Text

Proposed Typed,Final Tech Specs Pages for LARs 246 & 116, Consisting of Editorial Changes Due to Pagination,Changes Incorporated by Previous Amends & Corrected Typos
	ML20198D671
Person / Time
Site:	Beaver Valley
Issue date:	12/14/1998
From:	; DUQUESNE LIGHT CO.
To:	;
Shared Package
ML20198D660	List: L-98-230, Forwards Typed,Final TS Pages for LARs 246 & 116,consisting of Changes Due to Pagination,Changes Incorporated by Previous Amends & Correction of Typos; ML20198D671;
References
	NUDOCS 9812230167
	Download: ML20198D671 (68)
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ATTACHMENT 246 l

1 Unit No. 1 Technical Snecification Paces l

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9912230167 981214 7 ,

PDR ADOCK 05000334. (

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ATTACHMENT TO LICENSE AMENDMENT NO.

FACILITY OPERATING LICENSE NO. DPR-66 DOCKET NO. 50-334 Replace the following pages of Appendix A, Technical Specifications, with the enclosed pages as indicated. The revised pages are identified by amendment number and contain vertical lines indicating the areas of change.

Remove Insert Operating License Page 6 Operating License Page 6 IV IV X X XV XV XVI XVI 1-3 1-3 1-6 1-6

~1-8 1-8 )

3/4 0-1 3/4 0-1 3/4 0-2 3/4 0-2 3/4 0-3 3/4 0-3 3/4 3-34 3/4 3-34 ;

3/4 3-34a 3/4 3-34a ,

3/4 3-35 3/4 3-35 l 3/4 3-38 3/4 3-38 3/4 3-41 ----

3/4 3-42 ----

3/4 3-43 ----

3/4 3-54 3/4 3-54 3/4 4-10e 3/4 4-10e 3/4 5-3 3/4 5-3 )

3/4 5-6 3/4 5-6 j 3/4 7-23 3/4 7-23 l 3/4 11-2 3/4 11-2 !

3/4 11-4 3/4 11-4 B 3/4 3-2 B 3/4 3-2 B 3/4 4-1 B 3/4 4-1 5-1 5-1 6-16 6-16 6-17 6-17 6-18 6-18 6-19 6-19 i 6-20 ----

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. DPR-66 !

l (6) Systems 'Intaarity Duquesne Light Company shall implement a program to I reduce leakage from systems outside containment that 4 would or could contain highly radioactive fluids during )

a serious transient or accident to as low as practical levels. This program shall include the following:

1. Provisions establishing preventive maintenance and periodic visual inspection requirements, and

2. Integrated leak test requirements'for each system at a frequency not to exceed refueling cycle !

intervals.

(7) Iodine Monitorina i i

Duquesne Light Company shall implement a program which ,

will ensure the capability to accurately determine the l airborne iodine concentration in vital areas under i accident conditions. This program shall include the l following:

1

1. Training of personnel,

2. ' Procedures for monitoring, and

3. Provisions for maintenance of sampling and i analysis equipment.

(8) Backun Method for Determinina Subcoolina Marcin Duquesne Light Company shall implement a program which will ensure the capability to accurately monitor the Reactor Coolant System subcooling margin. This program shall include the following:

1. Training of personnel, and

2. Procedures for monitoring.

(9) Surveillance Interval Extension Deleted l Amendment No.

. DPR-66 INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.1.3.3 Position Indication System - Shutdown.... 3/4 1-21 3/4.1.3.4 Rod Drop Time............................ 3/4 1-22 3/4.1.3.5 Shutdown Rod Insertion Limit............. 3/4 1-23 3/4.1.3.6 Control Rod Insertion Limits............. 3/4 1-23a 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX DIFFERENCE.................... 3/4 2-1 3/4.2.2 HEAT FLUX HOT CHANNEL FACTOR............. 3/4 2-5 3/4.2.3 NUCLEAR ENTHALPY HOT CHANNEL FACTOR...... 3/4 2-8 3/4.2.4 QUADRANT POWER TILT RATIO................ 3/4 2-10 3/4.2.5 DNB PARAMETERS........................... 3/4 2-12 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION...... 3/4 3-1 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION.......................... 3/4 3-14 3/4.3.3 MONITORING INSTRUMENTATION 3/4.3.3.1 Radiation Monitoring..................... 3/4 3-33 3/4.3.3.2 Movable Incore Detectors................. 3/4 3-37 3/4.3.3.3 Seismic Instrumentation.................. 3/4 3-38 l

3/4.3.3.5 Remote Shutdown Instrumentation.......... 3/4 3-44 3/4.3.3.7 Chlorine Detection System................ 3/4 3-49 3/4.3.3.8 Accident Monitoring Instrumentation...... 3/4 3-50 3/4.3.3.11 Explosive Gas Monitoring Instrumentation. 3/4 3-54 BEAVER VALLEY - UNIT 1 IV Amendment No.

. DPR-66 ,

i INDEX i~ BASES SECTION PAGE 3/4.2.2 AND 3/4.2.3 HEAT FLUX AND NUCLEAR ENTHALPY j HOT CHANNEL FACTORS.......................... B 3/4 2-4 l 3/4.2.4 QUADRANT POWER TILT RATIO.................... B 3/4 2-5 3/4.2.5 DNB PARAMETERS...............................B 3/4 2-6 3/4.3 INSTRUMENTATION i

3/4.3.1 AND 3/4.3.2 PROTECTIVE AND ENGINEERED !

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SAFETY FEATURES (ESF) INSTRUMENTATION........B 3/4 3-1 3/4.3.3 MONITORING INSTRUMENTATION ................... B 3/4 3-2 3/4.3.3.1 Radiation Monitoring Instrumentation......... B 3/4 3-2 3/4.3.3.2 Moveable Incore Detectors.................... B 3/4 3-2 3/4.3.3.3 Seismic Instrumentation...................... B 3/4 3-2 l '

3/4.3.3.5 Remote Shutdown Instrumentation.............. B 3/4 3-3 '

l 3/4.3.3.7 Chlorine Detection Systems................... B 3/4 3-3' 3/4.3.3.8 Accident Monitoring Instrumentation.......... B 3/4 3-3 )

.3/4.3.3.11 Explosive Gas Monitoring Instrumentation.....B 3/4 3-4 3/4.4 REACTOR COOLANT SYSTEM

.3/4.4.1 REACTOR COOLANT LOOPS........................ B 3/4 4-1 3/4.4.2 AND '/4.4.3 SAFETY VALVES........................ B 3/4 4-la

^3/4.4.4 PRESSURIZER.................................. B 3/4 4-2 3/4.4.5 STEAM GENERATORS............................. B 3/4 4-2 3/4.4.6 REACTOR COOLANT SYSTEM LEAKAGE............... B 3/4 4-3 3/4.4.6.1 Leakage Detection Instrumentation............ B 3/4 4-3 3/4.4.6.2 Operational Leakage.......................... B 3/4 4-3d 3/4.4.6.3 Pressure Isolation Valve Leakage............. B 3/4 4-3j 3/4.4.7 CHEMISTRY .................................... B 3/4 4-4 BEAVER VALLEY - UNIT 1- X Amendment No.

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DPR-66 INDEX

! ADMINISTRATIVE CONTROLS 1

l SECTION PAGE l

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6.8 PROCEDURES....................................... 6-6 j l

6.9 REPORTING REOUIREMENTS........................... 6-16 I

j. .6.9.1 Occupational Radiation Exposure Report .. 6-16 I

6.9.2 Annual Radiological Environmental l' Operating Report ........................ 6-17

! 6.9.3 Annual Radioactive Effluent Release j Report .................................. 6-17 i

6.9.4 Monthly Operating Report ................ 6-17 6.9.5 Core Operating Limits Report (COLR) ..... 6-18 i

6.10 DELETED 6.11 RADIATION PROTECTION PROGPE .................... 6-19 l I

j 6.12 HIGH RADIATION AREA............................. 6-23 t

6.13 PROCESS' CONTROL PROGRAM (PCP) ................... 6-24 f

6.14 OFFSITE DOSE CALCULATION MANUAL (ODCM) .......... 6-24 i

i 6.16 MAJOR CHANGES TO RADIOACTIVE WASTE TREATMENT SYSTEMS............................... 6-25 ;

1 l 6.17 CONTAINMENT LEAKAGE RATE TESTING PROGRAM........ 6-25 l.

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BEAVER VALLEY - UNIT 1 XV Amendment No.

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l .. DPR-66 TABLE INDEX TABLE TITLE PAGE

2. 2-l' Reactor Trip System Instrumentation Trip 2-6 Setpoints

! 3.1-1 Accident Analyses Requiring Reevaluation 3/4 1-19a in the event of an Inoperable Full or Part Length Rod 3.2-1 DNB Parameters 3/4 2-13

3.3-1 Reactor Trip System Instrumentation '3/4 3-2 l

l 4.3-1 Reactor Trip System Instrumentation 3/4 3-11 Surveillance Requirements l

l 3.3-3 -Engineered Safety Features Actuation System 3/4 3-15 Instrumentation i

l 3.3-4 Engineered Safety Features Actuation System 3/4 3-22 Instrumentation Trip Setpoints i

4.3-2 Engineered Safety Feature-Actuation System 3/4 3-29 Instrumentation Surveillance Requirements g 3.'3-6 Radiation' Monitoring Instrumentation 3/', 3-34 e

4.3-3 Radiation Monitoring Instrumentation 3/4 3-36 Surveillance Requirements 3.3-7 Seismic Monitoring Instrumentation 3/4 3-39 4.3-4 Seismic Monitoring. Instrumentation 3/4 3-40 Surveillance Requirements i

'3.3-9 Remote Shutdown Panel Monitoring 3/4 3-45 l Instrumentation 4.3-6 Remote Shutdown Monitoring Instrumentation 3/4 3-46 Surveillance Requirements L

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BEAVER VALLEY - UNIT 1 XVI Amendment No.

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. DPR-66 LDEFINITIONS

CHANNEL CHECE i 2 10 A CHANNEL CHECK shall be the qualitative assessment of channel

-, behavior during operation by observation. This determination shall i include,.where possible, comparison of the channel indication and/or

status with other indications and/or status derived from independent 3

instrument channels measuring the same parameter. 1 i

i CHANNEL FUNCTIONAL TEST l 1.11 A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated signal into the channel as close to the primary sensor as

practicable to verify OPERABILITY including alarm and/or trip

! functions.

CORE ALTERATION i

1.12 CORE ALTERATION shall be the movement of any fuel, sources, or reactivity, control components within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

SHUTDOWN MARGIN 1.13 SHUTDOWN MARGIN shall be the instantaneous amount of reactivity by which the reactor is or would be subcritical from its present condition assuming all full length rod cluster assemblies (shutdown and control) are fully inserted except for the single rod cluster' assembly of highest reactivity worth which is assumed to be fully withdrawn.

LEAKAGE 1.14 LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump seal water injection or leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be Pressure Boundary LEAKAGE, or BEAVER VALLEY - UNIT 1 1-3 Amendment No.

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. DPR-66 DEFINITIONS SQURCE CHECK 1.27' A SOURCE CHECK shall be the qualitative assessment of channel response when the channel sensor is exposed to a radioactive source.

PROCESS CONTROL PROGRAM 1.28 The PROCESS CONTROL PROGRAM -(PCP) shall contain the current formulas, sampling, analyses, test, and determinations to be made to ensure that processing and packaging of solid radioactive wastes based on demonstrated processing of actual or simulated wet solid

. wastes will be accomplished in such a way as to assure compliance with 10 CFR Parts 20, 61, and 71, State regulations, burial ground requirements, and other requirements governing the disposal of solid l radioactive waste.

1.29 DELETED 1

OFFSITE DOSE CALCULATION MANUAL (ODCM) !

i 1.30 The OFFSITE DOSE CALCULATION MANUAL (ODCM) shall contain the

! methodology and parameters used in the calculation of offsite doses l resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid affluent monitoring Alarm / Trip Setpoints, and in the conduct of the Environmental Radiological Monitoring Program. The ODCM shall also contain (1) the Radioactive Effluent Controls and Radiological Environmental Monitoring Programs required by Section 6.8.6 and (2) descriptions of the information that should be included in the Annual Radiological Environmental Operating and Annual Radioactive Effluent Release Reports required by l Specifications in the Administrative Control Section. l l

l GASEOUS RADWASTE TREATMENT SYSTEM 1.31 A GASEOUS RADWASTE TREATMENT SYSTEM is any system designed and installed to' reduce radioactive gaseous affluents by collecting primary coolant system offgases from the primary system and providing for delay or holdup for the purpose of reducing the total radioactivity prior to release to the environment.

VENTILATION EXHAUST TREATMENT SYSTEM l 1.32 A VENTILATION EXHAUST TREATMENT SYSTEM is any system designed and installed to reduce gaseous radiciodine or radioactive !

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BEAVER VALLEY - UNIT 1 1-6 Amendment No.

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, DPR-66 DEFINITIONS ;

2) Major changes in the design of radwaste treatment systems (liquid, gaseous and solid) that could significantly increase the quantities or activity of effluents released or volumes of solid waste stored or shipped offsite from those previously considered in the FSAR and SER (e.g., ust of asphalt system in place of cement) ;

3) Changes in system design which may invalidate the accident analysis as described in the SER (e.g.,

changes in' tank capacity that would alter the curies released); and j 4

4) Changes in systen design that could potentially result l in a significant increase in occupational exposure of l operating personnel (e.g., use of temporary equipment I without adequate shielding provisions.)

MEMBER (S) OF THE PUBLIC 1.36 MEMBER (S) OF THE PUBLIC means any individual except when that individual is receiving an occupational dose.

CORE OPERATING LIMITS REPORT I 1.37 The CORE OPERATING LIMITS REPORT (COLR) is the unit-specific document that provides core operating limits for the current operating reload cycle. These cycle-specific core operating limits shall be determined for each reload cycle in accordance with Specification 6.9.1.12. Plant operation within these operating limits is addressed in individual specifications.

l BEAVER VALLEY - UNIT 1 1-8 Amendment No.

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- DPR-66 I l-3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS l

3/4.O APPLICABILITY

! LIMITING CONDITION FOR OPERATION l

3.0.1 Compliance with the Limiting Conditions for Operation

( contained in the succeeding specifications is required during the OPERATIONAL MODES or other conditions specified therein; except that upon failure to meet the Limiting conditions for Operation, the associated ACTION requirements shall be met, except as provided in Limiting Condition for Operation 3.0.6.

3.0.2 Noncompliance with a specification shall exist when the requirements of the Limiting Condition for Operation and associated ACTION requirements are not met within the specified time intervals.

If the Limiting condition for Operation is restored prior to expiration of the specified time intervals, completion of the ACTION requirements is not required.

3.0.3 When a Limiting Condition for Operation is not met except i as provided in the associated ACTION requirements, within one hour i action shall be initiated to place the unit in a MODE in which the ;

specification does not apply by placing it, as applicable, in: 1

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

2. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and 1

3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . I j

Where corrective measures are completed that permit operation under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits as measured from the time of failure to l

meet the Limiting Condition for Operation. Exceptions to ' these 1 l requirements are stated in the individual specifications. l l

3.0.4 Entry into an OPERATIONAL MODE or other specified condition shall not be made when the conditions for the Limiting conditions for Operation are not met and the associated ACTION requires a shutdown if they are not met within a specified time interval. Entry into an OPERATIONAL MODE or specified condition may be made in accordance with ACTION requirements when conformance to them permits continued operation of the facility for an unlimited period of time. This provision shall not prevent passage through or to OPERATIONAL MODES as required to comply with ACTION requirements. Exceptions to these requirements are stated in the individual specifications.

3.0.5 When a system, subsystem, train, component or device is ,

determined to be inoperable solely because its emergency power source l is inoperable, or solely because its normal power source is inoperable, it may be considered OPERABLE for the purpose of satisfying the requirements of its applicable Limiting Condition for Operation, provided: (1) its corresponding normal or emergency power i BEAVER VALLEY - UNIT 1 3/4 0-1 Amendment No.

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- DPR-66 3/4.O APPLICABILITY LIMITING CONDITION FOR OPERATION (continued) source is OPERABLE; and (2) all of its redundant system (s),

subsystem (s), train (s), component (s) and device (s) are OPERABLE, or likewise satisfy the requirements of this specification. Unless both conditions (1) and (2) are satisfied within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , action shall be initiated to place the unit in a MODE in which the applicable Limiting Condition for Operation does not apply, by placing j t, as applicable, in:

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

2. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

This specification is not applicable in MODES 5 or 6.

3.0.6 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to Limiting Condition for Operation 3.0.1 for tha system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

SURVEILLANCE REQUIREMENTS 4.0.1 Surveillance Requirements shall be met during the OPERATIONAL MODES or other conditions specified for individual Limiting Conditions for Operation unless otherwise stated in an individual Surveillance Requirement.

4.0.2 Each Surveillance Requirement shall be performed within the specified time interval with a maximum allowable extension not to exceed 25% of the surveillance interval.

4.0.3 Failurta to perform a Surveillance Requirement within the allowed surveillance interval, defined by Specification 4.0.2, shall constitute norcompliance with the OPERABILITY requirements for a Limiting Condition for Operation. The time limits of the ACTION requirements 7.re applicable at the time it is identified that a Surveillance Requirement has not been performed. The ACTION requirements may be delayed for up to 24 hours to permit the completion of the surveillance when the allowable outage time limits of the ACTION requirements are less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Surveillance Requirements do not have to be performed on inoperable equipment.

4.0.4 Entry into an OPERATIONAL MODE or other specified condition shall not be made unless the Surveillance Requirement (s) associated BEAVER VALLEY - UNIT 1 3/4 0-2 Amendment No.

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. DPR-66 3/4.0 APPLICABILITY l'

SURVEILLANCE REQUIREMENTS

, with a Limiting Condition for Operation has been performed within the j' stated surveillance interval or as otherwise specified. This l

provision shall not prevent passage through or to OPERATIONAL MODES as required to comply with ACTION requirements.

4.0.5 Surveillance Requirements for inservice inspection and testing of ASME Code Class 1, 2 and 3 components shall be applicable l as follows:

a.1; Inservice inspection of ASME Code Class 1, 2 and 3 components shall be performed in accordance with Section XI 'of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50, Section 50.55a(g).

a.2 Inservice testing of ASME Code Class 1, 2 and 3 pumps and valves shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50, Snction 50.55a(f).

b. Surveillance intervals specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda for the inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and applicable Addenda shall be applicable as follows in these Technical Specifications:

ASME Boiler and Pressure Vessel Required frequencies for Code and applicable Addenda performing inservice terminology for inservice inspection and testing jnspection and testina activities activities Weekly At least once per'7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days

c. The provisions of Specification 4.0.2 are anplicable to the above required frequencies for performing inservice inspection and testing activities.

d. Performance of the above inservice inspection and testing activities shall be in addition to other specified Surveillance Requirements.

e. Nothing in the ASME Boiler and Pressure Vessel Code shall be

construed to supersede the requirements of any Technical l Specification.

BEAVER VALLEY - UNIT 1 3/4 0-3 Amendment No.

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TABLE 3 3-6 DPR-66

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RADIATION MONITORING INSTRUMENTATION MINIMUM <

CHANNELS APPLICABLE MEASUREMENT INSTRUMENT OPERABLE MODES SETPOINT I3I RANGE ACTION

1. AREA MONITORS

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a. Fuel Storage Pool Area 1 (1) $ 15 mR/hr 10 - 10 mR/hr 19 (RM-207) -

b. Containment 3 6

i. Purge & Exhaust 1 6 s-1.6 x 10 cpm 10 - 10 cpm 22 Isolation (RMVS 104 A & B)

7 ii. Area (RM-RM-219 2 1,2,3 &4 5 1.5 x 10 R/hr 1 - 10 R/hr 35 l A & B)

c. Control Room Isolation 2 1,2,3,4,5I#I,6I#I $ .47 mR/hr 10

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- 10 3

41 (RM-RM-218 A & B) (in either unit) mR/hr ,

2. PROCESS MONITORS

a. Containment 6

i. Gaseous Activity 1 1,2,3 & 4 N/A 10 - 10 cpm 20 RCS Leakage Detection (RM 215B) i 6

ii. Particulate Activity 1 1,2,3 & 4 N/A 10 - 10 cpm 20 RCS Leakage Detection (RM 215A)

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b. Fuel Storage Building 1 (2) s 4.0 x 10 cpm 10 - 10 cpm 21 Gross Activity (RMVS-103 A & B)

BEAVER VALLEY - UNIT 1 3/4 3-34 Amendment No.

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TABLE 3.3-6 (Continued) DPR-66 .

RADIATION MONITORING INSTRUMENTATION MINIMUM CHANNELS APPLICABLE MEASUREMENT INSTRUMENT OPERABLE MODES SETPOINT I3) RANGE ACTION ,

PROCESS MONITORS (Continued) 2.c. Noble Gas Effluent 1 Monitors 2

-10 uCi/cc II

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i. Supplementary Leak 1 1,2,3,&4 s ,.98 x 10 cpm 10 35 -l Collection and Release System (RM-VS-110 Ch.

7 & Ch. 9)I7I 2

-10 uCi/cc II

-2 ii. Auxiliary Building 1 1,2,3,&4 6 6.69 x 10 cpm 10 35 l Ventilation System (RM-VS-p09 Ch. 7 & ,

Ch. 9)I >

5 -2 iii. Process Vent System 1 1,2,3,&4 $ 1.83 x 10 cpm 10 -10 uCi/cc(6) 35 l (RM-GW-p09 Ch. 7&

Ch. 9)I !

iv. AtLC.., mric Steam Dump 1/SG 1,2,3,&4 1

s 5. 0 x 10 cpm 10

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-103 uci/cc 35 l Valve and Code Safety ;

Relief Valve Discharge (RM-MS-100 A, B, C) ,

2 -1 3

v. Auxiliary Feedwater 1. 1,2,3,&4 5 6.5 x 10 cpm 10 -10 uci/cc 35 l Pump Turbine Exhaust ,

(RM-MS-101) ,

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. DPR-66 TABLE 3.3-6 (Continued) i l

TABLE NOTATIONS (1) With fuel in the storage pool or building.

(2) With Irradiated fuel in the storage pool.

(3) Above background.

(4) During movement of irradiated fuel or movement of heavy loads over spent fuel.

(5) Nominal range for Ch. 7 and Ch. 9. Alarm set on Ch. 7.

(6) Nominal range for Ch. 7 and Ch. 9. Alarm set on Ch. 9.

(7) Other SPING-4 channels not applicable to this specification.

ACTION STATEMENTS ACTION 19 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 20 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.4.6.1.

ACTION 21 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the applicable ACTION requirements of Specification 3.9.12 and 3.9.13.

ACTION 22 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.9.9.

ACTION 35 - With the number of OPERABLE channels less than required j by the Minimum Channels OPERABLE requirement, either restore the inoperable Channel (s) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or:

a) Initiate the preplanned alternate method of monitoring the appropriate parameter (s), and b) Return the channel to OPERABLE status within 30 days, or, explain in the next Annual Radioactive Effluent Release Report why the inoperability was not corrected in a timely manner.

ACTION 41 - a) With the number of Unit 1 OPERABLE channeD one less than the Minimum Channels OPERABLE requirement:

1. Verify the respective Unit 2 control room radiation monitor train is OPERABLE within 1 l hour and at least once per 31 days.

l BEAVER VALLEY - UNIT 1 3/4 3-35 Amendment No.

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DPR-66 INSTRUMENTATION SEISMIC INSTRUMENTATION LIMITING CONDITION FOR OPERATION l 3.3.3.3 The seismic monitoring instrumentation shown in Table 3.3-7 shall be OPERABLE.

APPLICABILITY: At all times.

i ACTION:

a. With the number of OPERABLE seismic monitoring instruments less than required by Table 3.3-7, restore the inoperable i I

instrument (s) to OPERABLE status within 30 days.

b. With one or more seismic monitoring instruments inoperable for more than 30 days, prepare and submit a Special Report in accordance with 10 CFR 50.4 within the next 10 days l outlining the cause of the malfunction and the plans for l restorilig the instrument (s) to OPERABLE status,

c. The provisions of Specification 3.0.3 are not applicable.

l SURVEILLANCE REQUIREMENTS 4.3.3.3.1 Each of the above seismic monitoring instruments shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-4.

4.3.3.3.2 A seismic event greater than or equal to 0.01g shall be reported to the Commission within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . Each of the above seismic monitoring instruments actuated - during a seismic event greater than or equal to 0.01g shall be ' restored to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and a CHANNEL CALIBRATION performed within 30 days following the seismic event. Data shall be retrieved from actuated instruments

.and analyzed to determine the magnitude of the vibratory ground motion. A- Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 within 30 days describing the magnitude, frequency spectrum and resultant effect upon facility features important to safety.

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1 BEAVER VALLEY - UNIT 1 3/4 3-38 Amendment No.

DPR-66 INSTRUMENTATION EXPLOSIVE GAS MONITORING INSTRUMENTATION l

l LIMITING CONDITION FOR OPERATION l

3.3.3.11 The explosive gas monitoring instrumentation channels shown in Table 3.3-13 shall be OPERABLE with their alarm / trip setpoints set to ensure that the limits of Specification 3.11.2.6 are not exceeded.

APPLICABILITY: As shown in Table 3.3-13.

ACTION:

a. With an explosive gas monitoring instrumentation channel alarm / trip setpoint less conservative than required by the above specification, declare the channel inoperable and take the ACTION shown in Table 3.3-13.

b. With less than the minimum number of explosive gas monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 3.3-13. Restore the inoperable instrumentation to OPERABLE status within 30 days and, if unsuccessful, prepare and submit a Special Report in accordance with 10 CFR 50.4 within 30 days to explain why this inoperability was not corrected in a timely manner.

c. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.11 Each explosive gas monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL CALIBRATION, and CHANNEL . FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-13.

l BEAVER VALLEY - UNIT 1 3/4 3-54 Amendment No.

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6 DPR-66 REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)

b. The steam generator shall be determined OPERABLE after completing the corresponding actions (plug or repair all l tubes exceeding the plugging or repair limit) required by Table 4.4-2.

4.4.5.5 Reports

a. Within 15 days following the completion of each inservice inspection of steam generator tubes, the number of tubes plugged or repaired in each steam generator shall be I submitted in a Special Report in t.ccordance with 10 CFR l 50.4. '

b. The complete results of the steam generator tube and sleeve inservice inspection shall be submitted in a Special Report in accordance with 10 CFR 50.4 within 12 months following the completion of the inspection. This Special Report shall include:

1. Number-and extent of tubes and sleeves inspected.

2. Location and percent of wall-thickness penetration for each indication of an imperfection.

3. Identification of tubes plugged or repaired.

c. Results of steam generator tube inspections which fall into Category C-3 shall be reported to the Commission pursuant to Specification 6.6 prior to resumption of plant operation. The written report shall provide a description of investigations conducted to determine the cause of the tube degradation and corrective measures taken to prevent recurrence.

d. For implementation of the voltage-based repair criteria to tube support plate intersections, notify the Commission prior to returning the steam generators to service (MODE 4) should any of the following conditions arise:

1. If estimated leakage based on the projected end-of-cycle (or if not practical, using the actual measured end-of-cycle) voltage distribution exceeds the leak limit (determined from the licensing basis dose calculation for the postulated main steamline break) for the next operating cycle.

1

2. If circumferential crack-like indications are detected at the tube support plate intersections.

l BEAVER VALLEY - UNIT 1 3/4 4-10e Amendment No.

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i . DPR-66 l EMERGENCY CORE COOLING SYSTEMS l 3/4.5.2 ECCS SUBSYSTEMS - Tava 2 350'F i

l LIMITING CONDITION FOR OPERATION l

( 3.5.2 Two separate and independent ECCS subsystems shall be OPERABLE with each subsystem comprised of:

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a. One OPERABLE centrifugal charging pump,

b. One OPERABLE low head safety injection pump, and

c. An OPERABLE flow path capable of taking suction from the ;

refueling water storage tank on a safety injection signal i and transferring suction to the containment sump during the recirculation phase of operation.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a. With one ECCS subsystem inoperable, restore the inoperable subsystem to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ,

b. In the event the ECCS is actuated and injects water into the Reactor Coolant S'f stem, a Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 within 30 days l describing the circumstances of the actuation and the total accumulated actuation cycles to date.

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BEAVER VALLEY - UNIT 1 3/4 5-3 Amendment No.

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- DPR-66 EMERGENCY COPF COOLING SYSTEMS i 3/4.5.3 ECCS SUBSYSTEMS - Tava < 350'F l

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( LIMITING CONDITION FOR OPERATION l 3.5.3 As a minimum, one ECCS subsystem comprised of the following shall be OPERABLE:

a. One OPERABLE centrifugal charging pump,#

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b. One OPERABLE Low Head Safety Injection Pump, and !

c. An OPERABLE flow path capable of taking suction from the refueling water storage tank upon being manually realigned and transferring suction to the containment semp during the I recirculation phase of operation.

APPLICABILITY: MODE 4. I l

ACTION:

a. With no ECCS subsystem OPERABLE because of the inoperability of either the centrifugal charging pump or the flow path from the refueling water storage tank, restore at least one ECCS subsystem to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in )

COLD SHUTDOWN within the next 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months .

1

b. In the event the ECCS is actuated and injects water into the ;

Reactor Coolant System, a Special Report shall be prepared l and submitted in accordance with 10 CFR 50.4 within 30 days l describing the circumstances of the actuation and the total accumulated actuation cycles to date.

SURVEILLANCE REQUIREMENTS .

4.5.3.1 The ECCS subsystem shall be demonstrated OPERABLE per the applicable Surveillance Requirements of 4.5.2.

4.5.3.2 All charging pumps except the above required OPERABLE pumps, shall be demonstrated inoperable at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months whenever the temperature of one or more of the non-isolated RCS cold legs is s the enable temperature set forth in Specification 3.4.9.3 by verifying that the control switches are placed in the PULL-TO-I4CK

-position and tagged.

A maximum of one centrifugal charging pump shall be OPERABLE l whenever the temperature of one or more of the non-isolated RCS I

' cold legs is A the enable temperature set forth in Specification 3.4.9.3.

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BEAVER VALLEY - UNIT 1 3/4 5-6 Amendment No. l 1

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DPR-66 PLANT SYSTEMS t

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SURVEILLANCE REQUIREMENTS (Continued)

a. Sources in use - At least once per six months for all sealed sources containing radioactive materials.

1. With a half-life greater than 30 days (excluding Hydrogen 3) and

2. In any form other than gas.

b. Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous six months.

Sealed sources and fission detectors transferred without a certificate indicating the last test date shall be tested prior to being placed into use.

c. Startup sources and fission detectors - Each sealed startup source and fission detector shall be tested within 31 days prior to being subjec ted to core flux or installed in the core and following repair or maintenance to the source.

4.7.9.1.3 Reports -

A Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 on an annual basis if sealed l source or fission detector leakage tests reveal the presence of 2 0.005 microcuries of removable contamination.

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l BEAVER VALLEY - UNIT 1 3/4 7-23 Amendment No.

(next page is 3/4 7-26)

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r DPR-66 3/4.11 RADIOACTIVE EFFLUFJiTA i 3/4.11.1 LIOUID EFFLUENTS l

LIQUID HOLDUP TANKS LIMITING CONDITION FOR OPERATION 3.11.1.4 The quantity of radioactive material contained in each of the following tanks shall be limited to less than or equal to 10 l curies,. excluding tritium and dissolved or entrained noble gases.

a. BR-TK-6A (Primary Water Storage Tank)

b. BR-TK-6B (Primary Water Storage Tank)

c. LW-TK-7A (Steam Generator Drain Tank)

d. LW-TK-7B (Steam Generator Drain Tank)

e. Miscellaneous temporary outside radioactive liquid storage tanks.

APPLICABILITY: At all times.

ACTION:

a. With the quantity of radioactive material in any of the above listed tanks exceeding the above limit, immediately suspend all additions of radioactive material to the tank and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tank contents to within the limit, and

b. Submit a Special Report in accordance with 10 CFR 50.4' within 30 days and . include a schedule and a description of activities planned and/or taken to reduce the contents to within the specified limits.

c. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.11.1.4.1 The quantity of radioactive material contained in each of the above listed tanks shall be determined to be within the above limit by analyz'ing a representative sample of the tank's contents at

'least once per 7 days when radioactive materials'are being added to the tank.

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. BEAVER VALLEY - UNIT 1 3/4 11-2 Amendment No.

DPR-66 RADIOACTIVE. EFFLUENTS 3/4.11.2 GASEOUS EFFLUENTS GAS STORAGE TANKS LIMITING CONDITION FOR OPERATION 3.11'.2.5 The quantity of radioactivity contained in each gas storage tank shall be limited to less than or equal to 52,000 curies noble gases (considered as Xe-133).

APPLICABILITY: At all times.

ACTION:

a. With the quantity of radioactive material in any gas storage tank exceeding the above limit, immediately suspend all additions of radioactive material to the tank and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tank contents to within the limit, and

b. Submit a Special Report in accordance with 10 CFR 50.4 within 30 days and include a schedule and a description of activities planned and/or taken to reduce the contents to within the specified limits.

c. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS . . . . .

4.11.2.5.1 The quantity of radioactive material contained in each gas storage tank shall be determined to be within the above limit at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when radioactive materials are being added to the tank. Performance of this surveillance is required when the gross concentration of the primary coolant is greater than 100 uC1/ml.

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BEAVER VALLEY - UNIT 1 3/4 11-4 Amendment No.

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~ DPR-66 INSTRUMENTATION l BASES 3/4.3.3 MONITORING INSTRUMENTATION 3/4.3.3.1 RADIATION MONITORING INSTRUMENTATION l

The OPERABILITY of the radiation monitoring channels ensures that: '

1) the radiation levels are continually measured in the areas served l by the individual channels; 2) the alarm or automatic action is l initiated when the radiation level trip setpoint is exceeded; and l

3) sufficient information is available on selected plant parameters to monitor and assess these variables following an accident. This capability is consistent with the recommendations of NUREG-0737,

" Clarification of TMI Action Plan Requirements," October, 1980.

3/4.3.3.2 MOVABLE INCORE DETECTORS The OPERABILITY of the movable incore detectors with the specified minimum complement of equipment ensures that the measurements obtained from use of this system accurately represent the spatial neutron flux distribution of the reactor core. The OPERABILITY of

this system is demonstrated by irradiating each detector used and l determining the acceptability of its voltage curve.

For the purpose of measuring Fg(Z) or F3H, a full incore flux map is j used. Quarter-core flux maps, as defined in WCAP-8648, June 1976, 1 i may be used in recalibration of the excore neutron flux detection i system, and full incore flux maps or symmetric incore thimbles may be :

used for monitoring the Quadrant Power Tilt Ratio when one Power Range Channel is inoperable. l 3/4.3.3.3 SEISMIC INSTRUMENTATION The OPERABILITY of the seismic instrumentation ensures that sufficient capability is available to promptly determine the i magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured response to that used in the design basis 2

for the facility and is consistent with the recommendations of

> Regulatory Guide 1.12, " Instrumentation for Earthquakes."

3/4.3.3.4 DELETED I

BEAVER VALLEY - UNIT 1 B 3/4 3-2 Amendment No.

DPR-66 3/4.4 REACTOR COOLANT SYSTEM BASES 3/4.4.1.1. 2. 3 REACTOR COOLANT LOOPS The plant is designed to operate with all reactor coolant loops in operation and maintain DNBR above the design DNBR limit during all normal operations and anticipated transients. In Modes 1 and 2, with one reactor coolant loop not in operation, THERMAL POWER is restricted to less than or equal to 31 percent of RATED THERMAL POWER until the Overtemperature AT trip is reset. Either action ensures that the DNBR will be maintained above the design DNBR limit. A loss of flow in two loops will cause a reactor trip if operating above P-7 (11 percent of RATED THERMAL POWER) while a loss of flow in one loop will cause a reactor trip if operating above P-8 (31 percent of RATED THERMAL POWER).

In MODE 3, a single reactor coolant loop provides sufficient heat removal capability for removing decay heat; however, due to the initial conditions assumed in the analysis for the control rod bank withdrawal from a subcritical condition, two operating coolant loops are required to meet the DNB design basis for this Condition II event.

In MODES 4 and 5, a single reactor coolant loop or RHR subsystem provides sufficient heat removal capability for removing decay heat; but single failure considerations require that at least two loops be OPERABLE. Thus, if the reactor coolant loops are not OPERABLE, this specification requires two RHR loops to be OPERABLE.

The operation of one Reactor Coolant Pump or one RHR pump provides adequate flow to ensure mixing, prevent stratification and produce gradual reactivity changes during boron concentration reductions in the Reactor Coolant System. The reactivity change rate associated with boron reduction will, therefore, be within the capability of operator recognition and control.

The restrictions on starting a Reactor Coolant Pump with one or more RCS cold legs less than or equal to the enable temperature set forth in Specification 3.4.9.3 are provided to prevent RCS pressure transients, caused by energy additions from the secondary system, which could exceed the limits of Appendix G to 10 CFR Part 50. The RCS will be protected against overpressure transients and will not exceed the limits of Appendix G by either (1) restricting the water level in the pressurizer and thereby providing a volume for the primary coolant to expand into or (2) by restricting starting of the RCPs to when the secondary water temperature of each steam generator is less than 25 F above each of the RCS cold leg temperatures. '

l BEAVER VALLEY - UNIT 1 B 3/4 4-1 Amendment No.

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'o DPR-66 5.0 DESIGN FEATURES 5.1 SITE LOCATION The Beaver Valley Power Station Unit No. 1 is located in Shippingport Borough, Beaver County, Pennsylvania, on the south bank of the Ohio j River. The site is approximately 1 mile southeast of Midland, l Pennsylvania, 5 miles east of East Liverpool, Ohio, and approximately l 25 miles northwest of Pittsburgh, Pennsylvania.

1 5.2 REACTOR CORE 5.2.1 FUEL ASSEMBLIES The reactor shall contain 157 fuel assemblies. Each assembly shall

! consist of a matrix of Zircaloy or ZIRLO fuel rods with an initial composition of natural or slightly-enriched uranium dioxide (UO 2) as fuel material. Limited substitutions of zirconium alloy or stainless-l steel filler rods for fuel rods, in accordance with approved I applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design

! bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core ,

regions, j 5.2.2 CONTROL ROD ASSEMBLIES l

The reactor core shall contain 48 full length and no part length control rod assemblies. The full length control rod assemblies shall contain a nominal 142 inches of absorber material. The nominal values of absorber material shall be 80 percent silver, 15 percent indium and 5 percent cadmium. All control rods shall be clad with l stainless steel tubing.

l l 5.3 FUEL STORAGE

! 5.3.1 CRITICALITY 5.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

l a. Fuel assemblies having a maximum U-235 enrichment as set l-forth in Specification 3.9.14; l

b. K gr s 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in UFSAR Section 9.12; l

4 BEAVER VALLEY - UNIT 1 5-1 Amendment No.

I

DPR-66 l ADMINISTRATIVE CONTROLS l

l

3) Participation in an Interlaboratory Comparison Program to ensure that independent checks on the precision and accuracy of the measurements of radioactive materials in environmental sample matrices are performed as part l of the quality assurance program for environmental l monitoring.

l l 6.9 REPORTING REQUIREMENTS

[ The following . reports shall be submitted in accordance with 10 CFR 50.4.

6.9.1 Occuoational Radiation Exoosure Report )

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A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

A tabulation on an annual basis of the number of station, utility, l and other personnel (including contractors) receiving exposures greater than 100 mrem /yr and their associated man-rem expeure according to work and job functions (e.g., reactor operationc and l surveillance, inservice inspection, routine maintenance, special maintenance (describe maintenance), waste processing, and refueling).

This tabulation supplements the requirements of 10 CFR 20.2206. The l dose assignments to various duty functions may be estimated based on pocket dosimeter, thermoluminescent dosimeter (TLD), or film badge l measurements. Small exposures totalling less than 20 percent of the individual total dose need not be accounted for. In the aggregate, i at least 80 percent of the total whole body dose received from external sources should be assigned to specific major work functions.

The report shall be submitted by April 30 of each year. l i-d I. BEAVER VALLEY - UNIT 1 6-16 Amendment No.

o

. DPR-66 l ADMINISTRATIVE CONTROLS l 6.9.2 ANNUAL RADIOLOGICAL ENVIRONMENTAL OPERATING REPORT l

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A single submittal may be made for a multiple unit station. The l submittal should combine sections common to all units at the j station.

The Annual Radiological Environmental Operating Report covering the l operation of the unit during the previous celendar year shall be submitted before May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM) and in 10 CFR Part 50 Appendix I Sections IV.B.2, IV.B.3, and IV.C.

6.9.3 ANNUAL RADIOACTIVE EFFLUENT RELEASE REPORT l

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A single submittal may be made for a multi-unit station. The submittal should combine those sections that are common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

r The Annual Radioactive Effluent Release Report covering the operation l of the unit during the previous 12 months of operation shall be submitted before April 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of i radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program (PCP) and l in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I Section IV.B.1.

6.9.4 MONTHLY OPERATING REPORT l Routine reports of operating statistics and shutdown experience, l including documentation of all challenges to the pressurizer power operated relief valves or pressurizer safety valves, shall be submitted on a monthly basis no later than the 15th of each month l following the calendar month covered by the report.

l BEAVER VALLEY - UNIT 1 6-17 Amendment No.

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DPR-66 ADMINISTRATIVE CONTROLS 6.9.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

i 3.1.3.5 Shutdown Rod Insertion Limits l 3.1.3.6 Control Rod Insertion Limits i 3.2.1 Axial Flux ~ Difference-Constant Axial Offset

! Control l' 3.2.2 Heat Flux Hot Channel Factor-Fg(Z)

! 3.2.3- Nuclear Enthalpy Rise Hot Channel Factor-F,au

b. The analytical methods used to determine the core operating 1 limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

WCAP-9272-P-A, " WESTINGHOUSE RELOAD SAFETY EVALUATION l METHODOLOGY," July 1985 (Westinghouse Proprietary).

WCAP-10266-P-A Rev. 2/WCAP-11524-NP-A Rev. 2, "The 1981 Version of the Westinghouse ECCS Evaluation Model Using the -

BASH Code," Kabadi, J. N., March 1987; including Addeltdum i I

1-A " Power Shape Sensitivity Studies" 12/87 and Adder dum 2-A " BASH Methodology Improvements and Reliability Enhancements" 5/88.

WCAP-8385, " POWER DISTRIBUTION CONTROL AND LOAD FOLLOWING PROCEDURES - TOPICAL REPORT." September 1974 (Westinghouse Proprietary). l l

T. M. Anderson to K. Kniel (Chief of Core Performance Branch, NRC) January 31, 1980 --

Attachment:

Operation and Safety Analysis Aspects of an Improved Load Follow Package.

NUREG-0800, ' Standard Review Plan, U.S. Nuclear Regulatory I Commission, Section 4.3, Nuclear Design, July 1981. Branch Technical Position CPB 4.3-1, Westinghouse Constant Axial Offset Control (CAOC) , Rev. 2, July 1981.

WCAP-12610-P-A, " VANTAGE + Fuel Assembly Reference Core Report," April 1995 (Westinghouse Proprietary).

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limite, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as shutdown margin, transient analysis limits, and accident analysis limits) of the safety analysis are met.

BEAVER VALLEY - UNIT 1 6-18 Amendment No.

I ^. l DPR-66 l ADMINISTRATIVE CONTROLS l I

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CORE OPERATING LIMITS REPORT (Continued) I

d. The COLR, including any midcycle revisions or supplements, )

shall be provided upon issuance for each reload cycle to the NRC. j 6.10 DRT.RTED i

l 6.11 RADIATION PROTECTION PROGRAM l Procedures for personnel radiation protection shall be prepared i consistent with the requirements of 10 CFR ' Part 20 and shall be I approved, maintained and adhered to for all operations involving l personnel radiation exposure. !

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l BEAVER VALLEY - UNIT 1 6-19 Amendment No.

(next page is 6-23)

ATTACHMENT B-1 Channe Summary Unit 1 Tvoed Panes Editorial Channes Operating License Page 6 No additional changes are included.

IV X

XV Pagination - changes the page number for the Monthly Operating Report and Radiation Protection Program.

XVI No additional changes are included.

1-3 Previous amendment - The changes proposed by License Amendment Request 246 have been incorporated on this

, page which was previously modified by Amendment 216.

. 1-6 No additional changes are included.

1-8 3/40-1 3/40-2 Pagination - added due to shifting.

3/4 0-3 3/4 3-34 No additional changes are included.

3/4 3-34a 3/43-3f 3/4 3-38 3/4 3-54 3/4 4-10e 3/45-3 3/45-6 3/4 7-23 3/4 11-2 i 3/4 11-4 B 3/4 3-2 ,

B 3/4 4-1 5-1 l 6-16 i 6-17 Correct a typo - The last sentence of Administrative !

Control 6.9.3 has been modified from the marked-up page by moving "10 CFR Part 50 Appendix I" after the "and" to be consistent with NUREG 1431.

6-18 Correct a typo -Insert F is printed on these pages. There is no Insert G.

6-19

l ATTACHMENT 116 I

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Unit No. 2 Technical Specification Paaes

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. ATTACHMENT TO LICENSE AMENDMENT NO.

-FACILITY OPERATING LICENSE NO. NPF-73 DOCKET NO. 50-412 i Replace the following pages of Appendix A, Technical Specifications,

with the enclosed pages as indicated. The revised pages are ,

l identified by amendment number and contain vertical lines indicating '

the areas'of change.

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Remove Insert Operating License Page 7 Operating License Page 7 i IV IV X X XIV XIV XV XV 1-3 1-3 .

1-6 1-6 1-7 1-7 3/4 0-1 3/4 0-1 3/4 0-2 3/4 0-2 3/4 0-3 3/4 0-3 3/4 3-40 3/4 3-40 3/4 3-41 3/4 3-41 3/4 3-42 3/4 3-42 3/4 3-46 3/4 3-46 3/4 3-49 ----

3/4 3-50 ----

3/4 3-51 ----

3/4 3-61 3/4 3-61 3/4 3-63 3/4 3-63 ,

3/4 4-7 3/4 4-7 3/4 4-14a 3/4 4-14a 3/4 4-14b 3/4 4-14b 3/4 5-3 3/4 5-3 3/4 5-6 3/4 5-6 3/4 7-21 3/4 7-21 3/4 9-8 3/4 9-8 3/4 11-2 3/4 11-2 3/4 11-4 3/4 11-4 B 3/4 3-11 B 3/4 3-11 5-1 5-1 6-16 6-16 6-17 6-17 6-18 6-18 6-19 6-19 6-20 ----

6-21 ----

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NPF-73 1

DLCo may make changes to the approved fire protection program without prior approval of the Commission only if ,

those changes would not adversely affect the ability to l achieve and maintain safe shutdown in the event of a fire.

G. Reportina to the Commission DELETED l 1

H. Financial Protection i

! The licensees shall have and maintain financial protection j of such type and in such amounts as the Commission shall

require in accordance with section 170 of the Atomic Energy j

?

Act of 1954, as amended, to cover.public liability claims. l l

I. Exoiration

This license is effective on the date of issuance and shall !

expire at midnight on May 27, 2027.

I FOR THE NUCLEAR REGULATORY COMMISSION l

4 Thomas E. Murley, Director Office of Nuclear Reactor Regulation l

I 1

Enclosures:

1. Appendix A - Technical Specifications (NUREG-1279) l

2. Appendix B - Environmental Protection Plan Date of Issuance: August 14, 1987 Amendment No.

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. NPF-73 INDEX LIMITING CONDITION FOR OPERATION AND SURVEILLANCE REQUIREMENTS l t _ _ . - . .

PAGE l SECTLQH l

3/4.1.2.9 Isolation of Unborated Water Sources - j L

i Shutdown................................ 3/4 1-17 ,

L 3/4.1.3 MOVABLE CONTROL ASSEMBLIES 3/4.1.3.1 Group Height............................ 3/4 1-18 3/4.1.3.2 Position Indication Systems - Operating. 3/4 1-21 ;

i 3/4.1.3.3 Position Indication System - Shutdown... 3/4 1-22 )

3/4.1.3.4 Rod Drop Time........................... 3/4 1-23 l 3/4.1.3.5 Shutdown Rod Insertion-Limit............ 3/4 1-24 3/4.1.3.6' Control Rod Insertion Limits............ 3/4 1-25 l

3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX DIFFERENCE (AFD) ............. 3/4 2-1 ;

3/4.2.2 HEAT FLUX HOT CHANNEL FACTOR - Fg(Z) . . . . 3/4 2-4 3/4.2.3 NUCLEAR ENTHALPY HOT CHANNEL FACTOR -

N FAH ................................... 3/4 2-7 3/4.2.4 QUADRANT POWER YILT RATIO............... '3/4 2-9

.3/4.2.5 DNB PARAMETERS.......................... 3/4 2-11 3/4.3 INSTRUMENTATION

'3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION..... 3/4 3-1 3/4.3.2_ ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION......................... 3/4 3-14 3/4.3.3 MONITORING INSTRUMENTATION ,

3/4.3.3.1 Radiation Monitoring.................... 3/4 3-39

-3/4.3.3.2 Movable Incore Detectors................ 3/4 3-45 3/4.3.3.3 Seismic Instrumentation................. 3/4 *-46a

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BEAVER VALLEY - UNIT 2 IV Amendment No.

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. . NPF-73 INDEX BASES i SECTION PAGE 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AXIAL FLUX DIFFERENCE (AFD) .................. B 3/4 2-1 3/4.2.2 AND 3/4.2.3 HEAT FLUX AND NUCLEAR ENTHALPY HOT CHANNEL FACTORS Fg(Z) AND F{H . . . . . . . . . . . . B 3 /4 2-2 l- 3/4.2.4 QUADRANT POWER TILT RATIO.................... B 3/4 2-5 3/4'.2.5 DNB PARAMETERS...............................B 3/4 2-5 1

I 3/4.3 ' INSTRUMENTATION 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION.......... B 3/4 3-1 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION....................... B 3/4 3-1 3/4.3.3. MONITORING INSTRUMENTATION 3/4.3.3.1 Radiation Monitoring Instrumentation......... B 3/4 3-10 3/4'.3.3.2 Movable Incore Detectors..................... B 3/4 3-10 3/4.3.3'.3 Seismic Instrumentation......................B 3/4 3-11 l

3/4.3.3.5 Remote Shutdown Instrumentation.............. B 3/4 3-31 3/4.3.3.7 Chlorine Detection Systems...................B 3/4 3-11 3/4.3.3.8 Accident Monitoring Instrumentation .......... B 3/4'3-12 3/4.3.3.11 Explosive Gas Monitoring Instrumentation..... B,3/4 3-12 3/4.3.4 TURBINE OVERSPEED PROTECTION................. B 3/4 3-12 3/4.4 REACTOR COOLANT SYSTEM 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT CIRCULATION.................................. B 3/4 4-1 3/4~.4.2 AND 3/4.4.3 SAFETY VALVES........................B 3/4 4-2 3/4.4.4 PRESSURIZER.................................. B 3/4 4-2 BEAVER VALLEY - UNIT 2 X Amendment No.

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i l . NPF-73 l- INDEX ADMINISTRATIVE CONTROLS SECTION PAGE l l

6.2.2 UNIT STAFF.............................. 6-1 l

6.3 FACILITY STAFF OUALIFICATIONS.................... 6-6 l

I l 6.4 TRAINING......................................... 6-6 l

t 6.5 DELETED i 6.6 REPORTABLE EVENT ACTION.......................... 6-6 6.7 SAFETY LIMIT VIOLATION........................... 6-6 i 6.8 PROCEDURES....................................... 6-7 6.9 REPORTING REOUIREMENTS 6.9.1 Occupational Radiation Exposure-Report.. 6-16 6.9.2 Annual Radiological Environmental Operating Report........................ 6-16 l 6.9.3 Annual Radioactive Effluent Release Report.................................. 6-17 l 6.9.4 Monthly Operating Report................ 6-18 i 6.9.5 Core Operating Limits Report............ 6-19 6.10 DELETED

( 6.11 RADIATION PROTECTION PROGRAM.................... 6-19 l l

BEAVER VALLEY - UNIT 2 Amendment No.

XIV l

- NPF-73 INDEX ADMINISTRATIVE CONTROLS SECTION PAGE 6.12 HIGH RADIATION AREA............................. 6-19 l 6.13 PROCESS CONTROL PROGRAM (PCP) ................... 6-24 6.14 OFFSITE DOSE CALCULATION MANUAL (ODCM) .......... 6-25 6.16 MAJOR CHANGES TO RADIOACTIVE WASTE TREATMENT SYSTEMS (Licuid. Gaseous and Solid) ............. 6-25 6.17 CONTAINMENT LEAKAGE RATE TESTING PROGRAM........ 6-25 l

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BEAVER VALLEY - UNIT 2 XV Amendment No.

j.

1 NPF-73 i DEFINITIONS CORE ALTERATION 1.12 CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

SHUTDOWN MARGIN 1.13 SHUTDOWN MARGIN shall be the instantaneous amount of reactivity by which the reactor is or would be suberitical from its present condition assuming all full length rod cluster assenblies (shutdown and control) are fully inserted except for the single rod cluster assembly of highest reactivity worth which is assumed to be fully withdrawn.

LEAKAGE 1.14 LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump seal water injection or leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leap. age detection systems or not to be Pressure Boundary LEAKAGE, or

3. Reactor Coolant System LEAKAGE through a steam generator to the secondary system.

b. Unidentified LEAKAGE Unidentified LEAKAGE shall be all LEAKAGE (except reactor coolant pump seal water injection or leakoff) that is not Identified LEAKAGE.

c. Pressure Boundary LEAKAGE Pressure Boundary LEAKAGE shall be LEAKAGE (except steam generator tube LEAKAGE) through a nonisolable fault in a Reactor Coolant System component body, pipe wall or vessel wall.

BEAVER VALLEY - UNIT 2 1-3 Amendment No.

$ .* NPF 1 DEFINITIONS .

OFFSITE DOSE CALCULATION MANUAL (ODCM) (Continued) i Effluent Controls and Radiological Environmental Monitoring Programs required by Section 6.8.6 and (2) descriptions of the information that should be included in - the Annual Radiological Environmental Operating and Annual Radioactive Effluent Release Reports required by Specifications in the Administrative Control section. l

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GASEOUS RADWASTE TREATMENT SYSTEM i

l 1.01 A GASEOUS RADWASTE -TREATMENT SYSTEN is any system designed and installed to reduce radioactive gaseous effluents by collecting Primary Coolant System offgases from the primary system and providing

for . delay or holdup for the purpose of reducing the total I radioactivity prior to release to the environment.

7 VENTILATION EXHAUST TREATMENT SYSTEM j 1.32 VENTILATION EXHAUST TREATMENT SYSTEM is any system designed !

i and installed to reduce gaseous radioiodine or radioactive material 4 in particulate form in effluents by passing ventilation or vent exhaust gases through charcoal adsorbers and/or HEPA filters for the !

4 purpose of removing lodines or particulates from the gaseous exhaust

, stream prior to the release to the environment (such a system is not

' considered to have any effect on noble gas effluents). Engineered i

Safety Feature (ESF) atmospheric cleanup systems are not considered to be VENTILATION EXHAUST TREATMENT SYSTEM components.

PURGE-PURGING L

1.33 PURGE or PURGING is the controlled process of discharging air or gas from a confinement to maintain temperature, pressure, humiditV, concentration or other operating conditions, in such a manner that replacement air or gas is required to purify the confinement.

VENTING 1.34 VENTING is the controlled process of discharging air or gas from a confinement to maintain temperature, pressure, humidity, concentration or other operating conditions, in such'a manner that replacement ' air or gas is not provided or required during VENTING.

Vent, used in system names, does not imply a VENTING process.

MAJOR CHANGES 1.35 MAJOR CHANGES to radioactive waste systems (liquid, gaseous and solid), as addressed in the PROCESS CONTROL PROGRAM, shall include the following:

BEAVER VALLEY - UNIT 2 1-6 Amendment No.

j . NPF-73 DEFINITIONS l' ;

I MAJOR CHANGES (Continued) I

1) MAJOR CHANGES in process equipment, components, structures, and effluent monitoring instrumentation from those described in the Final Safety Analysis Report (FSAR) or the Hazards Summary Report and evaluated in the staff's l l Safety Evaluation Report (SER) (e.g., deletion of '

l evaporators and installation of demineralizers; use of fluidized bed calciner/ incineration in place of cement solidification systems);

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2) MAJOR CHANGES in the design of radwaste treatment systems (liquid, gaseous, and solid) that could sianificantly increase the quantities or activity of effluents released or volumes of solid waste stored or shipped offsite from

those previously considered in the FSAR and SER (e.g., use of asphalt system in place of cement);

3) Changes in system design which may invalidate the accident analysis as described in the SER (e.g., changes in tank ,

capacity that would alter the curies released); and

4) Changes in system design that could potentially result in a significant increase'in occupational exposure of operating personnel (e.g., use of temporary equipment without adequate shielding provisions).

MEMBER (S) OF THE PUBLIC 1.36 MEMBER (S) OF THE PUBLIC means any individual except when that individual is receiving an occupational dose.

. CORE OPERATING LIMITS REPORT 1.37 The CORE OPERATING LIMITS REPORT (COLR) is the unit-specific document that provides core operating limits for the current operating reload cycle. These cycle-specific core operating limits shall be determined for each reload cycle in accordance with Specification 6.9.1.12. Plant operation within these operating limits is addressed in individual specifications.

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Amendment No.

BEAVER VALLEY - UNIT 2 1-7

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+ NPF-73 3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS 3/4.0 APPLICABILITY LIMITING CONDITION FOR OPERATION 3.0.1 Compliance with the Limiting Conditions for Operation contained in the succeeding specifications is required during the OPERATIONAL MODES or other conditions specified therein; except that upon failure to meet the Limiting Conditions for Operation, the associated ACTION requirements shall be met, except as provided in Limiting Condition for Operation 3.0.6.

3.0.2 Noncompliance with a specification shall exist when the requirements of the Limiting Condition for Operation and associated ACTION requirements are not met within the specified time intervals.

If the Limiting condition for Operation is restored prior to expiration of the specified time intervals, completion of the ACTION requirements is not required.

3.0.3 When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in:

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

2. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Where corrective measures are completed that permit operation under the ACTION requirements, the ACTION may be taken in accordance with the specified time limits as measured from the time of failure to meet the Limiting Condition for Operation. Exceptions to these requirements are stated in the individual specifications.

3.0.4 Entry into an OPERATIONAL MODE or other specified condition shall not be made when the conditions for the Limiting Condition for Operation are not met and the associated ACTION requires a shutdown if they are not met within a specified time interval. Entry into an OPERATIONAL MODE or specified condition may be made in accordance with ACTION requirements when conformance to them permits continued operation of the facility for an unlimited period of time. This provision shall not prevent passage through or to OPERATIONAL MODES as required to comply with ACTION requirements. Exceptions to these requirements are stated in the individual specifications.

3.0.5 When a system, subsystem, train, component or device is determined to be inoperable solely because its emergency power source is inoperable, or solely because its normal power source is inoperable, it may be considered OPERABLE for the purpose of satisfying the requirements of its applicable limiting Condition for Operation, provided: (1) its corresponding normal or emergency power BEAVER VALLEY - UNIT 2 3/4 0-1 Amendment No.

NPF-73 APPLICABILITY LIMITING CONDITION FOR OPERATION (Continued) source is OPERABLE;. and (2) all of its redundant system (s),

y' subsystem (s), train (s), component (s) and device (s) are OPERABLE, or likewise satisfy the requirements of this specification. Unless both conditions (1) and (2) are satisfied within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , action shall be initiated to place the unit 'in a MODE in which the applicable 4 Limiting Condition for Operation does not apply, by placing it, as applicable, in:

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , i 2. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

This specification is not applicable in MODES 5 or 6.

3.0.6 Equipment removed from service or declared inoperable to j comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to Limiting Condition for Operation 3.0.1 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

l, 2 SURVEILLANCE REQUIREMENTS i 4.0.1 Surveillance Requirements shall be met during the j OPERATIONAL MODES or other conditions specified for individual

Limiting Conditions for Operation unless otherwise stated in an individual Surveillance Requirement.

4.0.2 Each Surveillance Rcqd ;ement shall be performed within the

! specified time interval witt 6 maximum allowable extension not to i exceed 25% of the surveillance interval.

4.0.3 Failure to perform a Surveillance Requirement within the i allowed surveillance interval, defined by Specification 4.0.2, shall i constitute noncompliance with the OPERABILITY requirements for a Limiting Condition for Operation. The time limits of the ACTION j requirements are applicable at the time it is identified that a

- Surveillance Requirement has not been performed. The ACTION requirements may be delayed for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to permit the completion of the surveillance when the allowable outage time limits of . the ACTION requirements are less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Surveillance Requirements do not have to be performed on inoperable equipment.

4.0.4 Entry into an OPERATIONAL MODE or other specified condition shall not be made unless the Surveillance Requirement (s) associated )

BEAVER VALLEY - UNIT 2 3/4 0-2 Amendment No. j l

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NPF-73 APPLICABILITY SURVEILLANCE REQUIREMENTS l with a Limiting Condition for Operation has been performed within the l stated surveillance interval or as otherwise specified. This provision shall not prevent passage through or to OPERATIONAL MODES as required to comply.with ACTION requirements.

l 4.0.5 Surveillance Requirements for inservice inspection and testing of-ASME Code Class 1, 2 and 3 components shall be applicable as follows:

a.1 Inservice inspection of ASME Code Class 1, 2 and 3 components shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50, Section 50.55a(g).

a.2 Inservice testing of ASME Code Class 1, 2 and 3 pumps and valves i shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50, Section 50.55a(f).

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b. Surveillance intervals specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda for the l inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and applicable Addenda shall be applicable as follows in these Technical Specifications:

ASME Boiler and Pressure Vessel Required frequencies for code and applicable Addenda performing inservice terminology for inservice inspection and testing insoection and testina activiting activities Weekly At least once per 7 days Monthly At least once per 31 days

Quarterly or every 3 months At least once per 92 days l Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days l Yearly or annually At least once per 366 days

c. The provisions of Specification 4.0.2 are applicable to the above required frequencies for performing inservice inspection l

and testing activities.

d. Performance of the above inservice inspection and testing activities shall be in addition to other specified Surveillance Requirements.

e. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any Technical Specification.

BEAVER VALLEY - UNIT 2 3/4 0-3 Amendment No.

TABLE 3.3-6 NPF-73 ,

RADIATION MONITORING INSTRUMENTATI_OE MINIMUM CHANNELS- APPLICABLE MEASUREMENT INSTRUMENT OPERABLE MODES SETPOINT I3I RANGE ACTIOl

1. AREA MONITORS

-1 #

a. Fuel Storage Pool Area 'l (1) 575.8 mR/hr 10 to 10 mR/hr 19 (2RMF-RQ202) ,

7

b. Containment Area 2 1,2,3 &4 52.0x104 R/hr 1 to 10 R/hr 35 l (2RMR-RQ206 & 207)

-2 3

,3& & 50.476 mR/hr to 10 mR/hr 6( g

c. Control Room Area 2 1 10 46,47 (2RMC-RQ201 & 202) 5

2. PROCESS MONITORS

a. Containment

i. Gaseous Activity (Xe-133) 1 1,2,3 & 4 N/A 10-6to 10-ApCi/cc 20 RCS Leakage Detection (2RMR-RQ303B) ii. Particulate Activity (I-131) 1 1,2,3 &4 N/A 10-10 to 10- pCi/cc 20 RCS Leakage Detection (2RMR-RQ303A)

b. Fuel Building Vent

i. Gaseous Activity (Xe-133) 1 (2) 57.82x10-6pCi/cc 10-6to 10-1pCi/cc 21 (2RMF-RQ301B)

BEAVER VALLEY - UNIT 2 3/4 3-40 Amendment No.

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TABLE 3;3-6 (Continuedi. NPF-73

-RADIATION MONITORING INSTRUMENTATION MINIMUM CHANNELS APPLICABLE MEASUREMENT ,

INSTRUMENT OPERABLE MODES SETPOINT I3I RANGE ACTION I

2. PROCESS MONITORS (Continued) ii. Particulate (I-131) 1 (2) 56.70x10-9pCi/cc 10-10to 10-SpCi/cc 21 (2RMF-RQ301A)

c. Noble Gas - and Effluent Monitors

i. Supplementary Leak Collection and Release System

1) Mid Range Noble Gas 1 1,2,3&4 N.A. 10-4to 102 pCi/cc 35 l (Xe-133) (2HVS-RQ109C)

2) High Range Noble Gas 1 1,2,3&4 N.A. 10"Ito 105 Ci/cc 35 l (Xe-133) (2HVS-RQ109D) ii. Containment Purge Exhaust 1 6 $1.01x10-3 C1/cc 10-'to 10-lpCi/cc 22 (Xe-133) (2HVR-RQ104A & B) iii. Main Steam Discharge 1/SG 1,2,3&4 $3.9x10 pCi/cc-2 10-2to 10 pCi/cc 3 35 l ,

(Kr-88) (2 MSS-RQ101A,B & C)

BEAVER VALLEY - UNIT 2 3/4 3-41 Amendment No.

> NPF-73 TABLE 3.3-6 (Continued)

TABLE NOTATIONS (1) With fuel in the storage pool or building.

l l (2) With irradiated fuel in the storage pool.

(3) Above background.

.(4) During movement of irradiated fuel.

ACTION STATEMENTS l

ACTION 19 -

With the number of channels OPERABLE loss than required by the Minimum Channels OPERABLE requirement, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 20 -

With .the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.4.d.1.

ACTION 21 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the applicable ACTION requirements of Specifications 3.9.12 and 3.9.13.

ACTION 22 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.9.9.

ACTION 35 -

With the number of OPERABLE channels less than l required by the Minimum Channels OPERABLE requirement, either restore the inoperable channel (s) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or:

1) Initiate the preplanned alternate method of monitoring the appropriate parameter (s), and

2) Return the channel to OPERABLE status within 30 days, or, explain in the next Annual Radioactive Effluent Release Report why the inoperability was not corrected in a timely

manner.

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L BEAVER VALLEY --UNIT 2 3/4 3-42 Amendment No.

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NPF-73 INSTRUMENTATION SEISMIC INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.3 The seismic monitoring instrumentation shown in Table 3.3-7 shall be OPERABLE.

APPLICABILITY: At all times.

ACTION:

a. With the number of OPERABLE seismic monitoring instruments less than required by Table 3.3-7, restore the inoperable instrument (s) to OPERABLE status within 30 days.

b. With one or more seismic monitoring instruments inoperable for more than 30 days, prepare and submit a Special Report in accordance with 10 CFR 50.4 within the next 10 days l outlining the cause of the malfunction and the plans for restoring the instrument (s) to OPERABLE status.

c. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.3.1 Each of the above seismic monitoring instruments shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3-4.

4.3.3.3.2 A seismic event greater than or equal to 0.01g shall be reported to the Commission within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . Each of the above seismic monitoring instruments actuated during a seismic event greater than or equal to 0.01g shall be restored to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and a CHANNEL CALIBRATION performed within 30 days following the seismic event. Data shall be retrieved from actuated instruments and analyzed to determine the magnitude of the vibratory ground motion. A Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 within 30 days describing the magnitude, frequency spectrum and resultant effect upon facility features important to safety.

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BEAVER VALLEY - UNIT 2 3/4 3-46 Amendment No.

NPF-73 INSTRUMENTATION EXPLOSIVE GAS MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.11 The explosive gas monitoring instrumentation channels shown in Table 3.3-13 shall be OPERABLE with their Alarm / Trip Setpoints set to ensure that the limits of Specification 3.11.2.6 are not exceeded.

APPLICABILITY: As shown in Table 3.3-13.

ACTION: ,

a. With an explosive gas monitoring instrumentation channel Alarm / Trip Setpoint less conservative than required by the above specification declare the channel inoperable and take the ACTION shown in Table 3.3-13.

b. With less than the minimum number of explosive gas monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 3.3-13. Restore the inoperable instrumentation to OPERABLE status within 30 days and, if l unsuccessful, prepare and submit a Special Report in !

accordance with 10 CFR 50.4 within 30 days to explain why the inoperability was not corrected in a timely manner. !

c. The provisions of Specification 3.0.3 are not applicable.

1 SURVEILLANCE REQUIREMENTS 4.3.3.11 Each explosive gas monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, CHANNEL l CALIBRATION, and CHANNEL FUNCTIONAL TEST operations at the !

l frequencies shown in Table 4.3-13.

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r BEAVER VALLEY - UNIT 2 3/4 3-61 Amendment No.

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NPF-73 TABLE'3.3-13 (Continued) l ACTION STATEMENTS ACTION 27 -

(This ACTION is not used)

ACTION 28 -

(This ACTION is not used)

ACTION 29 -

(This ACTION is not used) l ACTION 30 -

(This ACTION is not used)

ACTION 31 -

With the number of channels OPERABLE one less than

! required by the MINIMUM Channels OPERABLE requirement, operation of this system may continue provided grab samples are taken and analyzed at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . With both channels inoperable, operation may continue provided grab samples are taken and analyzed at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months during degassing operations and at least once per 24 hours during other operations.

ACTION 32 -

(This ACTION is not used) l l

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t i BEAVER VALLEY - UNIT 2 3/4 3-63 Amendment No.

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. NPF-73 REACTOR CGOLANT SYSTEM REACTOR COOLANT PUMP-STARTUP 1

LIMITING CONDI'IION FOR OPERATION l I

1 3.4.1.6 An idle reactor coolant pump in a non-isola loop shall I not be started, unless the secondary water temperature,ted of each steam generator is less than 50 F above each of the inservice RCS cold leg !

temperatures.

APPLICABILITX: When the temperature of one or more of the non- I' isolated loop cold legs is 5 350 F.

ACTION:

With the temperature of the steam generator in the loop associated with the reactor coolant pump being started greater than or equal to l 1 50 F above the cold leg temperature of the other non-isolated loops, 1 suspend the startup of the reactor coolant pump.

SURVEILLANCE REQUIREMENTS 4.4.1.6.1 The secondary water temperature of the non-isolated steam generators shall .be determined within 10 minutes prior to starting a reactor coolant pump.

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The secondary water temperature is to be verified by direct measurement of the fluid temperature, or contact temperature readings on the steam generator secondary, or blowdown piping after purging of stagnant water within the piping.

BEAVER VALLEY - UNIT 2 3/4 4-7 Amendment No.

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NPF-73 REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)

7. Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break as specified in 4.4.5.3.c, above.

8. Tube Insnection means an inspection of the steam generator tube from the point of entry (hot leg side) completely around the U-bend to the top support to the cold leg.

9. Tube Renair refers to sleeving which is used to maintain a tube in-service or return a tube to service. This includes the removal of plugs that were installed as a corrective or preventive measure. The following sleeve designs have been found acceptable:

a) Babcock & Wilcox kinetic welded sleeves, BAW-2094P, Revision 1 including kinetic sleeve

" tooling" and installation process parameter changes.

b) Westinghouse laser welded sleeves, WCAP-13483, Revision 1.

b. The steam generator shall be determined OPERABLE after completing the corresponding actions (plug or repair all tubes exceeding the plugging or repair limit) required by Table 4.4-2.

4.4.5.5 Egnorts

a. Within 15 days following the completion of each inservice inspection of steam generator tubes, the number of tubes plugged or repaired in each steam generator shall be submitted in a Special Report in accordance with 10 CFR 50.4.

b. The complete results of the steam generator tube and sleeve inservice inspection shall be submitted in a Special Report in accordance with 10 CFR 50.4 within 12 months following the completion of the inspection. This Special Report shall include:

1. Number and extent of tubes and sleeves inspected.

BEAVER VALLEY - UNIT 2 3/4 4-14a Amendment No.

NPF-73 REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)

2. Location and percent of wall-thickness penetration for each indication of an imperfection.

3. Identification of tubes plugged or repaired.

c. Results of steam generator tube inspections which fall into Category C-3 shall be reported to the Commission pursuant to Specification 6.6 prior to resumption of plant operation. The written report shall provide a description of investigations conducted to determine the cause of the tube degradation and corrective measures taken to prevent recurrence. l i

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BEAVER VALLEY - UNIT 2 3/4 4-14b Amendment No.

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NPF-73' ,

EMERGENCY CORE COOLING SYSTEMS I 3/4.5.2 ECCS SUBSYSTEMS - Tava 2 350 F f

4 LIMITING CONDITION FOR OPERATION

[ 3.5.2 Two separate and independent ECCS subsystems shall be OPERABLE with each subsystem compriced of:

a. One OPERABLE centrifugal charging pump,

b. One OPERABLE low head safety injection pump,

c. One OPERABLE recirculation spray pump OI capable of sup lying the safety injection flow path during rec rculation phase, and

d. An OPERABLE flow path capable of taking suction from the

, refueling water storage tank on a safety injection signal

, and transferring suction to the containment sump during the j recirculation phase of operation.

l APPLICABILITY: MODES 1, 2 and 3. (2)

ACTION:

1

a. With one ECCS subsystem inoperable, restore the inoperable

. subsystem to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next~12 hours.

b. In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 l within 30 days describing the circumstances of the actuation and the total accumulated actuation cycles to date.

SURVEILLANCE REQUIREMENTS 4.5.2 Each ECCS subsystem shall be demonstrated OPERABLE:

a.1. At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the following valves are in the indicated positions with power to the valve operator control circuits disconnected by removal of 1 the plug in the lock out circuit from each circuit: )

(1) Recirculation spray pump 2RSS-P21C or 2RSS-P21D.

'(2) The provisions of Specifications 3.0.4 and 4.0.4 are not applicable for entry into MODE 3 for the centrifugal charging pumps declared inoperable pursuant to Specification 4.5.3.2 provided the centrifugal charging pumps are restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or prior to the temperature of one or more ,i l

of the RCS cold legs exceeding 375 F, whichever comes first.

1 BEAVER VALLEY - UNIT 2 3/4 5-3 Amendment No.

l

I NPF-73 EMERGENCY CORE COOLING SYSTEMS ECCS SUBSYSTEMS - Tavg < - 3 50'F LIMITING CONDITION FOR OPERATION 3.5.3 As a minimum, one ECCS subsystem comprised of the following shall be OPERABLE:

a. .One OPERABLE centrifugal charging pump,

b. One OPERABLE Low Head Safety Injection Pump, and

c. One OPERABLE recirculation spray pump

capable of supplying i the safety injection flow path during recirculation phase, and

d. An OPERABLE flow path capable of taking suction from the refueling water storage tank upon being manually realigned and transferring suction to the containment sump during the recirculation phase of operation.

APPLICABILITY: MODE 4.

ACTION:

a. With no ECCS subsystem OPERABLE because of the inoper-ability of either the centrifugal charging pump or the flow path from the refueling water storage tank, restore at least one ECCS subsystem to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in COLD SHUTDOWN within the next 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months .

-b. In the-event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 l within 30 days describing the circumstances of the actuation and the total accumulated actuation cycle to date. !

l SURVEILLANCE REQUIREMENTS I 4.5.3.1 The ECCS subsystem shall be demonstrated OPERABLE per the applicable Surveillance Requirements of 4.5.2.

4.5.3.2 All charging pumps, except the above required OPERABLE

-charging pump, shall be demonstrated inoperable ** by verifying that the control switches are placed in the PULL-TO-LOCK position and tagged within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 4 from MODE 3 prior to the temperature 325 F, of one or more of the RCS cold legs decreasing below whichever comes first, and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter. .

I

Recirculation spray pump 2RSS-P21C or 2RSS-P21D.

An inoperable pump may be energized for testing provided the j discharge of the pump has been isolated from the RCS by a closed i isolation valve with power removed from the' valve operator, or by i a manual isolation valve secured in the closed position. j i

BEAVER VALLEY - UNIT 2 3/4 5-6 Amendment No. l l

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NPF-73 PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) ,

b. Stored sources not in use - Each sealed source and fission detector shall be tested prior to use or transfer to another licensee unless tested within the previous six months. Sealed sources and fission detectors transferred without a certificate indicating the last test date shall be tested prior to being placed into use,

c. Startup sources and fission detectors - Each sealed startup source and fission detector shall be tested within 31 days prior to being subjected to core flux or installed in the core and following repair or maintenance to the source.

4.7.9.1.3 Reports - A Special Report shall be prepared and submitted in accordance with 10 CFR 50.4 on an annual basis if sealed source or l

-fission detector leakage tests reveal the presence of 2 0.005 microcuries of removable contamination.

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l BEAVER VALLEY - UNIT 2 3/4 7-21 Amendment No.

4

. i NPF-73 REFUELING OPERATIONS

! 3/4.9.8 RESIDUAL HEAT REMOVAL AND COOLANT CIRCULATION LIMITING CONDITION FOR OPERATION

. 3.9.8.1 At least one residual heat removal (RHR) loop shall be OPERABLE and in operation. l 1

APPLICABILITY: MODE 6.

ACTION:

a. With less than one residual heat removal loop in operation, i i except as provided below, suspend all operations involving an increase in the reactor decay heat load or a reduction )

i in boron concentration of the Reactor Coolant System.

Close all containment penetrations providing direct access i from the containment atmosphere to the outside atmosphere

within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . -

4

b. The residual heat removal loop may be removed from i operation for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period during the l performance of CORE ALTERATIONS in the vicinity of the reactor pressure vessel hot legs.

c. The residual heat removal loop may be removed from operation for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period during the :

performance of Ultrasonic In-service Inspection inside the I I

reactor vessel nozzles provided there is at least 23 feet of water above the top of the reactor vessel flange.

d. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 1 4.9.8.1 Verify at least one residual heat removal loop is in operation and circulating reactor coolant at:

a. A flow rate 2 1000 gpm twice per shift when the Reactor i Coolant System is in a reduced inventory condition *. l

b. A flow rate 2 3000 gpm prior to the start of and once per 1 hour during a reduction in the Reactor Coolant System boron

. concentration.

)

The reactor coolant system water level is lower than three feet

below the reactor vessel flange.

i BEAVER VALLEY - UNIT 2 3/4 9-8 Amendment No.

4

't

NPF-73 3/4.11 RADIOACTIVE EFFLUENTS 3/4.11.1 LIQUID EFFLUENTS LIQUID HOLDUP TANKS LIMITING CONDITION FOR OPERATION 3.11.1.4 The quantity of radioactive material contained in each miscellaneous temporary outside r;tioactive liquid storage tank shall be limited to less than or equal c.o 10 curies, excluding tritium and dissolved or entrained noble gases.

APPLICABILITY: At all times.

ACTION:

a. With ' the quantity. of radioactive material in any of the above tanks exceeding the above limit, immediately suspend all additions of radioactive material to the tank and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tank contents to within the limit, and

b. Submit a Special Report in accordance with 10 CFR 50.4 within 30 days and include a schedule and a description of activities planned and/or taken to reduce the contents to within-the specified limits.

c. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.11.1.4.1 The quantity of radioactive material contained in each of the above listed tanks shall be determined to be within the above limit by analyzing a representative sample of the tank's contents at least once per 7 days when radioactive materials are being added to the tank.

BEAVER VALLEY - UNIT 2 3/4 11-2 Amendment No.

1 y , - -

e l - NPF-73 RADIOACTIVE EFFLUENTS

! 3/4.11.2 GASEOUS EFFLUENTS I GASEOUS WASTE STORAGE TANKS l

3.11.2.5 The quantity of radioactivity contained in any connected group of gaseous waste storage tanks shall be limited to less than or equal to 19,000 curies noble gases (considered as Xe-133).

APPLICABILITY: At all times.

ACTION: /

L

a. With the quantity of radioactive material in any connected group of gaseous waste storage tanks exceeding the above limit, immediately suspend all additions of radioactive material to the tanks and within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months reduce the tanks' contents to within the limit, and

b. Submit a Special Report in accordance with 10 CFR 50.4 within 30 days and include a schedule and a description of activities planned and/or taken to reduce the contents to within the specified limits.

c. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS l

4.11.2.5.1 The quantity of radioactive material contained in any j connected group of gaseous waste storage tanks shall be determined to be within the abo'e limit at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when radioactive i materials are beirg added to the tanks.

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BEAVER VALLEY - UNIT 2 3/4 11-4 Amendment No.

[

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NPF-73 1 3/4.3 INSTRUMENTATION BASES 3/4.3.3.3 SEISMIC INSTRUMENTATION The OPERABILITY of the seismic instrumentation ensures that sufficient capability is available to promptly determine the j magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured response to that used in the design basis i for the facility and is consistent with the recommendations of .

Regulatory Guide 1.12, " Instrumentation for Earthquakes."

3/4.3.3.4 DELETED l

3/4.3.3.5 REMOTE SHUTDOWN INSTRUMENTATION The OPERABILITY of the remote shutdown instrumentation ensures that ;

sufficient capability is available to permit shutdown and maintenance )

of HOT STANDBY of the facility from locations outside of the control room. This capability _ is required in the event control room habitability is lost and is consistent with General Design Criteria 19 of 10 CFR 50.

3/4.3.3.6 (This' Specification number is not used).

3/4.3.3.7 CHLORINE DETECTION SYSTEMS The OPERABILITY of the chlorine detection systems ensures that sufficient capability is available to promptly detect and initiate 1 protective action in the event of an accidental chlorine release. ]

This capability is required to protect control room personnel and is consistent with the recommendations of Regulatory Guide 1.95,

< " Protection of Nuclear Power Plant Control Room Operators Against an Accidental Chlorine Release," January 1977.

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BEAVER VALLEY - UNIT 2 B 3/4 3-11 Amendment No.

l

. i NPF-73 l' 5.0 DESIGN FEATURES 5.1 SITE LOCATION The Beaver Valley Power Station Unit No. 2 is located in Shippingport Borough, Beaver County, Pennsylvania, on the south bank cf the Ohio River. The site is approximately 1 mile southeast of Midland, Pennsylvania, 5 miles east of East Liverpool, Ohio, and approximately 25 miles northwest of Pittsburgh, Pennsylvania.

5.2 REACTOR CORE 5.2.1 FUEL ASSEMBLIES The reactor shall contain 157 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy or ZIRLO fuel rods with an initial composition of natural or slightly enricbr$ uranium dioxide (UO )2 as - '

fuel material. Limited substitutions of eirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel !

assemblies shall be limited to those fuel designs that have been I analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

5.2.2 CONTROL ROD ASSEMBLIES i l

The reactor core shall contain 48 full length and no part length control rod assemblies. The full length control rod assemblies shall 1 contain a nominal 142 inches of absorber material. The nominal values of absorber material shall be 80 percent silver, 15 percent indium and 5 percent cadmium. All control rods shall be clad with stainless steel tubing.

5.3 FUEL STORAGE 5.3.1 CRITICALITY 5.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment as set forth in Specification 3.9.14;

b. K,gg $ 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in UFSAR Section 9.1; BEAVER VALLEY - UNIT 2 5-1 Amendment No.

. NPF-73 ADMINISTRATIVE CONTROLS PROCEDURES (Continued)

10) 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 Part 190.

b. Radioloaical Environmental Monitorina Proaram A program shall be provided to monitor the radiation and radionuclides in the environs of the plant. The program shall provide (1) representative measurements of !

radioactivity in the highest potential exposure pathways, and (2) verification of the accuracy of the effluent monitoring program and modeling of environmental exposure ;

pathways. The program shall (1) be contained in the ODCM, '

(2) conform to the guidance of Appendix I to 10 CFR Part 50, and (3) include the following. ;

1) Monitoring, sampling, analysis, and reporting of radiation and radionuclides in the environment in accordance with the methodology and parameters in the ODCM,

2) A Land Use Census to ensure that changes in the use of areas at and beyond the SITE BOUNDARY are identified and that modifications to the monitoring program are l made if required by the results of this census, and

3) Participation in an Interlaboratory Comparison Program to ensure that independent checks on the precision and accuracy of the measurements of radioactive materials in environmental sample matrices are performed as part of the quality assurance program for environmental monitoring.

6.9 REPORTING REOUIREMENTS The following reports shall be submitted in accordance with 10 CFR 50.4.

6.9.1 Occupational Radiation Exoosure ReDort

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

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

BEAVER VALLEY - UNIT 2 6-16 Amendment No.

._. _. .__ m._. _ . __ . _ _ _ . . _ _ _ . . _ _ _ _ __ __ _ _ . . . _

NPF-73 ADMINISTRATIVE CONTROLS REPORTING REOUIREMENTS (Continued)

A tabulation on an annual basis of the number of station, utility, l and other personnel (including contractors) receiving exposure greater than 100 mrem /yr and their associated man-rem exposure according to work and job functions (e.g., reactor operations and l surveillance, inservice inspection, routine maintenance, special maintenance (describe maintenance), waste processing, and refueling).

This tabulation supplements the requirements of 10 CFR 20.2206. The l dose assignments to various duty functions may be estimated based on pocket dosimeter, thermoluminescent dosimeter (TLD), or film badge l measurements. Small exposures totalling less than 20 percent of the individual total dose need not be accounted for. In the aggregate, at least 80 percent of the total whole body dose received from external sources should be assigned to specific major work functions.

The report shall be submitted by April 30 of each year.

6.9.2 ENTAL OPERATING REPORT

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

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

I

< The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted before May 15 of each year. The report shall include l summaries, interpretations, and analyses of trends of the results of j the Radiological Environmental Monitoring Program for the reporting period. 'The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM) and in 10 CFR Part 50, Appendix I Sections IV.B.2, IV.B.3, and IV.C.

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k l BEAVER VALLEY - UNIT 2 6-17 Amendment No.

1

NPF-73 l ADMINISTRATIVE CONTROLS t

REPORTING REQUIREMENTS (Continued) 6.9.3 ANNUAL RADIOACTIVE EFFLUENT RELEASE REPORT l

_-_ _ _ _ _ _ _ _ _ _ _ _ --_ _ NOrE ________________

A single submittal may be made for a multi-unit station. The submittal should combine those sections that are common to all units

at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

l The Annual Radioactive Effluent Release Report covering the operation l l of the unit during the previous 12 months of operation shall be l- submitted before April 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous affluents and solid waste released .

from-the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program (PCP) and ;

in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I l Section IV.B.1.

6.9.4 MOdTHLY OPERATING REPORT l Routine reports of operating statistics and shutdown experience, including documentation of all ' challenges to the pressurizer power operated relief valves or pressurizer safety valves, shall be submitted on a monthly basis no later than the 15th of each month following the calendar month covered by the report.

6.9.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each I reload cycle, or prior to any remaining portion of a reload l cycle, and shall be documented in the COLR for the following:

3.1.3.5 Shutdown Rod Insertion Limits 3.1.3.6 Control Rod Insertion Limits 3.2.1 Axial Flux Difference-constant Axial Offset Control 3.2.2 Heat Flux Hot Channel Factor-Fg(Z) 3.2.3 Nuclear Enthalpy Rise Hot Channel Factor-F"AH

b. The analytical methods used to determine the core operatirg limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

WCAP-9272-P-A, " WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 (Westinghouse Proprietary).

BEAVER VALLEY - UNIT 2 6-18 Amendment No.

i j -

NPF-73 ADMINISTRATIVE CONTROLS REPORTING REQUIREMENTS (Continued) l WCAP-10266-P-A Rev. 2/WCAP-11524-NP-A Rev. 2, "The 1981 Version of the Westinghouse ECCS Evaluation Model Using the i BASH Code," Kabadi, J. N., March 1987; including Addendum 1-A " Power Shape Sensitivity Studies" 12/87 and Addendum 2-A " BASH Methodology Improvements and Reliability Enhancements" 5/88. l l WCAP-8385, " POWER DISTRIBUTION CONTROL AND LOAD FOLLOWING

! PROCEDURES - TOPICAL REPORT." September 1974 (Westinghouse Proprietary).

l T. M. Anderson to K. Kniel (Chief of Core Performance Branch, NRC) January 31, 1980 --

Attachment:

Operation and i Safety Analysis Aspects of an Improved Load Follow Package.

NUREG-0800, Standard Review Plan, U.S. Nuclear Regulatory ,

Commission, Section 4.3, Nuclear Design, July 1981. Branch l Technical Position CPB 4.3-1, Westinghouse Constant Axial l Offset Control (CAOC) , Rev. 2, July 1981.

l WCAP-12610-P-A, " VANTAGE + Fuel Assembly Reference Core Report," April 1995 (Westinghouse Proprietary).

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as shutdown ,

margin, transient analysis limits, and accident analysis l limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

6.10 DELETED 6.11 RADIATION PROTECTION PROGRAM Procedures for personnel radiation protection shall be prepared consistent with the requirements of 10 CFR Part 20 and shall be approved, maintained and adhered to for all operations involving personnel radiation exposure.

6.12 HIGH RADIATION AREA 6.12.1 In lieu'of the " control device" or " alarm signal" required by paragraph 20.1601 of 10 CFR 20, each high radiation area in which the intensity of radiation is greater than 100 mrem /hr but less than 1000 mrem /hr shall be barricaded and conspicuously posted as a high radiation area'and entrance thereto shall be controlled by requiring BEAVER VALLEY - UNIT 2 6-19 Amendment No.

(next page is 6-22)

~ l A'ITACHMENT B-2 l l

Channe Summary. Unit 2 '

Typed Panes Editorial Channes ;

1 Operating License Page 7 No additional changes are included. I IV X Previous amendment - This page previously changed in Amendment 94, as a result, changes proposed by License Amendment Request 116 require revised page numbers as cited on this index page.

1 XIV No additional changes are included.

XV Pagination - revised the page number for High Radiation Area.

1-3 No additional changes are included.

1-6 1-7 3/40-1 3/40-2 Pagination - added due to shifting.

3/40-3 1

3/4 3-40 No additional changes are included.

l 3/4 3-41

! 3/4 3-42 3/4 3-46 3/4 3-61 3/4 3-63 3/44-7 3/4 4-14a 3/4 4-14b Pagination - added due to shifting.

3/45-3 No additional changes are included.

3/45-6 3/4 7-21 3/49-8 3/4 11-2 3/4 11-4

{. .

O Attachment B-2, Continued Tvoed Pages Editorial Channes B 3/4 3-11 Previous amendment - This page previously changed in l

Amendment 94, as a result, the changes proposed by License Amendment Request 116 on marked-up page B 3/4 3-6 has been shifted to this page.

5-1 No additional changes are included. l 6-16 6-17 Correct a typo - Marked-up Administrative Control 6.9.1.10 has been revised by removing "6.9.1.10" and "(1)" to be consistent with the proposed format in the new 6.9.2.

6-18 Correct a typo - Insert F is printed on these pages. There is no Insert G.

6-19 l

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ML20198D671

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