ML17299A427
| ML17299A427 | |
| Person / Time | |
|---|---|
| Site: | Palo Verde  |
| Issue date: | 07/12/1985 |
| From: | Van Brunt E ARIZONA PUBLIC SERVICE CO. (FORMERLY ARIZONA NUCLEAR |
| To: | Knighton G Office of Nuclear Reactor Regulation |
| References | |
| ANPP-33009-EEVB, TAC-60706, NUDOCS 8507160124 | |
| Download: ML17299A427 (28) | |
Text
REGULATORY DEFORMATION DISTRIBUTION S EM (RIDS)
ACCESSION NBR: 8507160124 DOC ~ DATE: 85/07/12 NOTARIZED:
NO DOCKET FACIL:STN-50-529 Pal o Verde Nuclear Stationi Unit 2i Ar izona Publ i 05000529 AUTHNAME AUTHOR AFFILIATION VAN BRUNTiE.ED Arizona Public Service Co ~
RECIP ~ NAME RECIPIENT AFFILIATION KNIGHTON g G ~ N ~
Licensing Branch 3
SUBJECT:
Forwards marked up draft Tech Specs.Figures~graphs L tables will be available by 850815.Development schedule should be based on 851001 fuel load date
~ Util involved in C"E Owners Group investigation of diesel generator Tech Spec changes.
DISTRIBUTION CODE:
B001D COPIES R'ECEI VED: LTR ENCL SIZE',
TITLE: Licensing Submittal:
PSAR/FSAR Amdts L Related orrespondence NOTES:Standardized plant.
05000529 RECIPIENT ID CODE/NAME NRR/DL/ADL NRR LB3 LA INTERNAL: ACRS 41 ELD/HDS3 IE/DEPER/EPB 36 NRR ROEiM ~ L NRR/DE/CEB 11 NRR/DE/EQB 13 NRR/DE/MEB 18 NRR/DE/SAB 24 NRR/DHFS/HFEB40 NRR/DHFS/PSRB NRR/DSI/AEB 26" NRR/DSI/CPB 10 NRR/DSI/ICSB 16 NRR/DSI/PSB 19 NRR/DSI/RSB 23 RGN5 EXTERNAL: 2ilX DMB/DSS (AMDTS)
NRC PDR 0?
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RECIPIENT ID CODE/NAME NRR LB3 BC LICITRAiE 01 ADM/LFMB IE FILE IE/DQAVT/QAB21 NRR/DE/AEAB NRR/DE/EHEB NRR/DE/GB 28 NRR/DE/MTEB 17 NRR/DE/SGEB 25 NRR/DHFS/LQB 32'RR/DL/SSPB NRR/DS I/ASB NRR/DS I/CSB 09 NgR/DS I/METB 12 NRR/
AB 22 E
Fl 0Q RM/ODAMI/MI8 BNL(AMDTS ONLY)
LPDR 03 NSIC 05 COPIES LTTR ENCL 1
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TOTAL NUMBER OF COPIES REQUIRED:
LTTR 52 ENCL
Ill S'
Arizona Nuclear Power Project P.o. BOX 52034
~
PHOENIX. ARIZONA85072-2034 Mr. George W. Knighton, Chief Licensing Branch No.
3 Division,of Licensing U.S Nuclear Regul'atory Commission Washington, D.C.
20555 July 12, 1985 ANPP-33009/EEVB/JRP
Subject:
Palo Verde Nuclear Generating Station Unit 2 Docket No. 50-529 Plant Technical Specifications (Draft)
File:
85-055-026
Dear Mr. Knighton:
Enclosed are marked up pages of the Palo Verde. Unit 2 Technical Specifications.
Please note that marked up figures, graphs and tables will not be available until a later submittal, approximately August 15, 1985.
Presently we are involved with the CE Owners Group investigating Diesel Generator Technical Specification changes and plan to have a formalized version for the August submittal.
We would at this time like to bring to your attention the matter of an accelerated Technical Specification schedule for Unit 2.
Your letter'dated June 21, 1985, enclosed a development. schedule based on a December 1, 1985, fuel load date.
We request that development schedule be based on an October 1, 1985, fuel load date.
If you have any questions please call.
Very truly yours, EEVB/JRP/slh Attachments E. E.
Van Brunt, Jr.
Executive Vice President Project Director cc:
Director Region V, USNRC (all w/a)
NRC Project Manager E. A. Licitra NRC Resident Inspector R. P.
Zimmerman NRC Technical Reviewer S.
Brown 8507ihOi24 8507i2 PDR ADOCK 05000529 A
~p h
L t
I %)
N
INOEX
/
LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE RE UIREMENTS SECTION 3/4.7 PLANT SYSTEMS 3/~.7.,1 TURBINE CYCLE PAGE 3/4.7. 2 3/4.7.3 3/4.7.4 SAFETY VALVES.....................
AUXILIARYFEEDMATER SYSTEM........
CONDENSATE STORAGE TANK.......,...
ACTIVITY..........................
MAIN STEAM LINE ISOLATION VALVES..
ATMOSPHERIC DUMP VALVES...........
STEAM GENERATOR PRESSURE/TEMPERATURE ESSENTIAL COOLING MATER SYSTEM.......
~
~ ~ ~ ~ ~ ~ ~ ~ ~ ~
~
~ ~
~ ~ 0 1 ~
LIMITATION.........
~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~
~ ~ ~ ~ ~ ~
ESSENTIAL SPRAY POND SYSTEM.............................
3/4 7-1 3/4 7-4 3/4 7"6 3/4 7-7 3/4 7-9 3/4 7-10 3/4 7"11 3/4 7-12 3/4 7"13 3/4.7.5 ULTIMATE HEAT SINK..................................
3/4 7-14 3/4.7.6 ESSENTIAL CHILLED MATER SYSTEM..........................
3/4.7.7 CONTROL ROOM ESSENTIAL FILTRATION SYSTEM................
3/4.7.8 ESF PUMP ROOM AIR EXHAUST CLEANUP SYSTEM................
3/4.7.9 SNUBBERS..................................
3/4.7.10 SEALED SOURCE CONTAMINATION.....................
3/4.7.11 FIRE SUPPRESSION SYSTEMS 3/4 7"15 3/4 7"16 3/4 7"19 3/4 7"21 3/4 7-27 FIRE SUPPRESSION MATER SYSTEM................
SPRAY AND/OR SPRINKLER SYSTEMS...............
FIRE HOSE STATIONS...........................
YARD FIRE HYDRANTS AND HYDRANT HOSE HOUSES...
HALON SYSTEMS................,.....
3/4.7.12 FERE-RATED ASSEMBLIES........
3/4.7.13 SHUTDOMN COOLING SYSTEM..........................
~
~ ~ ~
3/4 7"29 3/4 7-32 3/4 7-35 3/4 7-37 3/4 7-40 3/4 7"42 3/4 7-43 3/4 7-45 3/4.7. 14 CONTROL ROOM AIR TEMPERATURE............................
'A 3/4.8 ELECTRICAL POMER SYSTEMS 3/4 7-46 3/4.8.1 A.C.
SOURCES OPERATING.......
SHUTDOMN o
~
~
~
~
~
~
~
~
~
~ ~ ~ ~ ~
uou~ PR5rec:VXO~
PALO VERDE - UNIT 2 VIII
BASES SECTION 3/4.7 PLANT SYSTEMS 3/4.7. 1 TURBINE CYCLE......;.....................-....-.........
PAGE B 3/4 7-1 3/4. 7. 2 STEAM GENERATOR PRESSURE/TEMPERATURE LIMITATION.........
B 3/4 7-3 3/4.7..3 ESSENTIAL COOLING MATER SYSTEM............... -.... -...
B 3/4 7-3 3/4.7.4 ESSENTIAL SPRAY POND SYSTEM..'.............-......--."..
B 3/4 7-4 3/4.7. 5 ULTIMATE HEAT SINK......................................
B 3/4 7-4 3/4 7.6 ESSENTIAL CHILLED MATER SYSTEM..........................
B 3/4 7"4 3/4.7.7 CONTROL ROOM ESSENTIAL FILTRATION SYSTEM................
B 3/4 7-5
3/4.7.8 ESF PUMP ROOM AIR EXHAUST CLEANUP SYSTEM................
B 3/4 7-5 3/4.7.9 SNUBBERS....................................
B 3/4 7"5 3/4.7.10 SEALED SOURCE CONTAMINATION.............................
B 3/4 7-7 3/4. 7. 12 3/4.7.13 FIRE"RATED ASSEMBLIES..................
SHUTDOMN COOLING SYSTEM.......................
3/4.7.11 FIRE SUPPRESSION SYSTEMS...................................
B 3/4 7"7 B 3/4 7-8 B 3/4 7-8 3/4.7.14 CONTROL ROOM AIR TEMPERATURE............................
B 3/4 7-8 3/4. 9. 3 DECAY TIME...........
3/4. 9. 4 CONTAINMENT BUILDING PEHETRATIONS.......................
3/4 ) 9 i 5 COMMUNICATIONS e
~
~ ~
~
~
~
~
~
~
~
~
~
~ ~
~ ~
~
~ ~
~ ~
~
~
~ ~ ~
~
~
~
~ ~
~ ~
~ ~
~
~
~
~ ~ ~
3/4.8 ELECTRICAL POWER SY TEMS 3/4.8.1, 3/4.8.2, and 3/4.8.3 A.C.
- SOURCES, D.C.
- SOURCES, and
~
OHSITE POWER DISTRIBUTIOH SBTEMS........'........
3/4.8.4 ELECTRICAL E(UIPMENT PROTECTIVE DEVICES.................
3/4. 9 REFUELING OPERATIONS 3/4. 9. 1 BORON CONCENTRATION.................,.:..
3/4. 9. 2 INSTRUMEHTATIOH..........................
B 3/4 8"1 B 3/4 8-3 B 3/4 9-1 B 3/4 9-1 B 3/4 9-1 B 3/4 9-1 B 3/4 9-1 PALO VERDE - UNIT 2
TABLE 3. 3-1 Continued)
TABLE NOTATIONS
- With the rotective s
p e system trsp breakers in the closed position, the CEA 0
drive system capable of CEA withdrawal, and fuel in the reactor vessel PThe pro<1-ions of Specification 3. 0.4 are no applicable.
(a) trip may be manually bypassed above 10-~X of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER is less than equal to 10-~X of RATED THERMAL POWER.
1s less than or (b)
Trip may be manually bypassed below 400 psia.
b h ll b automaticall ypass s
a be equal to 500 psia.
y removed whenever pressurizer pressure is gre t th I
aer an or (c)
Trip may be manually bypassed below 3X of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER is reate or. equal to 1X of RATED THERMAL POWER.
(d)
Trsp may be bypassed during testing pursuant to S
1 T t E
- 3. 10.3.
pecsa es Exception (e)
See Special Test Exception 3.10.2.
(f)
There are four channels, each of which is comprised of one of the four reactor trip breakers, arranged in a selective two-out-of-four configuration (i.e., one-out-of-two taken twice).
ACTION STATEMENTS ACTION 1 ACTION 2 With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be 1
t HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and/or open the rotect system trip breakers.
With the number of channels OPERABLE one less than the Total
- a~d/"r POWER OPERAT prov>ded the snoperabie channel ss placed'sn the bypassed or tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. If the inoperabl h
1
- bypassed, the dessrabi lity of maintaining this channel in the bypassed condition shall be reviewed in accordance with Specification 6.5. 1.6.j('he channel shall be returned to OPERABLE status no later than during the next COLD SHUTDOWN.
PALO YERDE - UNIT 2 3/4 3-5
TABLE 4.3-1 REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE RE UIREMENTS FUNCTIONAL UNIT I.
TRIP GENERATION A.
Process CHANNEL CHANNEL CHECK CALIBRATION CHANNEL FUNCTIONAL TEST MODES IN WHICH SURVEILLANCE RE UIRED 1.
Pressurizer Pressure - High 2.
Pressurizer Pressure - Low 3.
Steam Generator Level - Low 4.
Steam Generator Level - High 5.
Steam Generator Pressure Low 6.
Containment Pressure
" High 7.
Reactor Coolant Flow - Low 8.
Local Power Density - High 9.
DNBR - Low B.
Excore Neutron Flux 1.
Variable Overpower Trip 2.
Logarithmic Power. Level - High S
S-R R
R R
R R
R D (2, 4},
R (4, 5) 0 (2, 4),
R (4, 5}
M (8}, S'(7)
D (2, 4),
M (3, 4) 0 (4)
R (4}
M M
M M
M M'
M, R (6)
M, R (6)
M and S/U (1) 1 2
1 $
2
- l. 2 1,
2 3A'A 1
2 1,
2 1
2 1
2 1
2 1, 2, 3, 4, 5
and
~
C.
Core Protection Calculator System 1.
CEA Calculators 2.
Core Protection Cal cul ators R
M, R (6) 0 (2, 4),
R (4, 5)
~~'.M (9)
R (6)
M (8),
S (7)
'I 1 $
2 1,
2 S
TABLE 4.3-1 (Continued)
I CD FUNCTIONAL UNIT 0.
Supplementary Protection System Pressurizer Pressure - High CHANNEL MODES IN WHICH FUNCTIONAL SURVEILLANCE TEST REIEUfRED CHANNEL CHANNEL CHECK CALIBRATION 1,
2 II.
RPS LOGIC REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE RE UIREMENTS A.
Matrix Logic B.
Initiation Logic III. RPS ACTUATION DEVICES A.
Reactor Trip Breakers B.
Manual Trip N.A.
N.A.
N.A.
N.A.
N.A.
N.A.
N.A.
N.A.
M 3A g*
5A 3'k Q'4 5*
39[ 4)L'*
3A
/5k 5A'
il I
(2)
(3)
(6)
(?)
TABLE 4. 3-1 (Continued)
TABLE NOTATIONS D
CPC per Specification 2.2:2.
At least once per 18 months and following maintenance or adjustment of the reactor trip breakers, the CHANNEL FUNCTIONAL TEST shall include independent verification of the undervoltage and shunt trips.
the With reactor trip breakers in the closed position and the CEA drive system capable of CfA withdrawal, and fuel in the reactor vessel.
Each STARTUP or when required with the reactor trip breakers closed and the CEA drive system capable of rod withdrawal,. lf ro performed in the previous 7 days.
Heat balance only (CHANNEL FUNCTIONAL TEST not included),
above 15K of RATED THERMAL POWER; adjust the linear power level, the, CPC delta T power and CPC nuclear power signals to agree with the calorimetric calculation if absolute difference is greater than 2X.
During PHYSICS TESTS, these daily calibrations may be suspended provided these calibrations are performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.
Above 15K of RATED THERMAL POWER, verify that the linear power sub-channel gains of the excore detectors are consistent with the vaIues used to establish the shape annealing matrix elements in the Core Protection Calculators.
Neutron detectors may be excluded from CHANNEL CALIBRATION.
After each fuel loading and prior to exceeding 70K of RATED THERMAL POWER, the incore detectors shall be used to determine the shape annealing matrix elements and the Core Protection Calculators shall use these elements.
This CHANNEL FUNCTIONAL TEST shall include the injection of simulated process signals into the channel-as close to the sensors as pra'cticablay to verify OPERABILITY including alarm and/or trip functions.
Above ?OX of RATED THERMAl POWER, verify that the total steady-state RCS flow rate as indicated by each CPC is less than or equal to the actual RCS total flow rate determined by either using the reactor coolant pump differential pressure instrumentation or by calorimetric calculations and if, necessary, adjust the CPC addressable constant flow coefficients such that each CPC indicated flow is less than or equal to the actual flow rate.
The flow measurement uncertainty may be included in the BERR1 term in the CPC and is equal to or greater than 4X.
Above ?OX of RATED THERMAL POWER, verify that the total steady-state RCS flow rate as indicated by each CPC is less than or equal to the actual RCS total flow rate determined by either using the reactor coolant pump differentral pressure instrumentation and the ultrasonic flow meter adjusted pump curves or calorimetric calculations.
thl CHANNEL FUNCTIONA ven
>cation that PALO VERDE - UNIT 1 3/4 3-15
INSTRUMENTATION FIRE DETECTION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.7
~s a minimum, the fire detection instrumentation for each FPER detection zone shown in Table 3.3-11 shall be OPERABLE.
APPLICABILITY: Mhenever equipment protected by the fire detection instrument is required to be OPERABLE.
ACTION:
a.
b.
C.
With any, but not more than one-half the total in any fire zone Function X fire detection instrument shown in Table 3.3-11 inoperable, restore the inoperable instrument(s) to OPERABLE status within 14 days or within the next 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> establish a fire watch patrol to inspect the zone(s) with the inoperable instrument(s) at least once per hour, unless the instrument(s) is located inside the containment, then inspect that containment zone at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or monitor the containment air temperature at least once per hour at G og-j-the locations listed in Specification 4.6.1.5.
.,~~ J'-k'""
With more than one-half of the Function X fire detection instruments in any fire zone shown in Table 3.3-11 inoperable, or with any Function Y fire detection instruments shown in Table 3.3-11 inoperable, or with any two or more adjacent fire detection instruments shown in Table 3.3"11 inoperable, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> establish a fire watch patrol to inspect the zone(s) with the inoperable instrument(s) at least once per hour, unless the instrument(s) is located inside the containment, then inspect that containment zone at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or monitor the containment air temperature at least once per hour at<the locations listed in Specification 4.6. 1.5.
- 8o<
The provisiehs of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE RE UIREMENTS 4.3.3.7.1 Each of the above required fire detection instruments which are accessible during plant operation shall be demonstrated OPERABLE at least once per 6 months by performance of a CHANNEL FUNCTIONAL TEST.
Fire detectors which are not accessible during plant operation shall be demonstrated OPERABLE by the performance of a CHANNEL FUNCTIONAL TEST during each COLD SHUTDOMN exceeding 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> unless performed in the previous 6 months.
I 4.3.3.7.2 The NFPA Standard 72D supervised circuits supervision associated with the detector alarms of each of the above required fire detection instruments shall be demonstrated OPERABLE at least once per 6 months.
PALO VERDE - UNIT 2 3/4 3"60
CONTAINMENT SYSTEMS 3/4.6.4 CONBUSTIBLE GAS CONTROL HYDROGEN MONITORS LIMITING CONDITION FOR OPERATION 3.6.4.1 Two ind pond nt containment hydrogen monitors shall be OPERABLE.
APPLICABILITY:
MODES 1 and 2.
ACTION:
a.
b.
C.
With one hydrogen monitor inoperable, restore the inoperable monitor to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
With both hydrogen monitors inoperable, restore at least one monitor to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
With one hydrogen monitor inoperable, and the hydrogen monitor in the Post Accident Sampling System OPERABLE, the provisions of Specification 3.0.4 are not applicable.
SURVEILLANCE RE UIREMENTS C46 B>pgghrC )~~~i4a~y~~ Oq~ha~
I 4.6.4. 1 Each hydrogen monitor shall be demo strated OPERABLE by the performance of a CHANNEL CHECK at least once per 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> a
CHANNEL FUNCTIONAL TEST at least once per 31 days, and at least once per 92 days on a STAGGERED TEST BASIS by performing a
CHANNEL CALIBRATION using sample gases containing a nominal:
a.
One volume percent
b.
Four volume percent
PALO VERDE - UNIT 2 3/4 6-36
PLANT SYSTEMS FIRE HOSE STATIONS LIMITING CONDITION FOR OPERATION 3.7.11.4 The fire hose stations shown in Table 3.7-4 shall be OPERABLE.
r m
f the fs re hose stats ons shown s n Tabl e 3. 7 4 inoperable, provide a gated wye on the nearest OPERABLE hose station.
One outlet of the wye shall be connected to the standard length of hose provided for the OPERABLE hose station.
The second outlet of the wye shall be connected to a length of hose sufficient to provide coverage for the area left unprotected by the inoperable hose station.
The above action shall be accomplished within one hour if the inoper-able fire hose is the primary means of fire suppression; otherwise provide the additional hose in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
The hose for the unprotected area shall be stored at the OPERABLE hose station.
Signs identifying the purpose and location of the fire hose and,related valves shall be mounted above the hose and at the inoperable hose station.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE RE UIREMENTS APPLICABILITY: Whenever equipment in the areas protected by the fire hose stations is required to be OPERABLE, except that fire hose stations located in containment shall have their containment isolation valves closed in MODES 1, 2, 3, 4, and 5~.
ACTION:
a.
With one o
ore o
4.7.11.4 Each of the fire hose stations shown in Table 3.7-4 shall be demonstrated OPERABLE:
a 0 At least once per 31 days by visual inspection of the stations accessible during plant operation to assure all required equipment is at the station.
b.
At least once per 18 months by:
2.
3.
Visual inspection of the stations 'not accessible during plant operations to assure all required equipment is at the station.
Removing the hose for inspection and reracking, and Inspecting all gaskets and replacing any degraded gaskets in the couplings.
"If is to be performed in containment during MODE 5, the fire hose stations located in containment shall have their containment id ~i i
f hog voce==,~
PALO VERDE - UNIT 2 3/4 7-37
TABLE 3.7-5 YARD FIRE HYDRANTS AND ASSOCIATED HYDRANT HOSE HOUSES LOCATION 150'lant North of Fuel Bldg.
100'lant Nest of Rad ':la~+e Bldg.
150'lant Northwest of F!.. l Bldg.
HYDRANT NUMBER
- ~
F.
H.
~~~,'.-.,i-F.
H.
~~~1Ljp'~k,'No hose
- house, however, the hose station is used to service condensate transfer pump PALO VERDE - UNIT 2 3/4 7-41
PLANT SYSTEMS HALON SYSTEMS LIMITING CONDITION FOR OPERATION 3.7.11.6 The follow'ing Halon systems shall be OPERABLE.
a.
Train A Remote Shutdown Panel
- Room, Zone 10A - Control Building 100 ft. Elevation b.
Train B Remote Shutdown Panel
- Room, Zone 108 - Control Building 100 ft. Elevation APPLICABILITY: Mhenever equipment protected by the Halon system is required to be OPERABLE.
ACTION:
With one or more of the above required Halon systems inoperable, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> establish a continuous fire watch with backup fire suppression equipment for those areas in which redundant systems or components could be damaged; for other areas, establish an hourly fire watch patrol.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE RE UIREMENTS 4.7. llAaEach. of the above required Halon systems shall be demonstrated OPERABLE:
a.
b.
C.
At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) in the flow path is in its correct position.
At least once per 6 months by verifying Halon storage tank weight to be at least 95K of full'harge weight and. pressure to be at least 90K of full charge pressure.
\\
At least once per 18 months by:
2.
Verifying the system actuates manually and automatically, upon receipt of a simulated test signal, and
~a.o="'
Performance of g flow test through. headers and nozzles to assure no blockage.
PALO VERDE - UNIT 2 3/4 7-42
el' t
ELECTRICAL POWER SYSTEMS SURVEILLANCE RE UIREMENTS Continued) 4.
Verifying the diesel starts from ambient condition and acceler-ates to at least 600 rpm in less than or equal to 10 seconds."
The generator voltage and frequency shall be 4160 2 420 volts and 60 1.2 Hz within=10"sec:ondsWfter the start signal.
The diesel generator shall be 'started for this test by using one of the following signals:
a) b)
c) d)
Manual.
Simulated loss-of-offsite power by itself.
Simulated loss-of-offsite power in conjunction with an ESF actuation test signal.
An ESF actuation test signal by itself.
Verifying the generator is synchronized, loaded to greater than or equal to 5500 kW in less than or equal to 5 minutes, and operates with a load greater than or equal to 5500 kW for at least an additional 60 minutes, and 6.
Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.
b.
A t once per 31 days and after each o
s-cheee.l s~
where the,per~
reater than or equal to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> by '<r ch or and removing accumulated water rom e
a nks.
C.
By sampling new fuel oil in accordance with ASTH 04057-81 prior to addition to the storage tanks and:
1.
By verifying in accordance with the tests specified in ASTM 0975-81 prior to addition to the storage tanks that the sample has:
a)
An API Gravity of within 0.3 degrees at 60 F or a specific gravity of within 0.0016 at 60/60'F, when compared to the supplier's certificate or an absolute specific gravity at 60/60'F of greater than or equal to 0.83 but less than or equal to 0.89 or an API gravity at 60'F of greater than or equal to 27 degrees but less than or equal to 39 degrees, b)
A kinematic viscosity at 40'C of greater than or equal to 1.9 centistokes, but less than ot equal to 4.1 centistokes, if gravity was not determined by comparison with the supplier's certification, The diesel generator start (10 seconds) from ambient conditions shall be per-formed at least once per 184 days in hese surveillance tests.
All other en-gine starts for the purpose of
'surveillance testing may be preceded by an engine prelube period and/or other warmup procedures recommended by the manu-facturer so that mechanical stress and wear on the diesel engine is minimized.
PALO VEROE - UNIT 2 3/4 8-3
I
C 0
kWSQ.<
f p t~
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ELECTRICAL POWER SYSTEM SURVEILLANCE RE UIREMENTS Continued)
"AD%7 el.
"'ss.qf.,]At least once per 18 months during shutdorrn by:
ther properties specified i of ASTH"0975-1977 ~
and Reg ory Guide l.
evision 1, October 1979, Posi-tion 2.a.,
whe in accordance with ASTH-D975-1977; analysis e comp within 14 days after obtaining ut may be performed a
addition of new fuel o
2.
3.
Subjecting the diesel to an inspection in accordance with procedures prepared in corijunction with:its manufacturer's recommendations for this class of standby service.
II Verifying the generator capability to reject a single largest load of greater than or equal to 839 kW (Train B AFW pump) or 696 kW (Train A HPSI pump) while maintaining voltage at 4160 + 420 volts and frequency at 60 + 1.2 Hz.
Verifying the generator capability to reject a load of 5500 kW without tripping.
The generator voltage shall not exceed 6240 volts during and following the load rejection.
4.
Simulating a loss-of-offsite power by itself, and:
s a}
Verifying deenergization 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 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, the steady state voltage and frequency of the emergency busses shall be maintained at 4160 + 420 volts and 60 + 1.2/-,0.3 Hz during this test.
5.
Verifying that on an ESF 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 steady-state generator voltage and frequency shall be 4160
+ 420 volts and 60 + 1.2 Hz within 10 seconds after the auto-start signal; the generator voltage and frequency shall be maintained within these limits during this test.
6.
Simulating a loss-of-offsite power in conjunction with an ESF actuation test signal, and PALO VERDE - UNIT 2 3/4 8"5
ELECTRICAL POWER SYSTEMS SURVEILLANCE RE UIREMENTS (Continued) 11.
Verifying that the fuel transfer pump transfers fuel from each fuel storage tank to the day tank of each diesel via the installed cross connection lines.
12.
Verifying that the automatic load sequence timer is OPERABLE with the interval between each load block within k 1 second of its design interval.
13.
Verifying that the following diesel generator lockout features prevent diesel generator starting only when required:
a)
(turning gear engaged) b)
(emergency stop)
~; At least once per 10 years or after any modifications which could affect diesel generator interdependence by starting the diesel generators simultaneously, during shutdown, and verifying that the diesel generators accelerate to at least 600 rpm (steady"state generator voltage and frequency of 4160 + 420 volts and 60 + 1.2 Hz) in less than or equal to 10 seconds.
At least once per 10 years by:
l.
Draining each fuel oil storage
- tank, removing the accumulated sediment and cleaning the tank using a sodium hypochlorite solution or the equivalent, and 2.
Performing a pressure test of those portions of the diesel fuel oil system designed.to Section III, subsection NO of the ASt1E Code at a test pressure equal to 110K of the system design pr essure.
A.8.1. 1.3
~Re orts - All diesel generator failures, valid or nonvalid, shall be reported to the Commission within 30 days in a Special Report pursuant to Specification 6.9.2.
Reports of diesel generator failures shall include the information recommended in Regulatory 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 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 of Regulatory Guide 1. 108, Revision 1, August 1977.
PALO VERDE " UNIT 2 3/4 8-7
I 3/4. 9 REFUELING OPERATIONS 9/A. 9.1 BORON CONCENTRATION LIMITING CONDITION FOR OPERATION 3.9.l Mi h,+he reactor vessel head closure bolts less than fully tensioned or with the head
- removed, the boron concentration of all filled portions of the Reactor Coolant System and the refueling canal shall be maintained uniform and sufficient to ensure that the more restrictive of the following reactivity conditions is met:
a.
Either a Keff of 0.95 or less, or b.
A boron concentration of greater than or equal to 2150 ppm.
APPLICABILITY:
MODE 6".
ACTION:
With the requirements of the above specification not satisfied, immediately suspend all operations involving CORE ALTERATIONS or positive reactivity chagges and initiate and continue boration at greater than or equal to 84 ~gpm of a solution containing
> 4000 ppm boron or its equivalent until K ~~ is reduced to less than or equal to 0.95 or the boron concentration is
,r5ftored to greater than or equal to 2150 ppm, whichever is the more restrictive.
SURVEILLANCE RE UIREMENTS 4.9.1.1 The more restrictive of the above two reactivity conditions shall. be determined prior to:
a.
Removing or unbolting the reactor vessel
- head, and b.
Withdrawal of any full-length CEA in excess of. 3 feet from its fully inserted position within the reactor pressure vessel.
4.9. 1.2 The boron concentration of the Reactor Coolant System and the refueling canal shall be determined by chemical analysis at least once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
The reactor shall be maintained in MODE 6 whenever fuel is in the reactor vessel with the reactor vessel head closure bolts less than fully tensioned or with the head removed.
PALO VERDE - UNIT 2 3/4 9-1
3/4. 10 SPECIAL TEST EXCEPTIONS 3/4. 10. 1 SNUTQONN MARGIN LIMITING CONDITION FOR OPERATION 3.10.1 The SHUTDOWN MARGIN requirement of Specification 3.1.1.1 may be suspended for measurement of CEA worth and shutdown marg',n p.ovided reactivity equivalent to at least the highest estimated CEA worth is available for trip insertion from OPERABLE CEA(s), or the reactor is subcritical by at least the reactivity equivalent of the highest CEA worth.
APPLICABILITY:
MODES 2, 3" and 4~8.
ACTION:
a.
Mith any full-length CEA not fully inserted and with less than the above reactivity equivalent available for trip insertion, immedi-
... ately initiate and continue boration at greater than or equal to 24 ~gpm of a solution containing greater than or equal to 4000 ppm boron or its equivalent until the SHUTDOWN MARGIN required by.
Specification 3.1.1.1 is restored.
b.
Mith all full-length CEAs fully inserted and the reactor subcritical by less than he above reactivity equivalent, immediately initiate and continue boration at greater than or equal t(F59 gpm of a solution containing greater than or equal to 4000 ppm boron or its equivalent until the SHUTDOMN MARGIN required by Specification 3.1.1.1 is restored.
SURVEILLANCE RE UIREMENTS
- 4. 10. 1.1 The position of each full-length and part-length CEA required either partially or fully withdrawn shall be determined at least once per 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
4.10. 1.2 Each CEA not fully inserted shall be demonstrated capable of full insertion when tripped from at least the SO% withdrawn position within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to reducing the SHUTDOWN MARGIN to less than the limits of Specification 3.1.1.1.
4.10.1.3 Mhen in MODE 3 or MODE 4, the reactor shall be determined to be subcritical by at least the reactivity equivalent of the highest estimated CEA worth or the reactivity equivalent of the highest estimated CEA worth is, avai')-
able for trip insertion from OPERABLE CEAs at least once per 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> by con-sideration of at least the following factors:
a.
Reactor Coolant System boron concentration, b.
CEA position, c.
Reactor Coolant System average temperature, d.
Fuel burnup based on gross thermal energy generation, e.
Xenon concentration, and f.
Samarium concentration.
Operation in MODE 3 and MODE 4 shall be limited to 6 consecutive hours.
Limited to-low power PHYSICS TESTING at the 3204F plateau.
PALO VERDE - UNIT 2 3/4 10-1
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