Text

Revs 29 & 30 to Technical Requirements Manual (TRM) for Cpses,Units 1 & 2
	ML20211G740
Person / Time
Site:	Comanche Peak
Issue date:	07/27/1999
From:	; TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:	;
Shared Package
ML20211G738	List: ML20211G730; ML20211G740;
References
	PROC-990727, NUDOCS 9909010016
	Download: ML20211G740 (215)
	v • d • e

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l TECHNICAL REQUIREMENTS MANUAL (TRM)

FOR COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 AND 2 p

okOkoocK050$$I45PDR CPSES - UNITS 1 AND 2 -TRM July 27,1999

COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

RECORD OF CHANGES TRM Revision Date of Date Date Entered by No. Revision RW Entered (Print / Type and Signature) 1 through 28 29 I30 l

4

Revisions 1 through 28 have been previously issued. See effective page list for dates of Revisions.

Note: The date of the last offective Revision can be confirmed by contacting Regulatory Affairs at 254-8g7 5331.

The Ust of Effective Pages identMes au Revisions.

l CPSES - UNITS 1 AND 2 - TRM . ROC-1 July 27,1999 )

TABLE OF CONTENTS TECHNICAL REQUIREMENTS MANUAL 11.0 USE AND APPLICATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.0-1 11.1 Definitions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 1.0-1 11.2 Logical Connectors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.0-1 11.3 Completion Times . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11.0-1 11.4 Freq uency . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 1.0-1 13.0 TECHNICAL REQUIREMENT APPLICABILITY . . . . . . . . . . . . . . . . . . . . . . . . . . ,13.0-1 13.1 REACTIVITY CONTROL SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-1 13.1.31 Boration Flow Path - Operating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-1 13.1.32 Boration Flow Path - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-5 13.1.33 Charging Pump - Operating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-7 13.1.34 Charging Pump - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-10 13.1.35 Borated Water Sources - Operating . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-12 13.1.36 Borated Water Sources - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-16 13.1.37 Rod Group Alignment Limits and Rod Position Indicator . . . . . . . . . . 13.1-19 13.1.38 Control Bank Insertion Limits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-21 13.1.39 Rod Position Indication - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . . . 13.1-22

.13.2 POWER DISTRIBUTION LIMITS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.2-1 13.2.31 Movable incore Detection System . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.2-1 13.2.32 Axial Flux Difference (AFD) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.2-3 13.2.33 Quadrant Power Tilt Ratio (QPTR) Alarm . . . . . . . . . . . . . . . . . . . . . 13.2-5 13.3 INSTRUM ENTATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.3-1 13.3.1 Reactor Trip System (RTS) Instrumentation Response Times . . . . . . 13.3-1 13.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation Response Times . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.3-4 13.3.5 Loss of Power (LOP) Diesel Generator (DG)

Start Instrumentation Response Times . . . . . . . . . . . . . . . . . . . . . . . 13.3-11 13.3.31 Seismic Instrumentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.3-13 13.3.32 Source Range Neutron Flux . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.3-20 13.3.33 Turbine Overspeed Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.3-22 13.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.4-1 13.4.14 Reactor Coolant System Pressure isolation Valves . . . . . . . . . . . . . . 13.4-1 13.4.31 Loose Part Detection System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.4-2 13.4.32 Pressurizer Power Operated Relief Valves (PORVs) . . . . . . . . . . . . . 13.4-4 13.4.33 Reactor Coolant System (RCS) Chemistry . . . . . . . . . . . . . . . . . . . . 13.4-5 13.4.34 Pressurizer . . . . . . . . . . . . . . . . . . . . . . . . '. . . . . . . . . . . . . . . . . . . . . 13.4-9 13.4.35 Reactor Coolant System (RCS) Vent Specification . . . . . . . . . . . . . . 13.4-11 CPSES - UNITS 1 AND 2 -TRM i July 27,1999

TABLE OF CONTENTS (continusi) 13.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . . . . . . . . . . . . . . . 13.5-1 13.5.31 ECCS - Containment Debris . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.5-1 13.5.32 ECCS - Pump Line Flow Rates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.5-3 13.6 CONTAINMENT SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.6-1 13.6.3 Containment isolation Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.6-1 13.6.6 Containment Spray System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.6-15 13.6.31 Hydrogen Recombiners - Instrumentation and Control Circuits . . . . . 13.6-16 13.7 PLANT SYSTEM S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.7-1 13.7.31 Steam Generator Atmospheric Relief Valve (ARV)-

Air Accumulator Tank . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 3.7- 1 13.7.32 Steam Generator Pressure / Temperature Limitation . . . . . . . . . . . . . 13.7-2 13.7.33 U!timate Heat Sink - Sediment and Safe Shutdown impoundment (SS I) D a m . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.7-4 13.7.34 Flood Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.7-6 13.7.35 S n u b be rs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.7-9 13.7.36 Area Temperature Monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.7-11 13.7.37 Safety Chilled Water System -

Electrical Switchgear Area Emergency Fan Coil Units . . . . . . . . 13.7-15 13.7.38 Main Feedwater Isolation Valve Pressurefi'emperature Limit . . . . . . 13.7-16 13.7.39 Tomado Missile Shields . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.7-18 13.7.40 Feedwater Control Valves (FCVs) and Associated Bypass Valves . . 13.7-30 13.8 ELECTRICAL POWER SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.8-1 13.8.31 AC Sources (Diesel Generator Requirements) . . . . . . . . . . . . . . . . . . 13.8-1 13.8.32 Containment Penetration Conductor Overcurrent Protection Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.8-4 13.9 REFUELING OPERATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.9-1 13.9.31 De ca y Time . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.9-1 13.9.32 Refueling Operations / Communications . . . . . . . . . . . . . . . . . . . . . 13.9-2 13.9.33 Refueling Machine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.9-3 13.9.34 Refueling - Crane Travel - Spent Fuel Storage Areas . . . . . . . . . . . . 13.9-5 13.9.35 Water Level, Reactor Vessel, Control Rods . . . . . . . . . . . . . . . . . . . . 13.9-6 13.9.36 Fuel Storage Area Water Level . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.9-7 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING P RO G RAM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.10-1 13.10.31 Explosive Gas Monitoring Instrumentation . . . . . . . . . . . . . . . . . . . . . 13.10-1 13.10.32 Gas Storage Tanks . . . . . . . . . . . . . . . . . g . . . . . . . . . . . . . . . . . . . . . 13.10-5 13.10.33 Liquid Holdup Tanks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.10-7 13.10.34 Explosive Gas Mixture . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13.10-9 15.0 ADMINISTRATIVE CONTROLS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15.0-1 15.5 Programs and Manuals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15.0-1 15.5.17 Technical Requirements Manual (TRM) . . . . . . . . . . . . . . . . . . . . . . . 15.0-1 15.5.31 Snubber Augmented Insen/ ice Inspection Program . . . . . . . . . . . . . . 15.0-3 CPSES - UNITS 1 AND 2 - TRM il July 27,1999

Use and Application TR 11.0 11.0 USE AND APPLICATION NOTE For the purpose of the Technical Requirements, the Technical Requirements Manual terms specified below should be considered synonymous with the listed Technical Speedication terms:

Technical Reauirement Technical Specifications Technical Requirement (TR) Technical Specifications (TS) or Specification (s)

Technical Requirement Surveillance Requirement (SR)

Surveillance (TRS) 11.1 Definitions The definitions contained in the Technical Specifications Section 1.1, " Definitions" apply to the Technical Requirements contained in this manual.

11.2 Logical Connectors The guidance provided for the use and application of logical connectors in Section 1.2,

" Logical Connectors" of the Technical Specifications is applicable to the Technical Requirements contained in this manual.

11.3 Comoletion Times The guidance provided for the use and application of Completion Times in Section 1.3,

" Completion Times" of the Technical Specifications is applicable to the Technical Requirements contained in this manual.

11.4 Emquency The guidance provided for ths use and application of Frequency Requirements in Section 1.4, " Frequency" of the Technical Specifications is applicable to the Technical Requirements contained in this manual.

i CPSES - UNITS 1 AND 2 -TRM 11.0-1 Revision 29 -July 27,1999 l

TR Applicability 13.0 13.0 Technical Requirement (TR) LIMITING CONDITION FOR OPERATION (TR LCO) and TECHNICAL REQUIREMENT SURVEILLANCE (TRS) APPLICABILITY The guidance provided for the use and application of LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY in Section 3.0, " LIMITING CONDITION FOR OPERATION (LCO)

APPLICABILITY" of the Technical Specifications is applicable to the Technical Requirements contained in this manual, except as noted below.

The guidance provided for the use and application of SURVEILLANCE REQUIREMENT (SR)

APPLICABILITY in Section 3.0, " SURVEILLANCE REQUIREMENT (SR) APPLICAEILITY" of the Technical Specifications is applicable to the Technical Requirements Surveillance (TRS) contained in this manual.

A cross reference between Section 13.0 of the Technical Requirements Manual and Section 3.0 of the Technical Specifications is as follows:

Technical Reauirement Section Technical Soecinsi;on Section TR LCO 13.0.1 LCO 3.0.1 TR LCO 13.0.2 LCO 3.0.2 N/A (See Note 1 below) LCO 3.0.3 TR LCO 13.0.4 LCO 3.0.4 TR LCO 13.0.5 LCO 3.0.5 N/A (See Note 2 below) LCO 3.0.6 TR LCO 13.0.7 LCO 3.0.7 TRS 13.0.1 SR 3.0.1 TRS 13.0.2 SR 3.0.2 -

TRS 13.0.3 SR 3.0.3 TRS 13.0.4 SR 3.0.4 (continued)

CPSES - UNITS 1 AND 2 -TRM 13.0-1 Revision 29 - July 27,1999

c TR Applicability 13.0 13.0 TR APPLICABILITY (continued)

NOTES

1. As part of the conversion to the improved Technical Specifications in July 1999, certain Technical Specifications were relocated to the Improved Technical Requirements Manual. The shutdown requirements (similar to TS LCO 3.0.3) for each Technical Requirement are in three categories: (1) remains with the parent Technical Specification by direct reference to the Technical Specifications, (2) relocated by incorporation into the individual Technical Requirements (i.e. additional conditions were added), or (3) not applicable (i.e. all possible conditions were addressed within the TR LCO). Therefore, the TRM has no corresponding LCO 3.0.3 similar to the TS LCO 3.0.3.

When a Required Action and Completion Time is not met and no associated Required Action is provided, the condition will be documented in the corrective action program (e.g. the report required by Condition B.3 of TR 13.3.31 is not submitted within 14 days).

2. Technical Specification LCO 3.0.6 provides entry into the Safety Function Determination Program (SFDP). The SFDP is not directly applied to the Technical Requirements Manual. However, TRM requirements may result in inoperable items which either support a parent Technical Specification (e.g. TR 13.3.1, " Reactor Trip System (RTS) instrumentation Response Times.") or provide directions to declare the associated item inoperable and enter the applicable Technical Specification (e.g. TR 13.7.31, " Steam Generator Atmospheric Relief Valve (ARV)- Air Accumulator Tank").

CPSES - UNITS 1 AND 2 - TRM 13.0-2 Revision 29 - July 27,1999

I Boration Flow Path - Operating TR 13.1.31 13.1 REACTIVITY CONTROL SYSTEMS TR 13.1.31 Boration Flow Path - Operating TR LCO 13,1.31 At least two of the following three boron injection flow paths shall be OPERABLE:

a. The flow path from the boric acid storage tanks via either a boric acid transfer pump or a gravity feed connection and a charging pump to the Reactor Coolant System (RCS), and

b. Two flow paths from the refueling water storage tank via centrifugal charging pumps to the RCS.

APPLICABILITY: MODES 1,2,3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Only one of the above A.1 Restore at least two 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required boron injection boron injection flow paths flow paths to the RCS to the RCS to OPERABLE. OPERABLE status.

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.1-1 Revision 29 - July 27,1999

Boration Flow Path - Operating TR 13.1.31 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Tirne of Condition A not M met.

B.2 Be borated to a 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SHUTDOWN MARGIN equivalent to at least the value specified in the COLR at 200 F.

1 M

I B.3 Restore at least two flow 7 days,6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months -

paths to OPERABLE status.

C. Required Actions and C.1 Be in MODE 5. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months associated Completion Times of Condition B not met.

(continued) 1 1

CPSES - UNITS 1 AND 2 -TRM 13.1-2 Revision 29 - July 27,1999

I 4

Boration Flow Path - Operating TR 13.1.31 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. No required boron injection D.1 Action shall be initiated to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months l flow paths operable. place the unit in a lower MODE.

ABD.

D.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND D.3 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months AND D.4 Be in MODE 5. 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months i

I CPSES - UNITS I AND 2 - TRM 13.1-3 Revision 29 - July 27,1999 I

j

Boration Flow Path - Operating TR 13.1.31 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.1.31.1 For the required flow paths verify that the 7 days temperature of the flow path from the boric acid storage tanks is greater than or equal to 65'F when it is a required water source.

TRS 13.1.31.2 For the required flow paths verify that each valve 31 days (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

TRS 13.1.31.3 Verify that the flow path required by Technical 18 months Requirement 13.1.31a delivers at least 30 gpm to the RCS.

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CPSES - UNITS 1 AND 2 -TRM 13.1-4 Revision 29 - July 27,1999

Boration Flow Path - Shutdown TR 13.1.32 13.1 REACTIVITY CONTROL SYSTEMS TR 13.1.32 Boration Flow Path - Shutdown TR LCO 13.1.32 As a minimum, one of the following boron injection flow paths shall be OPERABLE and capable of being powered from an OPERABLE .

emergency power source:

a. A flow path from the boric acid storage tanks via either a boric acid transfer pump or a gravity feed connection and a charging pump to the Reactor Coolant System if the boric acid storage tank in Technical Requirement 13.1.36a. is OPERABLE, or

b. The flow path fr'om the refueling water storage tank via a centnfugal charging pump to the Reactor Coolant System if the refueling water storage tank in Technical Requirement 13.1.36b.

is OPERABLE.

APPLICABILITY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. None of the above flow A.1 Suspend all operations immediately paths OPERABLE and involving CORE capable of being powered ALTERATIONS or from an OPERABLE positive reactivity emergency power source. changes.

CPSES - UNITS 1 AND 2 - TRM 13.1-5 Revision 29 - July 27,1999

Boration Flow Path - Shutdown TR 13.1.32 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.1.32.1 For the required flow path, verify that the temperature 7 days of the flow path is greater than or equal to 65'F when a flow path from the boric acid storage tanks is used.

TRS 13.1.32.2 For the required flow path, verify that each valve 31 days (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

)

CPSES - UNITS 1 AND 2-TRM 13.1-6 Revision 29 - July 27,1999

Charging Pump - Operating TR 13.1.33 13.1. REACTMTY CONTROL SYSTEMS TR 13.1.33 Charging Pump - Operating LCO 13.1.33 At least two centrifugal charging pumps shall be OPERABLE.

APPLICABILITY: MODES 1,2,3, and 4.

NOTES

1. The provisions of Technical Requirements TR LCO 13.0.4 and TRS 13.0.4 are not applicable for entry into MODES 3 and 4 for the charging pump declared inoperable pursuant to TS 3.4.12 provided the charging pump is restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 3 or prior to the temperature of one or more of the RCS cold legs exceeding 375'F, whichever comes first.

2. In MODE 4 the positive displacement pump may be used in lieu of one of the required centrifugal charging pumps.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One of the above required A.1 Restore at least two 7 days charging pumps inoperable, charging pumps to OPERABLE status.

(continued) l

, i

( l I

CPSES - UNITS 1 AND 2 -TRM 13.1-7 Revision 29 -July 27,1999

Charging Pump - Operating TR 13.1.33 1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not M met.

B.2 Be borated to a 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SHUTDOWN MARGIN ,

equivalent to at least the value specified in the COLR at 200T.

M B.3 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. No required centrifugal C.1 Action shall be initiated to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months charging pumps operable, place the unit in a lower MODE.

M C.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months l

M !

C.3 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months M

C.4 Be in MODE 5. 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months CPSES - UNITS 1 AND 2 - TRM 13.1-6 Revision 29 - July 27,1999

Charging Pump - Operating TR 13.1.33 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY.

TRS 13.1.33.1 Demonstrate the required centnfugal charging in accordance with pump (s) OPERABLE by testing in accordance with the Inservice the Inservice Testing Plan. Testing Plan TRS 13.1.33.2

)

Demonstrate the required positive displacement in accordance with charging pump OPERABLE by performing TRS 13.1.31.3 TRS 13.1.31.3.

l i

l l

J l

CPSES - UNITS 1 AND 2-TRM 13.1-9 Revision 29 -July 27,1999

Charging Pump - Shutdown TR 13.1.34 13.1 REACTMTY CONTROL SYSTEMS TR 13.1.34 Charging Pump - Shutdown TR LCO 13.1.34 At least one charging pump in the boron injection flow path required by Technical Requirement 13.1.32 shall be OPERABLE and capable of being powered from an OPERABLE emergency power source.

APPLICABILITY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No charging pump A.1 Suspend all operations immediately OPERABLE and capable of involving CORE being powered from an ALTERATIONS or OPERABLE emergency positive reactivity power source. changes.

I CPSES - UNITS 1 AND 2-TRM 13.1-10 Revision 29 -July 27,1999

Chirging Pump - Shutdown TR 13.1.34 SURVEILLANCE REQUIREMENTS SURVEILL.ANCE FREQUENCY TRS 13.1.34.1 Demonstrate the above required positive 92 days displacement charging pump is OPERABLE by verifying that the flow path required by Technical Requirement 13.1.32a. is capable of delivering at least 30 gpm to the RCS.

~

TRS 13.1.34.2 Demonstrate the above required centrifugal charging In accordance with pump is OPERABLE by verifying, on recirculation the Inservice flow, that a differential pressure across the pump of Testing Program greater than or equal to 2370 psid is developed.

i i

CPSES - UNITS 1 AND 2 -TRM 13.1-11 Revision 29 -July 27,1999

Borated Water Sources - Operating l TR 13.1.35 I

13.1 REACTMTY CONTROL SYSTEMS l

TR 13.1.35 Borated Water Sources - Operating l I

LCO 13.1.35 As a minimum, the following borated water source (s) shall be l OPERABLE as required by TR 13.1.31:

a. A boric acid storage tank,

b. The refueling water storage tank (RWST). !

l l

APPLICABILITY: MODES 1,2,3, and 4.

1 ACTIONS !

CONDITION REQUIRED ACTION COMPLETION TIME A. Boric acid storage tank A.1 Restore boric acid 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ;

inoperable when used as storage tank to one of the required borated OPERABLE status. 4 water sources per TR 13.1.31.

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.1-12 Revision 29 - July 27,1999

Bor:ted Wat:r Sources - Operating TR 13.1.35 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not ANQ met.

B.2 Be borated to a 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SHUTDOWN MARGIN equivalent to at least the value specified in the COLR at 200 F.

AND B.3 Restore boric acid 7 days,6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

storage tank to l OPERABLE status.

l C. Required Actions and C.1 Be in MODE 5. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months associated Completion Times of Condition B not met.

D. RWSTinoperable. D.1 Enter the applicable in accordance with Condition (s) of TS 3.5.4. the applicable TS LCO (continued)

CPSES - UNITS 1 AND 2 - TRM 13.1-13 Revision 29 - July 27,1999

Bortted Wat:r Sources - Operating TR 13.1.35 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. No required borated water E.1 Action shall be initiated to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ,

source operable. place the unit in a lower MODE.

AND E.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AM2 E.3 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months AND E.4 Be in MODE 5. 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months CPSES - UNITS 1 AND 2-TRM 13.1-14 Revision 29 -July 27,1999

Borated Water Sources - Operating TR 13.1.35 SURVEILLANCE REQUIREMENTS NOTE TRS 13.1.35.1,TRS 13.1.35.2, and TRS 13.1.35.3 are only required to be met when the boric acid storage tank is one of the required borated water sources.

SURVEILLANCE FREQUENCY TRS 13.1.35.1 Verify the boron concentration of the boric acid 7 days storage tank has a minimum boron concentration of 7000 ppm.

TRS 13.1.35.2 Verify a minimum indicated borated water level of 7 days 50% when using the boric acid storage tank.

TRS 13.1.35.3 Verify the boric acid storage tank has a minimum 7 days solution temperature of 65'F.

i TRS 13.1.35.4 Perform RWST Technical Specification SR 3.5.4.1, in accordance with SR 3.5.4.2, and SR 3.5.4.3. the applicable TS SRs l

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l CPSES - UNITS 1 AND 2 -TRM 13.1-15 Revision 29 - July 27,1999

Borated Water Sources - Shutdown TR 13.1.36 13.1 REACTIVITY CONTROL SYSTEMS TR 13.1.36 Borated Water Sources - Shutdown TR LCO 13.1.36 As a minimum, one of the following borated water sources shall be OPERABLE:

a. A boric acid storage tank, or

b. The refueling water storage tank (RWST).

APPLICABILi'IY: MODES 5 and 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No borated water source A.1 Suspend all operations immediately OPERABLE. Involving CORE ALTERATIONS or positive reactivity changes.

CPSES - UNITS 1 AND 2 - TRM 13.1-16 Revision 29 - July 27,1999

Borated Wat;r Sources - Shutdown TR 13.1.36 SURVEILI.ANCE REQUIREMENTS NOTES

1. TRS 13.1.36.1, TRS 13.1.36.2, TRS 13.1.36.3, and TRS 13.1.36.4 are only required to be met when the boric acid storage tank is the required borated water source.

2. TRS 13.1.36.5, TRS 13.1.36.6, and TRS 13.1.36.7 are only required to be met when the RWST is the required borated water source.

SURVEILLANCE FREQUENCY TRS 13.1.36.1 Verify the boron concentration of the boric acid 7 days storage tank has a minimum boron concentration of 7000 ppm.

TRS 13.1.36.2 Verify a minimum indicated borated water level of 7 days 10% when using the boric acid pump from the boric acid storage tank.

TRS 13.1.36.3 Verify a minimum indicated borated water level of 7 days 20% when using gravity feed from the boric acid storage tank.

I TRS 13.1.36.4 Verify the boric acid storage tank has a minimum 7 days solution temperature of 65"F.

TRS 13.1.36.5 Verify the boron concentration of the RWST has a 7 days minimum boron concentration of 2400 ppm.

(continued)

CPSES - UNITS 1 AND 2 -TRM 13.1-17 Revision 29 - July 27,1999

Bortted Water Sources - Shutdown TR 13.1.36 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.1.36.6 Verify a minimum indicated borated water level of 7 days 24% when using the RWST.

TRS 13.1.36.7 NOTES Only required to be performed if the RSWT is the source of borated water and the outside temperature is less than 40*F Verify the RWST has a minimum solution 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months temperature of 40*F.

1 CPSES - UNITS 1 AND 2 -TRM 13.1-18 Revision 29 -July 27,1999

1 Rod Group Alignment Limits end Rod Position Indicator 1 TR 13.1.37 (

13.1 REACTIVITY CONTROL SYSTEMS TR 13.1.37 Rod Group Alignment Limits and Rod Position Indicator i

TR LCO 13.1.37 The Rod Position Deviation Monitor shall be OPERABLE.

APPLICABILITY: MODES 1 and 2. l l

ACTIONS l

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rods not A.1 Enter the applicable immediately within alignment limits. Condition (s) of TS 3.1.4 l I

B. One or more rod position B.1 Enter the applicable immediately indications inoperable. Condition (s) of TS 3.1.7 l

l CPSES - UNITS 1 AND 2 - TRM 13.1-19 Revision 29 - July 27,1999

Rod Group Alignment Limits and Rod Position Indicator TR 13.1.37 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY ,

I i

TRS 13.1.37.1 NOTE Only required to be performed when the rod position deviation monitor is discovered to be inoperable.

Verify individual rod positions to be within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months alignment limit perTechnical Specification SR 3.1.4.1.

TRS 13.1.37.2 NOTE Only required to be performed when the rod position deviation monitor is discovered to be inoperable.

Verify the OPERABILITY of the Demand Position 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Indication System and the Digital Rod Position Indication System (DPRI) while performing TRS 13.1.37.1 by verifying that the Demand Position Indication System and the DRPI, for each rod, agrees within 12 steps.

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i CPSES - UNITS 1 AND 2 -TRM 13.1-20 Revision 29 - July 27,1999

Control BSnk Insertion Limits TR 13.1.38 13.1 REACTIVITY CONTROL SYSTEMS TR 13.1.38 Control Bank Insertion Limits l TR LCO 13.1.38 The Control Bank Insertion Umit Monitor shall be OPERABLE.

APPLICABILITY: MODE 1, MODE 2 with k, > 1.0 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Controlbankinsertionlimits A.1 Enter the applicable immediately not met. Condition (s) of TS 3.1.6.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.1.38.1 NOTE Only reouired to be performed when the rod insertion limit monitor is discovered to be inoperable.

Verify the position of each control bank to be within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the insertion limit by verifying the individual rod positions per Technical Specification SR 3.1.6.2.

CPSES - UNITS 1 AND 2- TRM 13.1-21 Revision 29 - July 27,1999

o Rod Position Indication - Shutdown TR 13.1.39

\

13.1 REACTIVITY CONTROL SYSTEMS TR 13.1.39 Rod Position Indication - Shutdown {

TR LCO 13.1.39 One digital rod position indicator (excluding demand position indication) shall be OPERABLE and capable of determining the control rod position ,

within i 12 steps for each shutdown or control rod not fully inserted.

APPLICABILITY: MODES 3,4 and 5 NOTES

1. With the Rod Control System in a condition capable of rod withdrawal.

2. This requirement is not applicable during the performance of individual shutdown and control rod drop time measurements provided

a. only one shutdown or control bank is withdrawn from the fully inserted position at a time, and

b. DRPI is OPERABLE during the withdrawal of the rods.

However, this requirement is not applicable during the initial calibration of the Digital Position Indication System provided:

1. Keff is maintained less than or equal to 0.95, and

2. only one shutdown or control rod bank is withdrawn from the fully inserted position at one time.

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CPSES - UNITS 1 AND 2 -TRM 13.1-22 Revision 29 -July 27,1999 i

i

Rod Position Indication - Shutdown TR 13.1.39 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the above A.1 Place the Rod Control Immediately required rod position System in a condition indicator (s) OPERABLE. incapable of rod withdrawal.

B. Required Action and B.1 Action shall be initiated to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time of place the unit in a lower Condition A not met. MODE.

AND B.2 Be in MODE 4 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND B.3 Be in MODE 5 31 hours3.587963e-4 days 0.00861 hours 5.125661e-5 weeks 1.17955e-5 months CPSES - UNITS 1 AND 2 - TRM 13.1-23 Revision 29 - July 27,1999

)

Rod Position Indication - Shutdown TR 13.1.39 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.1.39.1 Perform Technical Specification SR 3.1.7.1 for each In accordance with required DRPl. Technical Specification SR 3.1.7.1 TRS 13.1.39.2 NOTE Only required to be met during the withdrawal of rods as part of Rod Drop time measurements.

Verify the required DRPI and Demand Position 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Indication System agree:

a. Within 12 steps when the rods are stationary, and

b. Within 24 steps during rod motion.

CPSES - UNITS 1 AND 2 -TRM 13.1-24 Revision 29 - July 27,1999

MovCble incore Detection System TR 13.2.31 13.2 POWER DISTRIBUTION LIMITS TR 13.2.31 Moveable inmre Detection System TR LCO 13.2.31 The Movable incore Detection System shall be OPERABLE with:

a. At least 75% of the detector thimbles,

b. A minimum of two detector thimbles per core quadrant, and

c. Sufficient movable detectors, drive, and readout equipment to map these thimbles.

APPLICABILIT(: When the Movable incore Detection System is used for:

a. Recalibration of the Excore Neutron Flux Detection System, or

b. Monitoring the QUADRANT POWER TILT RATIO, or

c. Measurement of Fh u Fo(Z) and Fy.

- ACTIONS NOTE The provisions of TR LCO 13.0.4 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME

, A. One or more required A.1 Restore the movable Prior to using the movable incore detection incore detection system system for the above system component (s) to OPERABLE status. listed monitoring and inoperable. calibration functions.

CPSES - UNITS 1 AND 2 -TRM 13.2-1 Revision 29 -July 27,1999 4

Movrble incore Detection System TR 13.2.31 i

SURVEILLANCE REQUIREMENTS l SURVEILLANCE FREQUENCY TRS 13.2.31.1 Verify Movable incore Detection System Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABILITY by irradiating each required detector prior to using the and determining the acceptability of its voltage curve. system for the above listed monitoring and .

I calibration functions.

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CPSES - UNITS 1 AND 2 -TRM 13,2-2 Revision 29 - July 27,1999

L-Axial Flux Difference TR 13.2.32 13.2 POWER DISTRIBUTION LIMITS TR 13.2.32 Axial Flux Difference (AFD)

TR LCO 13.2.32 The Axial Flux Difference (AFD) Monitor Alarm shall be OPERABLE.

i APPLICABILITY: MODE 1 with THERMAL POWER > 15% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits of TS A.1 Enter applicable immediately 3.2.3. Condition (s) in TS 3.2.3.

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CPSES-UNITS 1 AND 2-TRM 13.2-3 Revision 29 -July 27,1999

Axial Flux Diff;rence TR 13.2.32 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.2.32.1 NOTE -

1. Only required to be performed when the AFD Monitor Alarm is determined to be inoperable and for the first 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after restoring to OPERABLE status.

2. Logged values shall be assumed to exist during interval preceding each logging.

Monitor and log AFD to verify AFD is within limits for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for the first each OPERABLE excore channel. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months that the AFD Monitor Alarm is inoperable M

30 minutes when AFD Monitor Alarm is inoperable for

> 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months M

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for the first 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after {

restoring the AFD Monitor Alarm to OPERABLE status.

CPSES - UNITS 1 AND 2 - TRM 13.2-4 Revision 29 - July 27,1999

QPTR Alarm 13.2.33 13.2 POWER DISTRIBUTION LIMITS TR 13.2.33 Quadrant Power Tilt Ratio (OPTR) Alarm TR LCO 13.2.33 The Quadrant Power Tilt Ratio (QPTR) Alarm shall be OPERABLE.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RATED THERMAL POWER.

1 ACTIONS l CONDITION REQUIRED ACTION COMPLETION TIME A. QPTR not within limit. A.1 Enter the applicable immediately Condition (s) of TS 3.2.4.

I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.2.33.1 NOTE Only required to be performed when the OPTR alarm is determined to be inoperable.

Verify QPTR is within limit by calculation per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Technical Specification SR 3.2.4.1.

CPSES - UNITS 1 AND 2 -TRM 13.2-5 Revision 29 - July 27,1999

RTS Instrumentation Response Times I

TR 13.3.1 13.3 INSTRUMENTATION TR 13.3.1 Reactor Trip System (RTS) Instrumentation Response Times l Note: This Technical Requirement contains the listing of Reactor Trip System instrumentation Response Time limits associated with Technical Specification SR 3.3.1.16 and the applicable Functions in Technical Speerfication Table 3.3.1-1.

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CPSES - UNITS 1 AND 2 -TRM 13.3-1 Revision 29 -July 27,1999

RTS In:trumentation Response Times TR 13.3.1 Table 13.3.1-1 (Page 1 of 2)

Reactor Trip System (RTS) Instrumentation Response Time Limits INITIATION SIGNAL RESPONSE TIME IN SECONDS

1. Manual Reactor Trip NA

2. Power Range Neutron Flux

a. High Setpoint 50.5I 'I

b. Low Setpoint 50.5 N j

3. Power Range Neutron Flux High Positive Rate NA

4. Intermediate Range Neutron Flux NA

5. Source Range Neutron Flux NA )

6. Overtemperature N-16 58(1,2)

7. Overpower N-16 52 III

8. Pressurizer Pressure

a. Pressurtzer Pressure Low 52

b. Pressurizer Pressure High 52

9. Pressurizer Water Level High NA

10. Reactor Coolant Flow Low 51 9) 1 1

11. Not Used NA (continued)

(1) Neutron / gamma detectors are exempt from response time testing. Response time of the neutron / gamma flux signal portion of the channel shall be measured from detector output or input of first electronic component in a channel. .

(2) includes the thermal well response time.

(3) includes Single Loop (Above P-8) and Two Loops (Above P 7 and Below P-8).

CPSES - UNITS 1 AND 2 - TRM 13.3-2 Revision 29 - July 27,1999

l RTS Instrumentation Response Times TR 13.3.1 Table 13.3.1-1 (Page 2 of 2)

Reactor Trip System (RTS) Instrumentation Response Time Limits i

INITIATION SIGNAL RESPONSE TIME IN SECONDS

12. Undervoltage - Reactor Coolant Pumps 51.1(4)

13. Underfrequency - Reactor Coo. ant Pumps 5 0.6 ,

14. Steam Generator Water Level Low-Low 12 l

l Not Used NA 15.

16. Turbine Trip

a. Low Fluid Oil Pressure NA l

! b. Turbine Stop Valve Closure NA 1

17. Safety injection input from ESFAS NA

18. Reactor Trip System Interlocks l

a. Intermediate Range Neutron Flux, P-6 NA

b. Low Power Reactor Trips Block, P-7 NA

c. Power Range Neutron Flux, P-8 NA

d. Power Range Neutron Flux, P-9 NA

e. Power Range Neutron Flux, P-10 NA

f. Turbine First Stage Pressure, P-13 NA 1

19. ReactorTrip Breakers NA l

20. Reactor Trip Breaker Undervoltage and Shunt Trip Mechanisms NA

21. Automatic Trip Logic NA

~

(4) An additional 0.4 seconds maximum calculated voltage decay time from the opening of RCP breaker until voltage reaches the undervoltage set-point provides an overall time s 1.5 seconds.

CPSES - UNITS 1 AND 2 -TRM 13.3-3 Revision 29 - July 27,1999 l

ESFAS Instrumentation Response Times TR 13.3.2 13.3 INSTRUMENTATION TR 13.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation Response Times Note: This Technical Requirement contains the listing of ESFAS Instrumentation Response Time limits associated with Technical Specification SR 3.3.2.10 and the applicable functions in Technical Specification Table 3.3.2-1.

CPSES - UNITS 1 AND 2 -TRM 13.3-4 Revision 29 - July 27,1999 l

I ESFAS Instrumentation Response Times TR 13.3.2 Table 13.3.2-1 (Page 1 of 6)

Engmeered Safety Features Actuation System Instrumentation Response Time Limits FUNCTIONAL UNIT AND INITIATION SIGNAL RESPONSE TIME IN SECONDS

1. Safety injection

a. ManualInitiation NA

b. Automatic Actuation Logic and Actuation Relays N.A

c. Contamment Pressure High 1

1. ECCS s 27(1.5,8)/27(4,6,8)

2. ReactorTrip 5 2(15)

3. Containment Ventilation Isolation NA

4. Station Servhe Water NA

5. Component Cooling Water NA

6. EssentialVentilation Systems NA

7. Emergency Diesel Generator Operation 5 12

8. Control Room Emergency Recirculebon NA

9. Containment Spray II 5 32 (continued)

(1) includes Diesel Generator starting delay.

(4) Diesel generator starting delay is Dat included. Includes centrifugal charging pumps only.

(5) Sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close)is DD.t included.

(6) Includes sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close).

(7) includes Diesel Generator starting delay. Includes containment spray pumps only.

(8) RHR mini-flow valves are DQ1 included (15) The response time of less than or equal to 2 seconds is applicable for MODES 1 and 2 and is measured I to the loss of stationary gripper coil only. The response time is not applicable (NA) for MODES 3 and 4. i l

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CPSES - UNITS 1 AND 2 -TRM 13.3-5 Revision 29 - July 27,1999

ESFAS Instrumentafon Response Times TR 13.3.2 Table 13.3.21 (Page 2 of 6)

Engineered Safety Features Actuation System instrumentation Response Time Limits FUNCTIONAL UNIT AND INITIATION SIGNAL RESPONSE TIME IN SECONDS

1. Safety injection (continued)

d. Pressurtzer Pressure Low

1. ECCS 5 27(1.5.8)/27(4.6.8)

2. Reactor Trip 52(5)

3. Containment Ventilation Isolation 1 5 (16)

4. Station Service Water NA

5. Component Cooling Water NA

6. Essential Ventilation Systems NA

7. Emergency Diesel Generator Operation 1 12

8. Control Room Emargency Recirculation NA

9. Containment Spray NA (continued)

(1) Includes Diesel Generator starting delay.

(4) Diesel generator starting delay is D9.1 included, includes centrifugal charging pumps only.

(5) Sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close)is D9.1 included.

(6) includes sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close).

(8) RHR mini-flow valves are Dglincluded.

(15) The response time of less than or equal to 2 seconds is applicable for MODES 1 and 2 and is measurod to the loss of stationary gripper coil only. The response time is not applicable (NA) for MODES 3 and 4.

(16) includes containment pressure relief valves only.

CPSES - UNITS 1 AND 2 - TRM 13.3,6 Revision 29 - July 27,1999

ESFAS Instrumentation R2sponse Times TR 13.3.2 Table 13.32-1 (Page 3 of 6)

Engineered Safety Features Actuation System instrumentation Response Time Limits FUNCTIONAL UNIT AND INITIATION SIGNAL RESPONSE TIME IN SECONDS

1. Safety injection (continued)

e. Steam Une Pressure Low 1 l

1. ECCS s 37(3.6.8)/27(4.6,8)

2. Reactor Trip 5 2 (15)

3. Containment Ventilation Isolation NA l i

4. Station Service Water NA

5. Component Cooling Water NA

6. EssentialVentilation Systems NA

7. Emergency Diesel Generator Operation 5 12

8. Control Room Emergency Recirculation NA

9. Containment Spray NA i 1

I (continued) l l

(3) includes Diesel Generator starting delay, includes centrifugal charging pumps only.

(4) Diesel generator starting delay is Dglincluded includes centrifugal charging pumps only. J (6) includes sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, j then VCT valves close).

(8) RHR mini-flow valves are Dglincluded.

(15) The response time of less than or equal to 2 seconds is applicable for MODES 1 and 2 and is measured to the loss of stationary gripper coil only. The response time is not applicable (NA) for MODES 3 and 4. l CPSES - UNITS 1 AND 2 - TRM 13.3-7 Revision 29 - July 27,1999 l

ESFAS Instrumentation Response Times TR 13.3.2 Table 13.3.2-1 (Page 4 of 6)

Engineered Safety Features Actuation System instrumentation Response Time Limits FUNCTIONAL UNIT AND INITIATION SIGNAL RESPONSE TIME IN SECONDS

2. Containment Spray l

a. ManualInitiation NA

b. Automatic Actuation Logic and Actuation Relays NA !

c. Containment Pressure High 3 I 5 119 ')

3. ContainmentIsolation l

a. Phase A Isolation

1. ManualInitiation NA

2. Automatic Actuation Logic and Actuation Relays NA

3. Safety injection 5 17(2.10)/27(1,10)

b. Phase B isolation

1. ManualInitiation NA

2. Automatic Actuation Logic and Actuation Relays NA

3. Containment Pressure High 3 NA (continued)

(1) includes Diesel Generator starting delay.

(2) Diesel generator starting delay is Dgl included.

(9) includes containment spray header isolation valves only.

(10) includes Containment Pressure High 1, Pressurizer Pressure Low, and Steam Une Pressure Low initiation signals.

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- j CPSES - UNITS 1 AND 2 - TRM 13.3-8 Revision 29 - July 27,1999 j

ESFAS Instrumentation Response Times TR 13.3.2 Table 13.3.2-1 (Page 5 of 6)

Engineered Safety Featurw Actuabon System Instrumentation Response Time Umits FUNCTIONAL UNIT AND INITIATION SIGNAL RESPONSE TIME IN SECONDS

4. Steam Une Isolation

a. ManualInitisbon NA

b. Automatic Actuabon Logic and Actuabon Relays N.A.

c. Containment Pressure High 2 s7

d. Steam Une Pressure

1. Steam Une Pressure Low 57 1 .

l 2. Steam Une Pressure Negative Rate High 57

5. Turbine Trip and Foodwater Isolation j

a. Automatic Actuabon Logic and Actuation Relays NA l

b. Steam Generator Water Level High-High. P-14 5 11 III)

c. Safetyinjection s 7 (10,11) l (continued)

(10) includes Containment Pressure High 1, Pressurizer Pressure Low, and Steam Une Pressure Low initiation signals.

(11) Includes Feedwater isolation only. Turbine Trip is D9.t included.

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l I CPSES - UNITS 1 AND 2 -TRM 13.3-9 Revision 29 -July 27,1999

ESFAS instrumentation R spons3 Times TR 13.3.2 Table 13.3.2-1 (Page 6 of 6)

Engineered Safety Features Actuation System Instrumentation Response Time Limits FUNCTIONAL UNIT AND INITIATION SIGNAL RESPONSE TIME IN SECONDS

6. Auxiliary Feedwater

a. Automatic Actuation Logic and Actuabon Relays NA

b. Not Used NA

c. Steam Generator Water Level Low-Low 5 60 (12)/85(13)

d. Safety injection s 60 (1,10,12)

e. Loss of Offsite Power 5 58 II'I#I

f. Not Used NA

g. Trip of all Main Feedwater Pumps NA

h. Not Used NA

7. Automatic Switchover to Containment Sump

a. Automatic Actuation Logic and Actuation Relays NA

b. Refueling Water Storage Tank Level Low-Low s 30 Coincident with Safety injection

8. ESFAS Interlocks

a. Reactor Trip, P-4 ~ NA

b. Pressurizer Pressure, P-11 NA (1) Includes Diesel Generator starting delay.

(10) includes Containment Pressure High 1, Pressurizer Pressure Low, and Steam Line Pressure Low initiation signals.

(12) includes motor driven auxiliary feedwater pumps and feedwater split flow bypass valves only.

(13) includes turbine driven auxiliary feedwater pump and feedwater split flow bypass valves only.

(14) includes motor driven auxiliary feedwater pumps only.

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CPSES - UNITS 1 AND 2 - TRM 13.3-10 Revision 29 - July 27,1999

LOP DG Start Instrumentation Rrsponse Times TR 13.3.5 13.3 INSTRUMENTATION TR 13.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation Response Times Note: This Technical Requirement contains the listing of Loss of Power Diesel Generator Start Instrumentation Response Time limits associated with Technical Specification SR 3.3.5.4 and applicable functions in Technical Specification Table 3.3.5-1.

CPSES - UNITS 1 AND 2 - TRM 13.3-11 Revision 29 - July 27,1999

LOP DG Start instrumentation R:sponse Times TR 13.3.5 Table 13.3.5-1 (Page 1 of 1)

Loss of Power Diesel Generator Start Instrumentation Response Time Limits INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

1. Automatic Actuation Logic and Actuation Relays N.A.

2. Preferred Offsite Source bus UV N.A.

3. Altemate Offsite Source bus UV N.A.

4, 6.9 KV Class 1E Bus Undervoltage 52(I)

5. 6.9 KV Degraded Voltage 510(1,2,3)/563(1,2,4)

6. 480 V Class 1E Bus Low Grid Undervoltage 5 63 (1,2)

7. 480V Class 1E Bus Degraded Voltage s 10(1,2,3)/ 63(1,2,4)

(1) Response time measured to output of undervoltage channel only.

(2) Two additional seconds allowable for altomate offsite source breaker trip functions.

(3) Wsth SI (4) Without St 4

I CPSES - UNITS 1 AND 2 - TRM 13.3-12 Revision 29 - July 27,1999

g Seismic Instrumentation TR 13.3.31 13.3 INSTRUMENTATION TR 13.3.31 Seismic Instrumentation TR LCO 13.3.31 The seismic monitoring instrumentation shown in Table 13.3.31-1 shall be OPERABLE.

APPLICABILITY: At all times CPSES - UNITS 1 AND 2 - TRM 13.3-13 Revision 29 - July 27,1999

Seismic Instrumentation TR 13.3.31 ACTIONS NOTE The provisions of TR LCO 13.0.4 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. NOTE A.1 Restore the actuated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Only applicable to those seismic monitoring instruments in Table instrumentation to 13.3.31-1 which are OPERABLE status.

accessible in MODES 1-4.

AND One or more required A.2 Analyze data retrieved 14 days .

seismic monitoring from actuated 1 instruments are actuated instruments to determine during a seismic event >, the magnitude of the 0.01g. vibratory ground motion.

Prepare and submit a Special Report to the Commission describing the magnitude, frequency spectrum, and resultant effect upon facility features important to safety.

ANQ A.3 Perform a CHANNEL 15 days CAllBRATION per TRS 13.3.31.2 on the actuated instrumentation.

(continued) l l

4 i

CPSES - UNITS 1 AND 2 - TRM 13.3-14 Revision 29 - July 27,1999

S9ismic Instrumentation TR 13.3.31 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. - NOTE B.1 Restore the actuated After next entry into Only applicable to those seismic monitoring MODE 5 or below instruments identified in instrumentation to Table 13.3.31-1 which are OPERABLE status not accessible in MODES 1-4 AND B.2 Perform a CHANNEL After next entry into One or more required CAllBRATION per MODE 5 or below seismic-monitoring TRS 13.3.31.2 on the

- instruments which is actuated instrumentation.-

actuated during a seismic event > 0.01g ANQ B.3 Prepare and submit a Within 14 days of supplemental report to entry into MODE 5 or the Commission below describing the additional data from these instruments.

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.3-15 Revision 29 - July 27,1999 I I

l

Seismic Instrumentation TR 13.3.31 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. With one or more of the C.1 Restore all required 30 days required seismic monitoring seismic monitoring instruments inoperable for instruments to reasons other than OPERABLE status.

Conditions A or B.

D. Required Action and D.1 Prepare and submit a 10 days i associated Completion Special Report to the Time of Condition C not Commission outlining the met. cause of the malfunction I

and the plans for restoring the instrument (s) to OPERABLE status.

4 CPSES - UNITS 1 AND 2 - TRM 13.3-16 Revision 29 - July 27,1999

Seismic Instrumentation TR 13.3.31 SURVEILLANCE REQUIREMENTS NOTE Refer to Table 13.3.31-1 to determine which TRS apply for each seismic monitoring instrument.

SURVEILLANCE FREQUENCY TRS 13.3.31.1 Perform a CHANNEL CHECK. 31 days TRS 13.3.31.2 Perform a CHANNEL CALIBRATION. 18 months TRS 13.3.31.3 NOTE Setpoint verification is not required.

Perform a CHANNEL OPERATIONAL TEST. 184 days l

1 l

CPSES - UNITS 1 AND 2 - TRM 13.3-17 Revision 29 - July 27,1999

1 i

Ssismic Instrumentation TR 13.3.31 l

t Table 13.3.31 1 (Page 1 of 2)

SEISMIC MONITORING INSTRUMENTATION (a)

Instrument and Sensor Locations Surveillance Requirements

1. Triaxial Time-History Accelerographs

a. Accelerometer-Fuel Building TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3 b Accelerometer-Unit 1 Containment TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3

c. Accelerometer-Electrical Manhole (Yard) TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3

d. SeismicTrigger FuelBuilding ID) TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3

e. Recorder Unit, SMA-3 (Unit 1 Control Room) TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3

f. Playback Unit. SMP-1 (Unit 1 Contol Room) TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3

2. Triaxial Peak Accelerographs

a. Pressurizer Lifting Trunion - Unit 1 Containment TRS 13.3.31.2

b. Reactor Coolant Piping - Urnt 1 Containment TRS 13.3.31.2

c. CCW Heat Exchanger Auxiliary Building TRS 13.3.31.2 (continued)

(a) Unit i and Unit 2 control room alarms are connected to shared seismic instruments which are located in Unit 1 and common structures.

(b) With control room indication.

CPSES - UNITS 1 AND 2 - TRM 13.3-18 Revision 29 - July 27,1999 l

SeismicInstrument tion TR 13.3.31 Table 13.3.31 1 (Page 2 of 2)

SEASMIC MONITORING INSTRUMENTATION (a)

Instrument and Sensor Locations Surveillance Requirements

3. Triaxial Seismic Switch Fuel Building (D) TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3

4. Triaxial Response - Spectrum Recorders

a. Fuel Building IRS 13.3.31.2

b. Unit 1 Reactor Building Intemal Structure TRS 13.3.31.2

c. Unit 1 Safeguards Building TRS 13.3.31.2

5. Response Spectrum Annunciator @)(Unit 1 Control Room) TRS 13.3.31.1 TRS 13.3.31.2 TRS 13.3.31.3 (a) Unit 1 and Unit 2 control room alarms are connected to shared seismic instruments which are located in Unit 1 and common structures.

(b) With control room indication.

l CPSES - UNITS 1 AND 2 - TRM 13.3-19 Revision 29 - July 27,1999 j

Source Range Neutron Flux TR 13.3.32 13.3 (NSTRUMENTATION TR 13.3.32 Source Range Neutron Flux TR LCO 13.3.32 2 channels for the Source Range Neutron Flux function shall be OPERABLE.

APPLICABILITY: MODES 3,4, and 5 NOTE

1. Only applicable if the Rod Control System is not capable of rod 30 withdrawal and all control rods are fully inserted.

2. While this LCO is not met, MODE changes are not permitted 30 unless required to comply with Actions of other TS LCOs.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME l

A. One Source Range A.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Neutron Flux channel OPERABLE status, inoperable.

OH-A.2 Suspend all operations 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months involving positive reactivity changes.

(continued) i

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l CPSES - UNITS 1 AND 2 - TRM 13.3-20 Revision 30 - July 27,1999 '

Source Rangs N utron Flux TR 13.3.32 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Both Source Range B.1 Restore one channel to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Neutron Flux channels OPERABLE status.

Inoperable.

DB B.2 Suspend all operations 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months involving positive reactivity changes.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.3.32.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months TRS 13.3.32.2 Perform COT. 92 days TRS 13.3.32.3 NOTES

1. Neutron detectors may be excluded from CHANNEL CAllBRATION.

2. With the high voltage setting varied as recommended by the manufacturer, an initial discriminator bias curve shall be measured for each detector. Subsequent discriminator bias curves shall be obtained, evaluated and compared to the initial curves.

Perform CHANNEL CAllBRATION. ,

18 months CPSES - UNITS 1 AND 2 - TRM 13.3-21 Revision 29 - July 27,1999

Turbine Overspeed Protection TR 13.3.33 13.3 INSTRUMENTATION TR 13.3.33 Turbine Overspeed Protection TR LCO 13.3.33 At least one Turbine Overspeed Protection System shall be OPERABLE.

APPLICABILITY: MODES 1,2, and 3 NOTE Not applicable in MODES 2 and 3 with all main steam line isolation valves and associated bypass valves in the closed position.

ACTIONS NOTE Separate Condition entry allowed for each steam line.

CONDITION REQUIRED ACTION COMPLETION TIME A. One stop valve or one A.1 Restore the inoperable 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months control valve per high valve (s) to OPERABLE pressure turbine steam line status.

Inoperable. ;

DE !

I A.2 Close at least one valve 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months i in the affected steam line(s).

OB A.3 Isolate the turbine from 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months the steam supply.

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.3-22 Revision 29 - July 27,1999

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' Turbina Ov rspeed Protection TR 13.3.33 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One stop valve or one B.1 Restore the inoperable 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months control valve per low valve (s) to OPERABLE pressure turbine steam line status.

inoperable.

.QB B.2 Close at least one valve 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months in the affected steam line(s).

DB B.3 Isolate the turbine from 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months the steam supply.

C. Turbine overspeed C.1 Isolate the turbine from 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months protection inoperable for the steam supply.

reasons other than l Condition A or B.

D. Required Actions and D.1 1:iitiate action to place the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion unit in a lower MODE.

Times not met.

M D.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months M

D.3 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months I

I CPSES - UNITS 1 AND 2 - TRM 13.3-23 Revision 29 - July 27,1999

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Turbina Ovtrspeed Prot:ction TR 13.3.33 SURVEILLANCE REQUIREMENTS NOTE The provisions of TRS 13.0.4 are not applicable.

SURVEILLANCE FREQUENCY TRS 13.3.33.1 Tes; ne two mechanical overspeed devices using the 14 days Automatic Turbine Tester or manual test.

l

{

l TRS 13.3.33.2 Cycle each of the following valves through at least 6 weeks !

one complete cycle from the running position using the manual test or Automatic Turbine Tester (ATT). ;

a. Four high pressure turbine stop valves, l I

b. Four high pressure turbine control valves,

c. Four low pressure turbine stop valves, and

d. Four low pressure turbine control valves.

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TRS 13.3.33.3 Direct observation of the movement of each of the 6 weeks above valves (TRS 13.3.33.2) through one complete cycle from the running position.

TRS 13.3.33.4 Disassemble at least one high pressure turbine stop 40 months valve and one high pressure control valve and perform a visual and surface inspection of valve seats, disks and stems and verify no unacceptable flaws are found. If unacceptable flaws are found, all other valves of that type shall be inspected. l (continued)

CPSES - UNITS 1 AND 2 - TRM 13.3-24 Revision 29 - July 27,1999

Turbine Ov:rspeed Protection TR 13.3.33 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.3.33.5 Visually inspect the disks and accessible portions of 40 months the shafts of at least one low pressure turbine stop valve and one low pressure control valve and verify no unacceptable flaws are found, if unacceptable flaws are found, all other valves of that type shall be inspected.

CPSES - UNITS 1 AND 2 - TRM 13.3-25 Revision 29 - July 27,1999

RCS Pressura isolation Velves TR 13.4.14 13.4 REACTOR COOLANT SYSTEM (RCS)

TR 13.4.14 RCS Pressure Isolation Valves l This Technical Requirement contains a listing of the RCS Pressure Isolation l

Valves (PlVs) subject to Technical Specification 3.4.14.

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l TABLE 13.4.14-1 (Page 1 of 1)

REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES i

VALVE NUMBER FUNCTION 8948 A, B, C, D Accumulator Tank Discharge 8956 A, B, C, D Accumulator Tank Discharge 8905 A, B, C, D St Hot Leg injection 8949 A, B, C, D SI Hot Leg injection 8818 A, B, C, D RHR Cold Leg injection 8819 A, B, C, D SI Cold Leg injection 8701 A, B RHR Suction isolation 8702 A, B RHR Suction isolation 8841 A, B RHR Hot Leg injection 8815 CCP Cold Leg injection 8900 A, B, C, D CCP Cold Leg injection l

l CPSES - UNITS 1 AND 2 - TRM 13.4-1 Revision 29 - July 27,1999 l

r Loose P rt Detection System TR 13.4.31 13.4 REACTOR COOLANT SY5iEM TR 13.4.31 Loose Part Detection System TR LCO 13.4.31 The Loose-Part Detection System shall be OPERABLE.

APPLICABILITY: MODES 1 and 2 ACTIONS NOTE The provisions of TR LCO 13.0.4 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. With one or more required A.1 Restore required 30 days Loose-Part Detection channels to Operable System channels status.

inoperable.

B. Required Action and B.1 Prepare and submit a 10 days associated Completion Special Report to the Time not met. Commission outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.4.31.1 Perform a CHANNEL CHECK. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

CPSES - UNITS 1 AND 2 - TRM 13.4-2 Revision 29 - July 27,1999

Loose Part Det:ction Syst:m TR 13.4.31 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.4.31.2 NOTE Setpoint verification is not required.

31 days Perform a CHANNEL OPERATIONAL TEST.

TRS 13.4.31.3 Perform a CHANNEL CAllBRATION. 18 months CPSES - UNITS 1 AND 2 - TRM 13.4-3 Revision 29 - July 27,1999

Pressurizar PORV(s)

TR 13.4.32 13.4 REACTOR COOLANT SYSTEM TR 13.4.32 Pressurizer Power Operated Relief Valves (PORVs) l TR LCO 13.4.32 Pressurizer Power Operated Relief Valves (PORVs) actuation instrumentation shall be OPERABLE as needed to allow PORV automatic actuation.

l APPLICABILITY: MODES 1,2, and 3.

l i

NOTE l With PORV(s)in auto.

ACTIONS NOTE l 1. The provisions of TR LCO 13.0.4 are not applicable.

2. If PORV's actuation instrumentation is not functional, Technical Specification 3.4.11 does not require the associated PORV to be declared inoperable.

CONDITION REQUIRED ACTION COMPLETION TIME I

A. Actuationinstrumentation A.1 Place the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months !

inoperable such that one or PORV(s)in manual more PORV(s) are not mode.

capable of automatic actuation.

l SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY l TRS 13.4.32.1 Perform a CHANNEL CAllBRATION of the required 18 months PORV actuation instrumentation.

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CPSES - UNITS 1 AND 2 - TRM 13.4-4 Revision 29 - July 27,1999

f I

RCS Ch:mistry TR 13.4.33 13.4 REACTOR COOLANT SYSTEM I

TR 13.4.33 Reactor Coolant System (RCS) Chemistry TR LCO 13.4.33 The Reactor Coolant System chemistry shall be maintained within the limits specified in Table 13.4.33-1.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME NOTE i Only applicable in MODES 1, !

2,3 and 4.

A. One or more chemistry A.1 Restore parameter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months parameters in excess ofits within Steady-State limit.

Steady-State Limit but within its Transient Limit.

NOTE On!,applicable in MODES 1, 2,3 and 4.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not ANQ met.

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

.QB One or more chemisty ,

parameters in excess ofits Transient Limit.

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.4-5 Revision 29 - July 27,1999

)

RCS Chemistry TR 13.4.33 CONDITION REQUIRED ACTION COMPLETION TIME ;

l j NOTE Applicable in all conditions other than MODES 1,2,3 and 4.

C. Concentration of chloride or C.1 Restore concentration of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months floride in the RCS in excess chloride and floride to l of its Steady-State Limit. within its Steady-State limit. l 1

NOTE l

1. All Required Actions must be completed whenever I

this Condition is entered. ,

2. Applicable in all conditions !

other than MODES 1,2,3 l and 4.

D. Required Action and D.1 initiate action to reduce immediately associated Completion the pressurizer pressure Time of Condition C not to 5 500 ;,sig.

met.

M QB D.2 Perform an engineering Prior to increasing Concentration of chloride or evaluation to determine the pressurizer fluoride in the RCS in the effects of the out-of- pressure > 500 psig.

excess of its Transient limit condition on the Limit. structuralintegrity of the M RCS; determine that the RCS remains acceptable Prior to proceeding for continued operation. to MODE 4.

CPSES - UNITS 1 AND 2 - TRM 13.4-6 Revision 29 - July 27,1999

RCS Ch:mistry TR '13.4.33 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.4.33.1 NOTE Not required to be performed for dissolved oxygen when T, s 250 F.

Verify the RCS chemistry within the limits by analysis 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months of parameter specified in Table 13.4.33-1.

CPSES - UNITS 1 AND 2 - TRM 13.4-7 Revision 29 - July 27,1999

RCS Chemistry TR 13.4.33 TABLE 13.4.33-1 (Page 1 of 1)

REACTOR COOLANT SYSTEM CHEMISTRY LIMITS STEADY-STATE TRANSIENT PARAMETER LIMIT LIMIT Dissolved Oxygen W s 0.10 ppm s 1.00 ppm Chloride s 0.15 ppm s 1.50 ppm Fluoride s 0.15 ppm s 1.50 ppm (a) Limit not applicable with Toless than or equal to 250 *F.

l CPSES - UNITS 1 AND 2 - TRM 13.4-8 Revision 29 - July 27,1999

PressurizGr TR 13.4.34 :

13.4 REACTOR COOLANT SYSTEM TR 13.4.34 Pressurizer TR LCO 13.4.34 The pressurizer temperature shall be limited to:

a. A maximum heatup of 100*F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period, and

b. A maximum cooldown of 200*F in any 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. NOTE A.1 Restore pressurizer 30 minutes All Required Actions must temperature to within be completed whenever limits.

this Condition is entered.

AND Pressurizer temperature in A.2 Perform an engineering As assigned by the

~ excess of the required evaluation to determine Shift Manager, limits. that the effects of the out- commensurate with of-limit condition on the safety, structuralintegrity of the ,

pressurizer remains acceptable for continued operation.

B. Required Actions and B.1 - Be in at least MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times of Condition A not AND met.

B.2 Reduce pressyrizer 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure to < 500 psig.

(continued) !

'CPSES - UNITS 1 'AND 2 - TRM 13.4-9 Revision 29 - July 27,1999

Pr:ssurizar TR 13.4.34 l

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Actions and C.1 Be in MODE 4. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times of Condition B not ANQ i met. !

C.2 Be in MODE 5. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months !

I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.4.34.1 NOTE Only required to be performed during system heatup and cooldown.

Verity the pressurizer temperatures to be within the 30 minutes limits.

1 CPSES - UNITS 1 AND 2 - TRM 13.4-10 Revision 29 - July 27,1999

RCS Vents 1 TR 13.4.35 13.4 REACTOR COOLANT SYSTEM l i

TR 13.4.35 Reactor Coolant System (RCS) Vent Specification i TR LCO 13.4.35 At least one Reactor Coolant System vent path consisting of two vent !

valves in series powered from emergency busses shall be OPERABLE l and closed at each of the following locations: l

a. Reactor vessel head, and I

b. Pressurizer steam space. 1 APPLICABILITY: MODES 1, .2,3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Reactor Coolant A.1 Close the inoperable vent immediately System vent path path and remove power inoperable, from the valve actuators of all the vent valves in '

the inoperable vent path.

AND.

A.2 Restore the inoperable 30 days I

vent path to OPERABLE status.

j (continued) 1 l l

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i CPSE5 - UNITS 1 AND 2 - TRM _ 13.4-11 Revision 29 - July 27,1999 i

RCS Vents TR 13.4.35 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Both Reactor Coolant B.1 Close the inoperable vent immediately System vent paths paths and remove power inoperable. from the valve actuators of all the vent valves in the inoperable vent paths.

M B.2 Restore at least one of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months the vent paths to OPERABLE status.

C. Required Actions and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times of Condition A or B M not met.

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY l l

TRS 13.4.35.1 Verify all manual isolation valves in each vent path 18 months are locked in the open position.

TRS 13.4.35.2 Cycle each vent valve path through at least one 18 months complete cycle of full travel from the control room.

TRS 13.4.35.3 Verify flow through the Reactor Coolant System vent 18 months paths during venting.

CPSES - UNITS 1 AND 2 - TRM 13.4-12 Revision 29 - July 27,1999

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ECCS - Containment Debris TR 13.5.31 13.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)

TR 13.5.31 ECCS - Containment Debris l

TR LCO 13.5.31 Pursuant to TS 3.5.2 and 3.5.3, the containment shall be free of loose i debris which could restrict, during a LOCA, the pump suctions for the ECCS train (s) required to be OPERABLE.

l l

APPLICABILITY: MODES 1, 2,3 and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME ,

A. Loose debris left in A.1 Enter the applicable immediately containment which could Condition (s) of TS 3.5.2 restrict, during a LOCA, the or 3.5.3 for affected pump suctions for the ECCS train (s) inoperable.

ECCS train (s) required to be OPERABLE.

SURVEILLANCE REQUIREMENTS

=

SURVEILLANCE FREQUENCY TRS 13.5.31.1 Perform a visualinspection of accessible areas of Once prior to containment to verify that no loose debris (rags, entering MODE 4 trash, clothing, etc.) is present in the containment which could be transported to the containment sump and cause restriction of the pump suctions during LOCA conditions. .

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.5-1 Revision 29 - July 27,1999 l

ECCS - Containment Debris TR 13.5.31 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.5.31.2 NOTE Only required to be performed during periods when containment entries are made.

Perform a visual inspection of all areas within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months l containment affected by a containment entry to verify ;

I that no loose debris (rags, trash, clothing, etc.) is present in the containment which could be transported to the containment sump and cause

, restriction of the pump suctions during LOCA l conditions.

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CPSES - UNITS 1 AND 2 - TRM 13.5-2 Revision 29 - July 27,1999 l

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1 ECCS - Pump Line Flow Rates TR 13.5.32 13.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)

TR 13.5.32 ECCS - Pump Line Flow Rates l

TR LCO 13.5.32 Pursuant to TS 3.5.2 and 3.5.3, the pump lines for the ECCS train (s) required to be OPERABLE shall have the required flow rates.

l APPLICABILITY: MODES 1,2,3 and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pump lines for the ECCS A.1 Enter the applicable immediately train (s) required to be Condition (s) of TS 3.5.2 OPERABLE do not meet and 3.5.3 for affected required flow rates. ECCS train (s) inoperable.

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CPSES - UNITS 1 AND 2 - TRM 13.5-3 Revision 29 - July 27,1999

ECCS - Pump Line Flow Rates TR 13.5.32 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.5.32.1 Performing a flow balance test, during shutdown, and Once following verify that: completion of modifications to a) For centrifugal charging pump lines, with a the ECCS single pump running: subsystems that alter the

1) The sum of the injection line flow rates, subsystem flow excluding the highest flow rate, is characteristics.

1 245 gpm, and

2) The total pump flow rate is 5 560 gpm.

b) For safety injection pump lines, with a single pump running:

1) The sum of the cold leg injection line flow rates, evc!uding the highest flow rate, is 2 400 gpm, and

2) The total pump flow rate is 5675 gpm.

c) For RHR pump lines, with a single pump running, the sum of the cold leg injection line flow rates is E 4652 gpm.

CPSES - UNITS 1 AND 2 - TRM 13.5-4 Revision 29 - July 27,1999

Containment isolation Vriv:s TR 13.6.3 13.6- CONTAINMENT SYSTEMS TR 13.6.3 - Containment isolation Valves This Technical Requirement contains the listing of Containment isolation Valves subject to CPSES Technical Specification 3.6.3. Commensurate with Technical Specification Surveillance Requirement SR 3.6.3.5, Table 13.6.3-1 also contains the isolation time limit for each automatic power operated containment isolation valve.

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CPSES - UNITS 1 AND 2-TRM 13.6-1 Revision 29 -July 27,1999

Containment isolition Vriv:s TR 13.6.3 Table 13.6.3-1 (Page 1 of 13)

Containment isolation Valves FSAR Maximum Table Isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements

1. Phase 'A" Isolation Valves HV 2154 20 Feedwater Sample (FW to Stm Gen #1) 5 NA HV-2155 22 Feedwater Sample (FW to Stm Gen #2) 5 NA HV-2399 27 Blowdown From Steam Generator #3 5 NA HV-2398 28 Blowdown From Steam Generator #2 5 NA HV-2397 29 Blowdown From Steam Generator #1 5 NA HV 2400 30 Blowdown From Steam Generator #4 5 N.A 8152 32 Letdow Une to Letdown Heat Exchanger 10 C 8160 32 Letdow Une to Letdown Heat Excnanger 10 C 8890A 35 RHR to Cold Leg Loops #1 & #2 Test une 15 C 8890B 36 RHR to Cold Leg Loops #3 & #4 Test Une 15 C 8047 41 Reactor Makeup Water to Pressure Relief Tank & 10 C RC Pump Stand Pipe 8843 42 Si to RC System Cold Leg Loops #1, #2, #3, & #4 10 NA Test Line 8881 43 Si to RC System Hot Leg Loops #2 & #3 Test une 10 N.A.

8824 44 Si to RC System Hot Leg Loops #1 & #4 Test Line 10 N.A.

8823 45 Si to RC System Cold Leg Loops #1, #2, #3, & #4 10 NA Test une 8100 51 SealWater Retum and Excess Letdown 10 C 8112 51 SealWater Retum and Excess Letdown 10 C 7136 52 RCDT Heat Exchanger to Waste Hold up Tank 10 C LCV-1003 52 RCDT Heat Exchanger to Waste Hold up Tank 10 C HV-5365 60 Domineralized Water Supply 10 C HV-5366 60 Demineralized Water Supply 10 C CPSES - UNITS 1 AND 2-TRM 13.6-2 Revision 29 - July 27,1999

Containment Isolation Vdves TR 13.6.3 Table 13.6.3-1 (Page 2 of 13)

Containment isolation Valves FSAR Maximum Table isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements HV-5157 61 Containment Sump Pump Discharge 5 C HV-5158 61 Containment Sump Pump 5 C HV 3487 62 instrument Air to Containment 5 C 8825 63 RHR to Hot Leg Loops #2 & #3 Test Line 15 C l HV-2405 73 Sample from Steam Generator #1 5 N.A.

HV-4170 74 RC Sample from Hot Legs 5 C 5168 74 RC Sample fmm Hot Leg #1 5 C HV-4169 74 RC Sample from Hot Leg #4 5 C HV-2406 76 Sample from Steam Generator #2 5 N.A.

HV-4167 77 Pressurizer Liquid Space Sample 5 C HV-4166 77 Pressurizer Liquid Space Sample 5 C HV-4176 78 Pressurizer Steam Space Sample 5 C 1

HV-4165 78 Pressurizer Steam Space Sample 5 C HV 2407 79 Sample from Steam Generator #3 5 N.A.

HV-4175 80 Accumulators 5 C HV-4171 80 Sample From Accumulator #1 5 C HV-4172 80 Sample From Accumulator #2 5 C HV-4173 80 Sample From Accumulator #3 5 C HV-4174 80 Sample From Accumulator #4 5 C HV-7311 81 RC PASS Sample Discharge to RCDT 5 C HV-7312 81 RC PASS Sample Discharge to RCDT 5 C HV-2408 82 Sample from Steam Generator #4 5 N.A.

8871 83 Accumulator Test and Fill 10 C 8888 83 Accumulator Test and Fill . 10 C 8964 83 Accumulator Test and Fill 10 C CPSES - UNITS 1 AND 2 - TRM 13.6-3 Revision 29 - July 27,1999

1 Containment isolation Vtiv:s TR 13.6.3 Table 13.6.3-1 (Page 3 of 13)

Containment Isolation Valves FSAR Maximum Table Isolation Notes and Reference Time Leak Test Vaive No. No' Line or Service (Seconds) Requirements HV-5556 84 Containment Air PASS Retum 5 C HV-5557 84 Containment Air PASS Retum 5 C j HV-5544 94 Radiation Monitoring Sample 5 C HV-5545 94 Radiation Monitoring Sample 5 C l HV-5558 97 Containment Air PASS Inlet 5 C HV-5559 97 Containment Air PASS Inlet 5 C HV-5560 100 Containment Air PASS Inlet 5 C HV-5561 100 Containment Air PASS Inlet 5 C l HV-5546 102 Radiation Monitoring Sample Retum 5 C !

HV-5547 102 Radiation Monitoring Sample Retum 5 C 8880 104 N2Supply to Accumulators 10 C l 7126 105 H2Supply to RC Drain Tank 10 C )

7150 105 H2Supply to RC Drain Tank 10 C HV-4710 111 CCW Supply to Excess Letdown & RC Drain Tank 5 N.A.

Heat Exchanger HV-4711 112 CCW Retum to Excess Letdown & RC Drain Tank 5 N.A.

Heat Exchanger HV-3486 113 Service Air to Containment 5 C HV-4725 114 Containment CCW Drain Tank Pumps Discharge 10 C HV-4726 114 Containment CCW Drain Tank Pumps Discharge 10 C 8027 116 Nitrogen Supply to PRT 10 C 8026 116 Nitrogen Supply to PRT 10 C HV-6084 120 Chilled Water Supply to Containment Coolers 15 C HV-6082 121 Chilled Water Retum to Containment Coolers 15 C HV-6083 121 Chilled Water Retum to Containment Cdolers 15 C HV-4075B 124 Fire Protection System isolation 10 C HV-4075C 124 Fire Protection System isolation 10 C CPSES - UNITS 1 AND 2 - TRM 13.6-4 Revision 29 - July 27,1999

i Containment Isol tion Vrives TR 13.6.3 1

Table 13.6.3-1 (Page 4 of 13)

Containment Isolation Valves FSAR Maximum Table Isolation Notes and i

Reference Time Leak Test l Valve No. No.' Line or Service (Seconds) Requirements

2. Phase "B" Isolation Valves HV-4708 117 CCW Retum From RCP's Motors 30 C HV-4701 117 CCW Retum From RCP's Motors 30 C HV-4700 118 CCW Supply To RCP's Motors 30 C HV-4709 119 CCW Retum From RCP's Thermal Barrier 15 C HV-4696 119 CCW Retum From RCP's Thermal Barrier 15 C

3. Containment Ventilation Isolation Valves HV-5542 58 Hydrogen Purge Supply NA C HV-5543 58 Hydrogen Purge Supply NA C l HV-5563 58 Hydrogen Purge Supply NA C HV-5540 59 Hydrogen Purge Exhaust NA C HV-5541 59 Hydrogen Purge Exhaust NA C HV-5562 59 Hydrogen Purge Exhaust NA C HV-5536 109 Containment Purge Air Supply 5 C l HV-5537 109 Containment Purge Air Supply 5 C 1

HV-5538 110 Containment Purge Air Exhaust 5 C HV-5539 110 Containment Purge Air Exhaust 5 C HV 5548 122 Containment Pressure Relief 5 C Note 8 HV-5549 122 Containment Pressure Relief 5 C Note 8

4. Manual Valves MS-711# 4a TDAFW Pump Bypass Warm-up Valve NA NA l

MS-390 Sa N2Supply to Steam Generator #1 NA N.A. l MS-387 9a N2Supply to Steam Generator #2 **

NA NA l MS-384 13a N2Supply to Steam Generator #3 NA NA CPSES - UNITS 1 AND 2 - TRM 13.6-5 Revision 29 -July 27,1999

l Containment isol: tion Vdv;;s TR 13.6.3 Table 13.6.31 (Page 5 of 13)

Containment isolation Valves FSAR Maximum Table isolation Notes and :

Reference Time Leak Test I Valve No. No.* Line or Service (Seconds) Requirements MS-712# 17a TDAFW Pump Bypass Warm-up Valve NA NA MS-393 18a N2Supply to Steam Generator #4 N.A. NA FW-106 20b N2Supply to Steam Generator #1 NA NA FW-104 22b N2Supply to Steam Generator #2 NA NA I FW-102 24b N2Supply to Steam Generator #3 NA NA FW-108 26b N2Supply to Steam Generator #4 NA NA 7135# 52 RCDT Heat Exchanger to Waste Holdup Tank NA C MS-101 4 TDAFWP Steam Supply NA NA MS-128 17 TDAFWP Steam Supply N.N. NA SF-011 56 Refueling Water Purification to Refueling Cavity NA C SF-012 56 Refueling Water Purification to Refueling Cavity NA C SF-021 67 Refueling Cavity to Refueling Water Purification NA C SF-022 67 Refueling Cavity to Refueling Water Purification N.A. C 1SF-053 71 Refueling Cavity Skimmer Pump Discharge NA C 2SF-0055 1SF-054 71 Refueling Cavity Skimmer Pump Discharge NA C 2SF-0056 SI-8961# 83 Accumulator Test and Fill N.A. NA HV- 2 MSIV Bypass from Steam Generator #1 NA Note 1 2333B#

HV- 7 MSiV Bypass from Steam Generator #2 NA Note 1 2334B#

HV- 11 MSIV Bypass from Steam Generator #3 NA Note 1 2335B#

HV- 15 MSIV Bypass from Steam Generator #4 NA Note 1 2336B#

~~

1BS-0016# 130 Airlock Hydraulic System NA NA 1BS-0017# 130 Airlock Hydraulic System NA NA CPSES - UNITS 1 AND 2 -TRM 13.6-6 Revision 29 - July 27,1999

Containment isolation Valv:s TR 13.6.3 Table 13.6.3-1 (Page 6 of 13)

Containment Isolation Valves FSAR Maximum Table isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements 1BS-0030# 131 Airlock Hydraulically Operated Equalization NA Notes 5,6,7 1BS-0025# 131 Airlock Hydraulically Operated Equalization NA Notes 5,6,7 1BS-0056# 131a Airlock Manual Equalization NA Notes 5,6 1BS-0044# 131a Airlock Manual Equalization NA Notes 5,6 1BS-0029# 131a Airlock Manual Equalization NA Notes 5,6 1BS-0015# 131a Airlock Manual Equalization NA Notes 5,6 BS-0202# 132 Alriock Manual Equalization NA Notes 5,6,7 BS-0203# 132 Airlock Manual Equalization NA Notes 5,6,7 2BS-0016# 133 Airlock Hydraulic System NA Notes 5,6 2BS-0017# 133 Alrtock Hydraulic System NA Notes 5,6 2BS-0039# 133 Airlock Hydraulic System NA Notes 5,6 2BS-0040# 133 Airlock Hydraulic System N.A. Notes 5,6 2BS-0030# 134 Airlock Hydraulically Operated Equalization NA Notes 5,6,7 !

2BS-0025# 134 Airlock Hydraulically Operated Equalization N.A. Notes 5,6,7 2BS-0056# 134a Airlock Manual Equalization N.A. Notes 5,6 2BS-0044# 134a Airlock Manual Equalization N.A. Notes 5,6 2BS-0029# 134a Airlock Manual Equalization NA Notes 5,6 2BS-0015# 134a Airlock Manual Equalization N.A. Notes 5,6

5. Power-Operated Isolation Valves HV 24521 4 Main Steam to Aux. FPT From Steam Line # 4 NA N.A l PV-2325 5 Atmospheric Relief Steam Generator NA Note 3 PV-2326 9 Atmospheric Relief Steam Generator NA Note 3 PV-2327 13 Atmospheric Relief Steam Generator N.A. Note 3 HV-2452-2 17 Main Steam to Aux. FPT From Steam Line # 1 NA NA PV-2328 18 Atmospheric Relief Steam Generator NA Note 3 CPSES - UNITS 1 AND 2 -TRM 13.6-7 Revision 29 - July 27,1999

Containment Isolation Vriv;2 TR 13.6.3 Table 13.6.3-1 (Page 7 of 13)

Containment isolation Valves FSAR Maximum Table Isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements HV-2491A 20a Auxiliary Feedwater to Steam Generator #1 NA NA HV-24918 20a Auxiliary Feedwater to Steam Generator #1 NA NA HV 2492A 22a Auxiliary Feedwater to Steam Generator #2 NA NA HV-24928 22a Auxillary Feedwater to Steam Generator #2 NA NA HV-2493A 24a Auxiliary Feedwater to Steam Generator #3 NA NA HV-24938 24a Auxiliary Feedwater to Steam Generator #3 NA NA HV-2494A 26a Auxiliary Feedwater to Steam Generator #4 NA NA HV-24948 26a Auxiliary Feedwater to Steam Generator #4 NA NA 8701B 33 RHR From Hot Leg Loop #4 NA C 8701A 34 RHR From Hot Leg Loop #1 NA C 8809A 35 RHR From Cold Leg Loops #1 and #2 NA Note 4 8809B 36 RHR From Cold Leg Loops #3 and #4 NA Note 4 8801A 42 Safety injection to Cold Leg Loops #1, #2, #3, and N.A. NA

4 8801B 42 Safety injection to Cold Leg Loops #1, #2, #3, and NA NA

4 8802A 43 St Injection to RCS Hot Leg Loops #2 and #3 NA NA 8802B 44 Si injection to RCS Hot Leg Loops #1 and #4 NA NA 8835 45 Si injection to RCS Cold Leg Loops #1, #2, #3, and NA NA

4 8351A 47 SealInjection to RC Pump (Loop #1) N.A. NA 8351B 48 Sealinjection to RC Pump (Loop #2) N.A. NA 8351C 49 Sealinjection to RC Pump (Loop #3) NA NA 8351D 50 Sealinjection to RC Pump (Loop #4) NA NA CPSES - UNITS 1 AND 2- TRM 13.6-8 Revision 29 - July 27,1999

! Containment Isol: tion V lves TR 13.6.3 i Table 13.6.3-1 (Page 8 of 13)

Containment isolation Valves FSAR Maximum Table isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements HV-4777 54 Containment Spray to Spray Header (Train B) N A. Note 4 HV-4776 55 Containment Spray to Spray Header (Train A) NA Note 4 8840 63 RHR to Hot Leg Loops #2 and #3 NA Note 4 8811A 125 Containment Recire. Sump to RHR Pumps (Train A) NA NA 8811B 126 Containment Recire. Sump to RHR Pumps (Train B) NA NA HV-4782 127 Containment Recirc. to Spray Pumps (Train A) NA NA HV-4783 128 Containment Recire. to Spray Pumps (Train B) NA NA

6. Check Valves 8818A 35 RHR to Cold Leg Loop #1 NA NA 8818B 35 RHR to Ccid Leg Loop #2 NA NA 8818C 36 RHR to Cold Leg Loop #3 N.A. NA 8818D 36 kHR to Cold Leg Loop #4 NA NA l 8046 41 Reactor Makeup Water to Pressurizer Relief Tank NA C and RC Pump Stand Pipe 8815 42 High Head Safety injection to Cold Leg Loops #1, N.A. NA

2, #3, end #4 SI-8905B 43 Si to RC System Hot Leg Loop #2 NA NA SI-8905C 43 Si to RC System Hot Leg Loop #3 N.A. NA SI-8905A 44 Si to RC System Hot Leg Loop #1 NA NA SI-8905D 44 Si to RC System Hot Leg Loop #4 NA N.A.

SI-8819A 45 Si to RC System Cold Leg Loop #1 N.A. NA SI-8819B 45 Si to RC System Cold Leg Loop #2 N.A. N.A.

SI-8819C 45 Si to RC System Cold Leg Loop #3 NA NA l SI-8819D 45 Sl to RC System Cold Leg Loop #4 NA NA 8381 46 Charging Line to Regenerative Heat Exchanger NA C l

l CPSES - UNITS 1 AND 2 - TRM 13.6-9 Revision 29 - July 27,1999

Containment Isolation Vcives TR 13.6.3 Table 13.6.3-1 (Page 9 of 13)

Containment isolation Valves FSAR Maximum Table Isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements CS-8368A 47 Sealinjection to RC Pump (Loop #1) NA NA CS-83688 48 SealInjection to RC Pump (Loop #2) NA NA CS-8368C 49 Sealinjection to RC Pump (Loop #3) NA NA CS-8368D 50 SealInjection to RC Pump (Loop #4) NA NA CS-8180 M Seal Water Retum and Excess Letdown NA C CT-145

s , Containment Spray to Spray Header (Tr. B) NA Note 4 CT-142 55 Containment Spray to Spray Header (Tr. A) NA Note 4 Cl-030 62 Instrument Air to Containment NA C 8841A 63 RHR to Hot Leg Loop #2 N.A. NA 8841B 63 RHR to Hot Leg Loop #3 N.A. NA SI-8968 104 N2Supply to Accumulators NA C CA-016 113 Service Air to Containment NA C CC-629 117 CC Retum From RCP's Motors NA C CC-713 118 CC Supply to RCP's Motors N.A. C CC-831 119 CC Retum From RCP's Thermal Barrier N.A. C CH-024 120 Chilled Water Supply to Containment Coolers NA C

7. Steam Line isolation Signal HV-2333A 1 Main Steam From Steam Generator #1 5 Note 2 & 3 l HV-2409 3 Drain From Main Steam Line #1 5 N.A.

HV-2334A 6 Main Steam From Steam Generator #2 5 Note 2 & 3 HV-2410 8 Drain From Main Steam Line #2 5 N.A.

HV-2335A 10 Main Steam From Steam Generator #3 5 Note 2 & 3 {

HV-2411 12 Drain From Main Steam Line #3 5 NA HV-2336A 14 Main Steam From Steam Generator #4 '- 5 Note 2 & 3 HV-2412 16 Drain From Main Steam Line #4 5 NA CPSES - UNITS 1 AND 2-TRM 13.6-10 Revision 29 - July 27,1999

E l

Containment isolati:n Velv s TR 13.6.3 Table 13.6.3-1 (Page 10 of 13)

Containment Isolation Valves FSAR Maximum l Table Isolation Notes and

! Reference Time Leak Test Valve No. No.* Une or Service (Seconds) Requirements

8. Feedwater Isolation Signal HV-2134 19 Feedwater to Steam Generator #1 5 Note 3 l

FV 2193 20c Feedwater Preheat Bypass Line S.G. #1 5 Note 3 HV 2185 20d Feedwater Bypass Une S.G #1 5 Note 3 HV-2135 21 Feedwater to Steam Generator #2 5 Note 3 l

l FV-2194 22c Feedwater Preheat Bypass Line S.G. #2 5 Note 3 1

HV-2186 22d Feedwater Bypass Line S.G #2 5 Note 3 HV-2136 23 Feedwater to Steam Generator #3 5 Note 3 FV-2195 24c Feedwater Preheat Bypass Line S.G. #3 5 Note 3 HV 2187 24d Feedwater Bypass Line S.G #3 5 Note 3 HV 2137 25 Feedwater to Steam Generator #4 5 Note 3 FV-2196 26c Feedwater Preheat Bypass Une S.G. #4 5 Note 3 HV-2188 26d Feedwater Bypass Line S.G #4 5 Note 3

9. Safety injection Actuation isolation 8105 46 Charging Une to Regenerative Heat Exchanger 10 C

10. Relief Valves 87088 33 RHR From Hot Leg Loop #4 NA C 8708A 34 RHR From Hot Leg Loop #1 N.A. C MS-021 Sb Main Steam Safety Valve S.G. #1 NA Note 3 MS422 Sb Main Steam Safety Valve S.G. #1 NA Note 3 MS-023 Sb Main Steam Safety Valve S.G. #1 NA Note 3 MS-024 Sb Main Steam Safety Valve S.G. #1 NA Note 3 MS-025 Sb Main Steam Safety Valve S.G. #1 NA Note 3 CPSES - UNITS 1 AND 2 - TRM 13.6-11 Revision 29 - July 27,1999

l i Containment isol: tion Vcives TR 13.6.3 Table 13.6.3-1 (Page 11 of 13)

Containment isolation Valves FSAR Maximum Table Isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements MS-058 9b Main Steam Safety Valve S.G. #2 NA Note 3 MS-059 9b Main Steam Safety Valve S.G. #2 NA Note 3 MS-060 9b Main Steam Safety Valve S.G. #2 NA Note 3 MS-061 9b Main Steam Safety Valve S.G. #2 NA Note 3 ;

MS-062 9b Main Steam Safety Valve S.G. #2 NA Note 3 MS-093 13b Main Steam Safety Valve S.G, #3 N.A. Note 3 MS-094 13b Main Steam Safety Valve S.G. #3 NA Note 3 MS-095 13b Main Steam Safety Valve S.G. #3 NA Note 3 MS-096 13b Main Steam Safety Valve S.G. #3 NA Note 3 MS-097 13b Main Steam Safety Valve S.G. #3 NA Note 3 MS-129 18b Main Steam Safety Valve S.G. #4 NA Note 3 MS-130 18b Main Steam Safety Valve S.G. #4 N.A. Note 3 MS-131 18b Main Steam Safety Valve S.G. #4 N.A. Note 3 MS-132 18b Main Steam Safety Valve S.G. #4 N.A. Nota 3 MS-133 18b Main Steam Safety Valve S.G. #4 NA Note 3 RC-036 41a Penetration Thermal Relief NA C WP-7176 52a Penetration Thermal Relief N.A. C DD-430 60a Penetration Thermal Relief N.A. C 1VD-907 61a Penetration Thermal Relief NA C 2VD-896 PS-503 74a Penetration Thermal Relief NA C PS-501 77a Penetration Thermal Relief N.A. C PS-502 78a Penetration Thermal Relief N.A. C CPSES -UNITS 1 AND 2-TRM 13.6-12 Revision 29 - July 27,1999

1 Containment isol: tion Vcives i TR 13.6.3 Table 13.6.31 (Page 12 of 13)

Containment isolation Valves FSAR Maximum Table isolation Notes and Reference Time Leak Test Valve No. No? Line or Service (Seconds) Requirements PS-500 80a Pene dionThermalRelief NA C WP-7177 81a Penetration Thermal Relief NA C 1SI-8972 83a Penetration Thermal Relief NA C 2SI-8983

{

1CC-1067 114a Penetration Thermal Relief NA C 2CC-1090 1CH-0271 120a Penetration Thermal Relief N.A. C 2CH-0281 1CH-0272 121a Penetration Thermal Relief NA C 2CH-0282 SI-0182 125 Pressure Relief for Bonnet of MOV 8811 A NA NA SI-0183 126 Pressure Relief for Bonnet of MOV 8811B NA NA CT-0309 127 Pressure Relief for Bonnet of MOV HV-4782 NA NA CT-0310 128 Pressure Relief for Bonnet of MOV HV-4783 NA NA CPSES -UNITS 1 AND 2-TRM 13.6-13 Revision 29 - July 27,1999 l

1

Containment isol: tion Vcives TR 13.6.3 Table 13.6.3-1 (Page 13 of 13)

Containment Isolation Valves FSAR Maximum Table Isolation Notes and Reference Time Leak Test Valve No. No.* Line or Service (Seconds) Requirements Table Notations

Identification code for containment penetration and associated isolation valves in FSAR Tables 6.2.4-1,6.2.4-2, and 6.2.4-3.

May be opened on an intermittent basis under administrative control.

The table does not list local vent, drain and test connections as they are a special class of containment isolation valves and are locked closed to meet containment isolation criteria when located within the penetration boundary.

These valves are subject to the same leak rate testing as the other containment isolation valves in the associated penetration, including all applicable leak testing exceptions (see FSAR Table 6.2.4-2, including notes). In addition, if these volves are capped (or isolated by blind flange) and under administrative controls they are not required to be leak rate tested.

Note 1: All four MS!V bypass valves are locked closed in Mode 1. During Mode 2,3, and 4 one MSIV bypass valve may be opened provided the other three MS!V bypass valves are locked closed and their associated MSIVs are closed.

Note 2: These valves require steam to be tested and are thus not required to be tested until the plant is in MODE 3.

Note 3: These valves are included for table completeness; the requirements of Specification 3.6.3 do not apply.

Instead, the requirements of Specification 3.7.1,3.7.2,3.7.3 and 3.7.4 apply for main steam safety valves, main steam isolation valves, feedwater isolation valves and steam generator atmospheric relief valves, respectively.

Note 4: These valves are leak tested in accordance with Technical Specification Surveillance Requirement 3.6.3.12 and 3.6.3.13.

Note 5: 10 CFR 50 Appendix J, Type C testing of these valves is satisfied by the testing of the airlock under Technical Specification Surveillance Requirement 3.6.2.1.

Note 6: These valves are considered an integral part of the airlock associated with their respective airlock door.

Therefore, they are subject to the controls of Specification 3.6.2.

Note 7: These valves are secured in position by hydraulic system locks and/or interlocks and do not require separate locks.

Note 8: Including the instrumentation delays of the containment ventilation isolation signal from Pressurizer Pressure Low.

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CPSES - UNITS 1 AND 2-TRM 13.6-14 Revision 29 - July 27,1999 ;

Containment Spray System TR 13.6.6 13.6 CONTAINMENT SYSTEMS TR 13.6.6 Containment Spray System The performance test requirements for the Containment Spray System pumps subject to SR 3.6.6.4 is as follows:

In the test mode each Containment Spray pump is required to provide a total discharge flow through the test header of greater than or equal to 3300 gpm. at 245 psid with the pump eductor line open.

CPSES - UNITS 1 AND 2-TRM 13.6-15 Revision 29 -July 27,1999

Hydrogen Recombiners - In:trument tion end Control Circuits TR 13.6.31 13.6 CONTAINMENT SYSTEMS TR 13.6.31 Hydrogen Recombiners - Instrumentation and Control Circuits TR LCO 13.6.31 Pursuant to TS 3.6.8, the hydrogen recombiner instrumentation and control circuits shall be calibrated.

APPLICABILITY: MODES 1 and 2.

ACTIONS j CONDITION REQUIRED ACTION COMPLETION TIME A. One or more hydrogen A.1 Enter the applicable immediately recombiner system Condition (s) of TS 3.6.8 ,

instrumentation and control for affected hydrogen circuits not in calibration. recombiner(s) inoperable.

4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.6.31.1 Perform a CHANNEL CAllBRATION of all 18 months recombiner instrumentation and control circuits.

1 CPSES - UNITS 1 AND 2 -TRM 13.6-16 Revision 29 - July 27,1999 1

ARV - Air Accumulitor Tcnk TR 13.7.31 13.7 PLANT SYSTEMS TR 13.7.31 Steam Generator Atmospheric Relief Valve (ARV)- Air Accumulator Tank TR LCO 13.7.31 Pursuant to TS 3.7.4, the air accumulator tank for each ARV required to be OPERABLE shall be at a pressure greater than or equal to 80 psig.

APPLICABILITY: MODES 1,2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Airaccumulatortank(s) A.1 Enter the applicable immediately.

pressure not within limits. Condition (s) of TS 3.7.4 foraffected ARV(s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.31.1 Verify that the air accumulator tank pressure is within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limits.

I 1

CPSES - UNITS 1 AND 2 -TRM 13.7-1 Revision 29 - July 27,1999

Stzm Generator Pressure / Temperature Limitation TR 13.7.32 13.7 PLANT SYSTEMS TR 13.7.32 Steam Generator Pressure / Temperature Limitation TR LCO 13.7.32 The temperatures of both the primary and secondary coolants in the steam generators shall be greater than 70*F when the pressure of either coolant in the steam generator is greater than 200 psig.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressure / Temperature A.1 Reduce the steam 30 minutes Limitations not met. generator pressure of the applicable sides to less than or equal to 200 psig.

AND.

A.2 Perform an engineering evaluation to determine Prior to increasing the effect of the steam generator overpressurization on the coolant temperatures structuralintegrity of the above 200 *F steam generator.

Determine that the steam generator remains acceptable for continued ,

operation. I CPSES - UNITS 1 AND 2 - TRM 13.7-2 Revision 29 - July 27,1999 i

Steam Generator Pressure / TGmperature Limitation TR 13.7.32 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.32.1 NOTE Only required when the temperature of either the primary or secondary coolant is less than 70 *F.

Verify that the pressure in each side of the steam i hour generatoris less than 200 psig.

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CPSES - UNITS 1 AND 2 -TRM 13.7-3 Revision 29 - July 27,1999

Ultimate Heat Sink - Sediment and SSI Dam TR 13.7.33 13.7 PLANT SYSTEMS TR 13.7.33 Ultimate Heat Sink - Sediment and Safe Shutdown impoundment (SSI) Dam TR LCO 13.7.33 Pursuant to TS 3.7.9, the average sediment depth shall be less than or equal to 1.5 feet in the service water intake channel and the SSI dam shall exhibit no abnormal degradation or erosion.

APPLICABILITY: MODES 1,2,3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. With the average sediment A.1 Prepare and submit to the 30 days depth in the service water Commission a Special intake channel greater than Report that provides a 1.5 feet. record of all surveillances performed pursuant to TRS 13.7.33.2 and specify what measures will be employed to remove sediment from l the service waterintake channel. 1 l

B. The SSI dam has abnormal B.1 Enter the applicable immediately l degradation or erosion. Condition (s) of TS 3.7.9 )

for SSIinoperable due to a degraded dam.

4 CPSES - UNITS 1 AND 2 -TRM 13.7-4 Revision 29 - July 27,1999

Ultimate Heat Sink - Sediment and SSI D .m TR 13.7.33 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.33.1 Visually inspect the SSI dam and verify no abnormal 12 months degradation or erosion.

TRS 13.7.33.2 Verify that the average sediment depth in the service 12 months water intake channel is less than or equal to 1.5 feet.

CPSES - UNITS 1 AND 2 -TRM 13.7-5 Revision 29 -July 27,1999

Flood Protechon TR 13.7.34 13.7. PLANT SYSTEMS TR 13.7.34 Flood Protechon TR LCO 13.7.34 Flood protection shall be provided for all safety-related systems, ceriponents, and structures when the water level of the Squaw Creek Reservoir (SCR) exceeds 777.5 feet.

NOTE All elevations and SCR water levels in this specification are expressed in feet Mean Sea Level, USGS datum.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A NOTE A.1 Initiate action to place the 1 hours1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable in MODES unit in a lower MODE.

1,2,3 and 4.

M Required flood protection A.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months measure (s) not in place.

M A.3 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months M

A.4 Be in MODE 5. 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months ;

CPSES - UNITS 1 AND 2 -TRM 13.7-6 Revision 29 - July 27,1999

Flood Protection TR 13.7.34 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.34.1 NOTE Only required to be performed when SCR water level is < 776 feet.

Verify the water level of SCR is measured to be 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within the limits.

TRS 13.7.34.2 NOTE Only required to be performed when SCR water level is 2 776 feet.

Verify the water level of SCR is measured to be 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within the limits.

TRS 13.7.34.3 NOTE Only required to be performed when SCR water level is > 777.0 feet.

Verify flood protection measures are in effect by 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months verifying that flow paths from the SCR which are open for maintenance are isolated from the SCR by isolation valves, or stop gates, or are at an elevation above 790 feet.

(continued)

CPSES - UNITS 1 AND 2 -TRM 13.7-7 Revision 29 - July 27,1999

Flood Protechon TR 13.7.34 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.7.34.4 NOTE Only required to be performed when SCR water level is > 777.5 feet.

Verify flood protection measures are in effect by Once within verifying that any equipment which is to be opened or 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after SCR is open for maintenance is isolated from the SCR by water level isolation valves, or stop gates, or is at an elevation

> 777.5 feet above 790 feet.

AND Prior to opening any equipment for maintenance 1

l CPSES - UNITS 1 AND 2 -TRM 13.7-8 Revision 29 -July 27,1999 l I

p Snubbers TR 13.7.35 13.7 PLANT SYSTEMS TR 13.7.35 Snubbers TR LCO 13.7.35 All snubbers shall be OPERABLE. The only snubbers excluded from the requirements are those installed on nonsafety-related systems and then l only if their failure or failure of the system on which they are installed would have no adverse effect on any safety-related system.

APPLICABILITY: MODES 1,2,3, and 4. MODES 5 and 6 for snubbers located on systems required OPERABLE in those MODES.

NOTE 30 While this LCO is not met, MODE changes shall be restricted to those MODE changes allowed by the applicable LCO's for the equipment which may be potentially inoperable as a result of the inoperable snubber (s).

ACTIONS NOTE Separate Condition entry allowed for each snubber.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more snubbers A.1.1 Restore snubber (s) to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

.Q8 A.1.2 Replace snubber (s). 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND.

A.2 Perform an engineering 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months evaluation in accordance with the approved snubber augmented inservice inspection program on the attached component.

(continued)

CPSES - UNITS 1 AND 2 -TRM 13.7-9 Revision 30 -July 27,1999 i

Snubbers TR 13.7.35 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Actions and B.1 Enter appropriate immediately associated Completion Condition (s) for attached Times not met. system (s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.35.1 Each required snubber shall be demonstrated Per snubber OPERABLE by performance of the requirements of augmented the approved snubber augmented inservice inservice inspection program in TR 15.5.31. inspection program.

CPSES - UNITS 1 AND 2 - TRM 13.7-10 July 27,1999

F Area Temperature Monitoring TR 13.7.36 13.7 PLANT SYSTEMS TR 13.7.36 Area Temperature Monitoring TR LCO 13.7.36 The maximum temperature limit for normal conditions of each area shown in Table 13.7.36-1 shall not be exceeded for more than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and the maximum temperature limit for abnormal conditions of each area given in Table 13.7.36-1 shall not be exceeded.

APPLICABILITY: Whenever the equipment in an affected area is required to be OPERABLE.

NOTE 30 While this LCO is not met due to exceeding the maximum temperature limit l for abnormal conditions, MODE changes shall be restricted to those allowed i by the applicable LCOs for the equipment which may be potentially inoperable due to exceeding the limit for abnormal conditions.

I

-)1 CPSES - UNITS 1 AND 2-TRM 13.7-11 Revision 30 - July 27,1999

1 Ara- Temperature Monitoring TR 13.7.36 ACTIONS NOTE Separate condition entry is allowed for each area listed in Table 13.7.36-1.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more areas NOTE exceeds the maximum Required Action must be temperature limit (s) for completed whenever Condition A normal conditions shown in is entered.

Table 13.7.36-1 for more than 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

A.1 Prepare and submit a 30 days special report to the Commission that provides a record of the cumulative time and the amount by which the temperature in the affected area (s) exceeded the limit (s) and an analysis to demonstrate the continued OPERABILITY of the affected equipment.

B. One or more areas B.1 NOTE exceeds the maximum Required Action B.1 must temperature limit (s) for be completed whenever abnormal conditions shown Condition B is entered.

In Table 13.7.36-1.

Prepare and submit a 30 days Special Report as required by Required Action A.1 above.

AblQ (continued)

CPSES - UNITS 1 AND 2 -TRM 13.7-12 July 27,1999 1

Arco Temperature Monitoring TR 13.7.36 ACTIONS (continued) l CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Restore the area (s) to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within the maximum temperature limit (s) for abnormal conditions.

2 B.3.1 Enter the appropriate 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Condition (s)of the appropriate TS(s) for the equipment in the affected area (s) inoperable.

E B.3.2.1 Verify that the ,

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months qualification envelope for the affected equipment has not been exceeded.

E B.3.2.2 Declare the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months equipment which exceeded the qualification envelope INOPERABLE:

E B.3.3 Perform an analysis that 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months justifies continued operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

\

TRS 13.7.36.1 Verify the temperature in each of the areas shown in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Table 13.7.36-1 to be within limit (s).

I CPSES - UNITS 1 AND 2 -TRM 13.7-13 Revision 29 - July 27,1999 {

L Arem Tcmperature Monitoring TR 13.7.36 TABLE 13.7.36-1 (Page 1 of 1)

AREA TEMPERATURE MONITORING MAXIMUM

&BE6 TEMPERATURE LIMIT (*F)

Normal Abnormal Conditions Conditions

1. Electrical and Control Building Normal Areas 104 131 Control Room Main Level (El. 830'-0") 80 104 Control Room Technical Support Area (El. 840*-6") 104 104 UPS/ Battery Rooms 104 113 '

' Chiller Equipment Areas 122 131

~

2. Fuel Building Normal Areas 104 131 Spent Fuel Pool Cooling Pump Rooms 122 131

3. Safeguards Buildings Normal Areas 104 131 AFW, RHR, SI, Containment Spray Pump Rooms 122 131 RHR Valve and Valve isolation Tank Rooms 122 131 RHR/CT Heat Exchanger Rooms 122 131 Diesel Generator Area 122 131 Diesel Generator Equipment Rooms 130 131 Day Tank Room 122 131

4. Auxiliary Building Normal Areas 104 131 122 l CCW, CCP Pump Rooms 131 CCW Heat Exchanger Area 122 131 CVCS Vabe and Valve Operating Rooms 122 131 Auxiliary Steam Dmin Tank Equip. Room 122 131 Waste Gas Tank Valve Operating Room 122 131

5. Service Waterintake Structure 127 131

6. Containment Buildings General Areas 120 129 Reactor Cavity Exhaust 150 190 CRDM Shroud Exhaust 163 ,, 172 CPSES - UNITS 1 AND 2 - TRM 13.7-14 Revision 29 - July 27,1999

Safety Chilled Witer System - Electrical Switchgeir Arem Emergency Fen Coil Units TR 13.7.37 13.7 PLANT SYSTEMS TR 13.7.37 Safety Chilled Water System - Electrical Switchgear Area Emergency Fan Coil Units TR LCO 13.7.37 The safety chilled water system electrical switchgear area emergency fan coil units shall be OPERABLE.

APPLICABILITY: MODES 1,2,3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare Safety Chilled immediately.

electrical switchgear area Water train (s) inoperable emergency fan coil unit (s) (TS 3.7.19).

Inoperable.

OB A.2 Declare affected fan coil immediately unit (s) and their 1 supported equipment l inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.37.1 Verify electrical switchgear area emergency fan coi: 18 months units start on an actual or simulated Safety injection actuation signal.

i CPSES - UNITS 1 AND 2 -TRM 13.7-15 Revision 29 - July 27,1999

Main Feedwater Isolation Vciva Pressure / Tcmperatura Limt TR 13.7 38 13.7 ' PLANT SYSTEMS TR 13.7.38 Main Feedwater Isolation Valve Pressure / Temperature Limit TR LCO 13.7.38 The valve body and neck of each main feedwater isolation valve shall be I greater than or equal to 90'F, when feedwater line pressure is greater than 675 psig.

APPLICABILITY: MODES 1,2,3 and during pressure testing of the steam generator or main feedwater line.

ACTIONS NOTE Separate Condition entry allowed for each main feedwater isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more main A.1 Restore main feedwater 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months feedwater isolation valves isolation valve (s) outside of the required pressure and/or limits. temperature to within limits.

AblD.

A.2 NOTE Required Action A.2 must be completed whenever Condition A is entered.

Perform an engineering 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months evaluation to determine the effect of the overpressure on the structuralintegrity of the main feedwater isolation valve (s) and determine that the main feedwater isolation valve (s) remains acceptable for continued operation.

(continued)

CPSES - UNITS 1 AND 2 -TRM 13.7-16 Revision 29 - July 27,1999 l

Main Feedwit:r isolation Valvs Pressure / Tcmperature Limt TR 13.7.38 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Actions and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times of Condition A not ANQ met.

B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months I

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.38.1 NOTE Not required to be performed in MODE 1 viith the main feedwater isolation valve open.

Each main feedwater isolation valve shall be 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months determined to be greater than or equal to 90*F.

CPSES - UNITS 1 AND 2 -TRM 13.7-17 Revision 29 - July 27,1999

Tomado Missile Shields TR 13.7.39 13.7 PLANT SYSTEMS TR 13.7.39 Tornado Missile Shields TR LCO 13.7.39 Required equipment shall be protected from tomado generated missiles as required by Allowances of Table 13.7.39-1.

APPLICABILITY: Whenever supported equipment is required to be OPERABLE.

NOTE Only applicable if any required missile shield is not in its missile protection configuration.

ACTIONS NOTE Separate Condition entry allowed for each missile shield.

CONDITION REQUIRED ACTION COMPLETION TIME A. Allowances of Table A.1 Declare equipment immediately 13.7.39-1 not met for one supported by affected or more missile shields. missile shield (s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.7.39.1 Verify allowances of Table 13.7.39-1 are satisfied. Prior to removal of any missile shield

~

CPSES - UNITS 1 AND 2-TRM 13.7-18 Revision 29 -July 27,1999

Tomado Missile Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES

$hislds: S1-27 Door, Unit 1 Safeguards Corridor EL 810' 6" Related Snecifications: 3.7.12 Allowance:

1. Unit 1 and 2 in MODES 5 and 6, or Unit 1 in MODES 5 and 6 and the Unit 1 Safeguards Bldg. is HQIin Direct Communication with the Unit 2 Primary Plant Ventilation Pressure Boundary.

a. May be open under administrative control provided the capability to close immediately on notification of a Tomado Waming exist.

b. May be removed under administrative control provided the capability exists to reinstall immediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

2. Unit 1 in MODES 5 and 6, Unit 2 iri MODES 1,2,3 and 4, and the Unit 1 Safeguards Bldg. is in Direct Communication with the Unit 2 Primary Plant Ventilation Pressure Boundary,

s. May be open under adminis'rative control provided:

. Unit 2 enters LCO 3.7.12 CONDITION B. and

. It is continuously manned, with direct communications established to the control room, and

. It is capable of immediate closure upon notification from the Control Room of a Tomado Waming or Unit 2 Safety injection.

b. May be removed under administrative control provided:

. Unit 2 enters LCO 3.7.12 CONDITION B, and

. The capability exists to re-install imnW,diately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

3. Unit 1 and 2 in MODES 1,2,3 and 4.

May be open under administrative control for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a. Units 1 and 2 enter LCO 3.7.12 CONDITION B, and

b. It is continuously manned, with direct communications established to the control room, and

c. It is capable o'immediate closure upon notification from the Control Room of a Tomado Waming, Unit 1 Safety injecten or Unit 2 Safety injection.

CPSES - UNITS 1 AND 2-TRM 13.7-19 Revision 29 -July 27,1999

l Tornado Missile Shtlds TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: S2-27 Door, Unit 2 Safeguards Corridor El. 810' 6" Related Specifications: 3.7.12 Allowance:

1. Unit 1 and 2 in MODES 5 and 6, or Unit 2 in MODES 5 and 6 and the Unit 2 Safeguards Bldg. is H.QIin Direct Communication with the Unit 1 Primary Plant Ventilation Pressure Boundary.

a. May be open under administrative control provided the capability to close immediately on notification of a Tomado Waming exist.

b. May be removed under administrative control provided the capability exists to reinstall ir mediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

2. Unit 2 in MODES 5 and 6, Unit 1 in MODES 1,2,3 and 4, and the Unit 2 Safeguards Bldg. Is in Direct Communication with the Unit 1 Primary Plant Ventilation Pressure Boundary,

a. May be open under administrative control provided:

. Unit 1 enters LCO 3.7.12 CONDITION B, and

. It is continuously manned, with direct communications established to the control room, and

. It is capable of immediate closure upon notification from the Control Room of a Tomado Waming or Unit 1 Safety injection.

b. May be removed under administrative control provided:

. Unit 1 enters LCO 3.7.12 CONDITION B, and

. The capability exists to re-install immediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

3. Unit 1 and 2 in MODES 1,2,3 and 4. I May be open under administrative control for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a. Units 1 and 2 enter LCO 3.7.12 CONDITION B, and

b. It is continuously manned, with direct communications established to the control room, and

c. It is capable of immediate closure upon notification from the Control Room of a Tomado !

, Waming, Unit i Safety injection or Unit 2 Safety injection. )

CPSES - UNITS 1 AND 2 - TRM 13.7-20 Revision 29 -July 27,1999 l

j

Tornado Missile Shtids TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: S1-38B Door, Auxiliary Bldg. El. 852' 6' S1 -38D Door, Train B Electrical Equipment Area Related Specifications: 3.7.12 (S1-38B only); 3.8.9 (S-38D only)

Allowance:

1. Unit 1 and 2 in MODES 5 and 6, or Unit 1 in MODES 5 and 6 and the Unit 1 Safeguards Bldg. is HQIin Direct Communication with the Unit 2 Primary Plant Ventilation Pressure Boundary.

a. May be open under administrative control provided the capability to close immediately on notification of a Tomado Waming exist.

b. May be removed under administrative control provided the capability exists to reinstall immediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

2. Unit 1 in MODES 5 and 6, Unit 2 in MODES 1,2,3 and 4, and the Unit 1 Safeguards Bldg. is in Direct Communication with the Unit 2 Primary Plant Ventilation Pressure Boundary.

a. May be open under administrative control provided:

. It is continuously manned, with direct communications established to the control room, and e it is capable of immediate closure upon notification from the Control Room of a Tomado Waming or Unit 2 Safety injection.

b. May be removed under administrative control provided:

. Unit 2 enters LCO 3.7.12 CONDITION B, and

. The capability exists to re-install immediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

3. Unit 1 and 2 in MODES 1,2,3 and 4.

May be open under administrative control for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a. It is continuously manned, with direct communications established to the control room, and

b. It is capable of immediate closure upon notificatio'n from the Control Room of a Tomado Waming, Unit 1 Safety injection or Unit 2 Safety injection.

CPSES - UNITS 1 AND 2-TRM 13.7-21 Revision 29 -July 27,1999

Tomado Missile Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: S2-38B Door, Auxiliary Bldg. El. 852' 6" S2-38D Door, Train B Electrical Equipment Area Related Snecifications: 3.7.12 (S2-38B only); 3.8.9 (S-38D only)

Allowance:

1. Unit 1 and 2 in MODES 5 and 6, or Unit 2 in MODES 5 and 6 and the Unit 2 Safeguards Bldg. is HQIin Direct Communication with the Unit 1 Primary Plant Ventilation Pressure Boundary,

a. May be open under administrative control provided the capability to close immediately on notification of a Tomado Waming exist.

b. May be removed under administrative control provided the capability exists to reinstall immediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

2. Unit 2 in MODES 5 and 6, Unit 1 in MODES 1,2,3 and 4, and the Unit 2 Safeguards Bldg. is in Direct Communication with the Unit 1 Primary Plant Ventilation Pressure Boundary.

a. May be open under administrative control provided:

. It is continuously manned, with direct communications established to the control room, and l

. It is capable of immediate closure upon notification from the Control Room of a 1 Tomado Waming or Unit 1 Safety injection.

b. May be removed under administrative control provided:

. Unit i enters LCO 3.7.12 CONDITION B, and

. The capability exists to re-install immediately on notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather ,

Statement with winds in excess of 60 mph affecting CPSES.

3. Unit 1 and 2 in MODES 1,2,3 and 4.

May be opan under administrative control for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a. It is continuously manr.od, with direct communications established to the control room, and

b. It is capable of immediate closure upon notificati6n from the Control Room of a Tomado Waming, Unit 1 Safety injection or Unit 2 Safety injection. .

~

1 CPSES - UNITS 1 AND 2 -TRM 13.7-22 Revision 29 - July 27,1999 1

Torrtdo Missil3 Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: Access Cover Plates (4) El. 852' 6", above Unit 1 Safeguard Bldg. Corridor Related Soecifications: 3.4.7*, 3.4.8*, 3.7.12, 3.9.5*, and 3.9.6*.

Allowance:

1. Unit 1 and 2 in MODES 5 and 6, or Unit 1 in MODES S and 6 and the Unit 1 Safeguards Bldg. is MQI in Direct Communication with the Unit 2 Primary Plant Ventilation Pressure Boundary. May be removed under administrative control provided either:

a. The floor plugs (El. 831' 6" corridor) over each OPERABLE Unit 1 RHR heat exchanger are in place, or

b. The capability exists to re-install the misslie shield or floor plugs immediately upon notification of a National Weather Service issued Tornado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES. If only one RHR system is OPERABLE, either its missile shield or floor plug shall be in place.

2. Unit 1 in MODES 5 and 6, Unit 2 in MODES 1,2,3 and 4, and the Unit 1 Safeguards Bldg. is in Direct Communication with the Unit 2 Primary Plant Ventilation Pressure Boundary. May be removed under administrative control provided:

a. Unit 2 enters LCO 3.7.12 CONDITION B, and either b.

. The floor plugs (El. 831' 6" corridor) over each OPERABLE Unit 1 RHR heat exchanger are in place, or

. The capability exists to re-install the missile shield or floor plugs immediately upon notification of a National Weather Service issued Tornado Warning, Tornado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES. If only one RHR system is OPERABLE, either its missile shield or floor plug shall be in place.

Only affects RHR operability l

CPSES - UNITS 1 AND 2 -TRM 13.7-23 Revision 29 - July 27,1999

Tornado Missile Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Stdglda: Access Cover Plates (4) El. 852' 6", above Unit 2 Safeguard Bidg. Corridor Raintad Snacifications: 3.4.7*, 3.4.8*, 3.7.12, 3.9.5*, and 3.9.6*.

AHowance:

1. Unit 1 and 2 in MODES 5 and 6, or Unit 2 in MODES 5 and 6 and the Unit 2 Safeguards Bldg. is HQIin Direct Communication with the Unit 1 Primary Plant Ventilation Pressure Boundary. May be removed under administrative control provided either:

a. The floor plugs (El. 831' 6" corridor) over each OPERABLE Unit 2 RHR heat exchanger are in place, or

b. ' The capability exists to re-install the missile shield or floor plugs immediately upon notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES. If only one RHR system is OPERABLE, either its missile shield or floor plug shall be in place.

2. Unit 2 in MODES 5 and 6, Unit 1 in MODES 1,2,3 and 4, and the Unit 2 Safeguards Bldg. is in Direct Communication with the Unit 1 Primary Plant Ventilation Pressure Boundary. May be removed under administrative control provided:

a. Unit i enters LCO 3.7.12 CONDITION B, and either b.

. The floor plugs (El. 831' 6" corridor) over each OPERABLE Unit 2 RHR heat exchanger are in place, or

. The capability exists to re-install the missile shield or floor plugs immediately upon notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES if only one RHR system is OPERABLE, either its missile shield or floor plug shall be in place.

Only affects RHR operability CPSES - UNITS 1 AND 2 -TRM 13.7-24 Revision 29 -July 27,1999

Tornado Missile Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: E-40A Door, Control Room Related Snecifications: 3.7.10 Allowance:

In all MODES may be open under administrative control for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a. It is continuously manned, with direct communications established to the control room, and

b. It is capable of immediate closure upon notification from the Control Room (of a Tomado Waming, Safety injection, Loss-of-Offsite Power, or intake Vent-High Radiation) 1 CPSES - UNITS 1 AND 2 - TRM 13.7-25 Revision 29 -July 27,1999

Tornado Missile Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: Unit 1 Containment Equipment Hatch Missile Shield (Outer Cover)

Related Specifications: 3.4.15,3.6.1,3.6.6 Allowance:

1. The inner cover of the Equipment Hatch is considered part of the containment liner and is addressed in accordance with LCO 3.6.1," Containment".

2. May be removed in MODE 4 for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided the capability exists to immediately reinstall the missile shield upon notification of a National Weather Service issued Tomado Waming, Tomado Watch or other special Weather Statement with winds in excess of 60 mph affecting CPSES.

l l

l

~

I i

CPSES - UNITS 1 AND 2-TRM 13.7-26 Revision 29 - July 27,1999

Tornado Missile Sh';lds TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: Unit 2 Containment Equipment Hatch Missile Shield (Outer Cover)

Related Specifications: 3.4.15,3.6.1,3.6.6 Allowance:

1. The Inner cover of the Equipment Hatch is considered part of the containment liner and is addressed in accordance with LCO 3.6.1, " Containment".

2. May be removed in MODE 4 for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided the capability exists to immediately reinstall the missile shield upon notification of a National Weather Service issued Tomado Waming, Tomado Watch or other special Weather Statement with winds in excess of 60 mph affecting CPSES.

CPSES - UNITS 1 AND 2-TRM 13.7-27 Revision 29 -July 27,1999 i

Tomado Missile Shtids TR 13.7.39 i

Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: Related Specifications: I Access Cover Plate, Unit 1 Diesel FO Truck Fill Station 3.8.1, 3.8.2 Access Cover, Unit 1 RWST Nono Access Cover, Unit 1 CST 3.7.6 Access Cover, Unit 1 RMWST None Service Water Tunnel, Manhole Cover (Common) El. 810' 6" 3.7.0 Removable Slab (Hatch Cover), Electnc Fire Pumps 3.7.8 CPX-FPAPFP-01 AND CPX-FPAPFP-03 Access Cover Plate, Unft 2 Diesel FO Truck Fill Station 3.8.1,3.8.2 Access Cover, Unit 2 RWST None Access Cover, Unit 2 CST 3.7.6 Access Cover, Unit 2 RMWST None Allowance:

May be removed under administrative control provided the capability exist to re-install the missile shield imrrwxfiately upon notification of a National Weather Service issued Tomado Waming.

Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES.

I

, l CPSES - UNITS 1 AND 2 -TRM 13.7-28 Revision 29 -July 27,1999

Tornado Missile Shields TR 13.7.39 Table 13.7.39-1 MISSILE SHIELD ALLOWANCES Shields: Related Specifications: ,

l Cover Plates (2), Unit i Diesel FO Storage Tanks 3.8.1, 3.8.2 l

Access Cover Plates (2), Unit 1 Diesel FO Storage Tanks 3.8.1,3.82 1 Removable Slab SW Piping (Unit 1/2 Train B) El. 810' 6" 3.7.8 Removable Slab (Hatch Cover) SW Pump, CP-1-SWAPSW-02 3.7.8 i Removable Slab (Hatch Cover) SW Pump, CP1-SWAPSW-01 3.7.8 {

Manhole Cover, MH#E1 A1, Unit 1 SW Train A 3.7.8 Manhole Cover, MH#E1 A2, Unit 1 SW Train A 3.7.8 Manhole Cover, MH#E181, Unit 1 SW Train B 3.7.8 Manhole Cover; MH#E182, Unit i SW Train B 3.7.8 Cover Plates (2), Unit 2 Diesel FO Storage Tanks 3.8.1, 3.8.2 Access Cover Plates (2), Unit 2 Diesel FO Storage Tanks 3.8.1, 3.8.2 Removable Stab (Hatch Cover) SW Pump, CP2-SWAPSW-02 3.7.8 Removable Stab (Hatch Cover) SW Pump, CP2-SWAPSW-01 3.7.8 Manhole Cover, MH#E2A1, Unit 2 SW Train A 3.7.8 Manhole Cover, MH#E2A2, Unit 2 SW Train A 3.7.8 Manhole Cover, MH#E2A3, Unit 2 SW Train A 3.7.8 Manhole Cover, MH#E2A4, Unit 2 SW Train A 3.7.8 Manhole Cover, MH#E2AS, Unit 2 SW Train A 3.7.8 Manhole Cover, MH#E281, Unit 2 SW Train B 3.7.8 Manhole Cover, MH#E2B2, Unit 2 SW Train B 3.7.8 Manhole Cover, MH#E2B3, Unit 2 SW Train B 3.7.8 Manhole Cover, MH#E2B4, Unit:) SW Train B 3.7.8 Manhole Cover, MH#E285, Unit 2 SW Train B 3.7.8 Allowance-May be removed under administrative control for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months provided:

a. The capability exists to re-install the missile shield immediately upon notification of a National Weather Service issued Tomado Waming, Tomado Watch, or other Special Weather Statement with winds in excess of 60 mph affecting CPSES, and

b. No more than one OPERABLE train per unit of a system shall have its missile shields removed at one time.

l l

CPSES - UNITS 1 AND 2 - TRM 13.7-29 Revision 29 - July 27,1999 ,

FCV(s)and Associ:ted Bypass Valves TR 13.7.40 13.7 PLANT SYSTEMS .

TR 13.7.40 Feedwater Control Valves (FCVs) and Associated Bypass Valves TR LCO 13.7.40 Four FCVs and associated bypass valves shall be OPERABLE.

APPLICABILITY: MODES 1,2, and 3 except when FCV or associated bypass valve is closed and de-activated or isolated by a closed manual valve.

ACTIONS NOTE Separate Condition entry allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME

- A. One or more FCVs A.1 Restore affected FCV(s) 7 days inoperable. to OPERABLE.

DB A.2 Perform an assessment 7 days per the corrective action program to allow continued operation beyond 7 days. ,

B. One or more FCV bypass B.1 Restore affected FCV(s) 7 days i

valve (s) inoperable. to OPERABLE.

QB B.2 Perform an assessment 7 days

., per the corrective action program to allow continued operation beyond 7 days.

CPSES - UNITS 1 AND 2 -TRM 13.7-30 Revision 29 -July 27,1999

)

FCV(s)and Associ:ted Bypass Velv;s TR 13.7.40 SURVEILLANCE REQUIREMENTS NOTE These surveillance requirements may be satisfied by an engineering evaluation following packing adjustment.

SURVEILLANCE FREQUENCY TRS 13.7.40.1 Verify the isolation time of each FCV and associated 18 months bypass valve is s 5 seconds.

TRS 13.7.40.2 Verify each FCV and associated bypass valve 18 months actuates to the isolation position on an actual or simulated actuation signal.

I 1

CPSES - UNITS 1 AND 2 -TRM 13.7-3 f Revision 29 - July 27,1999

AC Sources (Dhsel Generitor Requirements) l TR 13.8.31 13.8 ELECTRICAL POWER SYSTEMS TR 13.8.31 AC Sources (Diesel Generator Requirements)

TR LCO 13.8.31 Pursuant to TS 3.8.1 and 3.8.2, the Technical Requirements Surveillances (TRS) listed below for the diesel generator (s) (DGs) required to be capable of supplying the onsite Class 1E power distribution 3 subsystem (s) shall be met.

l APPLICABILITY: MODES 1,2,3,4,5 and 6. j 1

ACTIONS -

l CONDITION REQUIRED ACTION COMPLETION TIME l A. One or more of the A.1 Enter the applicable immediately.

following surveillances not Condition (s) of TS 3.8.1 $

met for required DG(s). or 3.8.2 for the effected DG(s) inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.8.31.1 Verify diesel generator is aligned to provide 31 days standby power to the associated emergency busses.

(continued)

CPSES - UNITS 1 AND 2- TRM 13.8-1 Revision 29 - July 27,1999 )

AC Sources (Di:ssi Gentrator Requirements)

TR 13.8.31 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.8.31.2 NOTE Verify requirement during MODES 3,4,5,6, or with core off-loaded.

Subject the diesel to an inspection in accordance 18 months with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service.

TRS 13.8.31.3 NOTE Verify requirement during MODES 3,4,5,6, or with core off-loaded.

Verify that the auto-connected loads to each 18 months diesel generator do not exceed the continuous rating of 7,000 kW.

TRS 13.8.31.4 NOTE Verify requirement during MODES 3,4,5,6, or with core off-loaded.

I Verify that the following diesel generator lockout 18 months features prevent diesel generator from starting:

a. Barring device engaged, or

b. Maintenance Lockout Mode.

(continued)

CPSES - UNITS 1 AND 2 -TRM 13.8-2 Revision 29 - July 27,1999

AC Sources (Diesel Generator Requirements)

TR 13.8.31 ;

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY TRS 13.8.31.5 Pump out each fuel oil storage tank, remove 10 Years accumulated sediment and clean the tank using a sodium hypochlorite solution or equivalent.

TRS 13.8.31.6 Perform a pressure test of those portions of the 10 Years !

diesel fuel oil system designed to Section ill, l subsection ND of the ASME Code, when tested pursuant to the Inservice Inspection Program.

i CPSES - UNITS 1 AND 2 -TRM 13.8-3 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurre,nt Protection Devices TR 13.8.32 13.8 ELECTRICAL POWER SYSTEMS TR 13.8.32 Containment Penetration Conductor Overcurrent Protection Devices TR LCO 13.8.32 All containment penetration conductor overcurrent protective devices, which are listed in Table 13.8.32-1, shall be OPERABLE.

APPLICABILITY: MODES 1,2,3 and 4.

ACTIONS NOTES

1. TR LCO 13.0.4 is not applicable to overcurrent protective devices in circuits which have their associated protective device tripped / removed and their inoperable protective device racked out, locked open, or removed.

2. Separate Condition entry is allowed for each overcurrent protection device.

i S

CPSES - UNITS 1 AND 2 -TRM 13.8-4 Revision 29 - July 27,1999

Containment Penetration Conductor Ov;rcurrent Protection Devices TR 13.8.32 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1.1.1 Verify the circuit (s) de- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months containment penetration energized by racked out, conductor overcurrent locked open, or removed M protective device (s) inoperable protective inoperable. device (s). Once per 31 days thereafter M

A.1.1.2 Tripping / removing the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months associated protective device (s).

QB A.1.2.1 Verify the circuit (s) de- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months energized by tripped /

removed associated M protective device (s).

Once por 7 days thereafter

.QB A.1.2.2 Verify the circuit (s) de- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months energized by racked out, locked open, or removed M inoperable protective device (s). Once per 7 days thereafter M

A.2 Declare the affected 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months system (s) or component (s) inoperable.

B. Required Actions and B.1 Be in MODE 3,. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times not met. M B.2 Be in MCDE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months CPSES - UNITS 1 AND 2 - TRM 13.8-5 Revision 29 - July 27,1999

1 Containment P:netrction Conductor Ov:rcurr;nt Protection Devices i TR 13.8.32 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.8.32.1 Verify that the medium voltage 6.9 kV and low 18 months voltage 480V switchgear circuit breakers are OPERABLE by selecting, on a rotating basis, at least 10% of the circuit breakers of each current rating and performing the following:

a. A CHANNEL CAllBRATION of the associated protective relays,

b. An integrated system functional test which includes simulated automatic actuation of the system and verifying that each relay and associated circuit breakers and control circuits function as designed, and

c. For each circuit breaker found inoperable during these functional tests, one or an additional representative sample of at least 10% of all the circuit breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested.

(continued)

I 4

CPSES - UNITS 1 AND 2-TRM 13.8-6 Revision 29 - July 27,1999

)

Containment P:n:tration Conductor Ovsrcurrent Protection Devices TR 13.8.32 SURVEILLANCE REQUIREMENTS (continued)

SURVElLLANCE FREQUENCY j TRS 13.8.32.2 Select and functionally test a representative sample 18 months of at least 10% of each type 480 V molded case 3 circuit breakers and of lower voltage circuit breakers.

Circuit breakers selected for functional testing shall q be sa' acted on a rotating basis. Testing of these circuit breakers shall consist of injecting a current with a value equal to 300% of the pickup of the long-time delay trip element and 150% of the pickup of the short-time delay trip element, and verifying that the circuit breaker operates within the time delay band width for that current specified by the manufacturer. The instantaneous element shall be ,

tested by injecting a current equal to 120% of the pickup value of the element and verifying that the i circuit Dreaker trips instantaneously with no intentional time delay. Molded case circuit breaker testing shall also follow this procedure except that generally no more than two trip elements, time delay and instantaneous, will be involved. The ,

instantaneous element for molded case circuit breakers shall be tested by injecting a current for a frame size of 250 amps or less with tolerances of

+40%, -25% and a frame size of 400 amps or greater with tolerances of 25% and verifying that the circuit '

breaker trips instantaneously with no apparent time delay. Circuit breakers found inoperable during functional testing shall be restored to OPERABLE status prior to resuming operation. For each circuit breaker found inoperable during these functional )

tests, an additional representative sample of a least 10% of all the circuit breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested.

TRS 13.8.32.3 Subject each circuit breaker to an inspdction and 60 months preventive maintenance in accordance with procedures prepared in conjunction with its manufacturer's recommendations.

CPSES - UNITS 1 AND 2 -TRM 13.8-7 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 1 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED t

1. 6.9 KVAC from Switchgears

a. Switchgear Bus 1A1 RCP #11

1) Primary Breaker 1PCPX1 a) Relay 50M1-51' b) Relay 86M

2) Backup Breakers 1 A1-1 or 1 A1-2 a) Relay 51M3 b) Relay 51 for 1 A1-1 c) Relay 51 for 1 A1-2 d) Relay 86/1 A1

b. Switchgear Bus 1 A2 RCP #12

1) Primary Breaker 1PCPX2 a) Relay 50M1-51 b) Relay 86M

2) Backup Breakers 1 A2-1 or 1 A2-2 a) Relay 51M3 b) Relay 51 for 1 A2-1 c) Relay 51 for 1 A2-2 d) Relay 86/1A2 (continued) 1 CPSES - UNITS 1 AND 2 -TRM 13.8-8 Revision 29 - July 27,1999

t Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 2 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM

]

AND LOCATION POWERED 1

1. 6.9 KVAC from Switchgears (continued)

c. Switchgear Bus 1A3 RCP #13 l

1) Primary Breaker 1PCPX3 a) Relay 50M1-51 b) Relay 86M

2) Backup Breakers 1 A3-1 or 1 A3-2 a) Relay 51M3 b) Relay 51 for 1 A3-1 c) Relay 51 for 1 A3-2 d) Relay 86/1A3

d. Switchgear Bus 1 A4 RCP #14

1) Primary Breaker 1PCPX4 a) Relay 50M1-51 b) Relay 86M

2) Backup Breaker 1A4-1 or 1A4-2 a) Relay 51M3 b) Relay 51 for 1 A4-1 c) Relay 51 for 1 A4-2 d) Relay 86/1 A4 (continued) k

\

CPSES - UNITS 1 AND 2 -TRM 13.8-9 Revision 29 - July 27,1999

l Containment PInetration Conductor Ovzrcurrent Protection Devices 1 TR 13.8.32 I TABLE 13.8.32-1a (Page 3 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

2. 480 VAC from Switchgears 2.1 Device Location - 480V Switchgear 1 EB1, Containment Recire. Fans ,

1EB2,1EB3 and 1EB4 and CRDM Vent Fans

a. Primary Breakers - 1FNAV1,1FNAV2,1FNAV3,1FNAV4,1FNCB1 and 1FNCB2

b. Backup Breakers - 1EB1-1,1EB2-1,1EB3-1 and 1EB4-1, BT-1EB13 and BT-1EB24 1 l'

1) Long Time & Instantaneous Relays (Associated circuit breaker shown in parentheses)

M (1EB1-1) 50/51 (1EB2-1) 50/51 (1EB3-1)

{

1FNAV1 1FNAV2 1FNAV3 i l

50/51 (1EB4-1) 50/51 (1EB3-1) 5Dl51 (1EB4-1) 1FNAV4 1FNCB1 1FNCB2 j

2) Time Delay Relays (Associated circuit breaker shown in parentheses) 62-1 (1EB1-1 and BT-1EB13) 62-jX (1FNAV1) 1FNAV1 1FNAV1 62-1 (1EB2-1 and BT-1EB24) $2dX (1FNAV2) 1FNAV2 1FNAV2 62.1 (1EB3-1 and BT-1EB13) 62dX (tFNAV3) 1FNAV3 1FNAV3

$2-1 (1EB4-1 and BT-1EB24) $2dX (1FNAV4) 1FNAV4 1FNAV4 j

$2-1 (1EB3-1 and BT-1EB13) $2dX. (1FNCB1) 1FNCB1 1FNCB1

$2-1 (1EB4-1 and BT-1EB24) 62dX (1FNCB2) 1FNCB2 1FNCB2 (continued)

CPSES - UNITS 1 AND 2 - TRM - 13.8-10 Revision 29 - July 27,1999 I

Containment PInetration Conductor Ovarcurrcnt Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 4 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

3. 480VAC from Motor Control Centers 3.1 Device Location - MCC 1EB1-2 Compartmcnt Numbers listed below.

Primary and Backup - Both primary and backup breakers have identical trip Breakers ratings and are in the same MCC Compt. These breakers are General Electric type THED with thermal- magnetic trip elements.

MCC 1EB1-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 4G THED Motor Operated Valve 1-TV-4691 4M THED Motor Operated Valve 1-TV-4693 3F -THED Containment Drain Tank Pump-03 9H THED Reactor Cavity Sump Pump-01 9M THED Reactor Cavity Sump Pump-02 !

1 7H THED Containment Sump #1 Pump-01 7M THED Containment Sump #1 Pump-02 6H THED RCP #11 Motor Space Heater-01 6M THED RCP #13 Motor Space Heater-03 8B THED incore Detector Drive "A" 8D THED incore Detector Drive "B" 7B THED incore Detector Drive "F" 3B THED Stud Tensioner Hoist Outlet-01 7D THED Hydraulic Deck Lift-01 4B THED Reactor Coolant Pump Motor Holst Receptacle-42 8H THED RC Pipe Penetration Cooling Unit-01 8M THED RC Pipe Penetration Cooling Unit-02 5H THED RCP #11 Oil Lift Pump-01 SM THED RCP #13 Oil Lift Pump-03 10B THED Preaccess Filter Train Package Receptacle-17 10F THED. S.G. Wet Layup Cire. Pump 01 (CP1 CFAPRP-01) 12M THED S.G. Wet Layup Cire. Pump 03 (CP1-CFAPRP-03) 12H THED Containment Ltg. XFMR-28 (PNL C11 & C12) 2M THED RC Drain Tank Pump No.1 2F THED Containment Ltg. XFMR-16 (PNL C7 & C9) 1M THED Containment Ltg. XFMR-12 (PNL C1 & C5) 3M THED Preaccess Fan No.11 (continued)

CPSES - UNITS 1 AND 2-TRM 13.8 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection. Devices TR 13.8.32 TABLE 13.8.32-1a (Page 5 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

3. 480VAC from Motor Control Centers (continued) 3.2 Device Location - MCC 1EB2-2 Compartment Numbers listed below.

Primary and Backup - Both primary and backup breakers have Breakers identical trip ratings and are located in the same MCC compt. These breakers are General Electric type THED with thermal-magnetic trip elements.

MCC 1EB2-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED

]

4G THED Motor Operated Valve 1-W-4692 4M THED Motor Operated Valve 1-TV-4694 3F THED Containment Drain Tank Pump-04 7H THED Containment Sump No. 2 Pump-03 7M THED Containment Sump No. 2 Pump-04 ,

6H THED RCP #12 Motor Space Heater-02 6M THED RCP #14 Motor Space Heater-04 58 THED Incore Detector Drive "C" 2B THED incore Detector Drive "D" 7B THED incore Detector Drive "E" 5D THED Containment Fuel Storage Crane-01 3B THED Stud Tensioner Hoist Outlet-02 4B THED Containment Solid Rad Waste Compactor-01 10B THED RCC Change Fixture Hoist Drive-01 10F THED Refueling Cavity Skimmer Pump-01 12B THED Power Receptacles (Cont. E1. 841')

1M THED S.G. Wet Layup Cire. Pump 02 (CP1-CFAPRP-02) 12M THED S.G. Wet Layup Cire. Pump 04 (CP1-CFAPRP-04) 8H THED RC Pipe Penetration Fan-03 8M THED RC Pipe Penetration Fan-04 SH THED RCP #12 Oil Lift Pump-02 SM THED RCP #14 Oil Lift Pump-04 12H THED Preaccess Filter Train Packag eReceptacles - 18 6D THED Containment Auxiliary Upper Crane-01 2F THED Containment Lig. XFMR-13 (PNL C2) 2D THED Containment Access Rotating Platform-01 2M THED Reactor Coolant Drain Tank Pump-02 9F THED Containment Ltg. XFMR-17(PNL C8 & C10) 9M THED Containment Ltg. XFMR-15 (PNL C4 & C6) 3M THED Preaccess Fan-12 (continued)

CPSES - UNITS 1 AND 2-TRM 13.8-12 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 6 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

3. 480VAC from Motor Control Centers (continued) 3.3 Device Location -

MCC 1EB3-2 Compartment numbers listed below.'

Primary and Backup - Unless noted otherwise, both primary and Breakers backup breakers have identical trip ratings and are located in the same MCC compt. These breakers are General Electric type THED or THFK with thermal-magnetic trip elements.

MCC 1EB3-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 8RF THED JB-1S-10050, Altem. Feed to Motor Operated Valve 1-8702A 1G THED Motor Operated Valve 1-8112 9G THED Motor Operated Valve 1-8701 A 9M THED Motor Operated Valve 1-8701B SM THED Motor Operated Valve 1-8000A 5G THED Motor Operated Valve 1-HV-6074 4G THED Motor Operated Valve 1-HV-6076 4M THEDN Motor Operated Valve 1-HV-6078 2G THED Motor Operated Valve 1-HV-4696 2M THED Motor Operated Valve 1-HV-4701 3G THEDW Motor Operated Valve 1-HV-5541 3M THEDN Motor Operated Valve 1-HV-5543 1M THED Motor Operated Valve 1-HV-6083 6F THED Motor Operated Valve 1-8808A 6M THED Motor Operated Valve 1-8808C 7M THED Containment Ltg. XFMR-18 (PNL SC1 & SC3) l 8M THED Neutron Detector Well Fan-09 l 7F THFK Electric H, Recombiner Power Supply PNL-01 l 8RM THED Motor Operated Valve 1-HV-4075C

. (continued)

(a) Primary protection is provided by Gould Tronic TRS fusible switch with 3.2A fuse.

CPSES - UNITS 1 AND 2 -TRM 13.8-13 Revision 29 - July 27,1999 3

w Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 7 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED 3, 480VAC From Motor Control Centers (continued) 3.4 Device Location - MCC 1EB4-2 Compartment numbers listed below.

Primary and Backup - Unless noted otherwise, both primary and backup Breakers breakers have identical trip ratings and are located in the same MCC compt. These breakers are General Electric I type THED or THFK with thermal-magnetic trip elements. I MCC 1EB4-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED iM THED JB-1S-1230G, Altem. Feed to Motor Operated l Valve 1-8701B l 8G THED Motor Operated Valve 1-8702A l l

8M THED Motor Operated Valve 1-8702B 4M THED Motor Operated Valve 1-80008 4G THED Motor Operated Valve 1-HV-6075 3G. THED Motor Operated Valve 1-HV-6077 1 3M THEDM Motor Operated Valve 1-HV-6079 2G THED Motor Operated Valve 1-HV-5562 2M THEDM Motor Operated Valve 1-HV-5563 5F THED Motor Operated Valve 1-8808B SM THED Motor Operated Valve 1-8808D 6M THED Containment Lig. XFMR-19(PNL SC2 & SC4) 7M THED Neutron Detector Well Fan-10 6F THFK Elect. H, Recombiner Power Supply PNL-02 (continued)

(a) Primary protection is provided by Gould Tronic TRS fusible switch with 3.2A fuse.

l i

I CPSES - UNITS 1 AND 2 -TRM 13.8-14 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 8 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

4. 480VAC From Panelboards 4.1 Pressurizer Heater Groups A, B, & D q l

a. Primary Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No. & Location -

Ckt. Nos. 2 thru 4 of Panelboards 1EB2-1-2,1EB3-1-2,1EB4-1-1,1EB4-1-2 and Ckt. Nos. 2 thru 5 of Panelboards 1EB2-1-1 and 1EB3-1-1.

b. Backup Breakers - General Electric Type THJS with longtime and insts. solid state trip delvces with 400 Amp. sensor.

Breaker No. & Location -

Ckt. No.1 of Panelboards 1 EB2-1-1,1 EB2-1 -2,1 EB3-1 -1,1 EB3-1 -2, 1EB4-1-1 and 1EB4-1-2.

4.2 Pressurizer Heater group C

a. Primary Breakers - General Electric Type THED breakers.

Breaker No. & Location -

For both 1EB1-1-1 & 1EB1-1-2 are located at Ckt.

Nos. 2 thru 4.

b. Backup Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No. & Location -

Ckt Nos. 2 thru 4 of Switchboards 1EB1-1-1 & 1EB1-1-2.

(continued)

CPSES - UNITS 1 AND 2 -TRM 13.8-15 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 9 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR ,

OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED 4.3 480VAC From Plant Support Power System Panelboards Both primary and backup breakers have identical trip settings, and are located in the same panel board. These breakers are Square D type FC, KH, and LH.

a) Panelboard 1B11-1-1 Device Location Breaker Tvoe System Powered Ckt 2 FC Containment Elevator CP1-MEELRB-01 Ckt 4 KH Welding Receptacles Distribution Panel 1B11-1-1-1 Ckt 6 LH Containment Polar Crane CP1-MESCCP-01 b) Panelboard 1B11-1-2 Device Location Breaker Tvoe System Powered Ckt 2 FC Fuel Transfer System Rx Side Cont. Pnl for TBX-FHSTTS-02 Ckt 14 FC Containment Lighting Xfmr CP1-ELTRNT-14 Ckt 16 FC Manipulator Crane 1-01 TBX-FHSCMC-01 (continued)

CPSES - UNITS 1 AND 2 - TRM 13.8-16 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices .

TR 13.8.32 )

TABLE 13.8.32-1a (Page 10 of 13) 1 UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM ;

AND LOCATION POWERED

5. 120V Space Heater Circuits Containment Recire. Fan and and CRDM Vent from 480V Switchgears Fan Motor Space Heaters

a. Primary Devices - N/A (Fuse)

b. Backup Breakers ,

BKR. LOCATION WESTINGHOUSE

& NUMBER BKR. TYPE Swgr.1EB1, EB1010 Cubicle 3A, CP1-VAFNAV-01 Space Heater Bkr.

Swgr.1EB2, EB1010 Cubicle 3A, CP1-VAFNAV-02 Space Heater Bkr.

Swgr.1 EB3, EB1010 Cubicle 9A, CP1-VAFNAV-03 Space Heater Bkr.

Swgr.1 EB4, EB1010 Cubicle 9A, CP1-VAFNAV-04 Space Heater Bkr.

Swgr.1EB3, EB1010 Cubicle 8A, CP1-VAFNCB-01 Space Heater Bkr. .

Swgr.1EB4, EB1010 Cubicle 8A, CP1-VAFNCB-02 Space Heater Bkr.

(continued) .

CPSES - UNITS 1 AND 2-TRM 13.8-17 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 11 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

6. 125V DC Control Power Various

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE XED1-1 1,6 TED XED2-1 1,3,6 TED XD2-3 8 TED 1ED2-1 14,17 TED 1ED1-1 14 TED 1D2-3 7,10 TED 1 D2-2 9 TED 1ED2-2 12 TED 1ED3-1 5 TED 1ED1-2 7,8 TED TBX-WPXILP-01 Main (LBK3) FB(Westinghouse)

7. 120V AC Control Power from isolation XFMR TXEC3 & TXEC4

a. Primary Devices - N/A (Fuse)

b. Backup Breakers - Square D Type OOB located in Miscellaneous Signal Control Cabinet.

1) Panel Board A, Ckt. Bkr. connected at TB4-13

2) Panel Board B, Ckt. Bkr. connected at TB6-7 (continued)

CPSES - UNITS 1 AND 2-TRM 13.8-18 Revision 29 - July 27,1999

)

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 12 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

8. 120V AC Pcwer for Personnel and Emergency Airlocks

a. Primary Devices - N/A (Fuse)

b. Backup Breakers i GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE ;

l XE 2 34 TED !

XEC1-2 2 TED I

9.118V AC Control Power

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE 1C2 22 TED I 1PC1 10,13 TED iPC4 6,10 TEC 1EC1 7 TED 1EC2 7 TED 1ECS 8 TED 1EC6 3,8 TED (continued) i l

CPSES - UNITS 1 AND 2 - TRM 13.8-19 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1a (Page 13 of 13)

UNIT 1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

10. Emergency Evacuation System Waming Lights Power

a. Primary Devices - N/A (Fuse)

b. Backup Breakers SQUARE D PANELBOARD NO. CKT. NO. BREAKER WPE XEC3-3 9,10 FY

11. DRPI Data Cabinet Power Supplies

a. Primary Breakers SQUARE D PANELBOARD NO. CKT. NO. BREAKER TYPE 1C14 1,2 FA

b. Backup Breakers SQUARE D PANELBOARD NO. CKT. NO. EREAKER TYPE 1C14 Main Pnl. Bkrs. FA CPSES - UNITS 1 AND 2 - TRM 13.8-20 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 1 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

1. 6.9 KVAC from Switchgears

a. Switchgear Bus 2A1 RCP #21

1) Primary Breaker 2PCPX1 a) Relay 50M1-51 b) Relay 86M

2) Backup Breakers 2A1-1 or 2A1-2 a) Relay 51M3 b) Relay 51 for 2A1-1 c) Relay 51 for 2A1-2 d) Relay 86/2A1

b. Switchgear Bus 2A2 RCP #22

1) Primary Breaker 2PCPX2 a) Relay 50M1-51 b) Relay 86M

2) Backup Breakers 2A2-1 or 2A2-2 a) Relay 51M3 b) Relay 51 for 2A2-1 c) Relay 51 for 2A2-2 d) Relay 86/2A2 (continued)

CPSES - UNITS 1 AND 2 - TRM 13.8-21 Revision 29 - July 27,1999

)

\

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 2 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM ;

AND LOCATION POWERED

1. 6.9 KVAC from Switchgears (continued)

)

c. Switchgear Bus 2A3 RCP #23

1) Primary Breaker 2PCPX3 a) Relay 50M1-51 b) Relay 86M

2) ~ Backup Breakers 2A3-1 or 2A3-2 a) Relay 51M3 b) Relay 51 for 2A3-1 c) Relay 51 for 2A3-2 d) Relay 86/2A3

d. Switchgear Bus 2A4 RCP #24

1) Primary Breaker 2PCPX4 a) Relay 50M1-51 b) Relay 86M

2) Backup Breaker 2A4-1 or 2A4-2 a) Relay 51M3 b) Relay 51 for 2A4-1 c) Relay 51 for 2A4-2 d) Relay 86/2A4 (continued)

CPSES - UNITS 1 AND 2 - TRM 13.8-22 Revision 29 - July 27,1999

I Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 3 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR '

OVERCURRENT PROTECTIVE DEVICES i l

DEVICE NUMBER SYSTEM AND LOCATION POWERED

2. 480 VAC from Switchgears 2.1 Device Location - 480V Switchgears 2EB1, Containment Recirc. Fans 2EB2, 2EB3 and 2EB4 and CRDM Vent Fans

a. Primary Breakers - 2FNAV1,2FNAV2,2FNAV3,2FNAV4,2FNCB1 and 2FNCB2

b. Backup Breakers - 2EB1-1,2EB2-1,2EB3-1 and 2EB4-1, BT-2F.B13 and BT-2EB24

1) Long Time & Instantaneous Relays (Associated circuit breaker shown in parentheses) 50/51 (2EB1-1) 50/51 (2EB2-1) 50/51 (2EB3-1) 2FNAV1 2FNAV2 2FNAV3 50/51 (2EB4-1) 50/51 (2EB3-1) 50/51(2EB4-1) 2FNAV4 2FNCB1 2FNCB2

2) Time Delay Relays (Associated circuit breaker shown in parentheses) 02-1 (2EB1-1 and BT-2EB13) 02-1X (2FNAV1) 2FNAV1 2FNAV1

$2-1 (2EB2-1 and BT-2EB24) 62-1X (2FNAV2) 2FNAV2 2FNAV2 02-1 (2EB3-1 and BT-2EB13) 62-1X (2FNAV3) 2FNAV3 2FNAV3 62-1 (2EB4-1 and BT-2EB24) 62-J X (2FNAV4) 2FNAV4 2FNAV4

, 12-1 (2EB3-1 and BT-2EB13) 62-1X (2FNCB1) 2FNCB1 2FNCB1 62-1 (2EB4-1 and BT-2EB24)

_ $2-1X (2FNCB2) 2FNCB2 2FNCB2 (continued)

CPSES - UNITS 1 AND 2 - TRM 13.8-23 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 4 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

3. 480VAC from Motor Control Centers 3.1 Device Location - MCC 2EB1-2 Compartment Numbers listed below; Primary and Backup - Both primary and backup breakers have identical trip Breakers ratings and are in the sarne MCC Compt. These breakers are General Electric type THED with thermal-magnetic trip elements.

MCC 2EB1-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 4G THED Motor Operated Valve 2-TV-4691 4M THED Motor Operated Valve 2-TV-4693 3F THED Containment Drain Tank Pump-03 9H THED Reactor Cavity Sump Pump-01 9M THED Reactor Cavity Sump Pump-02 7H THED Containment Sump #1 Pump-01 7M THED Containment Sump #1 Pump-02 6H THED RCP #21 Motor Space Heater-01 6M THED RCP #23 Motor Space Heater-03 8B THED incore Detector Drive "A" 8D THED incore Detector Drive "B" 7B THED incore Detector Drive "F" 3B THED Stud Tensioner Holst Outlet-01 7D THED Hydraulic Deck Lift-01 48 THED Reactor Coolant Pump Motor Hoist Receptacle-42 8H THED RC Pipe Penetration Cooling Unit-01 8M THED RC Pipe Penetration Cooling Unit-02 5H THED RCP #21 Oil Lift Pump-01 SM THED RCP #23 Oil Lift Pump-03 10B THED Preaccess Filter Train Package Receptacle-17 10F THED S.G. Wet Layup Cire. Pump 01 (CP2-CFAPRP-01) 12M THED S.G. Wet Layup Cire. Pump 03 (CP2-CFAPRP-03) 12H THED Containment Ltg. XFMR-28 (PNL 2C11 & 2C12) 128 THED Personnel Air Lock Hydraulic Unit #2 2M THED RC Drain Tank Pump No.

2F THED Containment Ltg. XFMR-16 (PNL 2C7 & 2C9) I 1M THED Containment Ltg. XFMR-12 (PNL 2LPC1 & 2LPC5) 3M THED- Preaccess Fan No.11 (continued) .

CPSES - UNITS 1 AND 2-TRM 13.8-24 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices l TR 13.8.32 TABLE 13.8.32-1b (Page 5 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR j OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED l

3. 480VAC from Motor Control Centers (continued) 3.2 Device Location - MCC 2EB2-2 Compartment Numbers listed below.

Primary and Backup - Both primary and backup breakers have

)

Breakers identical trip ratings and are located in the same MCC compt. These breakers are General Electric type THED ,

with thermal-magnetic trip elements.

MCC 2EB2-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 1

4G THED Motor Operated Valve 2-W-4692 4M THED Motor Operated Valve 2-TV-4694 3F THED Containment Drain Tank Pump-04 7H THED Containment Sump No. 2 Pump-03 7M THED Containment Sump No. 2 Pump-04 6H THED RCP #22 Motor Space Heater-02 .

6M THED RCP #24 Motor Space Heater-04 l 5B THED incore Detector Drive "C" 2B THED incore Detector Drive "D" 7B THED incore Detector Drive "E" 5D THED Containment Fuel Storage Crane-01 3B THED Stud Tensioner Hoist Outlet-02 10B THED RCC Change Fixture Hoist Drive-01 10F THED Refueling Cavity Skimmer Pump-01 128 THED Power Receptacles (Cont. E1. 841')

1M THED S.G. Wet Layup Cire. Pump 02 (CP2-CFAPRP-02) 12M THED S.G. Wet Layup Cire. Pump 04 (CP2-CFAPRP-04) 8H THED RC Pipe Penetration Fan-03 BM THED RC Pipe Penetration Fan-04 5H THED RCP #22 Oil Lift Pump-02 SM THED RCP #24 Oil Lift Pump-04 12H THED Preaccess Filter Train Package Receptacles - 18 6D THED Containment Auxiliary UpperCrane-01 2F THED Containment Ltg. XFMR-13 (PNL 2LPC2) .

2D THED Containment Access Rotating Platform-01 2M THED Reactor Coolant Drain Tank Pump-02 9F THED Containment Ltg. XFMR-17 (PNL 2C8 & 2C10) 9M THED Containment Ltg. XFMR-15 (PNL 2LPC4 & 2LPC6)

I 3M THED Preaccess Fan-12

1C THFK Containment Welding Receptacles (continued) .

CPSES - UNITS 1 AND 2 - TRM 13.8-25 Revision 29 - July 27,1999

f Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 6 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

3. 480VAC from Motor Control Centers (continued) .

3.3 Device Location - MCC 2EB3-2 Compartment numbers listed below.

Pr' mary and Backup - Unless noted otherwise, both primary and backup breakers have identical trip ratings and are located in the same'MCC compt. These breakers are General Electric type THED or THFK with thermal-magnetic trip elements.

MCC 2EB3-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 8RF THED Altem. Feed to Motor Operated Valve 2-8702A 1G THED Motor Operated Valve 2-8112 9G THED Motor Operated Valve 2-8701 A 9M THED Motor Operated Valve 2-8701B 5M THED Motor Operated Valve 2-8000A SG THED Motor Operated Valve 2-HV-6074 4G THED Motor Operated Valve 2-HV-6076 4M THEDN Motor Operated Valve 2-HV-6078 2G THED Motor Operated Valve 2-HV-4696 2M THED Motor Operated Valve 2-HV-4701 3G THED Motor Operated Valve 2-HV-5541 3M THED Motor Operated Valve 2-HV-5543 1M THED Motor Operated Valve 2-HV-6083 6F THED Motor Operated Valve 2-8808A 6M THED Motor Operated Valve 2-8808C 7M THED Containment Ltg. XFMR-18 (PNL 2SC1 & 2SC3) "

8M THED Neutron Detector Well Fan-09 7F THFK Electric H2Recombiner Power Supply PNL-01 8RM THED Motor Operated Valve 2-HV-4075C (continued)

(a) Primary protection is provided by Gould Tronic TR5 fusible switch with 3.2A fuse.

CPSES - UNITS 1 AND 2 - TRM 13.8-26 Revision 29 - July 27,1999 J

Containment Penetration Conductor Overcurro 1 Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 7 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR '

OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED ;

3. 480VAC From Motor Control Centers (continued) 1 3.4 Device Location - MCC 2EB4-2 Compartment numbers listed below.

Primary and Backup - Unless noted otherwise, both primary and backup breakers have identical trip ratings and are located in the same MCC compt. These breakers are General Electric type THED or THFK with thermal-magnetic trip elements.

MCC 2EB4-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 1M THED Altem. Feed to Motor Operated Valve 2-8701B 8G THED Motor Operated Valve 2-8702A 8M THED Motor Operated Valve 2-8702B 4M THED Motor Operated Valve 2-8000B 4G THED Motor Operated Valve 2-HV-6075 3G THED Motor Operated Valve 2-HV-6077 3M THED (*) Motor Operated Valve 2-HV-6079 2G THED (*) Motor Operated Valve 2-HV-5562 2M THEDW Motor Operated Valve 2-HV-5563 5F THED Motor Operated Valve 2-8808B SM THED Motor Operated Valve 2-8808D 6M THED Containment Ltg. XFMR-19 (PNL 2SC2 & 2SC4) 7M THED Neutron Detector Well Fan-10 6F THFK Elect. H2 Recombiner Power Supply PNL-02 (continued) l (a) Primary protection is provided by Gould Tronic TRS fusible switch with 3.2A fuse. l CPSES - UNITS 1 AND 2 - TRM 13.8-27 Revision 29 - July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 8 of 14) )

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR l' OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

4. 480VAC From Panelboards 4.1 Pressurizer Heater groups A, B, & D

a. Primary Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No. & Location -

Ckt. Nos. 2 thru 4 of Panel boards 2EB2-1-2,2EB3-1-2,2EB4-1-1,2EB4-1-2 and Ckt. Nos. 2 thru 5 of Panelboards 2EB2-1-1 and 2EB3-1-1.

b. Backup Breakers - General Electric Type THJS with longtime and insts. solid state trip devices with 400 Amp. sensor.

Breaker No. & Location -

Ckt. No.1 of Panelboards 2EB2-1 -1,2 EB2-1 -2, 2EB3-1 -1, 2EB3-1 -2, 2EB4-1-1 and 2EB4-1-2.

4.2 Pressuizer Heater group C

a. Primary Breakers - General Electric Type THED breakers.

Breaker No. & Location - For both 2EB1-1-1 & 2EB1-1-2 are located at Ckt. Nos. 2 thru 4.

b. Backup Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No. & Location -

Ckt Nos. 2 thru 4 of Switchboards 2EB1-1-1 & 2EB1-1-2.

I (continued) j i

s CPSES - UNITS 1 AND 2 -TRM 13.8-28 Revision 29 - July 27,1999 _

i

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 9 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES

4. 480VAC From Panelboards (continued) 4.3 480 VAC From Plant Support Power Systems Panelboards Both primary and backup breakers have identical trip settings, and are located in the same panelboard. These breakers are Square D type FH, KH, and LH.

a) Panelboard 2B10-1-2 Device Location Breaker Tvne System Powered Ckt 2 FH Containment Elevator CP2-MEELRB-01 Ckt 4 KH Containment Welding Receptacles Ckt 6 LH Containment Polar Crane CP2-MESCCP-01 Ckt 1 LH Containment Jib Crane CP2-MEMECA-16 Disconnect Switches CP2- ECDSNC-15&16 (continued)

CPSES - UNITS 1 AND 2 - TRM 13.8-29 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 10 of 14) .

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES

4. 480VAC From Panelboards (continued) 4.3 480 VAC From Plant Support Power Systems Panelboards b) Panelboard 2B10-1-1-1 Device Location BreakerTvoe System Powered Ckt 4 N FH Personnel Airlock Hydraulic Units CP2-MEMEHU-01 and 02 Ckt 6 FH Fuel Transfer System Rx Side Cont. Pnl for TCX-FHSTTS-02 Ckt 10 FH Containment Lighting Xfmr CP2-ELTRNT-14 Ckt 8 FH Manipulator Crane 1-01 TCX-FHSCMC-01 (continued)

(b) Breakers become electrical penetration overcurrent protection devices only when transfer switch CP2-BSTSNB-01 is aligned to plant support power panel 2B10-1-1-1/04/BKR-1 and 2. Transfer switch CP2-BSTSNB-01 is normally aligned to MCC 2EB1-2/128/BKR-1 and 2.

CPSES - UNITS 1 AND 2 -TRM 13.8-30 Revision 29 - July 27,1999 l

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 11 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

5. 120V Space Heater Circuits Containment Recir. Fan and from 480V Switchgears CRDM Vent Fan Motor Space Heaters

a. Primary Devices - N/A (Fuse)

b. Backup Breakers BKR. LOCATION WESTINGHOUSE

& NUMBER BKR. TYPE Swgr. 2EB1, EB1010 Cubicle 3A, CP2-VAFNAV-01 Space Heater Bkr.

Swgr. 2EB2, EB1010 Cubicle 3A, CP2-VAFNAV-02 Space Heater Bkr.

Swgr. 2EB3, EB1010 Cubicle 9A, CP2-VAFNAV-03 Space Heater Bkr. -

Swgr. 2EB4, EB1010 Cubicle 9A, CP2-VAFNAV-04 Space Heater Bkr.

Swgr. 2EB3, EB1010 Cubicle 8A, CP2-VAFNCB-01 Space Heater.Bkr. .

Swgr. 2EB4, EB1010 Cubicle 8A, I CP2-VAFNCD-02 Space Heater Bkr. >

(continued)

CPSES - UNITS 1 AND 2 - TRM 13.8-31 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 12 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

6. 125V DC Control Power . Various

]

I

a. Primary Devices - N/A (Fuse) I

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE l

XED1-1 6W' TED XED2-1 6W TED '

2ED2-1 11,17,16 TED 2ED1-1 11,14 TED 2D2-3 6,10,11 TED 2D2-2 9 TED 2ED2-2 12 TED 2ED3-1 5 TED 2ED1-2 7,8 TED TBX-WPXILP-01 Main (LBK3) M FB(Westinghouse)

7. 120V AC Control Power from isolation XFMR TXEC3 & TXEC4

a. Primary Devices - N/A (Fuse)

b. Backup Breakers - Square D Type QOB located in Miscellaneous Signal Control Cabinet.

1) Panel Board A, Ckt. Bkr. connected at TB3-5

2) Panel Board B, Ckt. Bkr. connected at TB5-1 (continued)

(c) These circuits provide backup protection to both Units 1 and 2. Testing of these breakers is controlled by Unit i surveillance program.

CPSES - UNITS 1 AND 2 -TRM 13.8-32 Revision 29 -July 27,1999

Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 13 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

8. 120V AC Power for Personnel and Emergency Airlocks

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE XEC1 12 TED XEC2-2 3 TED

9. 118V AC Control Power

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE 2C2 22 TED 2PC1 10,13 TED 2PC4 6,10 TED 2EC1 7 TED 2EC2 4,7 TED 2EC5 8 TED 2EC6 3,8 TED (continued) i CPSES - UNITS 1 AND 2 -TRM 13.8-33 Revision 29 - July 27,1999 l

i Containment Penetration Conductor Overcurrent Protection Devices TR 13.8.32 TABLE 13.8.32-1b (Page 14 of 14)

UNIT 2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM l AND LOCATION POWERED ]

I

10. Emergency Evacuation System Waming Lights Power l

a. Primary Devices - N/A (Fuse)

b. Backup Breakers SQUARE D PANELBOARD NO. CKT. NO. BREAKER TYPE XEC4-3 9,10 FY

11. DRPI Data Cabinet Power Supplies

a. Primary Breakers l

SQUARE D PANELBOARD NO. CKT. NO. BREAKER TYPE 1

2C14 1,2 FA l

b. Backup Breakers SQUARE D PANELBOARD NO. CKT. NO. BREAKER TYPE 2C14 Main Pnl. Bkrs. FA 1

i

)

CPSES - UNITS 1 AND 2 -TRM 13.8-34 Revision 29 -July 27,1999

Decay Time TR 13.9.31 13.9 REFUELING OPERATIONS TR 13.9.31 Decay Time TR LCO 13.9.31 The reactor shall be subcritical for at least 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months .

APPLICABILITY: During movement of irradiated fuel in the reactor vessel.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactorsubcriticalforless A. Suspend all operations immediately than 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months , involving movement of irradiated fuelin the reactor vessel.

SURVEILLANCE REQUIREMENTS ,

SURVEILLANCE FREQUENCY TRS 13.9.31.1 Determine the reactor has been subcritical for at least Prior to movement 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months by verification of the date and time of ofirradiated fuelin subcriticality. the reactor vessel.

t CPSES - UNITS 1 AND 2 -TRM 13.9-1 Revision 29 - July 27,1999

R: fueling Operations / Communications TR 13.9.32 13.9 REFUELING OPERATIONS TR 13.9.32 Refueling Operations / Communications TR LCO 13.9.32 Direct communications shall be maintained between the control room and personnel at the refueling station.

APPLICABILITY: During CORE ALTERATIONS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No direct communications A. Suspend all CORE immediately between the control room ALTERATIONS.

and personnel at the refueling station.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.9.32.1 Verify direct communications between the control Once within 1 room and personnel at the refueling station. hour prior to the start of CORE ALTERATIONS AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months CPSES - UNITS 1 AND 2-TRM 13.9-2 Revision 29 -July 27,1999

Refueling Machine TR 13.9.33 13.9 REFUELING OPERATIONS

. TR 13.9.33 Refueling Machine TR LCO 13.9.33 The refueling machine main hoist and auxiliary monorail hoist shall be used for movement of drive rods or fuel assemblies and shall be OPERABLE with:

a. The refueling machine main hoist used for movement of fuel i assemblies having: I a

1) A minimum capacity of 2850 pounds, and

2) An overload cutoff limit less than or equal to 2800 pounds.

b. The auxiliary monorail hoist used for latching, uniatching and movement of control rod drive shafts having:

1) A minimum capacity of 610 pounds, and

2) A load indicator which shall be used to prevent lifting loads in excess of 600 pounds.

APPLICABILITY: During movement of fuel assemblies and/or latching, unlatching or movement of control rod drive shafts within the reactor vesse!

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements for refueling A.1 Suspend use of any Immediately machine main hoist and/or inoperable refueling auxiliary monorail hoist machine main hoist OPERABILITY not and/or auxiliary monorail satisfied. hoist from operations involving the movement of fuel assemblies and/or latching, uniatching or movement of control rod drive shafts within the reactor vessel.

CPSES - UNITS 1 AND 2 -TRM 13.9.3 Revision 29 -July 27,1999

R: fueling Machine TR 13.9.33 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.9.33.1 The refueling machine main hoist used for movement Once within 100 of fuel assemblies within the reactor vessel shall be hours prior to the demonstrated OPERABLE by performing a load test start of such of at least 2850 pounds and demonstrating an operations .

automatic load cutoff when the main hoist load exceeds 2800 pounds.

TRS 13.9.33.2 The auxiliary monorail hoist and associated load Once within 100 indicator used for latching, unlatching or movement of hours prior to the control rod drive shafts within the reactor vessel shall start of such be demonstrated OPERABLE by performing a load operations test of at least 610 pounds.

CPSES - UNITS 1 AND 2 - TRM 13.9-4 Revision 29 - July 27,1999

Rafueling - Crane Travel - Spent Fuel Storage Areas TR 13.9.34 13.9 Refueling Operations TR 13.9.34 Refueling - Crane Travel - Spent Fuel Storage Areas TR LCO 13.9.34 Loads in excess of 2150 pounds shall be prohibited from travel over fuel assemblies in a storage pool.

APPLICABILITY: With fuel assemblies in the storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Technical Requirement not A.1. Place the crane load in a immediately met. safe condition.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.9.34.1 NOTE Only required to be performed when the hoist is being used to move loads over a spent fuel storage pool.

Each hoist load indicator shall be demonstrated 7 days OPERABLE by performing a load test of at least 2200 pounds.

CPSES - UNITS 1 AND 2 -TRM 13.9-5 Revision 29 - July 27,1999

Water Lcv;l, Rrr:ctor Vessel, Control Rods TR 13.9.35 13.9 REFUELING OPERATIONS TR 13.9.35 Water Level, Reactor Vessel, Control Rods TR LCO 13.9.35 At least 23 feet of water shall be maintained over the top of the irradiated fuel assemblies within the reactor vessel.

APPLICABILITY: During movement of control rods within the reactor vessel while in MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Technical Requirement not A.1 Suspend all operations immediately met. Involving movement of control rods within the reactor vessel.

I SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.9.35.1 The water level shall be determined to be at least its 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months minimum required depth.

AND.

Once within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months prior to the movement of control rods in

, MODE 6 CPSES - UNITS 1 AND 2 - TRM 13.9-6 Revision 29 - July 27,1999

Fuel Storage Area Water Level TR 13.9.36 13.9 REFUELING OPERATIONS TR 13.9.36 Fuel Storage Area Water Level TR LCO 13.9.36 The fuel storage area water level shall be 123 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: Whenever irradiated fuel assemblies are in the storage racks.

NOTE 30 While this LCO is not met, do not commence crane operations with loads over irradiated fuel in the storage racks.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage area water A.1 Suspend crane 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months level < 23 feet above operations with loads in irradiated fuel assemblies the affected fuel storage -

seated in the storage racks. areas and restore the water level to within its limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY I

TRS 13.9.36.1 Verify the fuel storage area water level 2 23 ft above 7 days the irradiated fuel assemblies seated in the storage ,

racks.

~

CPSES - UNITS 1 AND 2 -TRM 13.9-7 Revision 30 - July 27,1999

i Explosiva G s Monitoring Instrumentation TR 13.10.31 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TR 13.10.31 Explosive Gas Monitoring instrumentation TR LCO 13.10.31 Pursuant to Technical Specification 5.5.12a, the explosive gas monitoring instrumentation channels shown in Table 13.10.31-1 shall be OPERABLE with their Alarm / Trip Setpoints set to ensure that the limits specified in TR 13.10.34 are not exceeded.

APPLICABILITY: During Waste Gas Holdup System operation on the inservice recombiner.

ACTIONS NOTE Separate Condition entry is allowed for each . scombiner.

. CONDITION REQUIRED ACTION COMPLETION TIME A. An explosive gas A.1 Declare channel Immediately monitoring instrumentation inoperable.

channel Alarm / Trip Setpoint less conservative than required.

B. 'Any required channel B.1 Restore the inoperable 30 days inoperable. channel to OPERABLE status.

.QB B.2 Submit a Special Report 60 days from when to the Cornmission to the channel was explain why the declared inoperable inoperability was not corrected within 30 days.

(continued)'

CPSES - UNITS 1 AND 2-TRM 13.10-1 Revision 29 - July 27,1999

Explosiva G s Monitoring Instrumentation TR 13.10.31 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. No inlet oxygen monitor C.1 Verify the associated inlet immediately channel OPERABLE on the hydrogen monitor (s) inservice recombiner. OPERABLE.

D. No outlet oxygen monitor D.1 Suspend operation of the immediately channel OPERABLE on the Waste Gas Holdup inservice recombiner. System. 30 QB D.2 Take and analyze grab Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months samples while maintaining oxygen

< 1% by volume.

E. Less than the required E.1 Suspend oxygen supply Immediately hydrogen monitor Channels to the affected OPERABLE on the . recombiner(s),

inservice recombiner.

ANQ QB E.2.1 Suspend addition of immediately No Inlet oxygen monitor waste gas to the system.

channel and no outlet oxygen monitor channel QB OPERABLE on the inservice recombiner. E.2.2 Take and analyze grab Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months samples while during degassing QB maintaining oxygen

< 1% by volume. QB No inlet oxygen monitor channel and no inlet ,

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months hydrogen monitor channel -

during other OPERABLE on the operations inservice recombiner.

CPSES - UNITS 1 AND 2-TRM 13.10-2 Revision 30 - July 27,1999 l

Explosive Gas Monitoring instrumentation TR 13.10.31 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.10.31.1 Perform a CHANNEL CHECK of each explosive gas Once per 24 monitoring instrumentation channel shown in Table hours during 13.10.31-1. Waste Gas Holdup System operation AtiD.

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to Waste Gas Holdup System operation.

TRS 13.10.31.2 Perform a CHANNEL OPERATIONAL TEST of each 31 days explosive gas monitoring instrumentation channel shown in Table 13.10.31-1.

TRS 13.10.31.3 Perform a CHANNEL CAllBRATION of each 92 days explosive gas monitoring instrumentation channel shown in Table 13.10.31-1. This shallinclude the use of standard gas samples in accordance with the manufacturer's recommendations.

l I

I I

CPSES -UNITS 1 AND 2-TRM 13.10-3 Revision 29 - July 27,1999

Explosive Gas Monitoring instrumentation TR 13.10.31 Table 13.10.31-1 (Page 1 of 1) I Explosive Gas Monitoring Instrumentation

INSTRUMENT REQUIRED i CHANNELS

1. Waste Gas Holdup System Explosive Gas Monitoring System

a. Hydrogen Monitors 1 per recombiner

b. Oxygen Monitors 2 per recombiner

One hydrogen and two oxygen monitors are required to be OPERABLE for the operating recombiner during Waste Gas HOLDUP System operation l

CPSES - UNITS 1 AND 2 -TRM 13.10-4 Revision 29 - July 27,1999

Gas Storage Tanks TR 13.10.32 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TR 13.10.32 Gas Storage Tanks TR LCO 13.10.32 Pursuant to TS 5.5.12b, the quantity of radioactivity contained in each gas storage tank shall be s 200,000 Curies of noble gases (considered as Xe-133 equivalent).

APPLICABILITY: At all times.

ACTIONS NOTE Separate condition entry allowed for each gas storage tank.

CONDITION REQUIRED ACTION COMPLETION TIME A. Radioactivity in one or A.1 Suspend all additions of Immediately more storage tank (s) not radioactive material to the within limit. tank (s).

AND A.2 Reduce radioactivity in 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months tank (s) to within limit.

AND A.3 NOTE Required Action A.3 must be completed whenever Condition Ais entered.

Describe events leading Per TS 5.6.3 to exceeding limits in ]

, Radioactive Emuent Release Report.

l CPSES - UNITS 1 AND 2 -TRM 13.10-5 Revision 29 -July 27,1999

Gas Storage Tanks TR 13.10.32 SURVEILLANCE REQUIREMENTS SURVEILI.ANCE FREQUENCY TRS 13.10.32.1 NOTE Only required to be performed when radioactive materia!s are being added to the tank.

Determine the quantity of radioactive material in each Once within 92 gas storage tank to verify within limit. days after the addition of .

radioactive material being added to the tank, but not more often than 92 days CPSES -UNITS 1 AND 2-TRM 13.10-6 Revision 29 - July 27,1999 l

Liquid Holdup Tanks TR 13.10.33 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TR 13.10.33 Liquid Holdup Tanks .

TR LCO 13.10.33 Pursuant to TS 5.5.12c, the quantity of radioactive material in each outdoor unprotected tank shall be limited to s 10 Curies, excluding tritium and dissolved or entrained noble gases.

APPLICABILITY: At all times.

ACTIONS NOTE Separate Condition entry allowed for each tank.

CONDITION REQUIRED ACTION COMPLETION TIME A. Quantity of radioactive A.1 Suspend all additions of immediately.

materialin one or more radioactive material to the tanks exceeds limits. tank (s).

M A.2 Reduce quantity of 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months radioactive materialin tank (s) to within limits.

M A.3 NOTE Required Action A.3 must be completed whenever Condition A is entered.

Describe events leading Per TS 5.6.3 to exceeding limits in Radioactive Effluent Release Report.

CPSES - UNITS 1 AND 2 -TRM 13.10-7 Revision 29 -July 27,1999

1 Liquid Holdup Tanks l TR 13.10.33 l SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY l

TRS 13.10.33.1 NOTE Only required to be performed when radioactive materials are being added to the tank.

Analyze a representative sample of each tank's 7 days contents to verify within limits.

CPSES -UNITS 1 AND 2-TRM 13.10-8 Revision 29 - July 27,1999 l

Explosive Gas Mixture TR 13.10.34 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TR 13.10.34 Explosive Gas Mixture TR LCO 13.10.34 Pursuant to TS 5.5.12a, the concentration of oxygen in the Waste Gas Holdup system shall be s 3% by volume whenever the hydrogen concentration is > 4% by volume.

APPLICABILITY: At all times.

ACTIONS NOTE Only applicable when hydrogen concentration in the Waste Gas Holdup system is > 4% by volume.

CONDITION REQUIRED ACTION COMPLETION TIME A. Oxygen concentration in A.1 Reduce oxygen 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Waste Gas Holdup system concentration to within

> 3% by volume and limits.

s 4% by volume.

B. Oxygen concentration in B.1 Suspend all additions of immediately Waste Gas Holdup System waste gases to the

> 4% by volume. system.

ate!

B.2 Reduce oxygen immediately concentration to s 4% by_ volume.

CPSES - UNITS 1 AND 2-TRM 13.10-9 Revision 29 - July 27,1999

Explosive Gas Mixture TR 13.10.34 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TRS 13.10.34.1 Monitor the hydrogen and oxygen in the Waste Gas As specifed in Holdup Systems as specified by TR 13.10.31. TR 13.10.31 CPSES -UNITS 1 AND 2-TRM 13.10-10 Revision 29 - July 27,1999

m Programs and Manuals 15.5 15.0 ADMINISTRATIVE CONTROLS 15.5 . Programs and Manuals TR 15.5.17 TRM - Administratwe Control Process

a. Introduction CPSES has relocated certain information from the Technical Specifications to a separate controlled document based on the NUMARC Technical Specification Improvement Program, the Westinghouse Owners Group MERITS Program, and the Commission's interim Policy

. Statement for improvement of Technical Specifications for nuclear power plants (52 FR 3788 of February 6,1987). This information is now contained in a separate document to be called the CPSES Technical Requirements Manual (TRM). The following is a description of the administrative program for control, distribution, updating, and amending the information contained in the TRM. The Explosive Gas and Storage Tank Radioactivity Monitoring Program, as required by TS 5.5.12, is contained in Section 13.10 of the TRM.

b. Document Control The TRM is considered a licensing basis document and as such, overall control of the document is addressed by the site-wide procedures for i licensing document control.

d. Document Distnbution

{

The TRM is considered a controlled document and distribution is controlled by Regulatory Affairs. Distribution includes those personnel / locations which receive the CPSES Technical Specifications as well as any other groups which need access to the information contained in the TRM.

(continued)

CPSES - UNITS 1 AND 2 -TRM 15.0-1 Revision 29 - July 27,1999

Programs and Manuals 15.5

e. Chances / Deletions to the TRM Changes to the TRM are controlled by the procedure on licensing document change control. This procedure addresses the administrative requirements necessary to change / amend CPSES licensing documents (e.g., Fire Protection Report, Offsite Dose Calculation Manual). For changes to the TRM, the procedure requires initiation of a Licensing Document Change Request (LDCR). The LDCR is the mechanism whereby changes are tracked to ensure that appropriate reviews, approvals, and signatures are obtained. TRM changes are evaluated per 10CFR50.59. TRM changes require a review by SORC and the approval of the Vice President of Nuclear Operations. Changes to the TRM must comply with the requirements of Technical Specification 5.5.17 of the CPSES Unit 1 and 2 Technical Specifications.

f. Plant Chanaes That May Affect the TRM I Changes made at CPSES have the potential to affect (or be affected by) the TRM. These include items such as design modifications, procedure changes, other licensing document changes, etc. The TRM has been identified as a CPSES licensing basis document by the 10CFR50.59 Program. This program requires that the TRM be considered in a manner similar to the FSAR when screening changes to determine if an unreviewed safe'y question might be involved.

g. Distribution of TRM Chanaes / Deletions Changes to the TRM will be issued on a replacement page basis to controlled document holders promptly following approval of the change.

h. Reoort of TRM Chanaes / Deletions to the NRC Changes to the TRM will be reported to the NRC within 30 days of the effective date of the change. Related safety evaluations will be reported as part of the 50.59 annual report.

Proposed TRM changes that are determined to constitute an unreviewed safety question (as defined by 10CFR50.59(a)(2)) will either not be made or will be submitted to the NRC for prior review and approval.

(continued)

CPSES - UNITS 1 AND 2-TRM 15.0-2 Revision 29 - July 27,1999

Programs cnd M:nuals 15.5 TR 15.5.31 Snubber Auamented Inservice insoection Procram

a. Insoection Tvoes As used in this specification, type of snubber shall mean snubbers of the same design and manufacturer, irrespective of capacity.

b. Visual Insoections Snubbers are categorized as inaccessible or accessible during reactor operation. Each of these groups (inaccessible and accessible) may be inspected independently. The first inservice visual inspection of ecch type of snubber shall be performed after 2 months but within 10 months of commencing POWER OPERATION and shallinclude all snubbers if all snubbers of each type on any system are found OPERABLE during the first inservice visual inspection, the second inservice visual inspection on that type shall be performed at the first refueling outage. Otherwise subsequent visualinspections of a given system shall be performed in accordance with the following schedule: l No. of Inoperable Snubbers of Each Type on any System Subsequent Visual oer Insoection Period" Insoection Period * )

0,1 12 months 125%

2 6 months 25 %

3,4 124 days 125%

5,6,7 62 days 25%

8 or more ,

31 days 25%

The inspection interval for each type of snubber shall not be lengthened more than one step at a time unless a generic problem has been identified and corrected; in that !

event the inspection interval may be lenthened one step the first time and two steps thereafter if no inoperable snubbers of that type are found on any system.

" If one or more snubbers of each type on any system are found inoperable during the first inservice visual inspection, the second inservice visual inspection on that type shall be performed no later than the first refueling outage or the subsequent visual inspection period, whichever comes first.

Visual inspection intervals following the second refueling outage shall be determined based upon the criteria provided in the Table 15.5.31-1.

CPSES - UNITS 1 AND 2 - TRM 15.0-3 Revision 29 - July 27,1999

p

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ProgrCms and Manuals 15.5

c. VisualInsoection Acceptance Cntaria Visual inspections shall verify that: (1) there are no visible indications of damage or impaired OPERABILITY, (2) attachments to the foundation or supporting structure are secure, and (3) fasteners for attachment of the snubber to the component and to the snubber anchorage are secure.

Snubbers which appear inoperable as a result of visual inspections may be determined OPERABLE for the purpose of establishing the next visual inspection interval, provided that: (1) the cause of the rejection is clearty established and remedied for that particular snubber and for other snubbers irrespective of type that may be generically susceptible; or (2) the affected snubber is functionally tested in the as-found condition and determined OPERABLE per 15.5.31f, the Functional Test Acceptance Criteria. All snubbers connected to an inoperable common hydraulic fluid reservoir shall be counted as irioperable snubbers.

d. IIacilentfvent inspection An inspection shall be performed of all snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a review of operational data. A visual inspection of those systems shall be performed within 6 months following such an event. In addition to satisfying the visual inspection acceptance criteria, freedom-of-motion of mechanical snubbers shall be verified using at least one of the following: (1) manually induced snubber movement; or (2) evaluation of in-place snubber piston setting; or (3) stroking th'e mechanical snubber through its full range of travel.

l CPSES - UNITS 1 AND 2-TRM 15.0-4 Revision 29 - July 27,1999

?

Progr ms end M:nuals ,

15.5 l

e. Functional Tests During the first refueling shutdown and at least once per 18 months thereafter during shutdown, a representative sample of snubbers of each type shall be tested using one of the following sample plans. The sample plan for each type shall be sekected prior to the test period and cannot be changed during the test period. The NRC Regional Administrator shall be notified in writing of the sample plaq selected for each snubber type prior to the test period or the sample plan used in the prior test period shall be implemented:

1

1. At least 10% of the total of each type of snubber shall be functionally tested either in-place or in a bench test. For each snubber of a type that does not meet the functional test j acceptance criteria of Test / Inspection TR3.1f, an additional 10% i of that type of snubber shall be functionally tested until no more j failures are found or until all snubbers of that type have been functionally tested; or

2. A representative sample of each type of snubber shall be

]

functionally tested in accordance with Figure 15.5.31-1. "C"is the total number of snubbers of a type found not meeting the acceptance requirements of 15.5.31f. The cumulative number of snubbers of a type tested is denoted by "N". At the end of each ,

day's testing, the new values of "N" and "C" (previous day's total plus current day's increments) shall be plotted on Figure 15.5.31-1. If at any time the point plotted falls in the " Accept" region, testing of snubbers of that type may be terminated. When the point plotted lies in the " Continue Testing" region, additional snubbers of that type shall be tested until the point falls in the

" Accept" region, or all the snubbers of that type have been tested.

Functional Test Acceotance Criteria I f.

The snubber functional test shall verify that:

1. Activation (restraining action)is achieved within the specified range in both tension and compression;

2. Snubber bleed, or release rate where required, is present in both )

tension and compression, within the specified range;

3. For mechanical snubbers, the force required to initiate or maintain motion of the snubber is within the specified range in both directions of travel. J l

Testing methods may be used io measure parameters indirectly or !

parameters other than those specified if those results can be correlated CPSES - UNITS 1 AND 2 - TRM 15.0-5 Revision 29 - July 27,1999 l

)

Progr:ms tnd Manuals 15.5 to the specified parameters through established methods.

g. FunctionalTest Failure Analysis An engineering evaluation shall be made of each failure to meet the functional test acceptance criteria to determine the cause of the failure.

The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the OPERABILITY of other snubbers irrespective of type which may be subject to the same failure mode. ]

i I

For the snubbers found inoperable, an engineering evaluation shall be performed on the components to which the inoperable snubbers are attached. The purpose of this engineering evaluation shall be to determine if the components to which the inoperable snut:bers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed service.

If any snubber selected for functional testing either fails to lock up or fails to move, i.e., frozen in-place, the cause will be evaluated and, if caused by manufacturer or design deficiency, all snubbers of the same type subject to the same defect shall be functionally tested. This testing requirement shall be independent of the requirements stated in 15.5.31e for snubbers not meeting the functional test acceptance criteria.

h. Functional Testina of Renaired and Reolaced Snubbers Snubbers which fall the visual inspection or the functional test acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers which have repairs which might affect the functional test results shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom-of-motion test must have been performed within 12 months before being installed in the unit.

i. Snubber Service Life Proaram The service life of hydraulic and mechanical snubbers shall be monitored to ensure that the service life is not exceeded between surveillance inspections. ' The maximum expected service life for various seals, springs, and other critical parts shall be determined and established based on engineering information and shall be extended or shortened based on monitored test results and failure history. Critical parts shall be replaced so that the maximum service life will not be exceeded during a

, period when the snubber is required to be OPERABLE. Part replacement shall be documented and the documentation shall be retained in accordance with Technical Specification 6.10.2.

CPSES - UNITS 1 AND 2 -TRM 15.0-6 Revision 29 -July 27,1999

Programs end Minuals 15.5 Table 15.5.31 1 (Page 1 of 1)

NUMBER OF UNACCEPTABLE SNUBBERS Population Column A Column B Column C or Category Extend Interval Repeatinterval Reduce Interval (Notes 1 & 2) (Notes 3 & 6) (Notes 4 & 6) (Notes 5 & 6) 1 0 0 1 M 0 0 2 100 0 1 4 150 0 3 8 200 2 5 13 300 5 12 25 400 8 18 36 500 12 24 48 750 20 40 78 1000 29 56 109 or greater Note 1: The next visual inspechon interval for a snubber population or category size shall be determined based upon the previous inspection interval and the number of unacceptable snubbers found during that interval. Snubbers may be categorized, based upon their accessibility during power operation, as accessible or inaccessible. These categories may be examined separately orjointly. However, the licensee must make and document that decision before any inspection and shall use that decision as the basis upon which to determine the next inspection interval for that category.

Note 2: Interpolation between population or category sizes and the number of unacceptable snubbers is permissible. Use next lower integer for the value of the limit for Columns A, B, or C if that integer includes a fractional value of unacceptable snubbers as determined by interpolation.

Note 3: If the number of unacceptable snubbers is equal to or less than the number in Column A, the next inspechon interval may be twice the previous interval but not greater than 48 months.

Note 4: If the numt'er of unacceptable snubbers is equal to or less than the number in Column B, but greater than the number in Column A, the next inspection interval shall be the same as the previous interval.

Note 5: If the number of unacceptable snubbers is equal to or greater than the number in Column C, the next inspection interval shall be two-thirds of the previous interval. However,if the number of unac=*=Na snubbers is less than the number in Column C but greater than the number in Column B, the next interval shall be reduced proportionally by interpolation, that is, the previous interval shall be reduced by a factor that is one-third of the ratio of the difference between the number of unacceptable snubbers found during the previous interval and the number in Column B to the difference in the numbers in Columns B and C.

Note 6: The provisions of Specification 4.0.2 are applicable for all inspection intervals up to and including 48 months.

CPSES - UNITS 1 AND 2 - TRM 15.0-7 Revision 29 - July 27,1999

l l

Progrcms and Manuals 15.5 I

I I

l 10 9

8 7

6 o 5 CONTINUE TESTING 4

3 C =0.055N - 2.007 2

1

/ ' ACCEPT j f l 0 !

0 10 20 30 40 50 60 70 80 90 100 N

l l

l Figure 15.5.31-1 Sample Plan 2) for Snubber Functional Test CPSES - UNITS 1 AND 2 - TRM 15.0-8 Revision 29 - July 27,1999 1

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TECHNICAL REQUIREMENTS MANUAL (TRM) BASES FOR COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 AND 2 CPSES - UNITS 1 AND 2 -TRM July 27,1999

TABLE OF CONTENTS B 13.0 TECHNICAL REQUIREMENT APPLICABILITY . . . . . . . . . . . . . . . . . . B 13.0-1 B 13.1 REACTIVITY CONTROL SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-1 B 13.1.31 Boration Flow Path - Operating . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-1 B 13.1.32 Boration Flow Path - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-3 B 13.1.33 Charging Pump - Operating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-4 8 13.1.34 Charging Pump - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-5 B 13.1.35 Borated Water Sources - Operating . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-6 B 13.1.36 Borated Water Sources - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-7 B 13.1.37 Rod Group Alignment Limits and Rod Position Indicator . . . . . . . . B 13.1-8 B 13.1.38 Control Bank insertion Limits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-9 B 13.1.39 Rod Position Indication - Shutdown . . . . . . . . . . . . . . . . . . . . . . . . B 13.1-10 B 13.2 POWER DISTRIBUTION LIMITS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.2-1 B 13.2.31 Movable Incore Detection System . . . . . . . . . . . . . . . . . . . . . . . . . B 13.2-1 B 13.2.32 Axial Flux Difference (AFD) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.2-2 B 13.2.33 Quadrant Power Tilt Ratio (QPTR) Alarm . . . . . . . . . . . . . . . . . . . B 13.2-3 B 13.3 INSTRU MENTATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.3-1 B 13.3.1 Reactor Trip System (RTS) instrumentation Response Times . . . . B 13.3-1 B 13.3.2 Engineered Safety Feature Actuation System (ESFAS) instrumentation Response Times . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.3-2 B 13.3.5 Loss of Power (LOP) Diesel Generator (DG)

Start Instrumentation Response Times . . . . . . . . . . . . . . . . . . . . . B 13.3-3 B 13.3.31 Seismic Instrumentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.3-4 B 13.3.32 Source Range Neutron Flux . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.3-5 B 13.3.33 Turbine Overspeed Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.3-6 j B 13.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . . . . . . . . . . . . . B 13.4-1 B 13.4.14 Reactor Coolant System (RCS) Pressure Isolation Valves . . . . . . B 13.4-1 i B 13.4.31 Loose Parts Detection System . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.4-2 B 13.4.32 Pressurizer Power Operated Relief Valves (PORVs) . . . . . . . . . . . B 13.4-3 B 13.4.33 Reactor Coolant System (RCS) Chemistry . . . . . . . . . . . . . . . . . . B 13.4-4 B 13.4.34 Pressurizer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.4-5 B 13.4.35 Reactor Coolant System (RCS) Vents Specification . . . . . . . . . . . B 13.4-6 (continued) l 1

CPSES - UNITS 1 AND 2 -TRM Bi July 27,1999 {

TABLE OF CONTENTS (continued) J l

B 13.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) . . . . . . . . . . . . . . B 13.5-1 B 13.5.31 ECCS - Containment Debris . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.5-1 B 13.5.32 ECCS - Pump Line Flow Rates . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.5-2 B 13.6 CONTAINM ENT SYSTEM S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.6-1 B 13.6.3 Containment isolation Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.6-1 B 13.6.6 Containment Spray System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.6-2 B 13.6.31 Hydrogen Recombiners - Instrumentation and Control Circuits . . . B 13.S-3 )

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B 13.7 PLANT SYSTEM S . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-1 B 13.7.31 Steam Generator Atmospheric Relief Valve (ARV)-

Air Accumulator Tank . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-1 B 13.7.32 Steam Generator Pressure / Temperature Limitation . . . . . . . . . B 13.7-2 B 13.7.33 Ultimate Heat Sink - Sediment and Safe Shutdown impoundment (S S I) Da m . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-3 B 13.7.34 Flood Protection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-4 B 13.7.35 S n u b be rs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-5 B 13.7.36 Area Temperature Monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-6 B 13.7.37 Safety Chilled Water System -

Electrical Switchgear Area Emergency Fan Coil Units . . . . . . B 13.7-7 8 13.7.38 Main Feedwater Isolation Valve Pressure / Temperature Limit . . . . B 13.7-8 B 13.7.39 Tornado Missile Shields . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.7-9 B 13.7.40 Feedwater Control Valves (FCVs) and Associated Bypass Valves B 13.7-11 B 13.8 ELECTRICAL POWER SYSTEMS . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.8-1 B 13.8.31 AC Sources (Diesel Generator Requirements) . . . . . . . . . . . . . . . . B 13.8-1 B 13.8.32 Containment Penetration Conductor Overcurrent Protection Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.8-2 B 13.9 REFUELING OPERATIONS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.9-1 B 13.9.31 Decay Time . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.9-1 B 13.9.32 Refueling Operations / Communications . . . . . . . . . . . . . . . . . . . . B 13.9-2 B 13.9.33 Refueling Machine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.9-3 B 13.9.34 Refueling - Crane Travel - Spent Fue! Storage Areas . . . . . . . . . . B 13.9-4 B 13.9.35 Water Level, Reactor Vessel, Control Rods . . . . . . . . . . . . . . . . . . B 13.9-5 B 13.9.36 Fuel Storage Area Water Level . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.9-6 B 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROG RAM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.10-1 B 13.10.31 Explosive Gas Monitoring Instrumentation . . . . . . . . . . . . . . . . . . B 13.10-1 B 13.10.32 Gas Storage Tanks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.10-2 B 13.10.33 Liquid Holdup Tanks . . . . . . . . . . . . . . . .': . . . . . . . . . . . . . . . . . . B 13.10-3 8 13.10.34 Explosive Gas Mixture . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B 13.10-4

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CPSES - UNITS 1 AND 2 - TRM B li July 27,1999

TR LCO cnd TRS Applicability TRB 13.0 B 13.0 TECHNICAL REQUIREMENT (TR)

LIMITING CONDITION FOR OPERABILITY (TR LCO)

AND TECHNICAL REQUIREMENT SURVEILLANCE (TRS) APPLICABILITY BASES Related information is located in Technical Specification Bases 3.0.

l CPSES - UNITS 1 AND 2 - TRM B 13.0-1 Revision 29- July 27,1999 i

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Borttion Flow Pith - Operating TRB 13.1.31 B 13.1 REACTIVITY CONTROL SYSTEMS TRB 13.1.31 Boration Flow Path - Operating BASES-Boration Systems The Boron injection System ensures that negative reactivity control is available during each mode of facility operation. The components required to perform this function include: (1) borated water sources, (2) charging pumps, (3) separate flow paths, (4) boric acid transfer pumps, and (5) an emergency power supply from OPERABLE diesel generators. .

With the RCS average temperature above 200*F, a minimum of two boron injection flow paths are required to ensure singia functional capability in the event an assumed failure renders one of the flow paths inoperable. The boration capability of either flow path is sufficient to provide the required SHUTDOWN MARGIN from expected operating conditions after xenon decay and cooldown to 200*F. The maximum expected boration capability requirement occurs at EOL from full power equilibrium xenon conditions and requires 15,700 gallons of 7000 ppm borated water from the boric acid storage tanks or 70,702 gallons of 2400 ppm borated water from the refueling water storage tank (RWST).

With the RCS temperature below 200*F, one Boron Injection System is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the additional restrictions prohibiting CORE ALTERATIONS and positive reactivity changes in the event the single Boron injection System becomes inoperable.

The limitation for a maximum of two charging pumps to be OPERABLE and the requirement to verify one charging pump to be inoperable below 350'F provides assurance that a mass addition pressure transient can be relieved by the operation of a single PORV.

The limitation for minimum solution temperature of the borated water sources are sufficient to prevent boric acid crystallization with the highest allowable boron concentration, The boron capability required below 200*F is sufficient to provide the required SHUTDOWN MARGIN after xenon decay and cooldown from 200*F to 140*F. This condition requires either 1,100 gallons of 7000 ppm borated water from the boric acid storage tanks or 7,113 gallons of 2400 ppm borated water from the RWST.

(continued)

CPSES -_ UNITS 1 AND 2 - TRM B 13.1-1 . Revision 29 - July 27,1999

Boration Flow Pcth - Operating I

TRB 13.1.31 BASES (continued)

As listed below, the required indicated levels for the boric acid storage tanks and the RWST include allowances for required / analytical volume, unusable volume, measurement l

uncertainties (which include instrument error and tank tolerances, as applicable), margin, and other required volume.

Tank MODES Ind. Unusable Required Measurement Margin Other Level Volume Volume Uncertainty (gal) (gal) (gal) (gal)

RWST 5, 6 24 % 98,900 7,113 4% of span 10,293 N/A 1,2,3,4 95 % 45,494 70,702 4% of span N/A 357,535*

Boric 5, 6 10% 3,221 1,100 6% of span N/A N/A Acid Storage 5, 6 20 % 3,221 1,100 6% of span 3,679 N/A Tank (gravity feed) 1,2,3,4 50 % 3,221 15,700 6% of span N/A N/A The OPERABILITY of one Boron injection System during REFUELING ensures that this system is available for reactivity control while in MODE 6.

Additional volume required to meet Technical Specification 3.5.4.

l CPSES - UNITS 1 AND 2- TRM B 13.1-2 Revision 29 - July 27,1999

Boration Flow P th - Shutdown TRB 13.1.32 B 13.1 REACTMTY CONTROL SYSTEMS TRB 13.1.32 Boration Flow Path - Shutdown BASES See TRB 13.1.31, "Boration Flow Path - Operating" CPSES - UNITS 1 AND 2-TRM B 13.1-3 Revision 29 - July 27,1999

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Charging Pump - Operating TRB 13.1.33 B 13.1 REACTMTY CONTROL SYSTEMS TRB 13.1.33 Charging Pump - Operating BASES See TRB 13.1.31, "Boration Flow Path - Operating"

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CPSES - UNITS 1 AND 2 -TRM B 13.1-4 Revision 29 -July 27,1999

Charging Pump - Shutdown TRB 13.1.34 813.1 REACTMTY CONTROL SYSTEMS TRB 13.1.34 Charging Pump - Shutdown BASES See TRB 13.1.31, "Boration Flow Path - Operating" CPSES - UNITS 1 AND 2 -TRM B 13.1-5 Revision 29 -July 27,1999

1 Bortted Water Sources - Operating TRB 13.1.35 B 13.1 REACTIVITY CONTROL SYSTEMS TRB 13.1.35 Borated 'Nater Sources - Operating BASES See TRB 13.1.31, "Boration Flow Path - Operating" I

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CPSES - UNITS 1 AND 2 -TRM B 13.1-6 Revision 29 - July 27,1999

Borated Wcter Sources - Shutdown TRB 13.1.36 B 13.1 REACTIVITY CONTROL SYSTEMS TRB 13.1.36 Borated Water Sources - Shutdown BASES See TRB 13.1.31, "Boration Flow Path - Operating" l

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i s l CPSES - UNITS 1 AND 2 -TRM B 13.1-7 Revision 29 -July 27,1999 9

Rod Group Alignment Limits End Rod Position Indicator TRB 13.1.37 B 13.1 REACTIVITY CONTROL SYSTEMS TRB 13.1.37. Rod Group Alignment Limits and Rod Position Indicator BASES -

Related requirements /information is located in Technical Specification Bases Secton 3.1.4.

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CPSES - UNITS 1 AND 2 -TRM B 13.1-8 Revision 29 -July 27,1999

Control Bank Insertion Limits TRB 13.1.38 B 13.1 REACTIVITY CONTROL SYSTEMS ,

.TRB 13.1.38 Control Bank insertion Limits BASES Related requirements /information is found in Technical Specification Bases Section 3.1.6.

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d CPSES -UNITS 1 AND 2-TRM B 13.1-9 Revision 29 -July 27,1999

L Rod Position Indication - Shutdown TRB 13.1.39 813.1 REACTIVITY CONTROL SYSTEMS TRB 13.1/49 Rod Position Indication - Shutdown I

BASES Related requirements /information is located in Technical Specification Bases Section 3.1.7.

In order to clarify the conditions in which TR 13.1.39 may be invoked the following is provided.

Control Rod Drive Mechanism testing is a required and integral prerequisite to Control Rod Drop timing. As such, TR 13.1.39 may be invoked to allow for Control Rod Drive Mechanism testing. Furthermore, Control Rod Drive Mechanism testing may be performed for all banks or a bank at a time as a prerequisite to performing Control Rod Drop timing.,

This interpretation has been utilized at other plants including Vogtle and the South Texas Project, l

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CPSES- UNITS 1 AND 2-TRM B 13.1-10 Revision 29 -July 27,1999

Movzble incore Detection System TRB 13.2.31 B 13.2 POWER DISTRIBUTION LIMITS TRB 13.2.31 Moveable incore Detection System BASES The OPERABILITY of the movable incore detectors with the specified + minimum complement of equipment ensures that the measurements obtained from use of this system accurr.tely represent the spatial neutron flux distribution of the core. The OPERABILITY of this system is demonstrated by irradiating each detector used and determining the acceptability of its voltage curve. For the purpose of measuring Fo(Z) or F1 a a full incore flux map is used. Quarter-core flux maps, as defined in WCAP-8648, June 1976, may be used in recalibration of the Excore Neutron Flux Detection 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.

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CPSES - UNITS 1 AND 2-TRM B 13.2-1 Revision 29 - July 27,1999

Axial Flux Diftrence (AFD)

TRB 13.2.32 B 13.2 POWER DISTRIBUTION LIMITS

~ TRB 13.2.32 Axial Flux Difference (AFD)

BASES Related information is located in Technical Specification Bases Section 3.2.3 l

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CPSES - UNITS 1 AND 2 -TRM B 13.2-2 Revision 29 -July 27,1999

E Quadrent Power Tilt Ratio (QPTR) Alarm TRB 13.2.33 813.2 POWER DISTRIBUTION LIMITS TRB 13.2.33 ' Quadrant Power Tilt Ratio (QPTR) Alarrn BASES Related information is located in Technical Specification Bases Section 3.2.4 CPSES - UNITS 1 AND 2-TRM B 13.2-3 Revision 29 - July 27,1999

o RTS Instrumentation Response Times TRB 13.3.1 B 13.3 INSTRUMENTATION TRB 13.3.1 ' Reactor Trip System (RTS) instrumentation Response Times BASES The bases for the Reactor Trip System are contained in the CPSES Technical Specifications.

The measurement of response time at the specified frequencies provides assurance that the Reactor trip actuation associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response times indicated as not applicable. Response time may be demonstrated by any series of sequential, overlapping, or total channel test measurements provided that such tests

. demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either. (1) in place, onsite, or offsite test measurements, or (2) utilizing replacement sensors with certified response time.

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l CPSES-UNITS 1 AND 2-TRM B 13.31 Revision 29 -July 27,1999

ESFAS Instrumentation Response Times TRB 13.3.2 B 13.3 INSTRUMENTATION TRB 13.3.2 Engineered Safety Featurer Actuation System (ESFAS) Instrumentation Response Times BASES The bases for the Engineered Safety Features Actuation System are contained in the CPSES Technical Specifications. The measurement of response time at the specired frequencies provides assurance Wat the Engineered Safety Features actuation associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response times indicated as not applicable. Response time may be demonstrated by any series of sequential, overlapping, or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either: (1)in place, onsite, or offsite test measurements, or (2) utilizing replacement sensors with certified response time.

CPSES - UNITS 1 AND 2 -TRM B 13.3-2 Revision 29 -July 27,1999 t

LOP DG Start Instrumentation Response Times TRB 13.3.5 B 13.3 INSTRUMENTATION '

TRB 13.3.5 Loss of Power (LOP) Diesel Generator (DG) Start instrumentation Response Times BASES The bases for the Loss of Power (6.9 KV and 480V Safeguards System UV) are contained in the CPSES Technical Specifications. The measurement of response time at the specifed frequencies provides assurance that the Loss of Power features associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the I analyses for these channels with response times indicated as not applicable. Response time j may be demonstrated by any series of sequential, overlapping, or total channel test (

measurements provided that such tests demonstrate the total channel response time as I defined. Sensor response time verification may be demonstrated by either: (1) in place, onsite, or offsite test measurements, or (2) utilizing replacement sensors with certified response time.

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CPSES - UNITS 1 AND 2 -TRM B 13.3-3 Revision 29 -July 27,1999 i

I Seismic Instrumentation TRB 13.3.31 B 13.3 INSTRUMENTATION TRB 13.3.31 Seismic instrumentation BASES The OPERABILITY of the seismic instrumentation ensures that sumcient capability is available to promptly determine the 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 for the facility to determine if plant shutdown is required pursuant to Appendix A of 10CFR100. .The instrumentation is consistent with the recommendations of Regulatory Guide 1.12, " Instrumentation for Earthquakes," April 1974.

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I CPSES - UNITS 1 AND 2 -TRM B 13.3-4 Revision 29 -July 27,1999 9

p-RTS Instrumentation - Source Range Neutron Flux TRB 13.3.32 B 13.3 INSTRUMENTATION TRB 13.3.32 - Reactor Trip System (RTS) instrumentation - Source Range Neutron Flu'x

, BASES Related information is located in Technical Specification Bases 3.3.1 l

i CPSES - UNITS 1 AND 2-TRM B 13.3-5 Revision 29 -July 27,1999

Turbine Overspeed Protection TRB 13.3.33 B 13.3 INSTRUMENTATION TRB 13.3.33 Turbine Overspeed Protection BASES This specification if provided to ensure that the turbine overspeed protection instrumentation and the turbine speed control valves are operable and will protect the turbine from excessive overspeed. Protection from turbine excessive overspeed is required since excessive overspeed of the turbine could generate potentially damaging missiles which could impact and damage safety-related components,' equipment or structures.

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CPSES - UNITS 1 AND 2-TRM B 13.3-6 Revision 29 -July 27,1999

m RCS Pressure Isolation Valves TRB 13.4.14 813.4 REACTOR COOLANT SYSTEM TRB 13.4.14 Reactor Coolant System (RCS) Pressure Ise!ation Valves BASES Related information is located in Technical Specification Bases 3.4.14.

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CPSES - UNITS 1 AND 2 -TRM B 13.4-1 Revision 29 -July 27,1999

Loose Parts Detection System TRB 13.4.31 B 13.4 REACTOR COOLANT SYSTEM TRB 13.4.31 Loose Parts Detection System BASES The OPERABILITY of the Loose-Part Detection System ensures that sufficient capability is available to detect loose metallic parts in the Reactor System and avoid or mitigate damage to Reactor System components. The allowable out-of-service times and surveillance requirements are consistent with the recommendations of Regulatory Guide 1.133, " Loose-Part Detection Program for the Primary System of Light-Water-Cooled Reactors," May 1981.

CPSES - UNITS 1 AND 2 -TRM B 13.4-2 Revision 29 - July 27,1999

l Pressurizer PORVs !

TRB 13.4.32 B 13.4 REACTOR COOLANT SYSTEM TRB 13.4.32 Pressurizer Power Operated Relief Valves (PORVs)

BASES Related information is located in Technical Specification Bases 3.4.11.

The PORVs are equipped with automatic actuation circuitry and manual control capability.

Because no credit for automatic PORV operation is taken in the FSAR analyses for MODE 1, 2 l

& 3 transients, the PORVs are considered OPERABLE in either the manual or automatic mode.

It should be noted that the automatic mode is the preferred configuration, as this provides pressure relieving capability without reliance on operator action. .

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i CPSES - UNITS 1 AND 2-TRM B 13.4-3 Revision 29 -July 27,1999

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9 RCS Chemistry TRB 13.4.33 B 13.4 REACTOR COOLANT SYSTEM TRB 13.4.33 Reactor Coolant System (RCS) Chemistry I BASES The limitations on Reactor Coolant System chemistry ensure that corrosion of the Reactor Coolant System is minimized and reduces the potential for Reactor Coolant System leakage or failure due to stress corrosion. Maintaining the chemistry within the Steady-State Limits provides adequate corrosion protection to ensure the structural integrity of the Reactor Coolant System over the life of the plant. The associated effects of exceeding the oxygen, chloride, and fluoride limits are time and temperature dependent. Corrosion studies show that operation may be continued with contaminant concentration. levels in excess of the Steady-State Limits, up to the Transient Limits, for the specified limited time intervals without having a significant effect on {

the structural integrity of the Reactor Coolant System. The time interval permitting continued operation within the restrictions of the Transient Limits provides time for taking corrective actions to restore the contaminant concentrations to within the Steady-State Limits. I The Surveillance Requirements provide adequate assurance that concentrations in excess of the limits will be detected in sufficient time to take corrective action.

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CPSES - UNITS 1 AND 2 - TRM B 13.4-4 Revision 29 - July 27,1999

l Pressurizer TRB 13.4.34 B 13.4 REACTOR COOLANT SYSTEM TRB 13.4.34 Pressurizer BASES-i The temperature and pressure changes during heatup and cooldown are limited to be consistent with the requirements given in the ASME Boiler and Pressure Vessel Code, Section lil, Appendix G and 10CFR50, Appendix G.

1. The pressurizer heatup and cooldown rates shall not exceed 100'F/h and 200*F/h, respectively

2. System preservice hydrotests and in-service leak and hydrotests shall be performed at pressures in accordance with the requirements of ASME Boiler and Pressure Vessel Code,Section XI.

Although the pressurizer operates in temperature ranges above those for which there is reason for concem of nonductile failure, operating limits are provided to assure compatibility of operation with the fatigue analysis performed in accordance with the ASME Code requirements.

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i CPSES - UNITS 1 AND 2- TRM B 13.4-5 Revision 29 -July 27,1999

RCS Vents TRB 13.4.35 B 13.4 REACTOR COOLANT SYSTEM TRB 13.4.35 Reactor Coolant System (RCS) Vents Specification BASES Reactor Coolant System vents are provided to exhaust noncondensible gases and/or steam from the Reactor Coolant System that could inhibit natural circulation core cooling. The OPERABILITY of at least one Reactor Coolant System vent path from the reactor vessel head, and the pressurizer steam space, ensures that the capability exists to perform this function.

The_ valve redundancy of the Reactor Coolant System vent paths serves to minimize the probability of inadvertent or irreversible actuation while ensuring that a single failure of a vent valve, power supply, or control system does not prevent isolation of the vent path.

The function, capabilities, and testing requirements of the Reactor Coolant System vents are .

consistent with the requirements of item II.B.1 of NUREG-0737, " Clarification of TMI Action Plan Requirements," November 1980.

CPSES - UNITS 1 AND 2 -TRM B 13.4-6 Revision 29 -July 27,1999

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ECCS - Containment Debris TRB 13.5.31 B 13.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)

TRB 13.5.31 ECCS - Containment Debris BASES Related information is located in Technical Specification Bases 3.5.2 and 3.5.3.

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CPSES - UNITS 1 AND 2 - TRM B 13.5-1 Revision 29 - July 27,1999

ECCS - Pump Line Flow Rates TRB 13.5.32 B 13.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)

TRB 13.5.32 ECCS - Pump Line Flow Rates BASES Related information is located in Technical Specification Bases 3.5.2 and 3.5.3.

1 CPSES - UNITS 1 AND 2 - TRM B 13.5-2 Revision 29 -July 27,1999 l

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Containment isolation Valves TRB 13.6.3 B 13.6 CONTAINMENT SYSTEMS TRB 13.6.3 Containment isolation Valves BASES The OPERABILITY of the containment isolation valves ensures that the containment atmosphere will be isolated from the outside environment in the event of a release of radioactive material to the containment atmosphere or pressurization of the containment and is consistent with the requirements of General Design Criteria 54 through 57 of 10CFR50; Appendix A. Containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used !n the analyses for a LOCA.

I CPSES - UNITS 1 AND 2 -TRM B 13.61 Revision 29 -July 27,1999

Containment Spray System TRB 13.6.6 813.6 CONTAINMENT SYSTEMS TRB 13.6.6 Containment Spray System -

BASES Related information is located in Technical Specification Bases 3.6.6.

CPSES - UNITS 1 AND 2 -TRM B 13.6-2 Revision 29 -July 27,1999

n Hydrogen Recombiners - Instrumentation and Contol Circuits TRB 13.6.31 B 13.6 CONTAINMENT SYSTEMS TRB 13.6.31 Hydrogen Recombiners - Instrumentation and Control Circuits BASES Related information is located in Technical Specification Bases 3.6.8.

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CPSES - UNITS 1 AND 2 -TRM B 13.6-3 Revision 29 -July 27,1999

ARV- Air Accumulator Tank TRB 13.7.31 B 13.7 PLANT SYSTEMS TRB 13.7.31 Steam Generator Atmospheric Relief Valve (ARV)- Air Accumulator Tank BASES Related requirements /information is located in Technical Specification Bases Section 3.7.4.

CPSES - UNITS 1 AND 2 -TRM B 13.7-1 Revision 29 - July 27,1999

Steam Generator Pressure / Temparature Limitation TRB 13.7.32 B 13.7 PLANT SYSTEMS TRB 13.7.32 Steam Generator Pressure / Temperature Limitation BASES The limitation on steam generator pressure and temperature ensures that the pressure-induced stresses in the steam generators do not exceed the maximum allowable fracture toughness stress limits. The limitations of 70*F and 200 psig are based on a steam generator RTNDT of 60'F and are sufficient to prevent brittle fracture.

CPSES - UNITS 1 AND 2 - TRM B 13.7-2 Revision 29 - July 27,1999

F' Ultimate Heat Sink - Sediment and (SSI) Dam TRB 13.7.33 B 13.7 PLANT SYSTEMS TRB 13.7.33 Ultimate Heat Sink - Sediment and Safe Shutdown impoundment (SSI) Dam BASES The limitations on the SSI Dam ensure that sufficient cooling capacity is available in the event of an SSE.

The limitation on average sediment depth is based on the possible excessive sediment buildup in the service waterintake channel.

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i CPSES - UNITS 1 AND 2 -TRM B 13.7-3 Revision 29 - July 27,1999

Flood Protection TRB 13.7.34 813.7 PLANT SYSTEMS TRB 13.7.34 Flood Protection BASES The limitation of flood protection ensures that facility protective actions will be taken in the event of flood conditions. The only credible flood condition that endangers safety related equipment is from water entry into the turbine building via the circulating water system from Squaw Creek Reservoir and then only if the level is above 778 feet Mean Sea Level. This corresponds to the elevation at which water could enter the electrical and control building endangering the safety chilled water system. The surveillance requirements are designed to implement level monitoring of Squaw Creek Reservoir should,it reach an abnormally high level above 776 feet.

The Limiting Condition for Operation is designed to implement flood protection, by ensuring no open flow path via the Circulating Water System exists, prior to reaching the postulated flood level.

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l CPSES - UNITS 1 AND 2-TRM B 13.7-4 Revision 29 - July 27,1999

Snubbers TRB 13.7.35 B 13.7 PLANT SYSTEMS TRB 13.7.35 Snubbers BASES All snubbers are required OPERABLE to ensure that the structural integrity of the Reactor Coolant System and all other safety-related systems is maintained during and following a seismic or other event initiating dynamic loads.

Snubbers are classified and grouped by design and manufacturer but not by size. For example, mechanical snubbers utilizing the same design features'of the 2-kip,10-kip and 100-kip capacity manufactured by Company "A" are of the same type. The same design mechanical snubbers manufactured by Company "B" for the purposes of this Technical Specification would be of a different type, as would hydraulic snubbers from either manufacturer.

- A list of individual snubbers with detailed information of snubber location and size and of system affected shall be available at the plant in accordance with 10CFR50.71(c). The accessibility of each snubber shall be determined and approved by the Station Operation Review Committee (SORC). The determination shall be based upon the existing radiation levels and the expected time to perform a visual inspection in each snubber location as well as other factors associated with accessibility during plant operations (e.g., temperature, atmosphere, location, etc.), and the recommendations of Regulatory Guides 8.8 and 8.10. The addition or deletion of any hydraulic or mechanical snubber shall be made in accordance with 10CFR50.59.

Surveillance to demonstrate OPERABILITY is by performance of the requirements of an i approved inservice inspection program.

Permanent or other exemptions from the surveillance program for individual snubbers may be j granted by the Commission if a justifiable basis for exemption is presented and, if applicable, l

snubber life destructive testing was performed to qualify the snubbers for the applicable design conditions at either the completion of their fabrication or at a subsequent date. Snubbers so exempted shall be listed in the list of individual snubbers indicating the extent of the exemptions.

The service life of a snubber is established via manufacturer input and information through consideration of the snubber service conditions and associated installation and maintenance records (newly installed snubbers, seal replaced, spring replaced, in high radiation area, in high temperature area, etc.). The requirement to monitor the sn'ubber service life is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions. These records will provide statistical bases for future consideration of snubber service life..

Revision 29 - July 27,1999 l CPSES - UNITS 1 AND 2 -TRM B 13.7-5

t Area Temperature Monitoring TRB 13.7.36 B 13.7 PLANT SYSTEMS TRB 13.7.36 Area Temperature Monitoring The limitations on nominal area temperatures ensure that safety-related equipment will not be i subjected to temperatures that would impact their environmental qualification temperatures. I Exposure to temperatures in excess of the maximum temperature for normal conditions for extended periods of time could reduce the qualified life or design life of that equipment.

Exposure to temperatures in excess of the maximum abnormal temperature could degrade the OPERABILITY of that equipment. '

Normal and abnormal temperature limits for the following areas are assured by monitoring other areas with a correlated temperature relationship:

TEMPERATURE LIMIT (F*)

Area Normal Abnormal Area Monitored j Conditions Conditions

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CRDM Platform 140 149 General Area CRDM Barrier Shroud Exhaust Reactor Cavity 135 175 Reactor Cavity Detector Well Exhaust R.C. Pipe 200 209 General Areas Penetration Exhaust Reactor. Cavity (N-16 Detectors) Exhaust l

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CPSES - UNITS 1 AND 2 - TRM B 13.7-6 Revision 29 - July 27,1999

Saf;ty Chilled WIhr System - Electrical Switchgear Area Emergency Fan Coil Units TRB 13.7.37 B 13.7 PLANT SYSTEMS TRB 13.7.37 Safety Chilled Water System - Electrical Switchgear Area Emergency Fan Coil Units BASES Related requirements /information is located in Technical Specification Bases Section 3.7.19.

Inoperable electrical switchgear area emergency fan coil units should not require actions more severe than the loss of the entire associated Safety Chilled Water System Train. Therefore, where one or more electrical switchgear area electrical fan coil units are inoperable it is acceptable to declare the associated Safety. Chilled Water System Train inoperable and enter

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Technical Specifications 3.7.19.

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CPSES - UNITS 1 AND 2 -TRM B 13.7-7 Revision 29 - July 27,1999 l

Main Feedwater Isolation Valve Pressure / Temperature Umit TRB 13.7.38 B 13.7 PLANT SYSTEMS TRB 13.7.38 Main Feedwater Isolation Valve Pressure / Temperature Limit BASES The fracture toughess requirements are satisfied with a metal temperature of 90*F for the main feedwater isolation valve body and neck, therefore, these portions will be maintained at or above this temperature prior to pressurization of these valves above 675 psig. Minimum temperature limitations are imposed on the valve body and neck of main feedwater isolation valves HV-2134, HV-2135, HV-2136 and HV-2137. These valves do not need to be verified at or above 90*F when in MODES 4,5, or 6 (except during special pressure testing) since Tm < 350*F which corresponds to a pressure at the valves of 140-150 psig or less. The maximum pressurization during cold conditions (valve temperature < 90*F) should be limited to no more than 20% of the valve hydrostatic test pressure (3375 psig X 20% = 675 psig).

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CPSES - UNITS 1 AND 2 -TRM B 13.7-8 Revision 29 - July 27,1999 i

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1 Tomado Missile Shields TRB 13.7.39 B 13.7 PLANT SYSTEMS 4 TRB 13.7.39 Tomado Missile Shields BASES The purpose of tomado miesile shields is to protect equipment from tomado generated missiles, and given the fact that adequate waming is availsbie for tomado conditions, it is not necessary to consider protected equipment inoperable solely due to its missile shield being removed. This TRM provides conservative pre-planned allowances for control of missile shields without further consideration of equipment OPERABILITY. Removal of missile shields not contained herein, or exceeding the bounds of these allowances require additional assessment of equipment OPERABILITY. The conservative option to declare affected equipment inoperable and comply with the provisions of Technical Specifications is always available.

The following allowances have considered the impact on HVAC pressure boundaries, but do not address Security and Fire Protection requirements.

The capability to immediately re-install missile shields as used in the TRM allowances is deemed to exist when the necessary equipment to perform the installation is located on site and is available for use. Personnel necessary to operate the equipment shall be onsite and available when weather conditions exist such that a potential for a Tomado Watch or Waming exists. If weather conditions pose no immediate potential for adverse weather, then personnel associated with the operation of the equipment shall be available and within 90 minutes of the site. The shield shall also be in such condition and location to support reinstallation.

Removal and installation of missile shields shall be conducted in accordance with approved plant procedures.

Installation of each removed shield shall begin immediately upon the associated notification (Tomado Watch, Tomado Waming, etc.) otherwise the affected system (s) shall be declared inoperable.

(continued)

CPSES - UNITS 1 AND 2 -TRM B 13.7-9 ' Revision 29 - July 27,1999

Tomado Missile Shields TRB 13.7.39 BASES (continued)

DEFINITIONS *:

1. Primary Plant Ventilation Pressure Boundary - An established physical boundary, within the confines of the Fuel, Auxiliary and Safeguards buildings, which has been demonstrated via surveillance testing to provide the negative pressure envelope required by LCO 3.7.12.

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2. Direct Communication - The condition of having a known flow path, from the building j through the Primary Plant Ventilation Pressure Boundary into the negative pressure j envelope, that does not contain barriers which have been proven to adequately maintain the negative pressure envelope required by LCO 3.7.12.

These definitions are used with the confines of this TRM specification only.

REFERENCE:

TE-SE-90-615 i

,7 CPSES - UNITS 1 AND 2 -TRM B 13.7-10 Revision 29 -July 27,1999

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FCVs cnd Associated Bypass Valves l TRB 13.7.40 ;

l B 13.7 PLANT SYSTEMS l TRB 13.7.40 Feedwater Control Valves (FCVs) and Associated Bypass Valves l

BASES I l

Later ,

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l CPSES - UNITS 1 AND 2 -TRM B 13.7-11 Revision 29 -July 27,1999

AC Sources (Diesel Generator Requirements)

TRB 13.8.31 -

B 13.8 ELECTRICAL POWER SYSTEMS TRB 13.8.31 AC Sources (Diesel Generator Requirements)

BASES Related requirements /information is located in Technical Specification Bases Section 3.8.1.

These surveillance requirements reflect normal design, maintenance or line-up activities / descriptions rather than features specifically needed to successfully mitigate a DBA or design transient.

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l CPSES - UNITS 1 AND 2-TRM B 13.8-1 Revision 29 - July 27,1999

Containment P:nstration Conductor Overcurrent Protection Devices TRB 13.8.32 B 13.8 ELECTRICAL POWER SYSTEMS TRB 13.8.32 Containment Penetration Conductor Overcurrent Protection Devices BASES Containment electrical penetrations and penetration conductors are protected by either deenergizing circuits not required during reactor operation or by demonstrating the OPERABILITY of primary and backup overcurrent protection circuit breakers during periodic surveillance. This is based on the recommendations of Regulatory Guide 1.63, Revision 2, July I 1978, " Electric Penetration Assemblies in Containment Structures for Light-Water-Cooled Nuclear Power Plants."

The Surveillance Requirements applicable to lower voltage circuit breakers provide assurance of breaker reliability by testing at least 10% of each manufacturers brand of circuit breaker.

Each manufacturers molded case and metal case circuit breakers are grouped into representative samples which are then tested c., a rotating basis to ensure that all breakers are tested. If a wide variety exists within any manufacturers brand of circuit breakers, it is necessary to divide that manufacturers breakers into groups and treat each group as a separate ty;e of breaker for surveillance purposes.

All Class 1E motor-operated valves' motor starters are provided with thermal overload protection which is permanently bypassed and provides an alarm function only at Comanche Peak Steam Electric Station. Therefore, there are no OPERABILITY or Surveillance Requirements for these devices, since they will not prevent safety-related valves from performing their function (refer to Regulatory Guide 1.106, " Thermal Overload Protection for Electric Motors on Motor Operated Valves," Revision 1, March 1977).

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CPSES - UNITS 1 AND 2 - TRM B 13.8-2 Revision 29 - July 27,1999

Decay Time TRB 13.9.31 B 13.9 REFUELING OPEPATIONS TRB 13.9.31 Decay Time BASES The minirnum requirement for reactor suberiticality prior to movement of irradiated fuel assemblies in the reactor vessel ensures that sufficient time has elapsed to allow the radioactive decay of the short-lived fission products. This decay time is consistent with the assumptions used in the safety analyses.

CPSES - UNITS 1 AND 2 -TRM B 13.9-1 Revision 29 -July 27,1999

Refueling Operations / Communications TRB 13.9.32 B 13.9 REFUELING OPERATIONS TRB 13.9.32 Refueling Operations / Communications BASES The requirement for communications capability ensures that refueling station personnel can be promptly informed of significant changes in the facility status or core reactivity conditions during CORE ALTERATIONS.

CPSES - UNITS 1 AND 2 -TRM B 13.9-2 Revision 29 - July 27,1999

o Refueling Machine TRB 13.9.33 813.9 REFUELING OPERATIONS TRB 13.9.33 Refueling Machine BASES The OPERABILITY requirements for the refueling machine main hoist and auxiliary monorail hoist ensure that: (1) the main hoist will be used for movement of fuel assemblies, (2) the auxiliary monorail hoist will be used for latching, uniatching and movement of control rod drive shafts, (3) the main hoist has sufficient load capacity to lift a fuel assembly (with control rods),

(4) the auxiliary monorail hoist has sufficient load capacity to latch, uniatch and move the control rod drive shafts, and (5) the core intemals and reactor vessel are protected from excessive lifting force in the event they are inadvertantly engaged during lifting operations.

CPSES - UNITS 1 AND 2-TRM B 13.9-3 Revision 29 -July 27,1999

i R; fueling - Crane Travel - Spent Fuel Storage Areas TRB 13.9.34 B 13.9 Refueling Operations TRB 13.9.34 Refueling - Crane Travel- Spent Fuel Storage Areas l

BASES The restriction on movement of loads in excess of the nominal weight of a fuel and control rod I assembly and associated handling tool over other fuel assemblies in a storage pool ensures that in the event this load is dropped: (1) the activity release will be limited to that contained in a single fuel assembly, and (2) any possible distortion of fuel in the storage racks will not result in a critical array. This assumption is consistent with the activity release assumed in the safety analyses.

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CPSES - UNITS 1 AND 2 -TRM B 13.9-4 Revision 29 - July 27,1999 !

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i Water Level, Reactor Vessel, Control Rods TRB 13.9.35 B 13.9 REFUELING OPERATIONS TRB 13.9.35 Water Level, Reactor Vessel, Control Rods BASES The restrictions on minimum water level ensure that sufficient water depth is available to remove 99% of the assumed 10% iodine gap activity released from the rupture of an irradiated '

fuel assembly. The minimum water depth is consistent with the assumptions of the safety analysis.

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CPSES - UNITS 1 AND 2-TRM B 13.9-5 Revision 29 - July 27,1999

Fuel Storage Area Water Level

.TRB 13.9.36 R 13.9 REFUELING OPERATIONS 1 TRB 13.9.36 Fuel Storage Area Water Level BASES The requirement to suspend crane operations over the spent fuel pool in the event pool water level is < 23 feet provides for conservative plant operations consistent with the accident '

analysis. The bounding design basis fuel handling accident in the spent fuel pool assumes 23 feet of water above the damaged fuel assembly in the spent fuel pool which mitigates the I radiological consequences.

Crane operations that could adversely affect fuel stored in the spent fuel pool are controlled in 3 accordance with plant procedures as analyzed in the review of heavy loads movements. !

Administrative controls are employed to prevent the handling of loads that have a greater potential energy than those which have been analyzed. This Technical Requirement further ensures, for loads < 2150 pounds, that the water level is greater than that assumed in the analysis.

REFERENCE:

NRC Bulletin 96-02," Movement of Heavy Loads Over Spent Fuel, Over Fuel in the Reactor Core, or Over Safety-Related Equipment."

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i CPSES - UNITS 1 AND 2 - TRM B 13.9-6 Revision 29 -July 27,1999

Explosive Gas Monitoring instrumentation TRB 13.10.31 8 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TRB 13.10.31 Explosive Gas Monitoring Instrumentation BASES )

The explosive gas instrumentation is provided to monitor and control, the concentrations of potentially explosive gas mixtures in the WASTE GAS HOLDUP SYSTEM. The OPERABILITY and use of this instrumentation is consistent with the requirements of General Design Criteria i 63, and 64 of 10 CFR 50, Appendix A.

I One hydrogen and two oxygen monitors are required to be OPERABLE for the operating l

recombiner during WASTE GAS HOLDUP SYSTEM (WGHS) operation. The following {

discussion provides clarification of "WGHS operation" and " degassing".

For the purpose of this specification, with no input gases allowed to the WGHS, recirculation of the WGHS as well as sampling, recirculation, storage, and discharge of a waste gas decay tank are not considered as WGHS operation.

Degassing operation (which is a type of WGHS operation)is defined as purging the RCS of residual gases during unit shutdown.

t CPSES - UNITS 1 AND 2 - TRM B 13.10-1 Revision 29 - July 27,1999

r G s Storage Tanks TRB 13.10.32 B 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TRB 13.10.32 Gas Storage Tanks )

I BASES The tanks included in this specification are those tanks for which the quantity of radioactmty contained is not limited directly or indirectly by another Technical Specification. Restricting the quantity of radioactivity contained in each gas storage tank provides assurance that in the event of an uncontrolled release of the tank's contents, the resulting whole body exposure to a MEMBER OF THE PUBLIC at the nearest SITE BOUNDARY will not exceed 0.5 rem. This is consistent with Standard Review Plan 11.3, Branch Technical Position ETSB 11-5, " Postulated Radioactive Releases Due to a Waste Gas System Leak or Failure,"in NUREG-0800, July 1981.

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I CPSES - UNITS 1 AND 2 -TRM B 13.10-2 Revision 29 - July 27,1999 I

Liquid Holdup Tanks TRB 13.10.33

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B 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TRB 13.10.33 Liquid Holdup Tanks BASES The tanks listed in this specification include all those unprotected outdoor tanks both permanent and temporary that are not surrounded by liners, dikes, or walls capable of holding the tank contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System.

Restricting the quantity of radioactive material contained in the specified tanks provides assurance that in the event of an uncontrolled release of the tank's contents, the resulting concentrations would be less than the values given in Appendix B, Table 2, Column 2, to 10 '

CFR 20.1001 - 20.2402, at the nearest potable water supply and the nearest surface water supplyin an UNRESTRICTED AREA.

CPSES - UNITS 1 AND 2 -TRM B 13.10-3 Revision 29 - July 27,1999

Explosive G0s Mixture TRB 13.10.34 B 13.10 EXPLOSIVE GAS AND STORAGE TANK RADIOACTIVITY MONITORING PROGRAM TRB 13.10.34 Explosive Gas Mixture BASES This specification is provided to ensure that the concentration of potentially explosive gas mixtures contained in the WASTE GAS HOLDUP SYSTEM is maintained below the flammability limits of hydrogen and oxygen. Automatic control features are included in the system to prevent the hydrogen and oxygen concentrations from reaching these flammability limits. These automatic control features include isolation of the source of hydrogen and/or oxygen. Maintaining the concentration of hydrogen and oxygen below their flammability limits provides assurance that the releases of radioactive materials will be controlled in conformance with the requirements of General Design Criterion 60 of 10CFR50 Appendix A.

l CPSES - UNITS 1 AND 2 - TRM B 13.10-4 Revision 29 -July 27,1999

COMANCHE PEAK ELECTRIC STATION UNITO 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING Revision Record:

Original Submitted July 21,1989 Revision 1 September 15,1989 Revision 2 January 15,1990 Revision 3 July 20,1990 Revision 4 April 24,1991 Revision 5 September 6,1991 Revision 6 November 22,1991 Revision 7 March 18,1992 '

Revision 8 June 30,1992 Revision 9 December 18,1992 Revision 10 January 22,1993 Revision 11 February 3,1993 Revision 12 July 15,1993 Revision 13 September 14,1993 Revision 14 November 30,1993 Revision 15 April 15,1994 Revision 16 May 11,1994 Revision 17 February 24,1995 Revision 18 April 14,1995 Revision 19 May 15,1995 Revision 20 June 30,1995 Revision 21 January 24,1996 Revision 22 February 24,1997 Revision 23 March 13,1997 Revision 24 June 26,1997 Revision 25 July 31,1997 Revision 26 February 24,1998 Revision 27 April 14,1999 Revision 28 April 16,1999 Revision 29 July 27,1999 Revision 30 July 27,1999 CPSES -UNITS 1 AND 2-TRM EPL-1 July 27,1999 9

5 COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING TRM-TAB Original .

Record of Changes July 27,1999 TRM -Title Page July 27,1999 j i July 27,1999 1 ll July 27,1999 11.0-1 Revision 29 l 13.0-1 Revision 29 l 13.0-2 Revision 29 l 13.1-1 Revision 29 j 13.1-2 Revision 29 I 13.1-3 Revision 29 13.1-4

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Revision 29 13.1-5 Revision 29 13.1 6 Revision 29 13.1-7 Revision 29 13.1-8 Revision 29 13.1-9 Revision 29 13.1-10 Revision 29

-13.1-11 Revision 29 13.1-12 Revision 29 13.1-13 Revision 29 13.1-14 Revision 29 13.1-15 Revision 29 13.1-16 Revision 29 13.1-17 Revision 29 13.1-18 Revision 29 13.1-19 Revision 29 13.1-20 Revision 29 13.1-21 Revision 29 13.1-22 Revision 29 13.1-23 Revision 29 13.1-24 Revision 29 13.2-1 Revision 29 13.2-2 Revision 29 13.2-3 Revision 29 13.2-4 Revision 29 13.2-5 Revision 29 13.3-1 Revision 29 13.3-2 Revision 29

. 13.3-3 ReWsion 29 13.3 4 Revision 29 13.3-5 Revision 29 13.3-6 Revision 29 13.3-7 Revision 29 13.3-8 Revision 29 13.3-9 Revision 29 CPSES - UNITS 1 AND 2-TRM EPL-2 July 27,1999

COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMEN7S MANUAL (TRM)

EFFECTIVE PAGE LISTING 13.3-10 Revision 29 13.3-11 Revision 29 13.3-12 Revision 29 13.3-13 Revision 29 13.3-14 Revision 29 13.3-15 Revision 29 13.3-16 Revision 29 13.3-17 Revision 29 13.3-18 Revision 29 13.3-19 Revision 29 13.3-20 Revision 30 13.3-21 Revision 29 13.3-22 Revision 29 13.3-23 Revision 29 13.3-24 Revision 29 13.3-25 Revision 29 13.4-1 Revision 29 13.4-2 Revision 29 13.4-3 Revision ?9 13.4-4 Revision 19 13.4-5 Revision 29 I 13.4-6 Revision 29 13.4-7 Revision 29 1 13.4-8 Revision 29 13.4-9 Revision 29 13.4-10 Revision 29 13.4-11 Revision 29 13.4-12 Revision 29 13.5-1 Revision 29 13.5-2 Revision 29 13.5-3 Revision 29 13.5-4 Revision 29 13.6-1 Revision 29 13.6-2 Revision 29 13.6-3 Revision 29 13.6-4 Revision 29 13.6-5 Revision 29 13.6-6 Revision 29 13.6-7 Revision 29 13.6-8 Re' vision 29 13.6-9 Revision 29 13.6-10 Revision 29 13.6-11 Revision 29 13.6-12 Revision 29 13.6-13 Revision 29 13.6-14 Revision 29 CPSES -UNITS 1 AND 2-TRM EPL-3 July 27,1999

1 COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

I EFFECTIVE PAGE LISTING 13.6-15 Revision 29 13.6-16 Revision 29 13.7-1 Revision 29 13.7-2 Revision 29 13.7-3 Revision 29 13.7-4 Revision 29 13.7-5 Revision 29 13.7-6 Revision 29 13.7-7 Revision 29 13.7-8 Revision 29 13.7-9 Revision 30 13.7-10 July 27,1999 13.7-11 Revision 30 13.7-12 July 27,1999 13.7-13 Revision 29 13.7-14 Revision 29 13.7-15 Revision 29 13.7-16 Revision 29 13.7-17 Revision 29 13.7-18 Revision 29 13.7-19 Revision 29 13.7-20 Revision 29 13.7-21 Revision 29 13.7-22 Revision 29 13.7-23 Revision 29 13.7-24 - Revision 29 13.7-25 Revision 29 13,7-26 Revision 29 13.7-27 Revision 29 13.7-28 Revision 29 13.7-29 Revision 29 13.7-30 Revision 29 13.7-31 Revision 29 13.8-1 Revision 29 13.8-2 Revision 29 13.8-3 Revision 29 13.8-4 Revision 29 13.8-5 Revision 29 ,

13.8-6 Revision 29 l 13.8-7 Revision 29 1 13.8-8 Revision 29 13.8-9 Revision 29 j 13.8-10 Revision 29 13.8-11 Revision 29 13.8-12 Revision 29 13.8-13 Revision 29 CPSES - UNITS 1 AND 2 - TRM EPL-4 July 27,1999

COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING 13.8-14 Revision 29 13.8-15 Revision 29 13.8-16 Revision 29 13.8-17 Revision 29 13.8-18 Revision 29 13.8-19 Revision 29 13.8-20 Revision 29 13.8-21 Revision 29 l 13.8-22 Revision 29 13.8-23 Revision 29 )

13.8-24 Revision 29 13.8-25 Revision 29 13.8-26 Revision 29 .

13.8-27 Revision 29 {

13.8-28 Revision 29 1 13.8-29 Revision 29 13.8-30 Revision 29 l 13.8-31 Revision 29 )

13.8-32 Revision 29 13.8-33 Revision 29 .

13.8-34 Revision 29 13.9-1 Revision 29 13.9-2 Revision 29 i 13.9-3 Revision 29 13.9-4 Revision 29 i 13.9-5 Revision 29 13.9-6 Revision 29 13.9-7 Revision 30 13.10-1 Revision 29 13.10-2 Revision 30 13.10-3 Revision 29 13.10-4 Revision 29 13.10-5 Revision 29 13.10-6 Revision 29 l 13.10-7 Revision 29 !

13.10-8 Revision 29 13.10-9 Revision 29 13.10-10 Revision 29 15.0-1 Revision 29 15.0-2 Revision 29 15.0-3 Revision 23 15.0-4 Revision 29 15.0-5 Revision 29 15.0-6 Revision 29 15.0-7 Revision 29 15.0-8 Revision 29 CPSES -UNITS 1 AND 2-TRM EPL-5 July 27,1999

COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING TRM Bases -Title Page July 27,1999 Bi July 27,1999 l B 11 July 27,1999 8 13.0-1 Revision 29 B 13.1-1 Revision 29 B 13.1-2 Revision 29 B 13.1-3 Revision 29 B 13.1-4 Revision 29 B 13.1-5 Revision 29 B 13.1-6 Revision 29 8 13.1-7 Revision 29 8 13.1-8 Revision 29 8 13.1-9 Revision 29 B 13.1-10 Revision 29 B 13.2-1 Revision 29 B 13.2-2 Revision 29 B 13.2-3 Revision 29 B 13.3-1 Revision 29 8 13.3-2 Revision 29 B 13.3-3 Revision 29 B 13.3-4 Revision 29 B 13.3-5 Revision 29 B 13.3-6 Revision 29 B 13.4-1 Revision 29 B 13.4-2 Revision 29 B 13.4-3 Revision 29 B 13.4-4 Revision 29 B 13.4-5 Revision 29 B 13.4-6 Revision 29 B 13.5-1 Revision 29 B 13.5-2 Revision 29 B 13.6-1 Revision 29 B 13.6-2 Revision 29 B 13.6-3 Revision 29 B 13.7-1 Revision 29 B 13.7-2 Revision 29 B 13.7-3 Revision 29 B 13.7-4 Revision 29 l B 13.7-5 Revision 29 j B 13.7-6 Re' vision 29 B 13.7-7 Revision 29 B 13.7-8 Revision 29 B 13.7-9 Revision 29 B 13.7-10 Revision 29 B 13.7-11 Revision 29 B 13.8-1 Revision 29 CPSES - UNITS 1 AND 2-TRM EPL-6 July 27,1999 I

COMANCHE PEAK ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING B 13.8-2 Revision 29 B 13.9-1 Revision 29 B 13.9-2 Revision 29 B 13.9-3 Revision 29 B 13.9-4 Revision 29 B 13.9-5 Revision 29 B 13.9-6 Revision 29 B 13.10-1 Revision 29 B 13.10-2 Revision 29 8 13.10-3 Revision 29 8 13.10-4 Revision 29 EPL-1 July 27,1999 EPL-2 Juy27,1999 EPL-3 July 27,1999 EPL-4 July 27,1999 EPL-5 July 27,1999 EPL-6 July 27,1999 EPL-7 July 27,1999

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CPSES - UNITS 1 AND 2-TRM EPL-7 July 27,1999

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ML20211G740

Text

REFERENCE:

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