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Proposed Revision 2 to Tech Spec Change Request 64,revising App a of License DPR-72 Re Emergency Power Supply,Diverse Containment Isolation,Auto Initiation of Feedwater,Auxiliary Feed Flow Indication & Min Shift Crew
	ML19340D745
Person / Time
Site:	Crystal River
Issue date:	12/31/1980
From:	; FLORIDA POWER CORP.
To:	;
Shared Package
ML19340D743	List: ML19340D742; ML19340D745;
References
	RTR-NUREG-0578, RTR-NUREG-0737, RTR-NUREG-578, RTR-NUREG-737, TASK-1.A.1.3, TASK-2.E.1.2, TASK-2.E.4.2, TASK-TM NUDOCS 8101050264
	Download: ML19340D745 (20)
	v • d • e

.

I O TECHNICAL SPECIFICATION CHANGE REQUEST NO. 64, REVISION 2 Replace the pages as indicated and replace with the indicated revised ,

pages:

I Delete Replace 3/4 3-13 3/4 3-13 3/4 3-14 3/4 3-14 3/4 3-16 3/4 3-16 3/4 3-17 3/4 3-17 3/4 3-17a 3/4 3-20 3/4 3-20 l 3/4 4-5 3/4 4-5 '

3/4 6-17 3/4 6-17 l 3/4 6-18 3/4 6-18 3/4 6-19 3/4 6-19 3/4 6-20 3/4 6-20 3/4 6-21 3/4 6-21 3/4 6-21a l 3/4 7-5 3/4 7-5 l 6-4 6-4 6-12 6-12 i

TSCRN64(Rev.2)DN79-2 l

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PROPOSED CHANGL The proposed change incorporates the recomendations of the following NUREG-0578 items into the Crystal River - Unit 3 Technical Specifications:

2.1.1 Emergency Power Supply Requirement (partially) 2.1.4 Diverse Containment Isolation 2.1.7.a Auto Initiation of Auxiliary Feed 2.1.7.b Auxiliary Feed Flow Indication In addition, the Mudel License Conditions proposed in Mr. Eisenhut's letter, are proposed as programs f or which implementing procedures are required.

The proposed change also incorporates the requirement of Item I.A.1.3 of NUREG-0737 into the Minimum Shift Crew Composition Table.

REASONS FOR PROPOSED CHANGE These changes are in response to Mr. Darrell Eisenhut's letter of July 2, 1980. These changes address those requirements that were not submitted in Technical Specification Change No. 64, Revision 1.

The revision to the Minimum Shift Crew Composition Table is required by Item I.A.1.3 of NUREG-0737.

SAFETY ANALYSIS JUSTIFYING THE PROPOSED CHANGE The proposed changes incorporate installed modifications into the Techni-cal Specifications. These modifications were required as pa rt of the implementation of NUREG-0578, Category A items. The Staff reviewed these modifications as pact of their review of all Lessons Learned changes and have issued a Safety Evaluation (dated May 5, 1980) on the systems as modified.

In addition, Item I. A.1.3 of NUREG-0737 has been approved by the Commis-sion for implementation. This will assure the availability of one senior reactor operator in the control room without affecting the freedal of the shift supervisor to move about th; ;ite as needed.

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l TSCRN64(Rev.2)DN79-2 l

LESSONS LEARNED TECHNICAL SPECIFICATIONS CROSS-REFERENCE NUREG-0578 Abbreviated Proposed Technical Section No. Title Specification Pages 2.1.1 Emergency Power Supply Requirement 3/4 4-5 2.1.4 Diverse Containment Isolation 3/4 6-17*

3/4 6-18 3/4 6-19 3/4 6-20 3/4 6-21 3/4 6-21a 2.1.7.a Auto Initiation of Auxiliary Feed 3/4 3-13 3/4 3-14 3/4 3-16 3/4 3-17 3/4 3-17a 3/4 3-20 3/4 7-5 2.1.7.b Auxiliary Feed Flow Indication 3/4 7-5 Model License Systems Integrity 6-12 Condition Model License Iodine Monitoring 6-12 Condition NUREG-0737 Shift Crew Composition 6-4 Item I.A.1.3

Table 3.6-1, Containment Isolation Valves has been revised to accurately name the function of each valve.

TSCRN64(Rev.2)DN79-2

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TABLE 3.3-3 (Cont'd)

} e, ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM i

[{

- -j TOTAL NO. CHANNELS CHANNELS APPLICABLE r- FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION x

{ h{ b. Steam Line Rupture Matrix I

w f i

1. Low SG Pressure 2 per steam 1 per steam 2 per steam 1, 2, 3*** 10 g generator generator generator j (( 2. Automatic Actuation Logic 1 per steam 1 per steam 1 per steam 1, 2, 3 10 4 generator generator ges.erator 1

j c. Emergency Feedwater ;

i 1

1. Main Feedwater Pump Turbines t , , .

A and B Control Oil Low 2 2 2 1, 2, 3## 10 l- 3:

i u, 2. OTSG A and B Level Low-Low 2 2 2 1,2,3,4 10

!' b3.

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1 2

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4 i

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4 t

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3 TABLE 3.3-3 (Continued)

TABLE NOTATION

Tri p function may be bypassed in this MODE with RCS pressure below 1700 psig. Bypass shall be aut~natically removed when RCS pressure exceeds 1700 psig.

2

- Trip function may be bypassed in this MODE with RCS pressure below 900 psig. Bypass shall be automatically removed when RCS pressure exceed; 900 psig.

- - Trip function may be bypassed in this MODE with steam generator pres-sure below 725 psig. Bypass shall be automatically removed when steam generator pressure exceeds 765 psig.

The provisions of Specification 3.0.4 are not applicable.

1. Trip function may be bypassed in this MODE prior to stopping the operating main feedwater pump. Bypass shall be manually removed after starting the first main feedwater pump.

ACTION STATEMENTS ACTION 9 - With the number of OPERABLE Channels one less than the Total Number of Channels operation may proceed until performance of the next required CHANNEL FUNCTIONAL TEST provided the inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

ACTION 10 - With the number of OPERABLE channels one less than the Total Number of Channels, be in at least H0T STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to I hour for surveillance testing per Specification 4.3.2.1.1.

ACTION 11 - With less than the Minimum Channels OPERABLE, operation may continue provided the containment purge and exhaust valves are maintained closed.

l ACTION 12 - With the number of OPEDt.BLE Channels one less than the Total i Number of Channels operation may proceed provided the inoper-able channel is placed in the bypassed condition and the minimum channels OPERABLE required is demonstrated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ; one additional channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for Surveillance testing per Specification 4.3.2.1.

ACTION 13 - With the number of OPERABLE Channels one less than the Total

l. Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the fol-i lowing 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

l CRYSTAL RIVER - UNIT 3 3/4 3-14 c

TABLE 3.3-4 (Cont'd) o ENGINEERED SAFETY FEATURE ACTUATION SYSTEMS INSTRUMENTATION TRIP SETPOINTS Q

U FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES P

x 3. REACTOR BLDG, SPRAY

$ a. Reactor Bldg. Pressure i High-High 1 30 psig I 30 psig c- coincident with HPI Signal See 1.a.2, 3, 4 See 1.a.2, 3, 4

] b. Automatic Actuation Logis: Not Applicable Not Applicable

4. OTHER SAFETY SYSTEMS

a. Reactor Bldg. Purge Exhaust Duct Isolation on High Radioactivity

$ Gaseous

Not Applicable

[ b. Steam Line Rupture Matrix cn

1. Low SG Pressure > 600 psig > 600 psig

2. Automatic Actuation Logic Not Applicable Not Applicable

c. Emergency Feedwater

1. Main Feedwater Punp Turbines > 55 psig > 55 psig A and B Control Oil Low

2. OTSG A and B Level Low-Low > 18 inches > 18 inches

Determined by requirements of Appendix "B" Tech. Specs. Section 2.4.2 - Crystal River 3 Operating License No. OPR-72.

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j TABLE 3.3-5 ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS *

1. Manual

a. High Pressure Injection Not Applicable

b. Low Pressure Injection Not Applicable

c. Reactor Building Cooling Not Applicable

d. Reactor Building Isolation Not Applicable

e. Reactor Building Spray Not Applicable

f. Reactor Building Purge Isolation Not Applicable

g. Steam Line Rupture Matrix

1) Emergency Feedwater Actuation Not Applicable

2) Feedwater Isolation Not Applicable

3) Steam Line Isolation Not Applicable

2. Reactor Building Pressure-High

a. High Pressure Injection 25*

b. Low Pressure Injection 25*

c. Reactor Building Cooling 25*

d. Reactor Building Isolation 60*

3. Reactor Building Pressure High-High (with HPI signal) l

a. Reactor Building Spray 56*

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4. RC_S Pressure Low

a. High Pressure Injection 25*

5. RCS Pressure Low-Low

a. High Pressure Injection 25*

i b. Low Pressure Injection 25*

CRYSTAL RIVER - UNIT 3 3/4 3-17 i

TABLE 3.3-5(Continuedl ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS *

6. Low Steam Generator Pressure

a. Feedwater Isolation 34

b. Steam Line Isolation 5

7. Main Feedwater Pump Turbines A and B Control Oil Low

a. Emergency Feedwater Actuation Not Applicable

8. OTSG A and B Level Low-Low

a. Emergency Feedwater Actuation Not Applicable i

(

Diesel Generator starting and sequence loading delays included.

Response time limit includes movement of valves and attainment of pump or blower discharge pressure.

CRYSTAL RIVER - UNIT 3 3/4 3-17a

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TABLE 4.3-2 (Cont'd)

!! ENGINEERED SAFETY FEATURE ACTUATION SYSTEMS INSTRUMENTATION SURVEILLANCE REQUIREMENTS

?2 i.

, CHANNEL MODES IN WHICH ,

g CHANNEL rHANNEL FUNCTIONAL SURVEILLANCE i

} g FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED l

[z 3. REACTOR BLDG. SPRAY

! El a. Reactor Bldg. Pressure co High-High coincident ,

] ..with HPI Signal S. R M(4) 1, 2, 3 i i b. Automatic Actuation Logic N/A N/A M(3) 1, 2, 3 i ,

! 4. OTHER SAFETY SYSTEMS t 5d l

- a. Reactor Bldg. Purge Exhaust Duct i

'o Isolation on High Radioactivity

} ;

i $ !

1. Gaseous s Q M All Modes 2

b. Steam Line Rupture Matrix !

, i l 1. Low SG Pressure N/A R N/A 1, 2, 3

! t i

2. Automatic Actuation Logic N/A N/A M(3) 1, 2, 3

c. Emergency Feedwater ;

! 1. Main ~Feedwater Pump Turbines S R N/A 1, 2, 3 j A and B Control Oil Low

'2. OTSG A and B Level Low-Low S R N/A 1,2,3,4 i

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REACTOR C0OLANT SYSTEM PRESSURIZER LIMITING CONDITION FOR OPERATION 3.4.4 The pressurizer shall be OPERABLE with:

a. A steam bubble,

b. A water level between 40 and 290 inches, and

c. At least 126 kW of pressurizer heaters.

APPLICABILITY: MODES 1 and 2.

ACTION:

With the pressurizer inoperable, be in at least H0T STANDBY with the control rod drive trip breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.4.4.1 The pressurizer shall be demonstrated OPERABLE by verifying pressurizer level to be within limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

l 4.4.4.2 The emergency power supply for the pressurizer heaters shall be demonstrated OPERABLE at least once per 18 months by manually transfer-ring power from the normal to the emergency power supply and energizing the heaters.

CRYSTAL RIVER - UNIT 3 3/4 4-5 L~.

TABLE 3.6-1 CONTAINMENT ISOLATION VALVES VALVE NUMBER FUNCTION ISOLATION TIME ~~~~

(seconds)

A. CONTAINMENT ISOLATION

1. BSV-27 check # closed dur. nor. operation NA and open dur. RB spray BSV-3 # 60 BSV-26 check # "

NA BSV-4 # 60

2. CAV-126(A) iso. CA sys. fr. RC letdn. 60 CAV-1**(A) iso. CA sys. fr. pzr. 60 CAV-3 (A) 60 CAV-2 (B) iso. CA sys. fr. RB 60 CAV-4 # (A) isolate liquid sampling o0 systen CAV-6 # (B) 60 CAV-5 # (A) 60 CAV-7 # (B) 60

3. CFV-20 check iso. N2 supply fr. CFT-1A NA CFV-28 (A/B) 60 CFV-17 check iso. N2 supply fr. CFT-1B NA CFV-27 (A/B) 60 rFV-18 check iso. MU system f r. CFT-1B NA CFV-26 (A/P: 60 CFV-19 check iso. MU systen fr. CFT-1A NA CFV-25 (A/B) 60 l

l CFV-42 (B) iso. liquid sampling fr. 60 CF system CFV-15 (A) iso. WD sys. fr. CF tanks 60 CFV-16 (A) 60 CFV-29 (B) 60 l

CFV-11 (A) iso. CF tanks fr. liquid 60 l

sampling system CFV-12 60 (A)

CRYSTAL RIVER - UNIT 3 3/4 6-17

TABLE 3.6-1 (Continued)

CONTAINMENT ISOLATION VALVES VALVE NUMBER FUNCTION ISOLATION TIME (seconds)

4. CIV-41 iso. Ci sys. fr. RB 60 CIV-40 60 CIV-34 60 CIV-35 60

5. DHV-93 check iso DH systen f r. pzr. NA CHV-91 60 DHV-43 # iso. DH sys. fr. RB sump 120 DHV-42 # 120 DHV-4# & 41# iso. DH sys. fr. RC 120 DHV-6 # iso. DH systen from 60 Reactor Vessel "

DHV-5 # 60

6. DWV-162 check iso. DW system fr. RB NA DWV-160 (A/B) 60

7. FWV-44 check # iso. feedwater NA from RCSG-1A FWV-45 check # NA FWV-43 check # iso. feedwater NA from RCSG-1B

, FWV-45 check # NA 1

l 8. MSV-130 #(A/B) iso. MDT-1 frca RCSG-1A 60 MSV-148 #(A/B) iso. MDT-1 f rom RCSG-1B 60 MSV-411 # iso. main steam lines 60 from RCSG-1A MSV-412 # iso. main steam lines 60

, from RCSG-1A l

MSV-413 # iso. main steam lines 60 from RCSG-1B MSV-414 # iso. main steam lines 60 i

from RCSG-1B l

CRYSTAL RIVER - UNIT 3 3/4 6-18

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TABLE 3.6-1 (Continued)

CONTAINMENT ISOLATION VALVES VALVE NUMBER FUNCTION ISOLATION TIME (seconds)

9. MUV-40 (A) iso. MU system from RC 60 MUV-41 (A) 60 MUV-49 (B) 60 MUV-253 60 MUV-261 iso. MU system from 60 control bleed-off MUV-260 60 MUV-259 60 MUV-258 00 M" 163 check # open during HPI and NA closed dur. nor operation

. :3 # "

60 h, '.64 check # NA MU/-26 # 60 MUV-160 check # NA MUV-23 # 60 MUV-161 check # NA MUV-24 # 60 MUV-27 # open dur. nor. operation 60 and closed during RB Isolation

10. SWV-39 # iso. NSCCC from AHF-1C 60 SWV-45 # 60 SWV-35 # iso. NSCCC from AHF-1A 60 SWV-41 # 60 SWV-37 # iso. NSCCC from AHF-1B 60 SWV-43 # 60 SWV-48 # isolate NSCCC from 60 MUHE-1A & 18 and WDT-5 SWV-47 # 60 SWV-49 # 60 SWV-50 0 60 SWV-80 # iso. NSCCC f rom RCP-1A 60 SWV-84 # 60 SWV-82 # iso. NSCCC from RCP-1C 60 SWV-86 # 60 CRYSTAL RIVER - UNIT 3 3/4 6-19

TABLE 3.6-1 (Continued)

CONTAINMENT ISOLATION VALVES VALVE NUMBER FUNCTION ISOLATION TIME (seconds)

SWV-81 # iso. NSCCC from RCP-1D 60 SWV-85 # 60 SWV-79 # iso. NSCCC from RCP-1B 60 SWV-83 # 60 SWV-109# iso. NSCCC from DRRD-1 60 SWV-110# 60

11. WDV-4 (B) iso. WDT-4 from RB sump 60 WDV-3 (A) 60 WDV-60 (A) iso. WDT-4 fror, L4! 60 WDV-61 (B) 60 i WDV-94 (A) iso. WDT-4 from WDP-8 60 WDV-62 (B) -0 WDV-406 (A) iso. waste gas disposal 0 from vents in RC system WDV-405 (B) 60

12. WSV-3 iso. containnent monitoring 60 system from RB WSV-4 60 WSV-5 60 WSV-6 60

. B. CONTAINMENT PURGE AND EXHAUST

1. AHV-1C (A) iso. pur. sup."

system fr. RB 60 AHV-10 (B) 60 l

AHV-1B (A) 'so, pur. exhaust system fr. RB 60 AHV-1A (B) 60 l

I

( C. MANUAL

1. IAV-28 iso. IA from RB NA IAV-29 NA

2. LRV-50 iso. leak rate test system NA from RB LRV-36 NA CRYSTAL RIVER - UNIT 3 3/4 6-20 l

L.

TABLE 3.6-1 (Continued)

CONTAINMENT ISOLATION VALVES VALVE NUMBER FUNCTION ISOLATION TIME (seconds)

LRV-51 iso. atmos. vent and RB NA purge exhaust" systsi from RB LRV-35 & 47 NA LRV-49 iso. atmos." vent from RB NA LRV-38 & 52 NA LRV-45 iso. LR test panel from RB NA LRV-44 NA LRV-46 NA

3. MSV-146# iso misc. waste storage NA tank from RCSG-1B

4. NGV-62 iso. NG system from NA steam generators NGV-81 # NA NGV-82 iso. NG system from pzr. NA

5. SAV-24 iso. ' from RB NA SAV-23 & 122 NA 4

6. SFV-18 iso. SF system fr. F.T. Canal NA SFV-19 NA SFV-119# iso. Fuel Transfer tubes NA from F.T. Canal

SFV-120# NA l

7. WSV-1 iso. containment monitoring NA system from RB WSV-2 NA D. PENETRATIONS REQUIRING TYPE B TESTS l

l Blind Flange 119 iso. RB NA Blind Flange 120 "

NA l

Blind Flange 202 NA l

l

[

CRYSTAL RIVER - UNIT 3 3/4 6-21

TABLE 3.6-1 (Continued)

CONTAINMENT ISOLATION VALVES VALVE NUMBER FUNCTION ISOLATION TIME (seconds)

Blint Flar.ge 348 ido. fuel tran.f er t. e from NA Transfer Canal Blind Flange 436 NA Equipment Hatch iso. RB NA Personnel Hatch iso. RB NA

Not subject to Type C Leakage Tes.

- The provisions of Specificatio, 3.0.4 are not applicable until startup for Cycle 3 operation. Isolation valves closed to satisfy the require nents of Specification 3.6.3.1 ACTION b. and

c. may be re-opened on an intermittent basis under administrative control for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months in any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period as necessary for sampling.

(A) Isolates on Diverse Isolation Actuation Signal A (B) Isolates on Diverse Isolation Actuation Signal B (A/B) Isolates on Diverse Isolation Actuation Signal A or B l

l CRYSTAL RIVER - UNIT 3 3/4 6-21a l

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1 j PLANT SYSTEMS J

! SURVEILLANCE REQUIREMENTS (Continued) i i

2. Verifying that each valve (manual, power operated, or l

automatic) in the flow path that is not locked, sealed, 1 l

or otherwise secured in position, is in its correct I position.

i

! 3. Verifying that the emergency feedwater ultrasonic flow j rate detector is zero-checked.

l b. At least once per 18 months, during shutdown, by:

1. Verifying that each automatic valve in the flow path

' act"2s to its correct posi. ion on an emergency feed-wa' actuation test signal.

l1 1 2. Verliying that the steam turbine driven pump and the I motor driven pump start automatically: L

a. Upon receipt of an emergency feedwater actuation

' OTSG A and B level low-low test signal, and

b. Upon receipt of an emergency feedwater actuation l

main feedwater pump turbines A and B control oil j low test signal.

1 j 3. Verifying that the operating air accumulators for

FWV-39 and FWV-40 maintain >27 psig for at least one hour when isolated from their air supply.

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CRYSTAL RIVER - UNIT 3 3/4 7-5 ,

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O TABLE 6.2-1 MINIMUM SHIFT CREW COMPOSITION #

APPLICABLE MODES LICENSE CATEGORY 1, 2, 3 & 4 586 50L 2 1*

OL 2 1 Non-Licensed 3 1

boes not include the licensed Senior Reactor Oper: or or denior Reactor Operator L1uitud to Fuel Handling dividual supervising CORE ALTERATIONS after the initial fco', loading.

Shift crew couposition ua, ou less that the minuuuu require-ment for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to decomodate unexpected absence of on duty shift crew members provided iumediate action is taken to restore the shif t crew couposition to within the mininum requirements of Table 6.2-1.

CRYSTAL RIVER - UNIT 3 6-4

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i ADMINISTRATIVE CONTROLS 6.7 SAFETY LIMIT VIOLATION

. 6.7.1 The following actions shall be taken in the event a Safety Limit

is violated

i a. The facility shall be placed in at least HOT STANDBY within i one hour. L i

l b. The Safety Limit violation shall be reported to the Conmission, i the Director-Power Production and to the NGRC within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

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c. A Safety Limit Violation Report shall be prepared. The report shall be reviewed by the PRC. This report shall describe (1) l applicable circumstances preceding the violation, (2) effects j of the violation upon facility components, systems or structure

, and (3) corrective action taken to prevent recurrence.

d. The Safety Limit Violation Report shall be submitted to the Comission, the NGRC and the Manager, Nuclear Operations !

within 14 days of the violation.

6.8 PROCEDURES (l

! 6.8.1 Written proceaures shall be established, implemented and main- [

tained covering the activities reterenced below: )

a. The applicable procedures recocnended in Appendix "A" of l Regulatory Guide 1.33, November,1972. ,

j

b. Refueling operations.

c. Surveillance and test activities of safety related equipment.

d. Security Plan implementation.

e. Emergency Plan implementation.

f. Fire Protection Program implementation.

g. Systems Integrity Program implementation.

h. Iodine Monitoring Program implementation. I r

6.8.2 Each procedure and administrative policy of 6.8.1 above, and changes thereto, shall be reviewed by the PRC and approved by the Nuclear Plant Manager prior to implementation and reviewed periodically as set forth in administrative procedures.

CRYSTAL RIVER - UNIT 3 6-12

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ML19340D745

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