ML20114E445
| ML20114E445 | |
| Person / Time | |
|---|---|
| Site: | Perry  |
| Issue date: | 06/18/1996 |
| From: | Hopkins J NRC (Affiliation Not Assigned) |
| To: | |
| Shared Package | |
| ML20114E449 | List: |
| References | |
| NUDOCS 9606250296 | |
| Download: ML20114E445 (39) | |
Text
-. - -
,p ue y
t UNITED STATES NUCLEAR REGULATORY COMMISSION I
'E WASHINGTON, D.C. 30806-0001
%,.....,o$
CLEVELAND ELECTRIC ILLLMINATING COMPANY. ET AL.
DOCKET N0. 50-440 PERRY NUCLEAR POWER PLANT. UNIT N0. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 85 License No. NPF-58 1.
The Nuclear Regulatory Commission (the Commission) has found that:
A.
The application for amendment by the Cleveland Electric Illuminating Company (CEICO), Centerior Service Company, Duquesne Light Company, Ohio Edison Company, OES Nuclear, Inc., Pennsylvania Power Company, and Toledo Edison Company (the licensees) dated April 26, 1996, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.
There is reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.
The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.
The issuance 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 Specifi-cations as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-58 is hereby amended to read as follows:
9606250296 960618 ADOCK0500gj40 DR
. (2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 85 are hereby incorporated into this license.
The Cleveland Electric Illuminating Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.
3.
This license amendment is effective as of its date of issuance and shall be implemented not later than 90 days after issuance.
FOR THE NUCLEAR REGULATORY COMMISSION g.
G
- ) '?
D,,. $P x
onB.Hopkins,Seni5rProjectManager Project Directorate III-3 Division of Reactor Projects III/IV Office of Nuclear Reactor Regulation
Attachment:
Changes to the Ter.hnical Specifications l
Date~ of issuance:
June 18, 1996 j
l
4 l
ATTAC MENT TO LICENSE AMENDMENT NO. 85 FACILITY OPERATING LICENSE NO. NPF-58 DOCKET NO. 50-440 Replace the following pages of the Appendix 'A" Improved Technical Specifications with the attached pages. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change.
Remove Insert ITS 3.1-20 ITS 3.1-20 ITS 3.3-19 ITS 3.3-19 ITS 3.3-23 ITS 3.3-23 ITS 3.3-41 ITS 3.3-41 ITS 3.3-54 ITS 3.3-54 ITS 3.3-55 ITS 3.3-55 ITS 3.3-56 ITS 3.3-56 ITS 3.3-59 ITS 3.3-59 ITS 3.4-1 ITS 3.4-1 ITS 3.4-25 ITS 3.4-25 ITS 3.4-30 ITS 3.4-30 ITS 3.6-6 ITS 3.6-6 ITS 3.6-19 ITS 3.6-19 ITS 3.6-35 ITS 3.6-35 ITS 3.6-48 ITS 3.6-48 ITS 3.6-65 ITS 3.6-65 ITS 3.6-66 ITS 3.6-66 ITS 3.6-67 ITS 3.6-67 ITS 3.7-4 ITS 3.7-4 ITS 3.7-8 ITS 3.7-8 ITS 3.7-18 ITS 3.7-18 ITS 3.8-6 ITS 3.8-6 ITS 3.8-8 ITS 3.8-8 ITS 3.8-10 ITS 3.8-10 ITS 3.8-15 ITS 3.8-15 ITS 3.8-28 ITS 3.8-28 ITS 3.8-29 ITS 3.8-29 ITS 3.8-30 ITS 3.8-30 ITS 3.8-31 ITS 3.8-31 ITS 4.0-2 ITS 4.0-2 ITS 5.0-1 ITS 5.0-1 ITS 5.0-4 ITS 5.0-4 ITS 5.0-9 ITS 5.0-9 ITS 5.0-12 ITS 5.0-12 ITS 5.0-20 ITS 5.0-20
SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7. Standby Liquid Control (SLC) System LC0 3.1.7-Two SLC subsystems shall be OPERABLE.
i APPLICABILITY:
MODES 1 and 2.
i i
ACTIONS CONDITION REQUIRED ACTION-COMPLETION TIME l
A.
One SLC subsystem A.1.
Restore SLC 7 days inoperable.
subsystem to OPERABLE status.
B.
Two SLC subsystems B.1-Restore one SLC 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.
l inoperable.
subsystem to l
OPERABLE-status.
I
-C.
Required Action and C.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.
a i
l l
i PERRY - UNIT 1 3.1-20 Amendment'No.85 i
Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1 1 (page 1 of 1)
Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS REQUIREMENTS 1.
Rod Pattern Control System a.
Rod withdrawal limiter (a) 2 SR 3.3.2.1.1 SR 3.3.2.1.6 SR 3.3.2.1.9 (b) 2 SR 3.3.2.1.2 SR 3.3.2.1.5 SR 3.3.2.1.7 SR 3.3.2.1.9 b.
Rod pattern controller 1 '2 2
SR 3.3.2.1.4 SR 3.3.2.1.5 SR 3.3.2.1.7 SR 3.3.2.1.9 2.
Reactor Mode Switch-Shutdown Position (d) 2 SR 3.3.2.1.8 (a) THERMAL POWER > 70% RTP.
(b) THERMAL POWER > 35% RTP and s 70% RTP.
(c) With THERMAL POWER 5 20% RTP.
(d) Reactor mode s6it s a the shutdown position.
PERRY - UNIT 1 3.3-19 Amendment No. 85
PAM Instrumentation 3.3.3.1 i
Table 3.3.3.1 1 (page 1 of 1)
Post Accident Monitoring Instrumentation CONDITIONS REFERENCED FROM REQUIRED REQUIRED f
FUNCTION CHANNELS ACTION D.1 1.
Reactor Steam. Dune Pressure 2
E 2.
Reactor vessel Water Levt. C'de Range 2
E 3.
Reactor Vessel Water Lev, f ar Zone 2
E 4.
Suppression Poot Water Level 2
E 5.
Suppression Poot Sector Water Temperature 2(c)
E 6.
Drywell Pressure 2
E 7.
Drywell Air Tenperature 2
E
.i 8.
Primary Containment /Drywell Area Gross Gansna 2
F Radiation Monitors 1
9.
Penetration Flow Path, PCIV Position 2perpenetgtg E
flow path
- 10. Primary Containment and Drywell Hz 2
E Concentration Anatyrer and Monitor 2
E
- 11. Primary Containment Pressure 2
E
- 12. Primary Containment Air Tenperature (a) Not required for isolation valves whose associated penetration flow path is isolated.
(b) only one position indication channet is required for penetration flow paths with only one installed control room indication channet.
(c) Monitoring each of eight sectors.
j PERRY - UNIT.1 3.3-23 Amendment No. 85
o ECCS Instrumentation 3.3.5.1 Table 3.3.5.1 1 (page 3 of 5)
Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REGUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE 2.
LPCI B and LPCI C Subsystems (continued) e.
LPCI Ptap B 1,2,3, 1 per purp E
= 1450 ppm and LPCI Puip C SR 3.3.5.1.2 Discharge 4(a) 5(a)
SR 3.3.5.1.3 F t ow - Low SR 3.3.5.1.5 (Bypass)
SR 3.3.5.1.6 f.
Manual Initiation 1,2,3, 1
C SR 3.3.5.1.6 NA 4(a) 5(a) 1 3.
High Pressure Core Spray (HPCS) System a.
Reactor Vessel 1,2,3, 4(')
B SR 3.3.5.1.1 e 127.6 inches l
l Water Level - Low SR 3.3.5.1.2 Low, Level 2 4('),5(a)
I b.
Drywet1 1,2,3 4(')
B SR 3.3.5.1.1 s 1.88 psig l
Pressure - High SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 c.
Reactor Vessel 1,2,3, 4
8 SR 3.3.5.1.1 5 221.7 inches Water SR 3.3.5.1.2 Level - High, 4(a) $(a)
SR 3.3.5.1.3 Level 8 SR 3.3.5.1.5 i
d.
Conoensate 1,2,3, 2
D SR 3.3.5.1.1 a 59,700 gallons Storage Tank SR 3.3.5.1.2 Level - Low 4(c) 5(C)
SR 3.3.5.1.5 SR 3.3.5.1.6 e.
Suppression Pool 1,2,3 2
D SR 3.3.5.1.1 s 18 ft 6 inches Water Level - High SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 (continued)
(a) When associated ad ystem(s) are required to be OPERABLE.
(c) When HPCS is OPERABLE for compliance with LC0 3.5.2, "ECCS - Shutdown," and aligned to the condensate storage tank while tank water levet is not within the limits of SR 3.5.2.2.
(e) Also required to initiate the associated diesel generator.
l PERRY - UNIT 1 3.3-41 Amendment No. 85
l
- l Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 1 of 6)
Primary Contairunent and Drywell Isolation Instrumentation l
APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 1
l 1.
Main Steam Line Isolation a.
Reactor vessel Water 1,2,3 2
D SR 3.3.6.1.1 a 14.3 inches Level - Low Low Low, SR 3.3.6.1.2 Level 1 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 b.
2 E
= 795.0 psig Pressure - Low SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 c.
Main Steam Line 1,2,3 2 per MSL D
SR 3.3.6.1.1 s 191 psid F low - High SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 d.
Condenser vacuum-Low 1,2(*),
2 D
SR 3.3.6.1.1 a 7.6 inches SR 3.3.6.1.2 Hg vacuun 3(a)
SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 e.
Main Steam Line Pipe 1,2,3 2
D SR 3.3.6.1.1 s 158.9'F Tunnel SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.7 f.
Main Steam Line Turbino 1,2,3 2
D SR 3.3.6.1.1 5 138.9'F Building SR 3.3.6.1.2 Tanperature-High SR 3.3.6.1.4 SR 3.3.6.1.5 g.
Manuel Initiation 1,2,3 2
G SR 3.3.6.1.5 NA 2.
Primary Containment and Drywell Isolation l
a.
Reactor vessel Water 1,2,3 2
H SR 3.3.6.1.1 a 127.6 inches Level-Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.3 l
SR 3.3.6.1.4 SR 3.3.6.1.5 l
(continued)
(a) With any turbine stop valve not closed.
i (b) Required to initiate the associated drywell isolation function.
i PERRY - UNIT 1 3.3-54 Amendment No. 85
Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 4
Table 3.3.6.1 1 (page 2 of 6)
Primary Containment and Drywell Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 2.
Primary Containment and-Drywell Isolation a.
Reactor vessel Water (c) 2 L
= 127.6 inches l
Levet-Low Low, Level 2 SR 3.3.6.1.2 (continued)
SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 b.
Drywell Pressure - High 1, 8.3 2
H SR 3.3.6.1.1 5 1.88 psig l
SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 c.
Reactor vessel Water 1,2,3 2
F SR 3.3.6.1.1 a 14.3 inches l
Level-Low Low Low, SR 3.3.6.1.2 Level 1 (ECCS SR 3.3.6.1.3 Divisions 1 and 2)
SR 3.3.6.1.4 SR 3.3.6.1.5 (c) 2 L
SR 3.3.6.1.1 a 14.3 inches l
SR 3.3.6.1.2 SR 3.3.6.1.3 i
SR 3.3.6.1.4 SR 3.3.6.1.5 d.
Drywell Pressure - High 1,2,3 2
F SR 3.3.6.1.1 s 1.88 psig (ECCS Divisions 1 SR 3.3.6.1.2 i
and 2)
SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 e.
Reactor Vessel Water 1,2,3 4
F SR 3.3.6.1.1 a 127.6 inches Level - Low Low, Level SR 3.3.6.1.2 2 (HPCS)
ER 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 (c) 4 L
SR 3.3.6.1.1 a 127.6 inches SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 f.
Drywell Pressure - High 1,2,3 4
F SR 3.3.6.1.1 s 1.88 psig (HPCS)
SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 g.
Contairunent and Drywell 1,2,3 2
F SR 3.3.6.1.1 s 4.D mR/hr l
Purge Exhaust Plenum SR 3.3.6.1.2 above Radiation. High SR 3.3.6.1.4 background SR 3.3.6.1.5 (continued) t l
(b) Required to initiate the drywell isolation function.
-(c) During CORE ALTERATIONS, and operations with a potentist for draining the reactor vesset.
PERRY - UNIT 1 3.3-55 Amendment No. 85
Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 3 of 6)
Primary Contalrunent and Drywell Isolation Instrtsnentation APPLICABLE CONDIT!DNS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVE!LLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACT!DN C.1 REQUIREMENTS VALUE 2.
Primary Containment and Drywell Isolation g.
Containment and (d) 2 K
SR 3.3.6.1.1 5 4.0 aft /hr above Drywell Purge Exhaust SR 3.3.6.1.2 background Pterun Radiation-High SR 3.3.6.1.4 (continued)
SR 3.3.6.1.5 h.
Manual Initiation 1,2,3 2
G SR 3.3.6.1.5 NA (d) 2 K
SR 3.3.6.1.5 NA 3.
Reactor Core Isolation Cooling (RCIC) System Isolation a.
RCIC Steam Line 1,2,3 1
F SR 3.3.6.1.1 s 298.5 inches F low - H igh SR 3.3.6.1.2 water SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 b.
RCIC Steam Line Flow 1,2,3 1
= 3 seconds and Time Delay SR 3.3.6.1.4 s 13 seconds SR 3.3.6.1.5 c.
RCIC Steam Supply Line 1,2,3 1
F SR 3.3.6.1.1 a 55 psis Pressure - Low SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 1
d.
RCIC Turbine Exhaust 1,2,3 2
F SR 3.3.6.1.1 s 20 psis Olaphragm SR 3.3.6.1.2 Pressure - High SR 3.3.6.1.3 4
SR 3.3.6.1.4 SR 3.3.6.1.5 e.
RCIC Equipment Area 1,2,3 1
F SR 3.3.6.1.1 s 145.9'F Anblent SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.7 1.
Main Steam Line Pipe 1,2,3 1
F SR 3.3.6.1.1 s 158.9'F Tunnel SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.7 (continued)
(b) Required to initiate the drywell isolation function.
(d) During CORE ALTERATIONS, operations with a potential for draining the reactor vessel, and movement of irradiated fuel assemblies in primary containment.
PERRY - UNIT 1 3.3-56 Amendment No. 85
Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 6 of 6)
Primary Containment and Drywell Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTION C.1 REQUIREMENTS VALUE 5.
RHR System isolation l
a.
RHR Equipment Area 2
,3 1 per area F
SR 3.3.6.1.1 s 159.9'F And) lent SR 3.3.6.1.4 Tamperature - High SR 3.3.6.1.5 SR 3.3.6.1.7 b.
Reactor vessel Water 1,2 ',3 2
= 177.1 l
Level Low, Level 3 SR 3.3.6.1.2 inches SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 2
3
,4, 2
= 177.1 l
5 SR 3.3.6.1.2 inches SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 c.
Reactor vessel Steam 1,2,3 2
F SR 3.3.6.1.1 s 150 psig Dome Pressure - High SR 3.3.6.1.2 SR 3.6.1.1.3 SR 3.6.1.1.4 i
SR 3.6.1.1.5 d.
Drywell Pressure - High 1,2,3 2
F SR 3.3.6.1.1 5 1.88 psig SR 3.3.6.1.2 SR 3.3.6.1.3 j
SR 3.3.6.1.4 SR 3.3.6.1.5 J
e.
Manual Initiation 1,2,3 2
G SR 3.3.6.1.5 NA (e) With reactor vessel steam dome pressure less than the RHR cut in permissive pressure.
(f) Only one trip system required in MODES 4 and 5 with RHR Shutdown Cooling System integrity maintained.
(g) With reactor vessel steam dome pressure greater than or equal to the RHR cut in permissive pressure.
1 i
PERRY - UNIT 1 3.3-59 Amendment No. 85
Recirculation Loops Operating 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LC0 -3.4.1 Either:
a.
Two recirculation loops shall be in operation with:
1.
Matched flows: and 2.
Total core flow and THERMAL POWER within limits.
E b.
One recirculation loop shall be in operation with:
1.
Thermal power s 2500 MWt:
2.
Total core flow and THERMAL POWER within limits:
1 3.
Required limits modified for single recirculation loop operation.as specified in the COLR: and J
4.
LC0 3.3.1.1. " Reactor Protection System (RPS)
Instrumentation " Function 2.b (Average Power Range
)
Monitors Flow Biased Simulated Thermal Power-High)
Allowable Value of Table 3.3.1.1-1 reset for single loop operation,
...................__....N0TE-------------------------------
Required limit and setpoint modifications for single recirculation loop operation may be delayed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after transition from two recirculation loop operation to single recirculation loop operation.
APPLICABILITY:
MODES 1 and 2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
Recirculation loo) jet A.1 Shut down one of the 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> pum) flow mismatc1 not recirculation loops.
wit 11n limits.
l (continued) i PERRY - UNIT.1 3.4-1 Amendment No. 85
RHR Shutdown Cooling System-Cold Shutdown l
3.4.10 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME I
i B.
No RHR shutdown B.1 Verify reactor 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from I
= cooling subsystem in coolant circulation discovery of no l-l operation.
by an alternate reactor coolant method.
circulation l
AND m
No recirculation pump in operation.
Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 8
thereafter M
B.2 Monitor reactor Once per hour coolant temperature and pressure.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> or recirculation pump is operating.
i l
PERRY - UNIT 1 3.4-25 Amendment No.85 l
RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY l
NOTE--------------------
Only required to be met in single loop operation during increases in THERMAL POWER or recirculation loop flow with the operating recirculation loop jet pum) flow s 50% of rated core flow or THERMAL 30WER i
s 30% of RTP, and with reactor vessel steam dome pressure a 25 psig.
l Verify the difference between the bottom Once within i
head coolant temperature and the RPV 15 minutes coolant temperature is s 100 F.
prior to an l
increase in THERMAL POWER or an increase in loop flow SR '3.4.11.9
NOTE--------------------
Only required to be met in single loop i
operation during increases in THERMAL POWER or recirculation loop flow with the 1
operating recirculation loop jet Jump flow j
s 50% of rated core flow, or THER%L POWER i
s 30% of RTP. and the idle recirculation L
loop not isolated from the RPV.
Once within l
l 15 minutes j
l prior to an i
Verify the difference between the reactor increase in coolant temperature in the recirculation THERMAL POWER l-loop not in operation and the RPV coolant or an increase temperature is s 50*F.
in loop flow SR 3.4.11.10 The reactor vessel material surveillance In accordance specimens shall be removed and examined to with the determine changes in reactor pressure schedule vessel material properties, required by i
l 10 CFR E0.
l Appendix H i
i l
PERRY - UNIT 1 3.4-30 Amendment No. 85 i
l '
I
l Primary Containment Air Locks l
3.6.1.2 l*
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. -(continued)
C.3 Restore air lock to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE status.
D.
Required Action and D.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A.
M B. or C not met in MODE 1. 2. or 3.
D.2 Be in MODE 4.
36 hca.s E.
Required Action and E.1 Suspend movement of Immediately associated Completion recently irradiated Time of Condition A.
fuel assemblies in B, or C not met during the primary movement of recently containment.
irradiated fuel assemblies in the M
primary containment, or during OPDRVs.
E.2 Initiate action to Innediately l.
suspend OPDRVs.
PERRY - UNIT 1 3.6-6 Amendment No. 85
PCIVs t
3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY 1
SR 3.6.1.3.11
NOTE-------------------
Only required to be met in MODES 1, 2, and 3.
j l
Verify combined leakage rate of I gpm
NOTE-----
times the total number of PCIVs through SR 3.0.2 is hydrostatically tested lines that not applicable l
penetrate the primary containment is not exceeded when these isolation valves are tested at it 1.1 P,.
In accordance with 10 CFR 50, Appendix J, as modified by approved exemptions SR 3.6.1.3.12
NOTE------------------
1 Only required to be met in MODES 1, 2, and 3.
Verify each outboard 42 inch primary 18 months containment purge valve is blocked to restrict the valve from opening > 50*.
SR 3.6.1.3.13
NOTE-------------------
Not required to Se met when the Backup i
Hydrogen Purge System isolation valves are open for pressure control, ALARA or air quality considerations for personnel entry, or Surve111ances or special testing of the Backup Hydrogen Purge System that require the valves to be j
open.
'Jerify each 2 inch Backup Hydrogen Purge 31 days System isolation valve is closed.
PERRY - UNIT 1 3.6-19 Amendment No. 85
r Containment Humidity Control 3.6.1.12 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME l
B.
Required Action and B.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A AND not met or in MODE 1,
- 2. or 3.
B.2 Be in MODE 4.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> l
l C.
Required Action and C.1 Suspend movement of Immediately associated Completion irradiated fuel Time of Condition A assemblies in the I
not met during primary containment.
movement of irradiated fuel assemblies in the AND primary containment.
during CORE C.2 Suspend CORE Immediately
~ ALTERATIONS or during ALTERATIONS.
AND C.3 Initiste action to Immediately suspend OPDRVs.
~;
i SURVEILLANCE REQUIREMENT SURVEILLANCE FREQUENCY
-SR 3.6.1.12.1 Verify containment average tem)erature-24 hours to-relative. humidity to be wit 11n limits.
i l
i l
1 l
-PERRY - UNIT 1 3.6-35 Amendment No. 85
)
Primary Containment and Drywell Hydrogen Igniters l
3.6.3.2
' SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.3.2.4 Verify each required igniter in 18 months accessible areas develops a surface l
t temperature of a 1700*F.
I
)
PERRY - UNIT 1 3.6-48 Amendment No. 85
t I
~
l Drywell Isolation Valves 3.6.5.3
\\
3.6 CONTAINMENT SYSTEMS 3.6.5.3 Drywell Isolation Valves l
LC0 3.6.5.3 Each drywell isolation valve, exce)t for Drywell Vacuum Relief System valves, shall be OPERABLE.
APPLICABILITY:
MODES 1. 2. and 3.
ACTIONS
...................-NOTES--------------------
1.
Penetration flow paths, except for the 24 inch and 36 inch purge supply and exhaust valve penetration flow path, may be unisolated intermittently under administrative controls.
i 2.
Separate Condition entry is allowed for each penetration flow path.
3.
Enter a)plicable Conditions and Required Actions for systems made inoperaale by drywell isolation valves.
4.
Enter applicable Conditions and Required Actions of LC0 3.6.5.1.
"Drywell." when drywell isolation valve leakage results in exceeding overall drywell bypass leakage rate acceptance criteria.
CONDITION REQUIRED ACTION COMPLETION TIME A.
One or more A.1 Isolate the affected 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> with one drywell ~ paths aenetration flow path penetration flow ay use of at least isolation valve one closed and de-l inoperable.
activated automatic valve, closed manual valve. blind flange, or check valve with flow through the valve secured.
AND (continued) l i
PERRY - UNIT 1 3.6-65 Amendment No. 85
\\
^
Drywell Isolation Valves 3.6.5.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
(continued)
A.2
NOTE---------
Isolation devices in high radiation areas may be verified by use of administrative means.
Verify the affected Prior to penetration flow path entering MODE 2 is isolated, or 3 from MODE 4. if not performed within the previous 92 days B.
One or more B.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> penetration flow paths
>enetration flow path with two drywell
)y use of at least isolation valves one closed and de-inoperable.
activated automatic valve, closed manual valve. blind flange, or check valve with flow through the valve secured.
C.
Required Action and C.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.
ANQ C.2 Be in MODE 4.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> PERRY - UNIT 1 3.6-66 Amendment No. 85
Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.3.1 Verify each 24 inch and 36 inch drywell 31 days purge supply and exhaust isolation valve is sealed closed.
SR 3.6.5.3.2 Deleted.
NOTES------------------
1.
Valves and blind flanges in high radiation areas may be verified by use of administrative means.
2.
Not required to be met for drywell isolation valves that ata open under administrative controls.
Verify each drywell isolation manual Prior to valve and blind flange that is required entering MODE 2
)
to be closed during accident conditions or 3 from is closed.
MODE 4. if not performed in the previous
)
92 days SR' 3.6.5.3.4 Verify the isolation time of each power In accordance operated and each automatic drywell with the isolation valve is within limits.
Inservice Testing Program SR 3.6.5.3.5 "erify each automatic drywell isolation 18 months hlve actuates to the isolation position u, an actual or simulated isolation signal.
l i
PERRY - UNIT 1 3.6-67 Amendment No. 85 I
I
CRER System l
3.7.3 3.7 PLANT SYSTEM 3.7.3 Control Room Emergency Recirculation (CRER) System i
LC0 3.7.3 Two CRER subsystems shall be OPERABLE.
APPLICABILITY:
MODES 1. 2. and 3.
During movement of irradiated fuel assemblies in the primary i
containment or fuel handling building.
During CORE ALTERATIONS.
1 During operations with a potential for draining the reactor vessel (OPDRVs).
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
One CRER subsystem A.1 Restore CRER 7 days inoperable.
subsystem to OPERABLE status.
1 B.
Required Action and B.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion l
Time of Condition A MD not met in MODE 1, 2.
or 3.
B.2 Be in MODE 4.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)
PERRY - UNIT 1 3.7-4 Amendment No. 85 j
i I
i Control Room HVAC System 3.7.4 3.7 PLANT SYSTEMS i
3.7.4 Control Room Heating. Ventilating, and Air Conditioning (HVAC) System LC0 3.7.4 Two control room HVAC subsystems shall be OPERABLE.
l APPLICABILITY:
MODES 1, 2. and 3.
I During movement of irradiated fuel assemblies in the primary containment or fuel handling building, During CORE ALTERATIONS, During operations with a potential for draining the reactor vessel (OPDRVs)
I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
One control room HVAC A.1 Restore control room 30 days subsystem inoperable.
HVAC subsystem to OPERABLE status.
i B.
Two control room HVAC B.1 Verify control room Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> subsystems inoperable.
air temperature is s 90 F.
AND B.2 Restore one control 7 days room HVAC subsystem to OPERABLE status.
C.
Required Action and C.1 Be in MODE 3.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion l
Time of Condition A or AND B not met in MODE 1, 2, or 3.
C.2 Be in MODE 4.
36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> (continued)
PERRY - UNIT 1 3.7-8 Amendment No. 85
m Fuel Handling Building Ventilation Exhaust System 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY t
SR 3.7.9.1 Operate each FHB ventilation exhaust 31 days subsystem for = 10 continuous hours with heaters operating.
SR 3.7.9.2 Perform FHB ventilation exhaust filter In accordance testing in accordance with the Ventilation with the VFTP Filter Testing Program (VFTP).
l i
SR 3.7.9.3 Perform a system functional test.
18 months SR 3.7.9.4 Perform a CHANNEL FUNCTIONAL TEST of the 92 days FHB ventilation exhaust radiation monitor (noble gas) l
)
.l PERRY - UNIT 1 3.7-18 Amendment No. 85
1 i
AC Sources-Operating 3.8.1 i
SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY 1
.!0TES-------------------
i 1.
DG loadings may include gradual l
i loading as recommended by the j
manufacturer.
2.
Momentary transients outside the load j
range do not invalidate this test.
i j
3.
This Surveillance shall be conducted i
on only one DG at a time.
}
4.
This SR shall be preceded by, and
~:
immediately follow, without shutdown.
a successful performance of SR 3.8.1.2 4
or SR 3.8.1.7 i
1 Verify each DG operates for a 60 minutes at i
i a load a 5600 kW and s 7000 kW for As specified in Division 1 and 2 DGs, and a 2600 kW for Table 3.8.1-1
)
i Division 3 DG.
1
)
I j
SR 3.8.1.4 Verify each day tank contains a 316 gal of 31 days l
fuel oil for Divisions 1 and 2 and j
2 279 gal for Division 3.
l i
SR 3.8.1.5 Check for and remove accumulated water from 31 days
~
each day tank.
1 SR 3.8.1.6 Verify the fuel oil transfer system
- 31. days operates to automatically transfer fuel oil from the storage tank to the day tank.
(continued)
PERRY - UNIT 1 3.8-6 Amendment No. 85
l AC Sources-0perating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.9
NDTES--------------------
1.
This Surveillance shall not be performed in MODE 1 or 2.
- However, credit may be taken for un)lanned events that satisfy this St.
2.
If performed with DG synchronized with offsite power, it shall be performed at a power factor s 0.9.
1 l
Verify each DG rejects a load greater than 18 months l
l or equal to its associated single largest.
post-accident load.
Following load rejection, engine speed is maintained less than nominal plus 75% of the difference between nominal speed and the overspeed trip setpoint, or 15% above nominal, whichever is less.
SR 3.8.1.10
NDTE--------------------
This Surveillance shall not be performed in MODE 1 or 2.
However, credit may be taken for unplanned events that satisfy this SR.
Verify each DG operating at a power factor 18 months s 0.9 does not trip and voltage is maintained s 4784 V for Division 1 and 2 DGs and s 5000 V for Division 3 DG during and following a load rejection of a load a 5600 kW for Division 1 and 2 DGs and a 2600 kW for Division 3 DG.
(continued) 1 PERRY - UNIT 1 3.8-8 Amendment No. 8.
I e
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY i
SR 3.8.1.12
NOTES-------------------
1.
All DG starts may be preceded by an j
engine prelube period.
2.
This Surveillance shall not be i
performed in MODE 1 or 2.
- However, i
credit may be taken for unalanned events that satisfy this St.
c i
Verify on an actual or simulated Emergency 18 months I
Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and:
i a.
In s 10 seconds for Divisions 1 and 2.
and s 13 seconds for Division 3 after i
i auto-start and during tests, achieves i
voltage = 3900 V and s 4400 V:
)
b.
In s 10 seconds for Divisions 1 and 2.
and s 13 seconds for Division 3 after auto-start and during tests, achieves frequency a 58.8 Hz and s 61.2 Hz: and l
c.
Operates for a 5 minutes.
l SR 3.8.1.13
NOTE--------------------
This Surveillance shall not be performed in MODE 1, 2. or 3.
However, credit may be taken for unplanned events that satisfy this SR.
Verify each DG's automatic trips are 18 months bypassed on an actual or simulated ECCS initiation signal except:
a.
Engine overspeed: and b.
Generator differential current.
(continued)
PERRY - UNIT 1 3.8-10 Amendment No. 85
AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.20
NOTE--------------------
All DG starts may be preceded by an engine prelube period.
Verify, when started simultaneously from 10 years standby condition, the Division 1 and 2 DGs achieve voltage = 3900 V and s 4400 V ar.d l
frequency a 58.8 Hz and s 61.2 Hz in s 10 seconds, and the Division 3 DG achieves a fre;9ency = 58.8 Hz in s 10 seconds, and a volt?se 2 3900 V and 5 4400 V and frecuency a 58.8 Hz and s 61.2 Hz in s 13 seconcs.
i l
i PERRY - UNIT 1 3.8-15 Amendment No. 85
s DC Sources-Shutdown
.~
3.8.5 I
3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 The following DC electrical power subsystems shall be l
OPERABLE:
a.
One Class 1E DC electrical )ower subsystem capable of supplying one division of tie Division 1 or 2 onsite Class 1E electrical power distribution subsystem (s) required by LCO 3.8.8. " Distribution Systems -
Shutdown":
b.
One Class 1E battery or battery charger, other than the DC electrical power subsystem in LC0 3.8.5.a. capable of supplying the remaining Division 1 or Division 2 onsite Class 1E DC electrical power distribution subsystem when required by LC0 3.8.8: and c.
The Division 3 DC electrical power subsystem capable of supplying the Division 3 onsite Class 1E DC electrical power distribution subsystem, when the Division 3 onsite l
Class 1E DC electrical power distribution subsystem is required by LCO 3.8.8.
APPLICABILITY:
MODES 4 and 5.
During movement of irradiated fuel assemblies in the primary containment or fuel handling building.
PERRY - UNIT 1 3.8-28 Amendment No. 85
DC Sources-Shutdown 3.8.5 ACTIONS
...........______.........-NOTE----------------------.....__.-__-_
LC0 3.0.3 is not applicable.
CONDITION REQUIRED ACTION COMPLETION TIME A.
One or more required A.1 Declare affected Immediately DC electrical power required feature (s) subsystems inoperable.
2 A.2.1 Sus)end CORE Immediately ALTERATIONS.
AND I
A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the primary containment and fuel handling building.
AND A.2.3 Initiate action to Immediately sus)end operations wit 1 a potential for draining the reactor vessel.
.A_E A.2.4 Initiate action to Immediately restore required DC electrical power subsystems to i
OPERABLE status.
PERRY - UNIT 1 3.8-29 Amendment No. 85
l DC Sources-Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1
NOTE-------------------
The following SRs are not required to be performed: SR 3.8.4.4. SR 3.8.4.6.
SR 3.8.4.7. and SR 3.8.4.8.
For DC sources required to be OPERABLE. the In accordance following SRs are applicable:
with applicable SRs SR 3.8.4.1 SR 3.8.4.4 SR 3.8.4.7 SR 3.8.4.2 SR 3.8.4.5 SR 3.8.4.8.
SR 3.8.4.3 SR 3.8.4.6 l
j PERRY - UNIT 1 3.8-30 Amendment No. 85
DC Sources-Shutdown 3.8.5 THIS PAGE INTENTIONALLY BLANK l
l PERRY - UNIT 1 3.8-31 Amendment No. 85
Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:
a.
k n s 0.95 if fully flooded with unborated water. which e
includes an allowance for uncertainties as described in Section 9.1.2 of the USAR:
b.
A nominal fuel assembly center to center storage spacing of 7 inches within rows and 12 inches between rows in the storage racks in the upper containment pool; and c.
A nominal fuel assembly center to center storage spacing of 6.625 inches, with a neutron poison material between
[
storage spaces, in the high density storage racks in the fuel handling building.
4.3.1.2 The new fuel storage racks are designed and shall be maintained with:
a.
k n s 0.95 if fully flooded with unborated water, which e
includes an allowance for uncertainties as described in Section 9.1.1 of the USAR: and l
b.
A nominal 7 inch center to center distance between fuel assemblies placed in storage racks.
4.3.2 Drainace The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 594 ft 6 inches.
4.3.3 Caoacity 4.3.3.1 The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 4020 fuel assemblies.
4.3.3.2 No more than 190 fuel assemblies may be stored in the upper containment pool.
PERRY - UNIT 1 4.0-2 Amendment No. 85
i Responsibility.
j 5.1
[
5.0 ADMINISTRATIVE CONTROLS
. 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation j
and shall delegate in writing the succession to this responsibility during his absence.
The plant manager, or his designee, shall approve, prior to implementation, each proposed test, experiment, or modification to l'
systems or equipment that affect nuclear safety, and all 1
administrative procedures.
l l
5.1.2 The shift supervisor (SS) shall be responsible for the control I
room command function.
During any absence of the SS from the control room while the unit is in MODE 1. 2. or 3. an individual l
with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function.
During any absence of the SS from the control room while the unit is in MODE 4 or 5. an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.
i l
l i
I i
PERRY - UNIT 1 5.0-1 Amendment No. 85
Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI N18.1-1971 for comparable positions as modified by Specification 5.2.2.f, except for the radiation i
protection manager, who shall meet or exceed the qualifications of j
Regulatory Guide 1.8, September 1975, and the licensed Reactor Operators and Senior Reactor Operators, who shall comply with the requirements of 10 CFR 55.
1 l
l I
PERRY - UNIT 1 5.0-4 Amendment No. 85
Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Proaram (continued) f.
Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the arinual dose ci dose commitment, conforming to 10 CFR 50.
Appendix I:
i g.
Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary as follows:
1.
for noble gases: 5 500 mrem /yr to the total body and s 3000 mrem /yr to the skin, and 2.
for iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-lives
> 8 days:
s 1500 mrem /yr to any organ:
h.
Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I:
i.
Limitations on the annual and cuarterly doses to a member of the public from iodine-131, iocine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from the unit to areas beyond the site boundary, conforming to 10 CFR 50. Appendix I: and j.
Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.
5.5.5 Comoonent Cyclic or Transient Limit This program provides controls to track the USAR Section 3.9.1.1, cyclic and transient occurrences to ensure that the reactor vessel 1
is maintained within the design lirtits.
(continued)
PERRY - UNIT 1 5,0-9 Amendment No. 85
I I
l l
Programs and Manuals 5.5 i
5.5 Programs and Manuals 5.5.7 Ventilation Filter Testina Prooram (VFTP)
(continued)
]
d.
Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters and the charcoal adsorbers is less than the value specified below when tested in accordance with Regulatory Guide 1.52. Revision 2. and ANSI N510-1980 at the system flowrate specified below i 10%:
ESF Ventilation System Delta P Flowrate a) Control Room Emergency Recirculation 4.9" H 0 30.000 scfm b) Fuel Handling Building 4.9" H 0 15.000 scfm c) Annulus Exhaust Gas Treatment 6.0" H 0 2,000 scfm e.
Demonstrate that the heaters for each of the ESF systems dissipate the value specified below 10% when corrected to nominal input voltage when tested in accordance with ANSI N510-1980:
ESF Ventilation System Wattaae a) Control Room Emergency Recirculation 100 kW b) Fuel Handling Building 50 kW c) Annulus Exhaust Gas Treatment 20 kW The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.
5.5.8 Exolosive Gas and Storaae Tank Radioactivity Monitorina Prooram This program provides controls for potentially explosive gas mixtures contained in the main condenser offgas treatment system.
and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.
The program shall include:
a.
The limits for concentrations of hydrogen in the main condenser offgas treatment system and a surveillance program to ensure the limits are maintained.
Such limits shall be appropriate'to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion); and (continued) l PERRY - UNIT 1 5.0-12 Amendment No. 85
High Radiation Area 5.7 5.7 High Radiation Area l
5.7.2 (continued)
Individuals qualified in radiation protection procedures (e.g.
health physics technicians) or personnel continuously escorted by such individuals may be exempt from the RWP issuance requirement during the performance of their assigned duties in high radiation areas with exposure rates s 3000 mrem /hr. provided they are otherwise following plant radiation protection procedures for entry into such high radiation areas.
i 5.7.3 In addition to the requirements of Specification 5.7.1. for individual high radiation areas accessible to personnel with radiation levels such that a major portion of the body could
'l 5
receive in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> a dose = 1000 mrem that are located within large areas such as reactor containment, where no enclosure exists for purposes of locking, or that are not continuously guarded, and l
where no enclosure can be reasonably constructed around the individual area, that individual area shall be barricaded and conspicuously posted, and a flashing light shall be activated as a warning device.
i 5.7.4 In addition to the requirements and exemptions of Specifications 5.7.1 and 5.7.2 for individual areas accessible to personnel such i
that a major portion of the body could receive in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> a dose i
> 3000 mrem, entry shall require an approved RWP which will specify dose rate levels in the immediate work area and the maximum allowable stay time for individuals in that area.
In lieu of the stay time specification of the RWP. continuous surveillance, direct or remote, such as use of closed circuit TV cameras, may be made by personnel qualified in radiation protection procedures to provide positive exposure control over activities within the areas.
PERRY - UNIT 1 5.0-20 Amendment No. 85