPERATIONAL CONDITTONS 4 and 5. Intermittent use of the 20-inch purge system during OPERATIONAL CONDITIONS 1, 2 and 3 is allowed only to reduce airborne activity levels and shall not exceed 1000 hours of use per 365 days. The design of the 6-inch purge supply and exhaust isolation valves meets the requirements of Brarch Technical Position CSB 6-4, " Containment Purging During Normal Plant Operations." l GRAND GULF-UNIT 1 B 3/4 6-2 , s
l 17.(66 N S- 5 +2 ) REFUELING OPERATIONS 3/4.9.2 INSTRUMENTATION 1 l I LIMITING CONDITION FOR OPERATION f 3.9.2 At least 2 source range monitor * (SRM) channels shall be OPERAELE ano ' inserted to the normal operating level with:
- a. Continuous visual indication in the control room,
- b. One of the required SRM detectors located in the quadrant wrere C RE ALTERATIONS are being performed and the other recuired SRM cetect:r located in an adjacent quadrant, and e CP I" l
- c. Prior to and during the time any control rod is withdrawn' dear g shutdown margin demonstrations are in progress, either:
- 1. The " shorting links" removed from the RPS circuitry, or
- 2. The rod pattern control system GPERAELE per Specification 3.1.*.2.
APPLICABILITY: OPERATIONAL CONDITION 5. ACTION: With the requirements of the above specification not satisfied, immediately suspend all operations involving CORE ALTERATIONS ** and insert all insertacle Control rods. SURVEILLANCE REQUIREMENTS
4.9.2 EachoftheaboverequiredSRMchannelsshallbedemoSstratedOPERAELEby
- a. At least once per 12 hours:
- 1. Performance of a CHANNEL CHECK,
- 2. Verifying the detectors are inserted to the normal operating level, and
- 3. During CORE ALTERATIONS, verifying that the detector of an OPERASLE SRM channel is located in the core quadrant where CORE ALTERATIONS are being performed and another is located in an adjacent quadrant.
A The use of special movable detectors during CORE ALTERATIONS in place of the normal SRM nuclear detectors is permissible as long as these special detectors are connected to the normal SRM circuits. AA Except movement of IRM, SRM or special movable detectors.
#Not required for control rods removed per Specification 3.9.10.1 and 3.9.10.2.
GRAND GULF-UNIT 1 3/4 9-3 a
3/4.5 EMERGENCY CORE COOLING SYSTEMS 20' (GG NS -547) 3/4.5.1 ECCS - OPERATING LIMITING CONDITION FOR OPERATION 3.5.1 ECCS divisions I, 2 and 3 shall be OPERABLE with:
- a. ECCS division 1 consisting of:
- 1. The OPERABLE low pressure core spray (LPCS) system with a flow path capable of taking suction from the suppression pool and 1 transferring the water through the spray sparger to the reactor vessel. ~
- 2. The OPERABLE low pressure coolant injection (LPCI) subsystem "A" of the RHR system with a flow path capable of taking suction from the suppression pool and transferring the water to-the reactor vessel.
- 3. At least 7 OPERABLE ADS valves.
- b. ECCS division 2 consisting of:
- 1. The OPERABLE low pressure coolant injection (LPCI) subsystems "B" and "C" of the RHR system, each with a flow path capable of taking suction from the suppression pool and transferring the water to the reactor vessel.
- 2. At least 7 OPERABLE ADS valves.
- c. ECCS division 3 consisting of the OPERABLE high pressure core spray (HPCS) system with a flow path capable of taking suction from ther suppression pool and transferring the water through the spray sparger to the reactor vessel.
APPLICABILITY: OPERATIONAL CONDITION 1, 2* # and 3*. -- ACTION: a., For ECCS division 1, provided that ECCS divisions 2 and 3 are OPERABLE:
- 1. With the LPCS system inoperable, restore the inoperable LPCS i system to OPERABLE status within 7 days. ,
- 2. With LPCI subsystem "A" inoperable, restore the inoperable LPCI subsystem "A" to OPERABLE status within 7 days.
- 3. With the LPCS system inoperable and LPCI subsystem "A" inoperable, restore at least the inoperable LPCI subsystem "A" or the inoperable LPCS system to OPERABLE status within 72 hours.
- 4. Otherwise, be in at least H01 SHUTDOWN within the next 12 hours and in COLD SHU1DOWN within the following 24 hours.
7 The ADS is not required to be OPERABLE when reactor steam dome pressure is less than or equal to 135 psig.
#5ee Special Test Exception 0. K.!,. S. fD,f.
GRAND GULF-UNIT 1 3/4 5-1
.. - - . _ - - _ _ - _ , - . . _ _ . .-, . - - - - . - - . ~ . - - - - - - - - - _ _ _ _ _ _ _ _ _
g
. n.(scus-su)ga.
PLANT SYSTEMS * "" 3/4.7.4 SNUBBERS LIMITING CONDITION FOR OPERATION 3.7.4 All snubbers listed in Tables 3.7.4-1 and 3.7.4-2 shall be OPERABLE. APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3 and OPERATIONAL CONDITIONS 4 and 5 for snubbers located on systems required OPERABLE in those OPERATIONAL CONDITIONS. ACTION: a With one or more snubbers inoperable, within 72 hours replace or restore the inoperable snubber (s) to OPERABLE status and perform an engineering evaluation per Specification 4.7.4.c on the supported component or declare the supported system inoperable and follow the appropriate ACTION statement for that system. SURVEILLANCYREOUIREMENTS
- 4. '7. 4 Each snubber shall be demonstrated OPERABLE by performance of the following augnented inservice inspection program and the requirements of Specification 4.0.5.
- a. Visual Insoections The first inservice visual inspection of snubbers shall be performed after 4 months but within 10 months of commencing POWER _0PERATION and shall include all snubbers listed in Tables 3.7.4-1 and 3.7.4-2.
If less than two snubbers are found inoperable during the first inservice visual inspection, the second inservice visual inspection shall be performed 12 months 225% from the date of the first-inspection. Otherwise, subsequent visual inspections shall be performed in accordance with the following schedule: No. Inoperable Snubbers Subsequent Visual per Inspection Period Inspection Period *# l 0 18 months 2 25% 1 12 months i 25% 2 6 months i 25% 3,4 124 days t 25% 5,6,7 62 days i 25% - 8 or more 31 days t 25% The snubbers may be categorized into two groups: Those accessible and those inaccessible during reactor operation. Each group may be inspected independently in accordance with the above schedule.
"The inspection interval shall not be lengthened more than one step at a time.
#The pro, visions of Specification 4.0.2 are not applicable.
GRAND GULF-UNIT 1 3/4 7-9
u.ccas-su) g PLANT SYSTEMS i SURVEILLANCE REQUIREMENTS
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- b. Visual Inspection Acceptance Criteria Visual inspections shall verify (1) that there are no visible indications of damage or impaired OPERABILITY, (2) that attachments to the foundation or supporting structure are secure, and (3) in those locations where snubber movement can be manually induced without discon-necting the snubber, that the snubber has freedom of movement and is not frozen up. Snubbers which appear inoperable as a result of these visual inspections may be determined OPERABLE for the purpose of establishing the next visual inspection interval, providing that (1) the cause of the rejection is clearly established and remedied for that particular snubber and for other snubbers that may be generically susceptible, and (2) the affected snubber is functionally tested in l V.7.3/.e. the as found condition and termined OPERA 8LE per Surveillance m
Requirements 4.7.4.d ord ",, as applicable. However, when a fluid l part of a hydraulic snubber is found to be uncovered, the snubber shall be declared inoperable and cannot be determined OPERABLE by functional testing for the purpose of establishing the next visual inspection interval. All snubbers connected to an inoperable common hydraulic fluid reservoir shall be counted as inoperable snubbers.
- c. Functional Tests During the first refueling shutdown and at 1sast once per 18 months thereaf ter during shutdown, a representative sample of at least:
- 1. 10% of the total of the hydraulic snubbers listed in Table 3.7.4-1 #
shall be functionally tested either in place or in a bench test.
- For each snubber that does not meet the functional test acceptance criteria of Surveillance Requirement 4.7.4.d. an additional 10%
- - of the hydraulic snubbers shall be functionally tested.
- 2. That number of mechanical snubbers which follows the expression l
35 (1 + j), where c = 2, the allowable number of snubbers not l
- meeting the acceptance criteria, shall be functionally tested either in-place or in's bench test. For each number of snubbers i
above c which does not meet the functional test acceptance criteria of Specifications 4.7.4.e, an additional sample selected according totheexpression35(1+j)(gfg)2(a-c)shallbefunctionally tested, where a is the total number of snubbers found inoperable during the functional testing of the representative sample. Functional testing shall continue according to the expression b [35 (1 + j) (, 2 j)2] where b is the number of snubbers found l inoperable in the previous re-sample, until no additional in'oper-j able snubbers are found within a sample or untti all snubbers in Table 3.7.4-2 have been functionally tested. GRAND GULF-UNIT 1 3/4 7-10 '
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[ ,. , 22o B. ADMINISTRATIVE CONTROLS AUDITS 6.5.2.8 Audits of' unit activities shall be performed under the cognizance of theJ44tr. These audits shall encompass: Cgag4ggg,qn (MG4h M m a ceW w Tnt MPom Ste w W ggO*
- a. The conformance of unit operation to provisions contained within the App'endix A Technical Specifications and applicable license conditions at least once per 12 months.
4
- b. The 7ecf;=; .Q training and qualifications of the entire unit staff at least once per 12 months:(Patr enws.c snga ac avat.uavsa AT L5ast oNce PsA 11 Mmm.s sr AppseeniAtt MAmstMrwr psmsev&sc.)
+ c. The results of actions taken to correct deficiencies occurring in unit equipment, structures, systems or method of operaticn that affect nuclear safety at least once per 6 months.
- d. The performance of activities required by the Operational Quality Assurance Program to meet the criteria of Appendix "B", 10 CFR 50, at least once per'24 months.
- e. The Emergency Plan and implementing procedures at least once per 24 months.
- f. The Security Plan and implementing procedures at least once per l months. l
- g. ' Any other area of unit operation considered appropriate by the SRC or the Senior Vice President - Nuclear.
- h. The Fire Protection Program and implementing procedures at least once
. per 24 months. ,
- 1. An independent fire protection and loss prevention inspection and audit shall be performed at least once per 12 months utilizing either qualified ,offsite licensee personnel or an outside fire protection firm.
- j. An inspection and audit of the fire protection and loss prevention program shall be performed by an outside qualified fire consultant
( at intervals no greater than 36 months.
- k. The radiological environmental monitoring program and the results thereof at least once per 12 months.
- 1. The CFF51TE DOSE CALCULATION MANUAL and impleme'nting procedures at least once per 24 months.
- m. The'PROCE55 CONTROL PROGRAM and implementing procedures for solidification of radioactive wastes at least once per 24 months.
- n. The performance of activities required by the Quality Assurance Program to meet the criteria of Regulatory Guide 4.15 February 1979, at least once per 12 months. ,
4 - GRAND GULF-UNIT 1 6-11
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