ML20082J249
| ML20082J249 | |
| Person / Time | |
|---|---|
| Site: | Diablo Canyon  |
| Issue date: | 11/10/1983 |
| From: | Knighton G Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML20082J253 | List: |
| References | |
| NUDOCS 8312020036 | |
| Download: ML20082J249 (24) | |
Text
_
PACIFIC GAS AND ELECTRIC COMPANY DIABLO CANYON NUCLEAR POWER PLANT, UNIT 1
~
DOCY.ET NO. 50-275 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 7 License No. DPR-76 1.
The Nuclear Regulatory Commission (the Commission) has found that:
A.
The applications for amendment by Pacific Gas and Electric Company (the licensee) dated December 29, 1982, May 5 and 23, 1983 and June 23, 1983 and supplemental letter dated September 12, 1983, comply with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission; C.
There is reasonable assurance (i) that the activities authorized
^
by this amendment can be conducted without endangering the health and safety of the public, and (ii) that t '-h activities will be conducted in compliance with the Commission's regulations; D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
2.
Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachme,t to this license amendment, and paragraph 2.C(2) of Facility Operating License No. DPR-76 is hereby amended to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environ-mental Protection Plan contained in Appendix B, as revised through Amendment No. 7, are hereby incorporated in this license. The Pacific Gas & Electric Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
8312020036 831110 PDR ADDCK 05000275 P
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3.
This license amendment is effective as of its date of issuance.
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FOR THE NUCLEAR REGULATORY COMMISSION George W. Knighton, Chief Licensing Branch No. 3 Division of Licensing
)
Date of Issuance:
NOV 101983 e
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9/28/83 9/p/83 9/
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NOV 101203 ATTACHMENT TO LICENSE AMENDMENT NO. 7 FACILITY OPERATING LICENSE N0. DPR-76 DOCKET NO. 50-275 Replace the following pages of the Appendix A Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change. Also to be replaced are the following overleaf pages to the amended pages.
Amendment Pages Overleaf Pages 3/4 28 3/4 27 3/4 30 3/4 29 3/4 18 3/4 17 3/4 20 3/4 19 3/4 21 3/4 22 3/4 24 3/4 23 3/4 36 3/4 35 3/4 42 3/4 41 3/4 8 3/4 7 3/4 11 3/4 11a 3/4 12 l
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1 TABLE 3.3-5 4
t ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 1.
Manual Initiation a.
Safety Injection (ECCS)
Not Applicable Feedwater Isolation Not Applicable Reactor Trip (SI)
Not Applicable Containment Isolation-Phase "A" Not Applicable Containment Ventilation Isolation Not Applicable Auxiliary Feedwater Pumps Not Applicable Component Cooling Water Pumps Not Applicable Containment Fan Cooler Units Not Applicable Auxiliary Salt Water Pumps Not Applicable b.
Containment Spray Not Applicable Containment Isolation-Phase "8" Not Applicable Containment Ventilation Isolation Not Applicable c.
Containment Isolation-Phase "A" Not Applicable Containment Ventilation Isolation Not Applicable d.
Steam Line Isolation Not Applicable 2.
Containment Pressure-High a.
Safety Injection (ECCS)
< 27.0(1) b.
Reactor Trip (from SI)
$2.0(2) c.
Feedwater Isolation
< 63.0 d.
Containment Isolation-Phase "A" i 18.054)/28.0(5) e.
Containment Ventilation Isolation NotApg{jcable f.
Auxiliary Feedwater Pumps
< 60.0 g.
Component Cooling Water Pumps
< 38 g )/48.0(3) 4 h.
Containment Fan Cooler Units i 405 i.
Auxiliary Salt Water Pumps 548.0(4)/58.0(5) 3.
Pressurizer Pressure-Low a.
Safety Injection (ECCS)
< 27.0(1)/12.0(4) b.
Reactor Trip (from SI) i 2.0 (2) c.
Feedwater Isolation i 63.0 d.
Containment Isolation-Phase "A" i 18.0(4) e.
Containment Ventilation Isolation HotApg{jcable f.
Auxiliary Feedwater Pumps
< 60.0 g.
Component Cooling Water Pumps i48(g()1)/38.0(4) h.
Containment Fan Cooler Units 7 40 i.
Auxiliary Saltwater Pumps j58.0(1)/48.0(4)
DIABLO CANYON - UNIT 1 3/4 3-27,
TABLE 3.3-5 (Continued)
ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 4.
Differential Pressure Between Steam Lines-High a.
Safety Injection (ECCS) 5 13.0(4)/23.0(5) b.
Reactor Trip (from SI)
$ 2.0 (2) c.
Feedwater Isolation
< 63.0 d.
Containment Isolation-Phase "A" i 18.0(4)/28.0(5) e.
Containment Ventilation Isolation NotApg 560.0})jcable f.
Auxiliary Feedwater Pumps g.
Component Cooling Water Pumps 538(gf4 /48.0(5) h.
Containment Fan Cooler Units
< 40 1.
Auxiliary Saltwater Pumps 348.0(4)/58.0(5) 5.
Steam Flow in Two Steam Lines - High Coincident with T
--Low-Low ag a.
Safety Injection (ECCS) 5 15.0(4)/25.0(5) b.
Reactor Trip (from SI)
$ 4.0 (2) c.
Feedwater Isolation
< 65.0 d.
Containment Isolation-Phase "A" i 20.0(4)/30.0(5) e.
Containment Ventilation Isolation HotApg}jcable f.
Auxiliary Feedwater Pumps
< 60.0(4)/50.0(5) g.
Ccmponent Cooling Water Pumps i 40.0 h.
Steam Line Isolation i10(g) i.
Containment Fan Cooler Units i 40 j.
Auxiliary Saltwater Pumps
{50.0(4)/60.0(5) 6.
Steam Flow in Two Steam Lines-High Coincident with Steam Line Pressure-Low a.
Safety Injection (ECCS)
< 13.0(4)/23.0(5) b.
Reactor Trip (from SI) i 2.0 (2) c.
Feedwater Isolation i 63.0(4)/28 0(5) d.
Containment Isolation-Phase "A" i 18.0 e.
Containment Ventilation Isolation RotApg}jcable i
f.
Auxiliary Feedwater Pumps
< 60.0 i
g.
Component Cooling Water Pumps 338.0(4)/48.0(5) l h.
Steam Line Isolation
<8.g1) i.
Containment Fan Cooler Units i 40 j.
Auxiliary Saltwater Pumps
{48.0(4)/58.0(5) 7.
Containment Pressure--High-High a.
< 48.5(6) l b.
Containment Isolation-Phase "B" Hot Applicable c.
Steam Line Isolation 57.0 DIABLO CANYON - UNIT 1 3/4 3-28 AMEN 0 MENT NO. 7
i TABLE 3.3-5 (Continued)
ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 8.
Steam Generator Water Level--High-High a.
Turbine Trip-Reactor Trip 52.5 b.
Feedwater Isolation 5 66.0(2) 9.
Steam Generator. Water Level Loi-Low a.
Motor-Driven Auxiliary Feedwater Pumps 5 60 b.
Turbine-Driven Auxiliary Feedwater Pump 5 60 10.
RCP Bus Undervoltage a.
Turbine-Driven Auxiliary Feedwater Pump 5 60 11.
Plant Vent Noble Gas Activity-High a.
Containment Ventilation Isolation 5 11 DIABLO CANYON
. UNIT 1 3/4 3-29
H 1
TABLE 3.3-5 (Continued)
I TABLE NOTATION (1) Diesel generator starting and sequence loading delays included.
Response
time limit includes opening of valves to establish SI path and attainment 3
of discharge pressure for centrifugal charging pumps, SI and RHR pumps (where applicable).
(2) Feedwater system overall response time shall include verification of each individual feedwater system valve closure time as shown below:
Closure Time (not including Valve instrumentation delays)
FCV-438
< 60 seconds 439 7 60 seconds 440 7 60 seconds 441 2 60 seconds 510 7 5 seconds 520 7 5 seconds j'
540 5 5 seconds 530
~$ 5 seconds (3) Diesel generator starting and loading delays included.
(4) Diesel generator starting and sequence loading delays not included.
Of fsite power available.
Response time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal l
charging pumps (where applicable).
(5) Diesel generator starting and sequence loading delays included.
Response
time limit includes opening of valves to establish SI path and attainment of discharge pressure for centrifugal charging pumps.
(6) The maximum response time of 48.5 seconds is the time from when the con-tainment pressure exceeds the high-high setpoint until the spray pump is started and the discharge valve travels to the fully open position assuming off-site power is not available.
The time of 48.5 seconds includes the 28-second maximum delay related to ESF loading sequence.
Spray riser piping fill time is not included.
The 80-second maximum spray delay time does not include the time from LOCA start to "P" signal.
DIABLO CANYON - UNIT 1 3/4 3-30 MIEN 0 MENT NO. 7
TABLE 3.6-1 e
E CONTAINMENT ISOLATION VALVES cm5 ISOLATION TIME VALVE NO.
FUNCTION (Seconds) n E
5 A.
PHASE "A" ISOLATION VALVES z
FCV-151#
Steam Generator No. 1 Blowdown OC
< 10 k
FCV-154#
Steam Generator No. 2 Blowdown OC 5 10 1
[
FCV-157#
Steam Generator No. 3 Blowdown OC 5 10
-l FCV-160#
Steam Generator No. 4 Blowdown OC
$ 10 FCV-244#
Steam Generator No. 4 Sampla OC
$ 10 FCV-246#
Steam Generator No. 3 Sample OC
$ 10 FCV-248#
Steam Generator No. 2 Sample OC
$ 10 FCV-250#
Steam Generator No. 1 Sample OC 5 10 t',
FCV-253 Reactor Coolant Dr. Tk. PP Disch. Isol. IC
$ 10 e
FCV-254 Reactor Coolant Dr. Tk. PP Disch. OC 5 10 h
FCV-255 Reactor Coolant Dr. TK. Vent. Isol. IC 5 10 FCV-256 Reactor Coolant Dr. Tk. Vent. Isol. OC
$ 10 FCV-257 Reactor Coolant Dr. Tk. Sample to GA OC 5 10 FCV-258 Reactor Coolant Dr. Tk. Sample to GA IC 5 10 FCV-260 Reactor Coolant Dr. Tk. N Supply OC 5 10 2
FCV-361 CCW Return from Excess Letdown HX OC
$ 10 FCV-500 Containment Sump Discharge Isolation IC 5 10 FCV-501 Containment Sump Discharge Isolation OC 5 10 FCV-584 Containment Instrument Air Supply OC 5 10 FCV-633 Containn.ent Fire Water Isolation OC
$ 10 FCV-654 Incore Cooler Chilled H O Supply OC 5 10 2
FCV-655 Incore Cooler Chilled H O Supply IC
$ 10 2
TABLE 3.6-1 (Continued)
E ISOLATION TIME VALVE NO.
FUNCTION (Seconds)
FCV-656 Incore Cooler Chilled H O Return OC i 10 2
7 FCV-657 Incore Cooler Chilled H O Return IC 5 10 2
8029 Primary H O Supply to Pressurizer Relief Tk. OC 1 10 g
2 Z
8034A Pressurizer Relief Tk. to GA IC
_ 10 80348 Pressurizer Relief Tk. to GA OC
$ 10 8045 Pressurizer Relief Tk. N Supply OC 5 10 2
8149A Letdown Orifice R0-27 Outlet IC
< 10 01498 Letdown Orifice R0-28 Outlet IC 2 10 8149C Letdown Orifice R0-29 Outlet IC i 10 8152 Letdown Line Isolation OC 5 10 1
'8871 ECCS Check Valve Test Line IC
< 10 y
8880 Accumulator N Fill OC 5 10 2
8883 ECCS Check Valve Test Line OC 5 10 8%1 ECCS Check Valve Test Line OC
< 10 9354A Pressurizer Steam Space Sample IC I_10 9354B Pressurizer Steam Space Sample OC
_ 10 9355A Pressurizer Liquid Space Sample IC
< 10 g
93558 Pressurizer Liquid Space Sample DC
$ 10 g
$ 10
]
_9356B RCS Hot Leg Sample OC
$ 10 9357A g
Accumulator Sample IC
$ 10 9357B Accumulator Sample OC
< 10 8100 RCP Seal Water Returo DC
_ 10 8112 RCP Seal Water Return IC
< 10 9
-,-w
TABLE 3.6-1 (Continued) e5 cm o
ISOLATION TIME VALVE NO.
FUNCTION (Seconds) g z
Ei B.
PHASE "B" ISOLATION VALVES z
FCV-356 CCW Supply to RCP's and Support Coolers OC NA Z
FCV-357 RCP Thermal Barrier CCW Return OC NA FCV-363 RCP Oil Cooler / Support Cooler CCW Return OC NA FCV-749 RCP Oil Cooler / Support Cooler CCW Return IC NA FCV-750 RCP Tr.ermal Barrier CCW Return IC NA C.
CONTAINMENT VENTILATION ISOLATION VALVES FCV-660##
Containment Purge Supply IC
< 2
{
FCV-661##
Containment Purge Supply OC
< 2
.g FCV-662 Containment Vacuum / Pressure Relief IC
< It FCV-663 Containment Pressure Relief OC
< 10 FCV-664 Containment Vacuum Relief OC 10 FCV-678 Containment Air Sample Supply IC
< 10 FCV-679 Contairanent Air Sample Supply OC
< 10 FCV-681 Containment Air Sample Return OC
_ 10 RCV-Il##
Containment Purge Exhaust IC
< 2 RCV-12##
Containment Purge Exhaust OC
_ 2 D. MANUAL VALVES AIR-I-1-585*
Instrument Air Supply to Containment NA (FCV-584 Bypass) OC AIR-S-1-200*
Service Air Supply to Containment OC NA y-a
- = - - - - - - - -
TABLE 3.6-1 (Continued) o5
' D3 5
ISOLATION TIME VALVE NO.
FUNCTION (Seconds) n'E'g AXS-1-26*
Aux. Steam Supply to Containment OC NA CS-1-31D Containment Spray to Misc. Equipment Drain NA c:
Tank OC z
- q CS-1-32D Containment Spray to Misc. Equipment Drain NA g
Tank OC FW-1-140#
Auxiliary Feedwater to Stm. Gen. No. 1 OC NA FW-1-147#
Auxiliary Feedwater to Stm. Gen. No. 2 OC NA FW-1-153#
Auxiliary Feedwater to Stm. Gen. No. 3 OC NA FW-1-157#
Auxiliary Feedwater to Stm. Gen. No. 4 OC NA MS-1-902#
Nitrogen to Steam Generators DC NA g3 RCS-1-512D*
Miscellaneous Equipment Drain Tank Isolation Valve OC NA SI-1-161*
9 Isolating Valve FE-927 OC NA E!
VAC-1-1*
Containment Hydrogen Purge Supply Fan No. 1 and NA External H Recombiner to Containment OC 2
VAC-1-2*
Containment Hydrogen. Purge Supply Fan No. 2 and NA External H Recombiner to Containment OC 2
8767 Refueling Cavity to Refueling Water NA Purification Pump OC 8787 Refueling Water Purification Pump to NA j5 Refueling Cavity DC 2
- ll 8795 Refueling Cavity to Refueling Water NA
.Q Purification Pump IC
-4 2 -
8796 Refueling Water Purification Pump to NA P
. Refueling Cavity IC 8969#
Charging Pump to S.I. Test Line OC NA PEN-1-65A*#'
Main Airlock Equalizing Valve to Atmosphere NA PEN-1-65B*#
Main Airlock Equalizing Valve to Containment NA 4
TABLE 3.6-1 (Continued)
E cm 5
ISOLATION TIME VALVE NO.
FUNCTION (Seconds) g z
y PEN-1-66A*#
Eniergency Airlock Equalizing Valve to Atmosphere NA i
PEN-1-66B*#
Emergency Airlock Equalizing Valve to Containment NA E
Z E.
FCV-22#
No. 4 Stm. Gen. Mn. Steam Isol. Valve Bypass OC NA FCV-23#
No. 3 Stm. Gen. Mn. Steam Isol. Valve Bypass OC NA FCV-24#
No. 2 Stm. Gen. Mn. Steam 1s01. Valve Bypass OC NA FCV-25#
No. 1 Stm. Gen. Mn. Steam Isol. Valve Bypass OC NA FCV-37#
Auxiliary FWP Turb. Steam Supply S/G No. 2 OC NA
-y FCV-38#
Auxiliary FWP Turb. Stm. Supply S/G No. 3 OC NA FCV-41#
No. 1 Stm. Generator Mn. Steam Isol. OC
<5 7
N FCV-42#
No.'2 Stm. Generator Mn. Steam Isol. OC
<5 FCV-43#
No. 3 Stm. Generator Mn. Steam Isol. OC
<5 FCV-44#
No. 4 Stm. Generator Mn. Steam Isol. OC
<5 FCV-235*
Containment H Sample SUPP y IC NA l
2 FCV-236*
Containment H Sample Supply DC NA 2
FCV-237*
Containment H Sample Return OC NA g
g
~g FCV-238*
Containment H Sample Supply IC NA 2
g FCV-239*
Containment H Sample Supply OC NA 2
FCV-240*
Containment H Sample Return OC NA z
2 P
FCV-658 Containment Purge to Aux. Bldg. Filters /
NA Ext. H Recombiners Supply IC.
y 2
FCV-668 Containment Purge to Aux. Bldg. Filters / Ext.
H Recombiner Supply DC NA 2
m m
TABLE 3.6-1 (Continued)
S 2#
ISOLATION TIME VALVE NO.
FUNCTION (Seconds)
O 4
FCV-659 Containment Purge to Purge System Filters / Ext.
H Recombiners Supply IC NA 2
FCV-669 Containment Purge to Purge System Filters / Ext.
E H Recombiners Supply OC NA 2
-d FCV-760#
Steam Generator No. 1 Blowdown IC NA FCV-761#
Steam Generator No. 2 Blowdown IC NA FCV-762#
Steam Generator No. 3 Blowdown IC NA FCV-763#
Steam Generator No. 4 Blowdown IC NA FCV-696*
Reactor Cavity Sump Sample (Post LOCA) Supply IC NA FCV-697*
Reactor Cavity Sump Sample (Post LOCA) Supply OC NA FCV-698*
Containment Air Sample (Post LOCA) Supply IC NA w
FCV-699*
Containment Air Sample (Post LOCA) Supply OC NA g
FCV-700*
Containment Air Sample (Post LOCA) Return OC NA PCV-19#
Steam Generator No. 1 10% Atmosphere Steam Dump OC NA PCV-20#
Steam Generator No. 2 10% Atmosphere Steam Dump OC NA-PCV-21#
Steam Generator No. 3 10% Atmosphere Steam Dump OC NA PCV-22#
Steam Generator No. 4 10% Atmosphere Steam Dump OC NA 8107#
Charging Line Isolation OC NA k
8700A#
RCS Hot Leg to RHR Pump 1 OC NA 8700B#.
RCS Hot Leg to RHR Pump 2 OC NA 8701#
RCS Loop 4 Hot Leg to RHR IC NA E
8703#
RHR to RCS Hot Legs 1 and 2 IC NA 8716A#
RHR to RCS Hot Legs OC NA 87168#
RHR to RCS Hot Legs OC NA 8801A#
Boron Injection Tank Discharge to RCS OC NA L-I
TABLE 3.6-1 (Continued) a ISOLATION TIME 5
VALVE-NO.
FUNCTION (Seconds) n E
8801B#
Boron Injection Tank Discharge to RCS OC NA 8802A#
Safety Injecticn to RCS Hot Legs DC NA
[
88028#
Safety Injection to RCS Hot Legs OC NA 8809A#
Residual Heat Removal to RCS Cold Legs 1 and 2 NA w
g 88098#
Residual Heat Removal to RCS Cold Legs 3 and 4 NA 8823#
Safety Injection Check Valve Test Line IC NA 8824#
Safety Injection Check Valve Test Line IC NA 8843#
Boron Injection Tank to Cold Leg Check Valve Test NA Line IC 8835#
Safety Injection to RCS Cold Legs OC NA w
8885A#
RHR to Cold Leg Test Line IC NA 88858#
RHR to Cold Leg Test Line IC NA g
8982A#
Containment Sump to Residual Heat Removal Train 1 OC NA 89828#
Containment Sump to Residual Heat Removal Train 2 OC NA 8980#
Refueling Water Storage Tank to RHR OC NA 9001A Containment Spray Pump No. 1 Isolation OC NA 900lb Containment Spray Pump No. 2 Isolation OC NA 9003A#
Residual Heat Removal to Containment Spray OC NA 90038#
Residual Heat Removal _to Containment Spray OC NA F.
CHECK VALVES 8028 Relief Valve Outlets to Pressurizer Relief Tank IC NA 8046 Primary Water to Pressurizer Relief Tank IC NA 8047 Nitrogen to Pressurizer Relief Tank IC NA 8109.
Seal Water Return IC NA m
TABLE 3.6-1 (Continued) 2 E
l 5
ISOLATION TIME VALVE NO.
FUNCTION (Seconds) n z
5 8368A thru Seal Water to Reactor Coolant Pumps IC NA 8368D r
a 8916 Nitrogen Supply to Accumulators IC NA g
l O
90llA Containment Spray IC NA
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9011B Containment Spray IC NA Check Valve CCW Supply to RCP IC NA Check Valve CCW Return from RCP (FCV-749 Bypass) IC NA Check Valve CCW Return from RCP (FCV-750 Bypass) IC NA Check Valve #
Nitrogen Supply to Stm.. Gen. IC NA l
Check Valve CCW Supply to Excess Letdown Heat Exchanger DC NA l
l Check Valve Containment Hydrogen Purge Supply IC NA I
T Check Valve Containment Hydrogen Purge Supply IC NA 5
. Containment Air Sample (Post LOCA) Return IC NA Check Valve Nitrogen Supply to Reactor Coolant Drain Tank IC NA l
Check Valve Instrument Air Supply IC NA Check Valve Service Air Supply IC NA Check Valve Containment Air Sample Return IC HA g
Check Valve Auxiliary Stm. Supply to Containment IC NA h
Check Valve-Containe' int Fire Water IC NA z
'g Check Valve Containment H Sample Return IC NA 2
_)
Check' Valve Containment H Sample Return IC NA 2
,o
- May be opened on an intermittent basis under administrative control (Normally closed manual or remotely y
OPERABLE valves only)
- Not subject to Type C leakage tests
- The provisions of Specification 3.0.4 are not applicable.
j PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) i b.
Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous six months.
Sealed sources and fission detectors transferred without a certificate indicating the last test date shall be tested prior to being placed into use.
c.
Startup sources and fission detectors - Each sealed startup source and fission detector shall be tested within 31 days prior to being subjected to core flux or installed in core components or the core and following repair or maintenance of the source.
4.7.8.1.3 Reports - A report shall be prepared and submitted to the Commission on an annual bases if sealed source or fission detector leakage tests reveal the presence of greater than or equal to 0.005 microcuries of removable contamination.
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i DIABLO CANYON - UNIT 1 3/4 7-35 AMENDMENT NO.'7 l
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PLANT SYSTEMS 3/4.7.9 FIRE SUPPRESSION SYSTEMS FIRE SUPPRESSION WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.9.1 The fire suppression water system shall be OPERABLE with; a.
At least two high pressure pump, each with a capacity of 2250 gpm, l
taking suction from the firewater tank containing a minimum usable volume of 270,000 gallons, with its discharge aligned to the fire suppression
b.
Gravity feed to the fire suppression header from a raw water reservior with a minimum usable volume of 270,000 gallons.
c.
An OPERABLE fire suppression header flow path through distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valves, the last valve ahead of the ter flow alarm device on each sprinkler, hose standpipe or spray system riser required to be OPERABLE per specifications 3.7.9.2 and 3.7.9.5.
APPLICABILITY:
At all times.
ACTION:
With either one pump and its water supply or the raw water gravity l
a.
feed water supply inoperable, restore the inoperable equipment to OPERABLE status within 7 days or, in lieu of any other report required by specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 30 days outlining the plans and procedures to be used to restore the inoperable equipment to OPERABLE status or to provide an alternate backup pump or supply.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
b.
With the fire suppression water system otherwise inoperable:
1.
Establish a backup fire suppression water system within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and 2.
In lieu of any other report required by Specification 6.9.1, submit a Special Report in accordance with Specification 6.9.2; a)
By telephone within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, b)
Confirmed by telegraph, mailgram or facsimile transmission no later than the first working day following the event, and.
c)
Ia writino within 14 days following the event, outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.
l
- Except the suppression header check valve bypass valves shall be closed l
unless the gravity feed to the suppression header is inoperable, or inadequate to supply the system for fire protection _ purposes.
DIABLO CANYON - UNIT 1 3/4 7-36 AMENDMENT NO. 7 i
TABLE 3.7-5 CO SYSTEM 2
a.
Diesel Generator No. 11 flooding subsystem b.
Diesel Generator No. 12 flooding subsystem c.
Diesel Generator No. 13 flooding subsystem d.
Unit No. I cable spreading room flooding subsystem e.
CO hose reel subsystem stations:
2 1)
No. 1 or No. 2 in 4 & 12 kv switchgear room 2)
No. 3 or No. 4 serving vital 4 kv cable spreading rooms 3)
No. 5 or No. 6 serving vital 4 kv switchgear rooms 4)
No. 8 serving vital 480 v load centers IF, 1G, lH 5)
No. 10 serving battery rooms 6)
No. 11 serving battery rooms 1
DIABLO CANYON - UNIT 1-3/4 7-41 1
4
~.
PLANT SYSTEMS HALON SYSTEM LIMITING CONDITION FOR OPERATION 3.7.9.4 The Protection and Safeguards Actuation System Room Halon System shall be OPERABLE.
APPLICABILITY:
Whenever equipment protected by the Halon system is required to be OPERABLE.
ACTION:
a.
With the above required Halon system inoperable, within one hour establish a continuous fire watch with backup fire suppression equip-ment for those areas in which redundant systems er components could be damaged.
Restore the system to OPERABLE status within 14 days or, in lieu of any other report required by Specification 6.9.1, prepare and submit a Special Report to the Commission pursuant to Specifica-tion 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.
b.
The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.
SURVEILLANCE REQUIREMENTS 4.7.9.4 The above required Halon system shall be demonstrated OPERAB r:
At least once per 6 months by verifying Halon storage tank weight to-a.
be at least 95% of full charge weight and pressure to be be at least 90% of full charge pressure.
b.
At least once per 18 months by:
1.
Verifying the system, including associated ventilation dampers, actuates manually and automatically, upon receipt of a simulated i
test signal.
2.
Performance of a flow test throcqh headers and nozzles.c0 assure no blockage.
c.
Prior to the expiration of its service life and at least once per l
5 years by replacement of the explosive initiator with_an explosive initiator from a certified manufacturing lot.
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DIABLO CANYON - UNIT 1 3/4 7-42 AMENDMENT NO. 7
I TABLE 4.8-1 DIESEL GENERATOR TEST SCHEDULE Number of Failures in Last 100 Valid Tests
- Test Frequency
$1 At least once Der 31 days 2
At least once per 1, days 3
At least once per 7 days
>4 At least once per 3 days 1
A Criteria for determining number of failures and number of valid tests shall be in accordance with Regulatory Position C.2.e of Regulatory Guide 1.108, Revision 1, August 1977, where the last 100 tests are determined on a per nuclear unit basis.
For the purposes of this test schedule, only valid tests conducted of the OL issuance date shall be included in the computation of the "last 100 valid tests." Entry into this test schedule shall be made at the 31 day test frequency.
DIABLO CANYON - UNIT l 3/4 8-7
TABLE 4.8-2 LOAD SEQUENCING TIMERS ESF TIMERS TIMER SETTINGS (SEC)
COMPONENT MINIMUM NOMINAL MAXIMUM BUS F Centrifugal Charging Pump No. 1
- 1. 5 2
3 Safety Injection Pump No. 1 5
6 7
Containment Fan Cooler Unit No. 2 9
10 11 Containment Fan Cooler Unit No. 1 13 14 15 Component Cooling Water Pump No. 1 17 18 19.5 Auxiliary Saltwater Pump No. 1 20.8 22 23.2 Auxiliary Feedwater Pump No. 3 24.5 26 28 BUS G Centrifugal Charging Pump No. 2 1.5 2
3 Residual Heat Removal Pump No. 1 5
6 7.5 Containment Fan Cooler Unit No. 3 9
10 11.5 Containment Fan Cooler Unit No. 5 13 14 15 Component Cooling Water Pump No. 2 17 18 19 Auxiliary Saltwater Pump No. 2 20.8 22 23.2 Containment Spray Pump No. 1 24.5 26 28 l
BUS H Safety Injection Pump No. 2 1
2 3
Residual Heat Removal Pump No. 2 5
6 7
l Containment Fan Cooler Unit No. 4 9
10 11 Component Cooling Water Pump No. 3 12.5 14 15 Auxiliary Feedwater Pump No. 2 17 18 19.5 Containment Spray Pump No. 2 20.8 22 23.2 l
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l DIABLO CANYON - UNIT 1-3/4 8-8 AMENDMENT NO. 7
ELECTRICAL POWER SYSTEMS 3/4.8.2 ONSITE POWER DISTRIBUTION OPERATING LIMITING CONDITION FOR OPERATION 3.8.2.1 The following electrical busses shall be energized in tne specified manner:
a.
4160 volt Vital Bus F d.
480 volt Vital Bus IF b.
4160 volt Vital Bus G e.
480 volt Vital Bus 1G c.
4160 volt Vital Bus H f.
480 volt Vital Bus 1H g.
120 volt Vital Instrument A.C. Bus 11 energized from its associated inverter connected to D.C. Bus 11*.
h.
120 volt Supplemental Vital Instrument A.C. Bus 11A energized from its associated inverter connected to D.C. Bus 11.*
i.
120 volt Vital Instrument A.C. Bus 12 energized from its associated inverter connected to D.C. Bus 12*.
J.
120 volt Vital Instrument A.C. Bus 13 energized from its associated inverter connected to D.C. Bus 13*.
k.
120 volt Supplemental Vital Instrument A.C. Bus 13A energized from its associated inverter connected to D.C. Bus 13.*
1.
120 volt Vital Instrument A.C. Bus 14 enargized from its associated inverter connected to D.C. Bus 12*.
125 volt D.C. Bus 11 energized from Battery Bank 11.
m.
125 volt D.C. Bus 12 energized from Battery Bank 12.
n.
125 volt D.C. Bus 13 energized from Battery Bank 13.
o.
APPLICABILITY:
MODES 1, 2, 3, and 4.
ACTION:
With one of the required 4160 volt and/or associated 480 volt vital a.
busses not energized, re energize them within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 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 /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
b.
With one Vital Instrument A.C. Bus not energized from its associated inverter, or with one inverter not connected to its associated D.C.
Bus, re-energize the Vital Instrument A.C. Bus from an alternate source within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 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 />
^Two Vital Instr ument A.C. inverters or one Vital and one Supplemental Vital Instrument A.C. inverter may be disconnected from their D.C. Busses for up to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for the purpose of performing an equalizing charge on their associated battery bank provided (1) their vital busses are energized, and (2) the vital busses associated with the other battery banks are energized'from their associated inverters and connected to their associated D.C. 'auses.
DIABLO CANYON - UNIT 1 3/4 8-11 AMENDMENT' NO. 7 4
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t ELECTRICAL POWER SYSTEMS l
LIMITING CONDITION FOR OPERATION (Continued)
ACTION (Continued) and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />; re-energize the Vital Instrument A.C. Bus from its associated inverter connected to its associated D.C. Bus within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 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 /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
With one D.C. Bus not energized from its associated Battery Bank, c.
re-energize it from its associated Battery Bank witin 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 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 /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
d.
With one Supplemental Vital Instrument A.C. Bus not energized from its associated inverter or with its inverter not connected to its associated D.C. bus, re energize the Supplemental Vital Instrument l
A.C. Bus from an alternate source within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> or be in at least l
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 in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />; re-energize the Supplemental Vital Instrument A.C. Bus from its associated inver ter connected to its associated D.C. Bus within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT STANDBY withfi. the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
SURVEILLANCE REQUIREMENTS 4.8.2.1 The specified busses shall be determined energized in the required manner at least once per 7 days by verifying correct breaker alignment and indicated voltage on the busses.
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DIABLO CANYON - UMIT 1 3/4 8-11a AMENDMENT NO. 7 a
y n-9 m -
ELECTRICAL POWER SYSTEMS ONSITE POWER DISTRIBUTION SHUTDOWN LIMITING CONDITION FOR OPERATION 3.8.2.2 As a minimum, t's following electrical busses shall be energized in the specified manner:
a.
One 4160 volt and its associated 480 volt A.C. Vital Bus.
b.
Two 120 volt Vital Instrument A.C. Busses and one 120 volt Supplemental Vital Instrument A.C. Bus energized from their associated inverters connected to their respective D.C. Busses, c.
One 125 volt D.C. Bus energized from its associated battery bank.
APPLICABILITY:
MODES 5 and 6.
ACTION:
With any of the above required electrical busses not energized in the required manner, immeciately suspend all operations involving CORE ALTERATIONS, positive reactivity changes, or movement of irradiated fuel, initiate corrective action to energize the required electrical busses in the specified manner as soon as possible.
SURVEILLANCE REQUIREMENTS 4.8.2.2 The specified busses shall be determined energized in the required manner at least once per 7 days by verifying correct breaker alignment and indicated voltage on the busses.
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DIABLO CANYON - UNIT 1 3/4 8-12 AMENDMENT NO. 7.
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