Text

Proposed Improved Tech Specs
	ML20108A258
Person / Time
Site:	Perry
Issue date:	04/26/1996
From:	; CENTERIOR ENERGY
To:	;
Shared Package
ML20108A249	List: ML20108A258; PY-CEI-NRR-1999, Application for Amend to License NPF-58,revising Improved Tech Specs.Changes Either Administrative in Nature or Reflect Minor Technical Errors Discovered During Implementation Process;
References
	NUDOCS 9605020193
	Download: ML20108A258 (43)
	v • d • e

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py.cruwan.i m t Atixhmen:2 SLC System Page I of 34 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. -

,a.

~

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION ._

REQUIRED ACTION ; . ( ,, .!, COMPLETION TIME A. One SLC subsystem '

-A.1 RestorezSLC inoperable. 7 days subsystem to OPERABLE status.

s Two SLC subsystems B.1 i operable Restore one SLC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months subsystem to ;

OPERABLE status.

C. Required Action and C.1 Be in MODE 3.

associated Completion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Time not met.

PERRY - UNIT 1 3.1-20 AmendmentNo.fy 9605020193 960426 PDR ADOCK 05000440 P PDR

PY<E1/NRR 1999L Attachment 2 Control Rod Block Instrumsntation Page 2 of 34 3.3.2.1

.s Table 3.3.2.1 1 (page 1 of 1)

Control Rod Block Instrumentation m .=me===

APPLICABLE MODES OR OTHER SPECIFIED FUNCTION REQUIRED CONDITIONS SURVEILLANCE CHANNELS REQUIREMENTS

1. Rod Pattern control System

a. Rod withdrawat limiter (a) 2 SR 3.3.2.1.1 SR 3.3.2.1.6 SR 3.3.2.1.9 h4 -Q SR 3.3.2.1.2 I

SR 3.3.2.1.5 heg, " ' '

SR 3.3.2.1.7

b. Rod pattern controtter SR 3.3.2.1.9

^\ 2 2 SR 3.3.2.1.3

'tg gy SR 3.3.2.1.4 j SR 3.3.2.1.5 4uh'Kr gl SR 3.3.2.1.7

2. SR 3.3.2.1.9 Reactor Mode Switch -Shutdown Position (d) 2 SR 3.3.2.1.8 (a) THERMAL POWER > 70% RTP. l (b) THERMAL POWER > 35% RTP and 5 70% RTP.

(c) With THERMAL POWER s 20% RTP.

(d) Reactor mode switch in the shutdown position. 1 l

I PERRY - UNIT 1 3.3-19 AmendmentNo.//

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PY-CEI/NRR-1999L Attachment 3 Page J of 34 .PAM Instrumentation 3.3.3.1 Table 3.3.3.1 1 (page 1 of 1)

Post Accident Monitoring Instrumentation m::

CONDITIONS REQUIRED REFERENCED FROM FUNCTIDN REQUIRLD CNANNELS ACTION D.1 1.

Reactor Steam Dome Pressure 2

2. E Reactor Vesset Water Levet-Wide Range

+ 2

3. E Reactor Vessel Water Level-fue! Zone 2

E 4 Suppression Poot Water Level 2

5 E S w ession Poot Sector Water Tenperature 2 I.C -

6. Drywell Pressure s,,, E 2

E 7 Drywett Air Tenperature 2

8. E.

Primary Containment /Drywell Area Cross Gersna Radiation Monitors 2 F

9.

Penetration flow Path, PCIV Position 2perpenet[gtg flow path E

10. Primary containment a5 Drywell H T Concentration Analyzer and Monitor]

4 b 2 E

11. Primary Containment Pressure 2

E

12. Primary Containment Air Tenperature

_ 2 E

(a)

Not required for isolation valves whose associated penetration flo (b) w path is isolated.

control room indication channel.Only one positionow indication channet is required for penetration fl paths with only one instatted (c) Monitoring each of eight sectors.

PERRY - UNIT 1 3.3-23 Nrandment No. g5

PY-CEl/NRR.1999L Attachment 2 l

Pue 4 cf 34 ECCS Instrumentation 3.3.5.1 i Tabte 3.3.5.1 1 (page 3 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE i

CONDITIONS MODES OR i REFERENCED l

DTHER REQUIRED FROM SPECIFIED CHANNELS PER l FUNCTION REQUIRED SURVEILLANCE CONDITIONS FUNCTIDW ALLOWABLE

! ACTION A.1 REQUIREMENTS VALUE 9

2. LPCI B and LPCI C SLAsystans (continued)

e. LPCI Ptsp B 1,2,3, i 1 per pum E and LPCI Ptmp C SR 3.3.5.1.1 a 1450 spm Discharge 4(a),5(a) SR 3.3.5.1.2 Itow- Low SR 3.3.5.1.3 (Bypass) SR 3.3.5.1.5 !

f. Manual Init(stian SR 3.3.5.1.6 l 1,2,3, 1 C SR 3.3.5.1.6 NA 4(a),5(a)

3. High Pressure Core Spray (HPCS) System '

a. Reactor vesset 1,2,3, 4 B Dater Level-Low SR 3.3.5.1.1 a 127.6 inches Low, Level 2 l 4(a),3(a) SR 3.3.5.1.2 gg 3,3,$,g,y SR 3.3.5.1.5

b. Drywell h SR 3.3.5.1.6 1,2,3 4@3 B Pressure - High SR '3.3.5.1.1 s 1.88 psig SR 3.3.5.1.2 l SR 3.3.5.1.3 !

SR 3.3.5.1.5

c. Reactor vesset SR 3.3.5.1.6 1,2,3, 4 B Water SR 3.3.5.1.1 s 221.7 inches Level - High, 4f '),5(a) SR 3.3.5.1.2 Level 8 SR 3.3.5.1.3 SR 3.3.5.1.5

d. Condensate SR 3.3.5.1.6 1,2,3, 2 D Storage Tank *a 3.3.5.1.1 = 59,700 gettons Level- Low 4(C),5(C) En 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5

e. Sq pression Pool SR 3.3.5.1.6 1,2,3 2 D Water Level -mish SR 3.3.5.1.1 5 18 ft 6 inches l

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) l (a) When associated stbsystem(s) are required to be OPERABLE.

h5 tsa rewired to initiate the associated diesel generathand '6"h +-A (c) ben HPCS is OPERABLE for conpliance with LCO 3.5.2, *ECCS -Shutdown,"

storage tank while tank water levet is not within the timits of SR 3.5.2.2.

4 W

PERRY - UNIT 1 3.3-41 Amendment No. 59, %

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PY-CEf tJRR-1999L Attachn.. 2 Page $ of 34 Primary Containment and Drywell Isolation Instrumentat 3.3.6.1 1 1

Table 3.3.6.1 1 (page 1 of 6)

Primary Contaltvoent and Drywell Isolation Instrunientation

=

APPLICABLE MODES OR CONDITIONS REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP , REGulRED OJNCTION Colelfl0NS STSTEM , ACTION C.1 SURVEILLANCE ALLOWABLE -

REQUIREMENTS VALUE 1.

Main Steam Line Isolation

a. Reactor Yesset Water .

1,2,3 2# .-

Level-Low Low Low, D Level 1 SR 3.3.6.1.1 a 14.3 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

b. Main Steam Line SR 3.3.6.1.6 1 2 Pressure - Low E SR 3.3.6.1.1 = 795.0 psta 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. Main Steam Line SR'3.3.6.1.6 1,2,3 2 per MSL Flow- H1sh D SR ~5.3.6.1.1 s 191 pstd SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3 4 1.5 l

d. Condenser Vacuta-Low SR 3.3.6.1.6 1,2(a) , 2 D SR 3.3.6.1.1 a 7.6 inches 3(a) SR 3.3.6.1.2 Hg vacuum SR 3.3.6.1.3 SR 3.3.6.1.4

e. Main Steam Line Pipe SR 3.3.6.1.5 Tunnet 1,2,3 2 D Tenperature-nigh SR 3.3.6.1.1 s 158.9'F SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 f.

Main Steam Line Turbine SR 3.3.6.1.7 BulIding 1,2,3 2 0 Teaperature-Nigh SR 3.3.6.1.1 8 138.9'F SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5

g. Manual Initiatiot 1,2,3 2 G

_ SR 3.3.6.1.5 NA

2. Primary Contairnent and Drywell Isolation ( f u. a c. di [ WyttRf

a. Reactor Vessel Water "

1,2,3 Level-Low Low, Level 2 H 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 (a) (continued)

With any turbine stop valve not closed.

(b)

R' equired to initiate the associated drywett isolation function .

PERRY - UNIT 1 3.3-54 knendment No. 69,

- pyggg,gg99t mchinen 2 Prinary Ccntainment and Drywell Isslaticn Instrumentat.icn Page 6of 34 3.3 6.1 Table 3.3.6.1 1 (page 2 of 6)

Primary Containment and Drywelt isolation Instrumentation APPLICA8LE CONDITIONS MODES OR REQUIRED REFERENCED' OTHER CHANNELS FROM

$PECIFIED PER TRIP FUNCTION REQUIRED CONDITIONS SYSTEM SURVEILLANCE ActIDN C.1 ALLOWABLE REQUIREMENTS VALUE

2. Primary Containment and Drywell isolation

s. Reactor vessel Water

(

LeveMow Low, Level 2 (continued)

(c) hj L SR 3.3.6.1.1 t 127.6 inches ER 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4

b. Drywell Pressure- High SR '3.3.6.1.5 1,2,3 4- 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

c. Reactor Vessel Water SR 3.3.6.1.5 1,2,3 !

Level - Low Low Low, F SR 3.3.6.1.1 Level 1 (ECCS 1 14.3 inches SR 3.3.6.1.2 Divisions 1 and 2) SR 3.3.6.1.3 j SR 3.3.6.1.4 SR 3.3.6.1.5 (c) 3

! ~

SR 3.3.6.1.1 h e.fca n b,A bu h] ,

SR 3,3.6.1.2 a 14.3 Inches byv at[,\ g SR 3.3.6.1.3 !

SR 3.3.6.1.4

d. Drywell Pressure - High SR 3.3.6.1.5 1,2,3 2 (ECCS Divisions 1 F SR 3.3.6.1.1 and 2) 5 1.88 psig SR 3.3.6.1.2 SR 3.3.6.1.3

(

SR 3.3.6.1.4

e. Reactor Vessel Water SR 3.3.6.1.5 1,2,3 4 Level -Low Low, Level F SR 3.3.6.1.1 2 (HPCS) t 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 (c) 4 L SR 3.3.6.1.1 2127.6 inches SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 f.

Drywell Pressure - High SR 3.3.6.1.5 1,2,3 4 (HPCS) F SR 3.3.6.1.1 5 1.88 psig SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4

p. Containment and Drywell SR 3.3.6.1.5 Purge Exhaust Plentsn 1,2,1 b( F SR 3.3.6.1.1 5 4.0 nR/hr Radiat ion - High SR 3.3.6.1.2 above SR 3.3.6.1.4 background SR 3.3.6.1.5 (b) (continued)

Required to initiate the drywell isolation function. ._

(c)

During CORE ALTERATIONS, and operations with a potential for draining th e reactor vessel.

PERRY - UNIT 1 l 3.3-55

! Amendment No. # '

1 PY-CEIMRR 1999L Anachment 2 Page 7of 34 Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 t

Table 3.3.6.1 1 (page 3 o' 6)

Primary Contelnaent and Drywell Isolatitn Instrtamentation .

APPL 1 CABLE l CONDITIONS MODES OR OTHER REQUIRED REFERENCED CNANNELS FROM FUNCTION SPECIFIED PER TRIP REQUIRED CCWITIONS EURVEILLANCE

l SYSTEM ACT10N'C.1 ALLOWABLE REQUIREIENTS VALUE

2. Primary contalisment and Drywell Isolation

s. Containannt and (d)

Drywatt Purge Exhaust 2 K SR 3.3.6.1.1 Ptersse Radiation-High SR 3.3.6.1.2 8 4.0 mR/hr above backgrotmd (continued) SR 3.3.6.1.4 T

LN' p* a'W !.! f.'.3 -

h. Manuel Initiation 1,2,3

Mt 6 sagagg. pk G BR 3.3 4 ,1.5 NA I (d) 2 l

K

3. seactor core Isolation SR 3.3.6.1.5 NA cooling (acIn system Isolation

a. RCIC Steam Line 1,2,3 Flow- High 1 F SR 3.3.6.1.1 8 298.5 inches SR 3.3.6.1.2 water

' SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.',.1.5

b. RCIC Steun Line ? low I

1,2,3 flee Detoy 1 F

SR 3.3.6.1.2 k 3 seconds and SR 3.3.6.1.4 s 13 seconds SR '3.3.6.1.5

c. RCIC Steam Stpply Line 1,2,3 1 Pressure-Low F SR 3.3.6.1.1 k 55 psig SR 3.3.6.1.2 I .

SR 3.3 6.1.3 SR 3.3.6.1.4

d. RCIC Turbine Exhaus,t SR 3.3.6.1.5 1,2,3 2 Diaphrase F SR 3.3.6.1.1 Pressure- Nigh s 20 psig SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4

e. RCIC Ecysipment Area SR 3.3.6.1.5 1,2,3 1 Anblent F SR 3.3.6.1.1 7enperature - High s 145.9'F SR 3.3.6.1.4 SR 3.3.6.1.5 i

f. SR 3.3.6.1.7

! Main Steam Line Pipe 1,2,3 Tunnet 1 F SR 3.3.6.1.1 s 158.9'F Tenperature - hlgh SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.7 (b) (continued)

Required to initiate the drywell isolation function.

(d)

, irradiated fuel assenblies in primary containment.During vessel,CORE and movement ALTERATIONS, of op 4

PERRY - UNIT 1 3.3-56 Anendment No. 59 D

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PY<Emm Anachment 2 Page 8of 34 Primary Containment and Drywell Isolation Inst 3.3.6.1 Table 3.3.6.1 1 (pege 6 of 6)

Primary Contelnment and Drywell Isolation Instrumentation APPLICABLE {

MODES OR CONDITIONS J OTHER REFERENCED REQUIRED FROM

- FUNCTION SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE CONDITIONS TRIP SYSTEM ACTION C.1

, REQUIEBENTS ALLOWABLE

5. Rint System Isolation VALUE

s. RNR Egsipment Ares Anblent ,

1 per , area F Temperature-sigh , SR 3.34.1.1 8 159.9'F r SR 3.SA1.4 h SR 3.3 A 1.5 .

b. Reactor Vessel Water Levet-Lew, Level 3 1,O,6*' 2 SR 3.34.1.7 F

SR 3.3 A 1.1 a 177.1 SR 3JA1.2 inches l

C4Jt.c4 S c. O d S *te. c st 3.3A1.3 Sfc/$L/ha

$ !*3 k b, ,4,5 M J SR 3.3A1.1

,5 a 177.1 l SR 3.34.1.2 inches SR ' 3.3A T.3' SR 3.3A1 4

c. Reactor Vesset Steam SR 3.3 A 1'.5 1,2,3 2 Dome Pressure-High F SR 3.3 A 1.1 5 150 psig SR 3.311.2 SR 3.611.3 SR 3.6.11.4 1

d. DrywetL Pressure-High SR 3.6.1.1'.5 i 1,2,3 2 7 SR '3.3 A 1.1 s 1.88 psig SR 3.3A1.2 SR 3.3 A T.3 SR 3.3A1.4 l

e. Manual initiation SR 3.3A1.5 I 1,2,3 2 C

SR 3.3 A 1.5 NA (e)

With reactor vesset steam dome pressure less than the RNR cut i =

(f) n permissive pressure.

Dnty one trip system required in MODES 4 and 5 with RHR Shutd (g)

With reactor steam cleme pressure greater than or equat to the RHRown Cooling cut in permlssive tusd )

? ""'

PERRY - UNIT 1 3.3-59 AmendmentNo.69M

i l

PY-CEl/NRR-1999L Attachment 3 Recirculation Loops Operating Page 9 of 34 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LCO 3.4.1 M itherd .

v Two recirculation loops'shall be in operation with:

1. Matched flows; and 2.

gg Total core flow and THERMAL POWER within limits.

b.

One recirculation loop shall be in operation with:

1.

Thermal power f 2500 MWt;

2. j Total core flow and THERMAL POWER within limits; 3.

Required limits modified for single recirculation loop operation as specified in the COLR; and 4.

LCO 3.3.1.1, " Reactor Protection System (RPS) l Monitors Flow Biased Simulated Thermal l

-Allowable loop operation. Value of Table 3.3.1.1-1 reset for single

)

NOTE-------------------------------

Required limit and setpoint modifications for single 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months operation after to single recirtransition from two recirculation

...........................culation loop operation.

APPLICABILITY:

MODES 1 and 2.

_ ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop jet A.1 pump flow mismatch not Shut down one of the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within lir.iits. recirculation loops.

(continued)

PERRY - UNIT 1.

3.4-1 AmendmentNo.((

I 1

{j[g*L RHR Shutdown Cooling System-Cold Sh m Page 10of 34 i

I ACTIONS (continued)

CONDITION 1 REQUIRED ACTION

~

COMPLETION TIME B. No RHR shutdown

%\bt $ n B.1 Verify reactor L cooling subsystem in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from

operation. coolant q: !:r q[- discovery of no by an alternate i

method. reactor coolant

\

1 O circulation l

No recirculation pump M l

in operation.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

,thereafter MQ -

B.2 Monitor reactor I

Once per hour coolant temperature and pressure.

l i i i

SURVEILLANCE REQUIREMENTS i

SURVEILLANCE l l FREQUENCY I SR 3.4.10.1 l Verify one RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

1

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PERRY - UNIT 1 3.4-25 AmendmentNo.//

PY CE!/NRR-1999L Anahmem 2 RCS P/T Liaits Page 11 of 34 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

. SURVEILLANCE FREQUENCY SR 3.4.11.8 4

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 pump flow s 50% of rated core floy or THERMAL POWER s 30% of RTP, and with reactor vessel steam dome pressure it 25 psig.

Verify the difference between the bottom. ,. (Once within head coolant temperature and the RPV

temperature is s 100*F. 15 minutes

, prior to an L

{c.%\ increase in THERMAL POWER or an increase in loop flow SR 3.4.11.9 -------------------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 pump flow s 50% of rated core flow, or THERMAL POWER s 30% of RTP, and the idle recirculation loop not isolated from the RPV.

Once within

15 minutes prior to an Verify the difference between the reactor coolant temperature in the recirculation increase in THERMAL POWER loop not in operation and the RPV coolant temperature is s 50*F. or an increase 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 10 CFR 50, Appendix H PERRY - UNIT 1 3.4-30 AmendmentNo.I[

, PY-CEl/NRR 19991. Primary Containment Air Locks Attachment 2 Page 12of 34 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued)- C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. Required Action and 0.1 Be in MODE 3.

associated Completion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Time of Condition A.

B. or C not met in M

MODE 1. 2. or 3.

D.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Required Action and E.1 Suspend movement of associated Com letion Immediately

recently irradiated Time of Condit on A.

B. or C not met during fuel assemblies in movement of recently the primary i

irradiated fuel containment. 1 assemblies in the M

' primary containment.

or OPDRVs. E.2 Initiate action to Immediately suspend OPDRVs.

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PERRY - UNIT 1 l 3.6-6 Amendment No. g , (6

i l

( , PYCEUNRR l%9L Amhment 2 PCIVs Pqe 13cf 34 3.6.1.3 I t SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY l SR 3.6.1.3.11 ------------------NOTE-------------------

Only required to be met in MODES 1, 2,

) and 3.

l _________________________________________

Verify combined leakage rate of I gpm -----NOTE-----

times the total number of PCIVs through SR 3.0.2 is not hydrostatically tested lines that applicable

penetrate the primary containment is not ---------------

l

' exceeded when these isolation valves are tested at 2 1.1 P . In accordance with 10 CFR 50, Appendix J, as modified by l

approved '

exemptions I

I l

1 '

SR 3.6.1.3.12 --------

NOTE------------------

Only required to be met in MODES 1, -

l . 2, and 3.

= = ==- ===--_ ______________

1 i Verify each outboard 42 inch primary 18 months l containment purge valve is blocked to restrict the valve from opening > 50*.

l SR 3.6.1.3.13 ------------------NOTE-------------------

l Not required to be met when the Backup Hydrogen Purge System isolation valves i

are open for pressure control, ALARA or air quality considerations for personnel entry, or Surveillances or special testing of the Backup Hydrogen Purge System that require the valves to be open.

l Verity each 2 inch Backup Hydrogen Purge 31 days System isolation valve is closed.

4

[ PERRY - UNIT 1 3.6-19 Amendment No. 43, l

l

PY CEl/NRR 1999L

^= tant 2 - Containm2nt Humidity Control P4114 of 34 3.6.1.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and 8.1 Be in MODE 3.

associated Completion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Time of Condition A E not met or in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months

\

C. Required Action and C.1 Suspend movement of associated Completion Immediately irradiated fuel Time of Condition A assemblies in the not met during primary containment.

movement of irradiated fuel assemblies in the M primary containment, CORE ALTERATIONS, @ C.2 Suspend CORE OPDRVs. Immediately f ALTERATIONS. l C.3 Initiate action to Immediately suspend OPDRVs.

l SURVEILLANCE REQUIREMENT SURVEILLANCE '

FREQUENCY SR 3.6.1.12.1 Verify containment average temperature- 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to-relative humidity to be within limits. .'

( _-

PERRY - UNIT 1 3.6-35 Amendment No. Ml,

' ["1*$"

Page 15cf 34 Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

\

SR 3.6.3.2.4 Verify each required igniter in l 18 months

@ccessible areas develops a surface temperature of 21700*F. [

i t

f i i i 1 l

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l PERRY - UNIT 1 3.6-48 Amendment No. AS,

o Co Mw 3 @cogMA-n

@h PY-CE!/NRR 1999L bCIYS g, 3.6.4.2 h ( Ahb dt. .

Attachment 2 Page 16of34 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.I Suspend movement of associated Completion Immediately irradiated fuel Time of Condition A assemblies in the or B not met during primary containment, movement of irradiated i

fuel assemblies in the ANQ primary containment, during CORE 0.2 Suspend CORE ALTERATIONS, or during Immediately

~

ALTERATIONS.

OPDRVs.

AN.Q D.3 Initiate action to Immediately.

suspend OPDRVs.

l SURVEILLANCE REQUIREMENTS l

SURVEILLANCE FREQUENCY SR 3.6.4.2.1 ------------------NOTES------------------

I. Valves and blind flanges in high radiation areas may be verified by i

use of administrative means.

2. Not required to be met for SCIVs

that are open under administrative

! controls.

Verify each secondary containment 31 days isolation manual valve and blind flange that is required to be closed during accident condition's is closed.

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, V j PERRY - UNIT I l

3.6-55 Amendment No. 69

p g, Drywell Isolation Valves ,

Amdmwnt 2 3*6*b'3 Pqe 17of 34 3.6 CONTAINMENT SYSTEMS 3.6.5.3 Drywell Isolation Valves i

LCO 3.6.5.3 Each drywell isolation valve, except 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 supp underexhaust and valvecontrols.

administrative penetration flow path, may be unisolated intermit 2.

Separate Condition entry is allowed for each penetration flow path .

3.

Enter applicable Conditions and Required Actions for systems made inoperable by drywell isolation valves.

4.

Enter applicable Conditions and Required Actions of LC0 3.6.5.1, "Drywell,"

overall when drywell by drywell isolation valve leakage results in. exceeding

_______________________ pass leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 penetration flow paths' Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months with one drywell penetration flow path isolation val.ve' b use of at least inoperable, g\,pJ one (E5!gFand de-activated automatic (

valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

MQ (continued)

Q,.

PERRY - UNIT 1 3.6-65 Amendment No. 6&'

o PY-CEUNRR 1999L DryWe11 Is01ation Valyes

^*hment 2 Page la of 34 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 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetration flow paths penetration flow path with two drywel'1 by use of at least isolation valves one closed and de-inoperable. activated automatic m valve? blind f1ange, hgadmawd i i or GTE5affvalve with g(>

flow through the l

3*Ettsecured.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met. AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months PERRY - UNIT 1 3.6-66 Amendment No. Ji@3

4-1 1

o PY-CEI/NRR 1999L 1

Attachment 2 Pqe 19of 34 Drywell Isolation Valves i 3.6.5.3 i

SURVEILLANCE REQUIREMENTS' .

SURVEILLANCE FREQUENCY !

i i

SR 3.6.5.3.1 Verify each 24 inch and 36 inch drywell 31 days.

! purge supply and exhaust isolation valve 2 1

is sealed closed. l t-

! SR 3.6.5.3.2 j f-~-trequire---------------NOTE------------------h No o be met w the Backup 134bMd*

Hydroge urge System ' solation valves ;

1 are n for press e control, ALA or i

gif quality co derations for rsonnel ,

entry, or S veillances or cial i testing the Backup H ogen Purge i

! Syst that require valves to be i j o .

i Verify h 2 inch Ba p Hydrog urge g System isolation val e is clos ,

,) (((lI(??f" h i i 1 SR 3.6.5.3.3 ------------------NOTES------------------

i

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 are 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 (continued)

PERRY - UNIT 1 3.6-67 Amendment No. 19f.

PY CEl/NRR-1999L

~

Attachment 2 Pqe 20of 34 3.7 PLANT SYSTEM 3.7.3 Control Room Emergency Recirculation. (CRER) System LCO 3.7.3 Two CRER subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, 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 (0PDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRER subeystem inoperable. A.1 Restore CRER 7 days subsystem to OPERABLE '

status, i

B. quired Action and .B.1 Be in MODE 3.

sociated Completion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ime of Condition A ANQ I ;

not met in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued) i q,4

/

PERRY - UNIT 1 3.7-4 Amendment No. If

l PY{IUNRR-lM9L Control Room HVAC System Attachment 2 Pqe 2l of 34 3.7.4 3.7 PLANT SYSTEMS 3.7.4 i

Control Room Heating. Ventilating, and Air Conditioning (HVAC) System LCO 3.7.4 Two control room HVAC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3,

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 (0PDRVs).

ACTIONS CONDITION i REQUIRED ACTION COMPLETION TIME i

! A. One control room HVAC

! A.1 Restore control room subsystem inoperable. 30 days HVAC subsystem to OPERABLE status.

B. Two control room HVAC subsystems inoperable.

B.1 Verify control room Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months l air temperature is 5 90*F.~

AND l

B.2 Restore one control 7 days room HVAC subsystem to OPERABLE status.

C. quired Ac.+. ion and C.1 Be in MODE 3.

sociated Completion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months me of Condition A or 6NQ l B not met in MODE 1, 2, or 3.

i J4 2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months l

l (continued) l i

PERRY - UNIT 1 3.7-8 Amendment No. gf,f

{ ,1 ] N Fuel Handling Building Ventilation Exhaust System Page 22 of 34 3.7.9

_ SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each FHB ventilation exhaust subsystem for 210 continuous hours with 31 days heaters operating.

i SR 3.7.9.2 Perform testing in FHB accordance ventilation w exhaust filter In accordance Filter Testing { ogram VFTP).(ith the with Ventilationthe VFTP I

L SR 3.7.9.3 Perform a system functional test.

~ 18 months 1

SR 3.7.9.4 Perform a CHANNEL FUNCTIONAL TEST of the 92 days i

1 FHB ventilation (noble gas) exhaust radiation monitor i

l I i

I PERRY - UNIT 1 3.7-18 Amendment No.)WV

.- . -. . -. . - . - - . . _ _ . - . .- =- _ - _ .

c PY-CEI/NRR 1999L Amstmwnt 2 Pqe 23 of 34 AC Sources-Operating 1 3"8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 3.8.1.3 SR

NOTES-------------------

1.

DG loadings may include gradual loading as recommended by the manufacturer.

2.

Momentary transients outside the load range do not invalidate this test.

3.

This on Surveillance only one DG at ashalltime.be conducted 4.

This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.7. ,

Verify a load each DG operates for 2 60 minutes at 2 5600 kW and g 7000 kW for As specified in I

Division 1 and 2 DGs, and Table 3.8.1-1 Division 3 DG. 2 2600 kW for ,,

SR 3.8.1.4 !

Verify each day tank contains 2 al of 31 days i fuel oil for 2({jjfgal forDivisions Division13.and 2 and [

~

b [

SR 3.8.1.5 Check each day for and tank. remove accumulated water from 31 days 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. /d[

PY<EUNRR-1999L e

Attachment 2 AC Sources-Operating '

i Page 24 or 34 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY !

SR 3.8.1.9 -----------------NOTES------------- ------

1.

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned {

events that satisfy this SR. I

2. If performed with DG synchronized with offsite power, it shall be performed I at a power factor s 0.9.

' ao ck),

\

or l Verify each DG rejects 3 greater than or I 1

18 months i

equal to its associated single largest {

t post-accident load. Following load rejertion, 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.

i SR 3.8.1.10 d.-----------------NOTE Mom tary tran nts out

[------------------ I l

d powe the 1 d ctor r o no inval ate this t st.

1 is Surveillance shall not be performed in MODE 1 or 2. However,g 4-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 2 5600 kW for Division 1 and 2 DGs and 2 2600 kW for Division 3 DG.

(continued)

PERRY - UNIT 1 3.8-8 Amendment No. $

i .

o PYGI/NRR 1999L Attachtnent 2 AC Sources-Operating Page 25of 34 3,8,1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY I SR 3.8.1.12 -------------------NOTES-------------------

1. All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be L

performed in MODE 1 or 2. However, i credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency 18 months Core Cooling System (ECCS) initiation !

signal each DG auto-starts from standby l condition and: '

a.

In s 10 seconds for Divisions 1 and 2, and s 13 seconds for Division 3 after auto-start and during tests, achieves voltage 2 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, achiev frequency.2 58.8 Hz and s 61.2 Hz; a l

c. Operates for 2 5 minutes [e g

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.

__________________________________________ l Verify each DG's automatic trips are bypassed on an actual"or simulated ECCS 18 months initiation signal except:

a. Engine overspeed; and b.

Generator differential current.

Q. ,

(continued)

PERRY - UNIT 1 3.8-10 AmendmentNo.//

i

, PY<E!/NRR 1999L i Amdmwnt 2 Pqe 26 of 34 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 GPVoltage 2 3900 V and s 4400 V and frequency 2 58.8 Hz and 5 61.2 Hz in s 10 I seconds, and the Division 3 DG achieves a

-frequency 2 58.8 Hz in s 10 seconds, and a }

voltage 2 3900 V and s 4400 V and frequency 2 58.8 Hz and 5 61.2 Hz in s 13 seconds .

1

,( _ . - l PERRY - UNIT 1 3.8-15 Amendment No./s/

PYCEUNRR-IPML DC Sources--Shutdown Anwhment 2 Pqe 27 of 34 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources--Shutdown LC0 3.8.5 (bhe following DC electrical power subsystems shall be OPERABLE: l a.

One Class IE DC electrical power subsystem capable of supplying one division of the Division 1 or 2 onsite Class IE electrical power distribution subsystem (s) required by LC0 3.8.8, " Distribution Systems -

Shutdown";

b.

One Class IE battery or battery charger, other than the DC electrical power subsystem in LCO 3.8.5.a, capable of supplying the remaining Division 1 or Division 2 onsite Class IE DC electrical power distribution subsystem when required by LCO 3.8.8; and The Division 3 DC electrical power subsystem capable of

($2uec supplying the Division 3 onsite Class IE DC electrical distribution subsyste p hen the Division 3 onsite I

Class requiredIE by DCLC0 electrica 3.8.8. Fpower distribution subsystem is APPLICABILITY: MODES 4 and 5, During movement of irradiated fuel assemblies in the primary containment or fuel handling building.

...r .

l A s PERRY - UNIT 1 3.8-28 Amendment No. A f

l l

. I py.camR 1999L DC Sources-Shutdown Attachment 2 Page 28 of 34 3.8.5 t

ACTIONS I CONDITION REQUIRED ACTION COMPLETION TIME i

. A. (continued) A.2.2 Suspend movement of Immediately irradiated fuel assemblies in the primary containment and fuel handling building. l AND

\

A.2.2 Suspend movement of Immediately.

irradiated fuel !

( assemblies in the I primary containment l and fuel handling !'

building.

QD A.2.3 Initiate action to Immediately ;

1 suspend operations with a potential for draining the reactor vessel. I AND A.2.4 Initiate action to i Immediately restore required DC electrical power subsystems to OPERABLE status.

l l

PERRY - UNIT 1 3.8-30 AmendmentNo.46

PY CEI/NRR 1999L Attachment 2 Design Features Page 29of 34 4.O 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 'c# s 0.95 if fully flooded with unborated water, which in ludes Section an ofallowance 9.1.2 the USAR; for uncertainties as described in 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 assembl 4 center to center storage spacing of 6.625 incheii,' -,u.iiy a neutron poison material between j 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 'c# 5 0.95 if fully flooded with unborated water, which in ludes an allowance for uncertainties as described in Section'9.1.1 of the USAR;j l

b.

A nominalplaced assemblies 7 inch-center in storage to center distance between fuel racks.

4.3.2 Drainaae The sp.egt 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 Capacity 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.

4 -

PERRY - UNIT 1 4.0-2 Amendment No. 8

+ . l py.cewgg.i999t Atrachment 2 Responsibility Page 30of 34 5.1 A 5.0 V ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 ..

and shall delegate in writing the succession to this responsibility during his absence.

The plant manager, or his designeo, shall ap systems or equipment administrative that affect hi(clear safety, and all procedures. {

5.1.2 The shift supervisor (SS) shall be responsible for the control room command function.

During an9 absence of the SS from the i with an active Senior Reactor SRO Operatorcontrol room while designated to assume the control room co(mman)d function. license 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 Reacto Operator command license shall be designated to assume the control room function.

D 4

PERRY - UNIT 1 5.0-1 Amendment No. A9

PY CEUNRR-1999L Attachtnent2 Page 31of 34 Unit Staff Qualifications 53 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member qualifications of the of ANSI unit staff shall meet or exceed N18.)-1971 the minimum for comparable positions as modified i;y Specification 5.c.2.f, except for the radiatiori protectionGulTE Hegulatory minager, who shall meet or exceed the qualifications of 1.8, September 197h7 Operators and Senior Reactor Operators,/he licensed Reactor

. ele tr.;

= ; r ga ,i.c;u;m. J 1..

shalpiscmers, exceea V 1

~

20ppi; men ml requir=cr,ts specified4r, NRC Sectione lettei iv oli l iceriasca.f A .nd C J "r.cle:ure 1 of the $8erch 28,1 Camg % u d k a p d * <~k e 16 ( FA. s r.

PERRY - UNIT 1 5.0-4 Amendment No. fff

l PY CEl/NRR-1999L Programs and Manuals Auckunt 2 Pqe 32 cf 34 5.5 l

j 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Procram (contir.ued) 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 red 0ce 1 releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose Appendix I; or dose commitment, conforming to 10 CFR 50, 1

l g.

I 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: s 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 l to areas beyond Appendix I; the site boundary, conforming to 10 CFR 50, j i.

'.imitatio.ns on the annual and quarterly doses to a member of

che public from iodine-131, iodine-133, tritium, and all

)

radionuclidas 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 rcdioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

5.5.5 Component Cyclic or Transient limit This program provides controls to track the USAR, Section 3.9.1.1, cyclic and transient occurrences to ensure that reactor vessel is maintained within the design limits. l (continued)

' ( ..

PERRY - UNIT I 5.0-9 Amendment No.,69"

PY CEIMRR 1999L Anachment 2 Progrcms and Manuals

(

Page 33of 34 5.5 5.5 Programs and Manuals i 5.5.7 i Ventilation Filter Testino Proaram (VFTP) (continued) !

d.

s.

Demonstrate for each of the ESF systems that the pressure drop across the combined.HEPA filters and the charcoal ,

a adsorbers is less than the value specified below when tested i in accordance with Regulatory Guide 1.52, Revision 2, and i

ANSI N510-1980 at the systen. flowrate specified below !

10%: i ESF Ventilation System

~

Delta P _ Flowrate a) he{m b) Control Room Emergency Recirculation 4.9" H 0 30,000 Fuel Handling Building 4.9" H 0 15,000 c) Annulus Exhaust Gas Treatment 6.0" H 0 2,0004 e.

Demonstrate that the heaters for each of the ESF systems dissipate the value specified below i 10% when corrected to i s

nomine.1 input voltage when tested in accordance with ANSI N510-1980:

I, ESF Ventilation System 1 Wattaae 4 a) Control Room Emergency Recirculation b) Fuel Handling Building 100 kW 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 VFTPi test frequencies.

5.5.8 Exolosive Gas and Storace Tank Radioactivity Monitorina Procram This program provides controls for potentially explosive gas mixtures liquid 'to' rage tanks.

s contained in the main condenser offga( ,

The program shall include: !

a.

The limits for concentrations of hydrogen in the main condenser offgas treatr:ent system and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate or not the s to the system's design criteria (i.e., whether !

i explosion); ys' and tem is designed to withstand a hydrogen (continued) m PERRY - UNIT 1 5.0-12 Amendment No. Af

- ... .. ~ . _ .. _ .

PY-CEl.HRR.1999L Attachment 2 tiigh Radiation Area Page 34 of 34 5.7 5.7 High Radiation Area 5.7.2 (continued)

Individuals qualified in radiation protection (e.g., hr.alth physics technicians) or personne. procedures l 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.

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 receive in I hour a dose 21000 mrem that are located within large N4. u 7 areas such as reactor containment, where no enclosure exists for purposes of locking, or that W r m t F# continuously guarded, and where no enclosure can be reasonably constructed around the l individual area, that individual area shall be barricaded and warning device. posted, and a flashing light shall be activated as a conspicuously 5.7.4 In addition to the requirements and exemptions of Specifications that a major portion of the body could receive in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months a

> 3000 mrem, entry shall require an approved RWP which will specify dose rate levels in the immediate work area and the maximum allowable .ay time for individuals in that area.

of the stay time specification of the RWP, continuous In lieu surveillance, direct or remote cameras, may be made by personn,el suchqualified as use of in closed radiationcircuit TV protection procedures to provide positive exposure control over activities within the areas.

PERRY - UNIT 1 5.0-20 Amendmenttio.//f

. _ _ - - ~ - _ - - - _ . _ . - - . - _ _ - - . - _ - .

. PY-CEl/NRR.1999L Attachment 3 Page I of 2 l

l SIGNIFICANT HAZARDS CONSIDERATION I

The standards used to arrive at a determination that a request for amendment involves no I

significant hazards consideration are included in the Commission's regulations, 10CFR50.92. This regulation states that a proposed amendment involves no significant !

hazards consideration if operation of the facility in accordance with the proposed I amendment would not: (1) involve a significant increase in the probability or consequences of an accident previously evaluated; (2) create the possibility of a new or i different kind of accident from any accident previously evaluated; or (3) involve a significant reduction in a margin of safety.

j The proposed changes have been reviewed with respect to these three factors and it has been determined that the proposed changes do not involve a significant hazard because:

1. The proposed changes do not involve a significant increase in the probability or l consequences of an accident previously evaluated.

l l Eight of the proposed changes are administrative in nature and either correct errors or incorporate into the improved Technical Specifications a change which was approved l by the NRC under Amendment 70 for the current Technical Specifications. Changing l the classification of the Backup Hydrogen Purge System isolation valves from i drywell isolation valves to primary containment isolation valves results in the same

actions being taken in the event one of these valves is declared inoperable. However, i the Completion Times are more restrictive for inoperable primary containment isolation valves than for inoperable drywell isolation valves. The proposed changes to the diesel generator fuel oil day tank minimum volumes provide more stringent i

requirements for operation of the facility to increase the reliability of the diesel generator fuel oil transfer pump operation. The more stringent requirements continue to ensure that the safety analysis and licensing basis are maintained. The proposed change to Specification 5.7.3 clarifies continuously guarding a high radiation area is an option, not a requirement. The proposed changes have been reviewed and determined to have no affect on accident conditions or assumptions.

Based on the above, the proposed changes do not significantly increase the probability or consequences of any accident previously evaluated.

1 l

1 I

PY CEI/NRR 1999L Attachment 3 Page 2 or 2

2. The proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated.

As stated above eight of the proposed changes are administrative in nature and do not increase the possibility of any new or different kind of accident. Changing the classification of the Backup Hydrogen Purge System isolation valves from drywell isolation valves to primary containment isolation valves results in the same actions being taken in the event one of these valves is declared inoperable. However, the -

Completion Times are more restrictive for inoperable primary containment isolation valves than for inoperable drywell isolation valves. The proposed changes to the diesel generator fuel oil day tank minimum volumes do not involve installation of new or different equipment nor do they change the methods governing normal plant operations. These changes are also consistent with assumptions made in the safety analysis and licensing basis. Clarifying the controls ofhigh radiation areas will not '

impact existing or introduce any new accident precursors. The proposed changes do not cceate the possibility of a new or different kind of accident since they do not affect the reacter coolaet pressure boundary or reactivity controls. Consequently, no new l failure mode: are introduced as a result of the proposed changes.

Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any previously evaluated.

l

3. The proposed changes do not involve a significant reduction in a margin of safety.

The margin of safety is unchanged because the proposed administrative changes do not affect any design basis or accident assumptions. Changing the classification of the Backup Hydrogen Purge System isolation valves from drywell isolation valves to primary containment isolation valves results in the same actions being taken in the event one of these valves is declared inoperable. However, the Completion Times are more restrictive for inoperable primary containr.1ent isolation valves than for inoperable drywell isolation valves. The imposition of more restrictive requirements

! for the diesel generator fuel oil day tank minimum volumes results from the i implementation of the Bases for the Technical Specification Surveillance Requirement. Clarifying the controls of high radiation areas is consister t with ALARA practices.

Therefore, the proposed changes do not involve a significant reduction in a margin of safety.

{

~__.

l'Y-CEUNRR.1999L 4'

TABLE OF CONTENTS

$llI57/

1.0 USE AND APPLICATION 1.1 Definitions ........ ............. 1.0-1 1.2 Logical Connectors . . . . . ........... 1.0-8 Completion Times . . . . .

1.3 1.4

.............. 1.0-11 Frequency ....

.................. 1.0-24 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.2

......... ................ 2.0-1 SL Violations ..................... 2.0-1 B 2.0 SAFETY LIMITS (SLs)

B 2.1.1 Reactor Core SLs . . . . . . . . . . . . . . . . . . . . B 2.0-1 B 2.1.2 Reactor Coolant System (RCS) Pressure SL . . . . . . . . B 2.0-6 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY . . 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ........ 3.0-4 8 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY . . . . B 3.0-1 B 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ........ B 3.0-10 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) ................. 3.1-1 3.1.2 Reactivity Anomalies . . ............. 3.1-5 3.1.3 Control Rod OPERABILITY .

.............. 3.1-7 3.1.4 Control Rod Scram Times ................. 3.1-12 3.1.5 Control Rod Scram Accumulators . . . . . . . . . . . . . 3.1-15 3.1.6 Control Rod Pattern ....... .......... 3.1-18 3.1.7 Standby Liquid Control (SLC) System .......... 3.1-20 3.1.8 Scram Dischar ge Volume (SDV) Vent and Drain Valves . . . 3.1-24 B 3.1 REACTIVITY CONTROL SYSTEMS B 3.1.1 SHUTDOWN MARGIN (SDM) . .

............ B 3.1-1 B 3.1.2 Reactivity Anomalies . . . .. .......... B 3.1-8 B 3.1.3 Control Rod OPERABILITY . .. ... .... B 3.1-13 8 3.1.4 Control' Rod Scram Times . .

........ B 3.1-22 8 3.1.5 Control Rod Scram Accumulators . .......... B 3.1-28 B 3.1.6 Control Rod Pattern .

........... ... B 3.1 B 3.1.7 Standby Liquid Control (SLC) System .......... B 3.1-38 B 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves . . . B 3.1-44 3.2 POWER DISTRIBUTION LIMITS 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) 3.2-1 3.2.2 3.2.3 MINIMUM CRITICAL POWER RATIO (MCPR) .. ....... 3.2-2 LINEAR HEAT GENERATION RATE (LHGR) ..... ... 3.2-3 8 3.2 POWER DISTRIBUTION LIMITS B 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) B 3.2-1 B 3.2.2 B 3.2.3 MINIMUM CRITICAL POWER RATIO (MCPR) . . .... B 3.2-6 LINEAR HEAT GENERATION RATE (LHGR) . .. .. B 3.2-10 (continued)

PERRY - UNIT 1 i Revision No. 0

, $[ra1D*'

Page got 7 TABLE OF CONTENTS 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation ... 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation . . . . . . . 3.3-10 3.3.2.1 Control Rod Block Instrumentation ....... . . 3.3-15 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation . . . 3.3-20 Remote Shutdown System . . . . . . . . . . . . . . . . .

3.3.3.2 3.3-24 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation .......... ....... 3.3-26 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation . . . . . .. 3.3-29 3.3.5.1 Emergency Core Cooling System (ECCS)

Instrumentation ................ . 3.3-32 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation ........... . .... 3.3-44 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation ..... . ..... . . 3.3-48 3.3.6.2 Residual Heat Removal (RHR) Containment Spray System Instrumentation . . . . ..... .... 3.3-60 3.3.6.3 Suppression Pool Makeup (SPMU) System Instrumentation ..... .. .... ... 3.3-64 3.3.6.4 Relief and Low-Low Set (LLS) Instrumentation . ... 3.3-68 3.3.7.1 Control Room Emergency Recirculation (CRER) System Instrumentation .. . . ........ 3.3-70 3.3.8.1 Loss of Power (LOP) Instrumentation ..... .... 3.3-74 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring .... .......... 3.3-77 8 3.3 INSTRUMENTATION B 3.3.1.1 Reactor Protection System (RPS) Instrumentation .... B 3.3-1 B 3.3.1.2 Source Range Monitor (SRM) Instrumentation . ..... B 3.3-33 B 3.3.2.1 Control Rod Block Instrumentation ... .... .. B 3.3-42 B 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation . .. B 3.3-51 B 3.3.3.2 Remote Shutdown System . . .. ...... . B 3.3-63 8 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation ...... . .... ... B 3.3-68 B 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation ....... B 3.3-79 B 3.3.5.1 Emergency Core Cooling System (ECCS)

Instrumentation ......... .. . B 3.3-88 B 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation ........ . . .. B 3.3-124 3 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation ...... .. .. B 3.3-136 B 3.3.6.2 Residual Heat Removal (RHR) Containment Spray System Instrumentation . . . .. . B 3.3-173 B 3.3.6.3 Suppression Pool Makeup (SPMU) System l Instrumentation .. B 3.3-184 (continued) l PERRY UNIT 1 ii Revision No. O

TABLE OF CONTENTS NM*'

Page 3 or 7 B 3.3 INSTRUMENTATION (continued)

B 3.3.6.4 Relief and Low-Low Set (LLS) Instrumentation . . . . . .

B 3.3.7.1 B 3.3-195 Control Room Emergency Recirculation (CRER) System Instrumentation .... .. .......... B 3.3-201 B 3.3.8.1 Loss of Power (LOP) Instrumentation .......

B 3.3.8.2 . . B 3.3-211 Reactor Protection System (RPS) Electric Power Monitoring . . .... . .. ..... B 3.3-218 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating ... ..... . . 3.4-1 3.4.2 Flow Control Valves (FCVs) . .. .......... 3.4-6 3.4.3 Jet Pum]s .... ........ ......... 3.4-8 3.4.4 Safety /lelief Valves (S/RVs) . . ....... 3.4-10 3.4.5 RCS Operational LEAKAGE . .............. 3.4-12 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage . . . . . . 3.4-14 3.4.7 RCS Leakage Detection Instrumentation .. .... 3.4-16 3.4.8 RCS Specific Activity ...... .... .. . . 3.4-19 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown . . . . . . . . . . . . . . . 3.4-21 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown . .. . . . . . 3.4-24 3.4.11 RCS Pressure and Temperature (P/T) Limits . ... 3.4-26 3.4.12 Reactor Steam Dome Pressure ... .... . . 3.4-32 l l

B 3.4 REACTOR COOLANT SYSTEM (RCS) !

B 3.4.1 Recirculation Loops Operating . . .... .... B 3.4-1 8 3.4.2 Flow Control Valves (FCVs) . ..... .... ... B 3.4-9 B 3.4.3 Jet Pumps .... ..... .

...... B 3.4-13 8 3.4.4 Safety / Relief Valves (S/RVs) . . .. . B 3.4-17 B 3.4.5 RCS Operational LEAKAGE .

............ B 3.4-22 B 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage . . . . B 3.4-27 B 3.4.7 RCS Leakage Detection Instrumentation . . . B 3.4-32 B 3.4.8 RCS Specific Activity ...... ... . .

B 3.4-39 8 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown . . . . . ... .

B 3.4-43 B 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown .... . .. . . B 3.4-48 B 3.4.11 RCS Pressure and Temperature (P/T) Limits .. . B 3.4-53 B 3.4.12 Reactor Stean. Dome Pressure .. . B 3.4-63 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS - 0)erating .

3.5-1 3.5.2 ECCS -S lutdown 3.5-6 3.5.3 RCIC System 3.5-10 (continued)

PERRY - UNIT 1 iii Revision No. O

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Page 4 or 7

' TABLE OF CONTENTS B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.1 ECCS -0)erating .

.................. B 3.5-1 B 3.5.2 ECCS-Slutdown . . .. ... .

......... B 3.5-15 B 3.5.3 RCIC System .. .... .. ........... B 3.5-20 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment--Operating ............. 3.6-1 3.6.1.2 Primary Containment Air Locks ............. 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) . . . . .. 3.6-9 3.6.1.4 Primary Containment Pressure . . . .. ...... 3.6-20 3.6.1.5 Primary Containment Air Tem .......... 3.6-21 3.6.1.6 Low-Low Set (LLS) Valves . perature .. .. ......... 3.6-22 i 3.6.1.7 Residual Heat Removal (RHR) Containment !

Spray System . . . . . . . . . . . . . . . . . . 3.6-24 3.6.1.8 l

Feedwater Leakage Control System (FWLCS) . ....... 3.6-26 l 3.6.1.9 Main Steam Isolation Valve (MSIV) Leakage Control System (LCS) l

...... .. .. . ... 3.6-27 3.6.1.10 Primary Containment-Shutdown . . . . . . .

l

. . ... 3.6-29 3.6.1.11 Containment Vacuum Breakers . .. ... ... 3.6-31 3.6.1.12 Containment Humidity Control . .... ..... 3.6-34 3.6.2.1 Suppression Pool Average Temperature ......... 3.6-36 3.6.2.2 Suppression Pool Water Level . . . ....... .. 3.6-39 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling .... ......... ...... 3.6-40 3.6.2.4 Suppression Pool Makeup (SPMU) System .. ..... 3.6-42 3.6.3.1 Primary Containment Hydrogen Recombiners . . . . . . . . 3.6-44 l 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters . . . ... . ... ...... 3.6-46 3.6.3.3 Combustible Gas Mixing System . ........ . 3.6-49 3.6.4.1 Secondary Containment ............. ... 3.6-51 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) . . ... 3.6-53 3.6.4.3 Annulus Exhaust Gas Treatment (AEGT) System .... 3.6-56 3.6.5.1 Drywell .. . . . .. . .. 3.6-59 3.6.5.2 Drywell Air Lock . . . . . . . . ..... 3.6-61 3.6.5.3 Drywell Isolation Valves . . . .... ... . 3.6-65 3.6.5.4 Drywell Pressure . . . . ..... 3.6-69 3.6.5.5 Drywell Air Temperature . . . . .. 3.6-70 3.6.5.6 Drywell Vacuum Relief System . . . . 3.6-71 B 3.6 CONTAINMENT SYSTEMS .

B 3.6.1.1 Primary Containment-0perating .. . ..... B 3.6-1 B 3.6.1.2 Primary Containment Air Locks .. .... .. B 3.6-5 B 3.6.1.3 Primary Containment Isolation Valves (PCIVs) . B 3.6-15 B 3.6.1.4 Primary Containment Pressure . . . B 3.6-31 B 3.6.1.5 Primary Containment Air Temperature . . B 3.6-34 8 3.6.1.6 Low-Low Set (LLS) Valves . B 3.6-37 (continued)

PERRY - UNIT 1 iv Revision No. O

UN" Page 5 of 7 TABLE OF CONTENTS B 3.6 CONTAINMENT SYSTEMS (continued)

B 3.6.1.7 Residual Heat Removal (RHR) Containment Spray System . . . . . . . . . . . . . . . . . . . . B 3.6-41

)

B 3.6.1.8 Feedwater Leakage Control System (FWLCS) . . . . . . . . B 3.6-46 i B 3.6.1.9 Main Steam Isola +. ion Valve (MSIV) Leakage Control !

System (LCS) . . . . . . . . ....... . . . . B 3.6-49 i B 3.6.1.10 Primary Containrr.ent-Shutdown . . . . . . . . . B 3.6-53

.... i B 3.6.1.11 Containment Vacuum Breakers .... ......... B 3.6-57 B 3.6.1.12 -Containment Humidity Control . . . . ......... B 3.6-63 B 3.6.2.1 Suppression Pool Average Temperature . . . . . . . B 3.6-68 B 3.6.2.2 Suppression Pool Water Level . . . . . . . . . . . . . . ... B 3.6-73 B 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling . ..

................. B 3.6-77 B 3.6.2.4 Suppression Pool Makeup (SPMU) System ......... B 3.6-81 i

i B 3.6.3.1 Primary Containment Hydrogen Recombiners . . . . . . . . B 3.6-88 B 3.6.3.2 Primary Containment and Drywell Hydrogen ;

Igniters . . . . ... .... ........ B 3.6-93 8 3.6.3.3 Combustible Gas Mixing System ............. B 3.6-99 B 3.6.4.1 Secondary Containment ....... ......... B 3.6-104 B 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) . . ... B 3.6-109 B 3.6.4.3 Annulus Exhaust Gas Treatment (AEGT) System ...... B 3.6-115 B 3.6.5.1 'Drywell ..... .. . ... ........ B 3.6-120 B 3.6.5.2 Drywell Air Lock . . . ... ............ B 3.6-124 8 3.6.5.3 Drywell Isolation Valves . ... .......... B 3.6-132 B 3.6.5.4 Drywell Pressure . . . . . .............. B 3.6-140 B 3.6.5.5 Drywell Air Temaerature ..... ........... B 3.6-143 B 3.6.5.6 Drywell Vacuum Relief System . . . . . . . . . . . . . . B 3.6-146 3.7 PLANT SYSTEMS 3.7.1 Emergency Service Water (ESW) System-Divisions 1 and 2 ................. 3.7-1 3.7.2 Emergency Service Water (ESW) System-Division 3 ... 3.7-3 3.7.3 Control Room Emergency Recirculation (CRER) System . . . 3.7-4 3.7.4 Control Room Heating. Ventilation. and Air Conditioning (HVAC) System .. ... ..... 3.7-8 3.7.5 Main Condenser Offgas ... .

........ 3.7-11 3.7.6 Main Turbine Bypass System . . .. ........ 3.7-13 3.7.7 Fuel Pool Water Level ..... ... ...... 3.7-14 3.7.8 Fuel Handling Building . . . . .. ..... . 3.7-15 3.7.9 Fuel Handling Building Ventilation Exhaust System ... 3.7-16 3.7.10 Emergency Closed Cooling Water (ECCW) System . . . .. 3.7-19 8 3.7 PLANT SYSTEMS B 3.7.1 Emergency Service Water (ESW) System-Divisions 1 and 2 ..... ... .. .. B 3.7-1 B 3.7.2 Emergency Service Water (ESW) System-Division 3 .. . B 3.7-7 B 3.7.3 Control Room Emergency Recirculation (CRER) System . B 3.7-10 (continued)

PERRY - UNIT 1 v Revision No. O

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i o PY-CEl/NRR.1999L

.o Attachment 4 TABLE OF CONTENTS l

j B 3.7 PLANT SYSTEMS (continued)

B 3.7.4 Control Room Heating. Ventilation and Air Conditioning (HVAC) System . . . ......... B 3.7-16 B 3.7.5 Main Condenser Offgas ...... ........... B 3.7-21 B 3.7.6 Main Turbine Bypass System . . . . . . . . . . . . . . . B 3.7-24 i B 3.7.7 Fuel Pool Water Level ..... ............ B 3.7-28 I B 3.7.8 Fuel Handling Building (FHB) . . ............ B 3.7-31 l

B 3.7.9 Fuel Handling Building (FHB) Ventilation Exhaust System . . . . . . . . . . . . . . . . . . . B 3.7-34 8 3.7.10 Emergency Closed Cooling Water (ECCW) System . . . . . . B 3.7-40 i

l 3.8 ELECTRICAL POWER SYSTEMS

! 3.8.1 AC Sources-0]erating .. ............. 3.8-1 3.8.2 AC Sources -Slutdown . . . . . . . . ......... 3.8-17 3.8.3 Diesel Fuel 011. Lube Oil, and Starting Air . . . ... 3.8-21 3.8.4 DC Sources-0)erating ..... ............ 3.8-24 3.8.5 DC Sources -Slutdown . . . . . . . . ........ 3.8-28 3.8.6 Battery Cell Parameters ...... ......... 3.8-32 3.8.7 Distribution Systems-0)erating .. ......... 3.8-36 3.8.8 Distribution Systems-Slutdown . . . ........ 3.8-38 B 3.8 ELECTRICAL POWER SYSTEMS l B 3.8.1 AC Sources-0)erating ... ............. B 3.8-1 B 3.8.2 B 3.8.3 AC Sources - S lutdown . . . . . . . . . . . . . . . . . . B 3.8-35 l Diesel Fuel Oil, Lube Oil, and Starting Air . . . ... B 3.8-42 i B 3.8.4 DC Sources-0)erating .... ............. B 3.8-52 8 3.8.5 DC Sources-Slutdown ... . ....... . B 3.8-61 i B 3.8.6 Battery Cell Parameters ..... ........... B 3.8-65 l B 3.8.7 Distribution Systems-0)erating .

........ B 3.8-72 l

B 3.8.8 Distribution Systems-Slutdown . ........... B 3.8-82 3.9 REFUELING OPERATIONS l 3.9.1 Refueling Equipment Interlocks ...... . . ... 3.9-1 3.9.2 Refuel Position One-Rod-Out Interlock ......... 3.9-2 3.9.3 Control Rod Position . . . . . . . ... . . ... 3.9-4 3.9.4 Control Rod Position Indication .. . . . . . 3.9-5 3.9.5 Control Rod OPERABILITY-Refueling . . . . . . . . . 3.9-7 3.9.6 Reactor Pressure Vessel (RPV) Water Level-Irradiated Fuel . . . .. ........... 3.9-8 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods .......... . . 3.9-9 3.9.8 Residual Heat Removal (RHR)-High Water Level . . 3.9-10 3.9.9 Residual Heat Removal (RHR)-Low Water Level . . 3.9-13 8 3.9 REFUELING OPERATIONS B 3.9.1 Refueling Equipment Interlocks . .. . . . B 3.9-1 (continued) t PERRY - UNIT 1 vi Revision No. 0 l

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[fm*0" Page 7 of 7 TABLE OF CONTENTS B 3.9 REFUELING OPERATIONS (continued)

B 3.9.2 Refuel Position One-Rod-Out Interlock ...... . B 3.9-5 B 3.9.3 Control Rod Position . . . .......... B 3.9-9 B 3.9.4 Control Rod Position Indication ............ B 3.9-12 B 3.9.5 Control Rod OPERABILITY-Refueling . . . . . ..... B 3.9-16 B 3.9.6 Reactor Pressure Vessel (RPV) Water Level-Irradiated Fuel .................. B 3.9-19 8 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods ............. B 3.9-22 B 3.9.8 Residual Heat Removal (RHR)-High Water Level ..... B 3.9-25 B 3.9.9 Residual Heat Removal (RHR)-Low Water Level ..... B 3.9-30 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testing Operation . 3.10-1 3.10.2 Reactor Mode Switch Interlock Testing .... .... 3.10-4 3.10.3 Single Control Rod Withdrawal-Hot Shutdown ... . 3.10-6 3.10.4 Single Control Rod Withdrawal-Cold Shutdown . . 3.10-9 3.10.5 Single Control Rod Drive (CRD) Removal-Refueling ... .. ...... ..... 3.10-13 3.10.6 Multiple Control Rod Withdrawal-Refueling . . 3.10-16 3.10.7 Control Rod Testing-Operating . .. 3.10-18 3.10.8 SHUTDOWN MARGIN (SDM) Test-Refueling . .. . 3.10-19 8 3.10 SPECIAL OPERATIONS B 3.10.1 Inservice Leak and Hydrostatic Testing Operation . . B 3.10-1 B 3.10.2 Reactor Mode Switch Interlock Testing . ...... B 3.10-6 B 3.10.3 Single Control Rod Withdrawal-Hot Shutdown . .. B 3.10-11 B 3.10.4 Single Control Rod Withdrawal-Cold Shutdown . . . . . . B 3.10-16 ,

B 3.10.5 Single Control Rod Drive (CRD) Removal- ;

Refueling ..................... B 3.10-21 B 3.10.6 Multiple Control Rod Withdrawal-Refueling . . B 3.10-26 B 3.10.7 Control Rod Testing-Operating . . .. . B 3.10-29 B 3.10.8 SHUTDOWN MARGIN (SDM) Test-Refueling . . . B 3.10-33 4.0 DESIGN FEATURES 4.1 Site Location ... . . . 4.0-1 4.2 Reactor Core . . . . . ... 4.0-1 4.3 Fuel Storage . . . . . . 4.0-2 j

5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility . .. 5.0-1 5.2 Organization . . . ... . . 5.0-2 5.3 Unit Staff Qualifications 5.0-4 5.4 Procedures . .. . 5.0-5 5.5 Programs and Manuals . . . . 5.0-6 5.6 Re orting Requirements . . 5.0-16 5.7 Hi h Radiation Area . 5.0-19 PERRY - UNIT 1 vii Revision No. O

ML20108A258

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