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APR1400-K-O-NR-14001-NP, Rev. 2, Deviation Report Between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications
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Issue date:	04/12/2018
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Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP G

Korea Hydro & Nuclear Power Co., Ltd.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP i

REVISION HISTORY Revision Date Page Description 0

October 2014 All Original Issued 1

November 2015 All Complete Revision 2

March 2018 All Complete Revision G

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Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP ii

ABSTRACT The APR1400 Technical Specifications presented in Chapter 16 of the DCD are based on NUREG-1432, Rev. 4.0, Standard Technical Specifications Combustion Engineering Plants, by reference.

This report provides the justification for the technical deviations from NUREG-1432 and the APR1400 Technical Specifications.

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Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP iiiG

TABLE OF CONTENTS I.

INTRODUCTION ****************************************************************************** 1 II. GENERAL DESCRIPTION OF DEVIATIONS ***************************************** 2

1. USE OF CONSERVATIVE VALUES ************************************************ 2

2. USE OF ADDITIONAL DEFINES ***************************************************** 5

3. USE OF CURRENT TECH. SPEC. ************************************************* 7

4. COL ITEMS ******************************************************************************** 8

5. DIFFERENT NAME OF SYSTEMS/COMPONENTS **************************** 8

6. TECHNICAL SPECIFICATIONS TASK FORCE (TSTF) TRAVELERS ***** 9 III. SYSTEM LEVEL DEVIATIONS AND JUSTIFICATION **************************** 13

1. INSTRUMENTATION ****************************************************************** 13

2. REACTOR COOLANT SYSTEM **************************************************** 16

3. EMERGENCY CORE COOLING SYSTEM ************************************** 17

4. ELECTRICAL POWER SYSTEMS ************************************************* 20

5. REFUELING OPERATION *********************************************************** 22

6. CONTAINMENT SYSTEM ************************************************************ 24

7. PLANT SYSTEM ************************************************************************ 25 IV. CONCLUSIONS **************************************************************************** 182 V. REFERENCE ******************************************************************************* 183

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP iiiG

LIST OF TABLE Table II-1 Conservative values in TS SRs that are different than NUREG-1432 ***** 3 Table II-2 Conservative values in LCOs that are different than NUREG-1432 ************ 4 Table II-3 Name of system and components that are different than NUREG-1432 ****** 8 Table II-4 TSTFs Included in NUREG-1432 Rev. 4 that are not included in APR1400 ***

- - - - ****** 10 Table II-5 APR1400 status of TSTFs that have been approved since NUREG-1432 Rev. 4 **************************************************************************************** ***11 Table III-1 Deviations and Justification between Standard Technical Specifications and the APR1400 Technical Specifications *********************************************** 27

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP viG

ACRONYMS AND ABBREVIATIONS ABCAEES Auxiliary Building Controlled Area Emergency Exhaust System AC Alternating Current ACU Air Cleaning Unit ADV Atmospheric Dump Valve ALT As-Left Tolerance AFAS Auxiliary Feedwater Actuation Signal AFT As-Found Tolerance AFW(S)

Auxiliary Feedwater (System)

AFWST Auxiliary Feedwater Storage Tank AMI Accident Monitoring Instrumentation APC-S Auxiliary Process Cabinet - Safety ASI Axial Shape Index AV Allowable Value BA Burnable Absorbers BAMP Boric Acid Makeup Pump BAST Boric Acid Storage Tank BDAS Boron Dilution Alarm Systems CCAS Containment Cooling Actuation Signal CCW(S)

Component Cooling Water (System)

CEA(C)

Control Element Assembly (Calculator)

CEDMCS Control Element Drive Mechanism Control System CFT Channel Functional Test CIV Containment Isolation Valve COL Construction and Operation License COLR Core Operating Limits Report COLSS Core Operating Limit Supervisory System CPC Core Protection Calculator CPCS CRUH3URWHFWLRQ&DOFXODWRU6\\VWHP CPIS Containment Purge Isolation System CPIAS Containment Purge Isolation Actuation System CRE Control Room Envelope CREACS Control Room Emergency (Makeup) Air Cleanup System CREATCS Control Room Emergency Air Temperature Control System CREVAS Control Room Emergency Ventilation Actuation System CRHS Control Room HVAC System

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP viG

CRIS Control Room Isolation CRSRS Control Room Supply and Return System CSAS Containment Spray Actuation Signal CS(P)

Containment Spray (Pump)

CSHX Containment Spray Heat Exchanger CSS Containment Spray System CST Condensate Storage Tank CTS Current Technical Specifications DBA Design Basis Accident DC Direct Current DCD Design Control Document DE DOSE EQUIVALENT DG Diesel Generator DNB(R)

Departure from Nucleate Boiling (Ratio)

DPS Diverse Protection System DRCS Digital Rod Control System DVI Direct Vessel Injection ECCS Emergency Core Cooling System ECW(S)

Essential Chilled Water (System)

EDG Emergency Diesel Generator EFAS Emergency Feedwater Actuation Signal EFPD Effective Full Power Days ENFMS Ex-core Neutron Flux Monitoring System EOG Emergency Operational Guideline ESFAS Engineered Safety Features Actuation System ESF-CCS Engineered Safety Features - Component Control System ESW(S)

Essential Service Water (System)

FBACS Fuel Building Air Cleanup System FHAEES Fuel Handling Area Emergency Exhaust System FHEVAS Fuel Handling Area Ventilation Actuation System FHIS Fuel Handling Isolation Signal FSAR Final Safety Analysis Report GCB Generator Circuit Breaker HMS Hydrogen Mixing System HPSI(P)

High Pressure Safety Injection (Pump)

HVAC Heating, Ventilation, and Air Conditioning HVT Holdup Volume Tank

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP viG

I&C Instrumentation and Control ICS Iodine Cleanup System IRWST In-Containment Refueling Water Storage Tank KHNP Korea Hydro & Nuclear Co., Ltd LC Load Center LCO Limiting Condition for Operation LHR Linear Heat Rate LOCA Loss Of Coolant Accident LOOP Loss Of Offsite Power LOVS Loss of Voltage Start LPD Local Power Density LPSI(P)

Low Pressure Safety Injection (Pump)

LTOP Low Temperature Overpressure Protection MCC Motor Control Center MCR Main Control Room MFIV Main Feedwater Isolation Valve MG Main Generator MSADV Main Steam Atmospheric Dump Valve MSIS Main Steam Isolation Signal MSIV Main Steam Isolation Valve MSSV Main Steam Safety Valves MTC Moderator Temperature Coefficient NPP Nuclear Power Plant NTSP Nominal Trip Setpoint OPP Over Pressure Protection PAM Post Accident Monitoring PIV Pressure Isolation Valve PORV Power Operated Relief Valves POSRV Pilot Operated Safety Relief Valve PPS PODQW3URWHFWLRQ6\\VWHP PREACS Pump Room Exhaust Air Cleanup System PTLR Pressure and Temperature Limits Report PZR Pressurizer RCGV(S)

Reactor Coolant Gas Vent (System)

RCP Reactor Coolant Pump

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP viG

RCPB Reactor Coolant Pressure Boundary RCS Reactor Coolant System RG Regulatory Guide RHR Residual Heat Removal RITS Risk Informed Technical Specification RITSTF Risk Informed Technical Specification Task Force RPCS Reactor Power Cutback System RPS Reactor Protection (Protective) System RSPT Reed Switch Position Transmitter RSR Remote Shutdown Room RTCB Reactor Trip Circuit Breaker RTD Resistance Thermal Detector RTP Rated Thermal Power RTS Reactor Trip System RTSS Reactor Trip Switchgear System RWT Refueling Water Tank SAT Standby Auxiliary Transformer SBEACS Shield Building Exhaust Air Cleanup System SBO Station Black Out SC(P)

Shutdown Cooling (Pump)

SCS Shutdown Cooling System SDC Shutdown Cooling SDM Shutdown Margin SFHM Spent Fuel Handling Machine SFP Spent Fuel Pool SFPCCS Spent Fuel Pool Cooling and Cleanup System SFPWL Spent Fuel Pool Water Level SG Steam Generator SI(P)

Safety Injection (Pump)

SIAS Safety Injection Actuation Signal SIS Safety Injection System SIT Safety Injection Tank SL Safety Limit SR Surveillance Requirement SRM Source Range Monitor SRP Standard Review Plan STE Special Test Exceptions STS Standard Technical Specifications SWS Service Water System TS Technical Specifications TSTF Technical Specifications Task Force TSP Trisodium Phosphate UAT Unit Auxiliary Transformer UHS Ultimate Heat Sink VOPT Variable Overpower Trip G

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 1G I. INTRODUCTION The APR1400 Technical Specifications satisfy 10 CFR 50.36 (Reference 1), "Technical specifications" and applies NUREG-1432, Rev. 4.0 (Reference 2) as the Standard Technical Specifications (STS). The difference between the STS and the APR1400 Technical Specifications exists only as necessary to reflect advanced design features and to incorporate operational experience into the APR1400.

This report provides the justification for the deviations of APR1400 Technical Specifications compared to the Standard Technical Specification (NUREG-1432, Rev. 4.0).

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Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 2G II. GENERAL DEVIATIONS AND JUSTIFICATION 1

Use of Conservative Values The APR1400 design has been developed based on operating and licensing experiences in Korea.

Such experiences are reflected in WKHAPR1400 Technical Specifications. The APR1400 Technical Specifications are not considered to be risk informed technical specification (RITS). Thus, some values such as completion times and frequencies are more conservative than those in NUREG-1432. Table II-1 below shows the difference in values for surveillances (such as frequencies) and Table II-2 shows LCO values (such as completion times). These differences in values between the APR1400 TS and those of NUREG-1432 are conservative and therefore do not require justification. Though the section listed for the APR1400 might have a different number than that of NUREG-1432, it is considered to be the equivalent specification. These lists are not repeated in Table III-1.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 3G Table II-1 Conservative values in TS SRs that are different than NUREG-1432 NUREG-1432 APR1400 TS Remark SR Section Value SR Section Value N/A N/A 3.1.1.2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months N/A N/A 3.1.1.3 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months N/A N/A 3.1.7.2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RITS not applied N/A N/A 3.1.8.1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RITS not applied 3.1.8.2 7 days 3.1.9.2 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months RITS not applied N/A N/A 3.1.9.3 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months APR1400 specific condition for STE N/A N/A 3.1.9.4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months APR1400 specific condition for STE N/A N/A 3.1.11.1 15 minutes APR1400 specific condition for STE N/A N/A 3.1.11.2 15 minutes APR1400 specific condition for STE N/A N/A 3.1.12.1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RITS not applied 3.2.2.1 70% RTP 3.2.2.1 80% RTP APR1400 specific condition 3.3.1.7 92 days 3.3.1.7 31 days 3.3.1.8 92 days 3.3.1.8 31 days 3.3.1.12 70% RTP 3.3.1.11 80% RTP APR1400 specific condition 3.3.1.13 92 days 3.3.1.12 31 days RITS not applied 3.3.2.2 92 days 3.3.2.2 31 days RITS not applied 3.3.2.3 92 days 3.3.2.3 31 days RITS not applied 3.3.3.3 92 days 3.3.3.3 31 days RITS not applied 3.3.4.2 92 days 3.3.4.1 31 days RITS not applied 3.3.4.4 Once within 7 days prior to each reactor startup 3.3.4.3 31 days RITS not applied 3.3.5.2 92 days 3.3.5.2 31 days RITS not applied 3.3.5.5 92 days 3.3.5.5 31 days RITS not applied 3.3.6.1 92 days 3.3.6.1 31 days RITS not applied 3.3.6.2 184 days 3.3.6.2 31 days on a STAGGERED TEST BASIS RITS not applied 3.3.6.3 18 months 3.3.6.1 31 days RITS not applied 3.3.13.2 92 days 3.3.13.2 31 days RITS not applied 3.4.9.2 18 months SR 3.4.9.2 92 days RITS not applied 3.4.15.2 92 days SR 3.4.14.3 31 days 3.9.3.1 None 7 days 3.9.3.1 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior to the start of movement of irradiated fuel Once per 7 days N/A N/A 3.9.7.1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RITS not applied

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 4G Table II-2 Conservative values in LCOs that are different than NUREG-1432 NUREG-1432 APR1400 TS Remark LCO Section Value LCO Section Value N/A N/A 3.1.12 A.1 3.1.12 A.2 3.1.12 A.3 Immediately Immediately 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 3.2.3 B.2 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months 3.2.3 B.2 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months CTS value used 3.4.13 b 1 gpm 3.4.12 b 0.5 gpm APR1400 specific condition for STE (DCD 15.1.5) 3.5.1 B.1 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 3.5.1 B.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months RITS not applied 3.5.2 A.1 7 days 3.5.2 A.1 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months RITS not applied 3.7.12 A.1 30 days 3.7.12 A.1 7 days

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 5G 2

Use of Additional Definition In the APR1400 TS, the following terminologies are defined to provide a clearer understanding relative to its application to the APR1400 design.

2.1 CORE ALTERATION In NUREG-1432, CORE ALTERATION is not included in the Definitions section of TS. Instead, the following statement is used:

movement of [recently] irradiated fuel assemblies within containment.

In the APR1400 TS, CORE ALTERATION is defined as follows to provide a more precise definition:

CORE ALTERATION shall be the movement or manipulation of any fuel, sources, reactivity control components, or other components (excluding control element assemblies (CEAs) withdrawn into the upper guide structure) affecting reactivity within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

APR1400 TS LCOs 3.3.8, 3.3.9, 3.9.3 and 3.9.6 are related to this deviation.

2.2 DOSE EQUIVALENT I-131 and XE-133 In NUREG-1432, DOSE EQUIVALENT I-131 (DE I-131) and -AVERAGE DISINTEGRATION ENERGY are defined as follows; DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in [Table III of TID-14844, AEC, 1962, Calculation of Distance Factors for Power and Test Reactor Sites, or those listed in Table E-7 of Regulatory Guide 1.109, Rev. 1, NRC, 1977, or ICRP 30, Supplement to Part 1, page 192-212, Table titled, Committed Dose Equivalent in Target Organs or Tissues per Intake of Unit Activity].

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 6G shall be the average (weighted in proportion to the concentration of each radionuclide in the reactor coolant at the time of sampling) of the sum of the average beta and gamma energies per disintegration (in MeV) for isotopes, other than iodines, with half lives > [15] minutes, making up at least 95% of the total noniodine activity in the coolant.

In the APR1400 TS, the definition of DE I-131 is consistent with TSTF-490, Rev. 0, Deletion of E Bar Definition and Revision to RCS Specific Activity Tech Spec. TSTF-490 recommends the following changes: 1) revise the definition of DE I-131, 2) delete the definition of E-Bar, 3) add a new definition for DE Xe-133, and 4) revise LCO 3.4.16, RCS Specific Activity.

DOSE EQUIVALENT I-131 and XE-133 are defined as follows in the APR1400 TS; DOSE EQUIVALENT I-131 shall be that concentration of I-131 (Bq/g) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes I-131, I-132, I-133, I-134, and I-135 actually present. The determination of DOSE EQUIVALENT I-131 shall be performed using thyroid dose conversion factors from Table 2.1 of EPA Federal Guidance Report No. 11, Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion, EPA-520/1-88-020, September 1988.

DOSE EQUIVALENT XE-133 shall be that concentration of Xe-133 (Bq/g) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-85, Kr-87, Kr-88, Xe-131m, Xe-133m, Xe-133, Xe-135m, Xe-135 and Xe-138 actually present.

The determination of DOSE EQUIVALENT XE-133 shall be performed using effective dose conversion factors for air submersion listed in Table III.1 of EPA Federal Guidance Report No. 12, External Exposure to Radionuclides in Air, Water, and Soil, EPA 402-R-93-081, September 1993.

APR1400 TS LCO 3.4.15 is related to this deviation.

2.3 OPERABLE - OPERABILITY In NUREG-1432, the term 'division' has not been used. In the APR1400 TS, 'division' is added and used which is defined as follows.

A division is a set of trains, performing various safety functions, separated both mechanically and electrically from another division. The separation between the divisions is provided geographically

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 7G or by physical barrier. The Class 1E onsite power system consists of two redundant divisions (Division 1 and Division 2) and each division is further broken down into Train A and Train C for Division 1 and Trains B and D for Division 2.

3 Use of current Tech. Spec.

There are 23 operating NPPs in Korea which use Current Technical Specifications (CTS). When CTS is considered with the STS, some definitions, statements, and classifications were kept in accordance with CTS to maintain consistency with the operating experience of those plants.

3.1 Operational mode classification When an operational mode is defined, NUREG-1432 uses RCS average temperature whereas the APR1400 TS uses RCS cold leg temperature. APR1400 TS Table 1.1-1 and LCO 3.4.2 are related to this deviation.

3.2 Days of 1 month NUREG-1432 uses 30 days as a definition of 1 month whereas APR1400 TS uses 31 days.

Completion Times in APR1400 TS LCOs 3.3.11, 3.3.12, 3.6.2, 3.6.3 and 3.8.6 and Surveillance Frequencies for numerous APR1400 TS LCOs are related on this deviation.

3.3 End States TSTF-422 Risk-Informed Modification to Selected Action End States for CEOG PWRs is not applied because the APR1400 design-specific analysis for modification of end state was not performed. Therefore, Mode 5 is defined as the safe end state in the APR1400 TS. Required Actions and/or Completion Times in APR1400 TS LCOs 3.3.5, 3.3.6, 3.3.8, 3.3.9, 3.6.2, 3.6.3, 3.6.4, 3.6.5, 3.6.6, 3.7.7, 3.7.8, 3.7.9, 3.7.10, 3.7.11, 3.7.12, 3.8.1, 3.8.4 and 3.8.7 are related to this deviation.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 8G 4

COL Items In the APR1400 TS, some parameters are described based on input parameters of the DCD Chapter 15 safety analysis, whereas NUREG-1432 defines these parameters as being provided in the COLR. These deviations are listed below.

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5 Different Name of Systems/Components The APR1400 TS uses some different system or component names from NUREG-1432, though the meaning is the same. The following list (Table II-3) shows these items which are generally not included in Table III-1.

Table II-3 Name of system and components that are different than NUREG-1432 NUREG-1432

Related Sections

APR1400 TS

Related Sections

Remark

Full/Part length CEA 1.1, 3.1.4, 3.1.7, 3.1.8, 3.1.9, 3.3.3, Full/Part Strength CEA 1.1, 3.1.4, 3.1.7, 3.1.9, 3.1.10, 3.1.11, 3.3.3, 4.2.2, 5.6.3 CRIS 3.3.9, 5.5.19 CREVAS 3.3.9, 5.5.19 CPIS 3.3.8, 5.5.19 CPIAS 3.3.8, 5.5.19 FHIS 3.3.10, 5.5.19 FHEVAS 3.3.10, 5.5.19 Remote Shutdown System 3.3.12 Remote Shutdown Display and Control 3.3.12 PAM 3.3.11, 5.6.5 AMI 3.3.11, 5.6.5 RWT 3.5.4, 3.5.5 IRWST 3.3.11, 3.3.12, 3.4.16, 3.5.2, 3.5.4, 3.5.5

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 9G NUREG-1432

Related Sections

APR1400 TS

Related Sections

Remark

Containment Spray and Cooling System 3.6.6 Containment Spray System 3.6.6, 5.5.2 Containment Cooling function is included in the Containment Spray System ADV 3.7.4 MSADV 3.7.4, 3.3.11, 3.3.12 Service Water System 3.7.8 Essential Service Water System 3.3.12, 3.7.8 ECW 3.7.10 ECWS 3.7.10 PREACS 3.7.13, 3.7.15 ABCAEES 3.7.12, 5.5.11 FBACS 3.3.10, 3.7.14 FHAEES 3.7.13, 5.5.11 FHIS 3.3.10, 5.5.19 FHEVAS 3.3.10, 5.5.19 DG 1.1, 3.3.7, 3.8.1, 3.8.2, 3.8.3, 5.5.19 EDG 1.1, 3.3.7, 3.3.12, 3.8.1, 3.8.2, 3.8.3, 5.5.19 Battery Parameters 3.8.6 Battery Cell Parameters 3.8.6 6

Technical Specifications Task Force (TSTF) Travelers The APR1400 TS adopts the approved technical specifications task force travelers that are included in NUREG-1432 Rev. 4. TSTFs that are not included in the APR1400 TS are indicated in Table II-4 with technical rationale. APR1400 TS status of applicable TSTF travelers that have been approved since NUREG-1432 Rev. 4 are indicated in Table II-5.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 10G Table II-4 TSTFs included in NUREG-1432 Rev. 4 that are not included in APR1400 Approved TSTF Traveler

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Status for APR1400

Technical Rationale

TSTF-30-A, Rev. 3 Extend the Completion Time for inoperable isolation valve to a closed system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Not Incorporated Risk Informed Technical Specification is not applied. Instead, NUREG-1432 Rev. 1 is used.

TSTF-51-A, Rev. 3 Revise containment requirements during handling irradiated fuel and core alterations Not Incorporated Risk Informed Technical Specification is not applied. Instead, NUREG-1432 Rev. 1 is used.

TSTF-68-A, Rev. 2 Containment Personnel Airlock Doors Open During Fuel Movement Not Incorporated Risk Informed Technical Specification is not applied. Instead, NUREG-1432 Rev. 1 is used.

TSTF-207-A, Rev. 5 Completion Time for Restoration of Various Excessive Leakage Rates Not Incorporated Not applicable to APR1400 since it has no secondary containment and has no containment penetrations with more than two CIVs. Instead, NUREG-1432 Rev. 1 is used.

TSTF-373-A, Rev. 2 Increase CIV Completion Time in Accordance With CE-NPSD-1168 Not Incorporated Risk Informed Technical Specification is not applied. Instead, NUREG-1432 Rev. 1 is used.

TSTF-422-A, Rev. 2 Change in Technical Specifications End States (CE NPSD-1186)

Not Incorporated Not applied because the APR1400 design-specific analysis for modification of end state was not performed. Instead, NUREG-1432 Rev. 1 is used.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 11G Table II-5 APR1400 status of TSTFs that have been approved since NUREG-1432 Rev. 4 Approved TSTF Traveler

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Status for APR1400

Technical Rationale

TSTF-426-A, Rev. 5 Revise or Add Actions to Preclude Entry into LCO 3.0.3 - RITSTF Initiatives 6b & 6c Not Incorporated Risk Informed Technical Specification is not applied for APR1400 DCD.

TSTF-490-A, Rev. 0 Deletion of E Bar Definition and Revision to RCS Specific Activity Tech Spec Incorporated In the APR1400, RCS specific activity specification is revised in accordance with TSTF-490-A, Rev. 0.

TSTF-505-A, Rev. 1 Provide Risk-Informed Extended Completion Times - RITSTF Initiative 4b Not Incorporated Risk Informed Technical Specification is not applied for APR1400 DCD.

TSTF-510-A, Rev. 2 Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection Incorporated In the APR1400, SG Program is revised in accordance with TSTF-510-A, Rev. 2.

TSTF-522-A, Rev. 0 Revise Ventilation System Surveillance Requirements to Operate for 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months per Month Incorporated TSTF-522-A, Rev. 0 is applied to APR1400 Technical Specifications.

TSTF-523-A, Rev. 2 Generic Letter 2008-01, Managing Gas Accumulation Incorporated TSTF-523-A (Managing Gas Accumulation) is applied to APR1400 Technical Specifications.

TSTF-529-A, Rev. 4 Clarify Use and Application Rules Not Incorporated Risk Informed Technical Specification is not applied for APR1400 DCD.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 12G Approved TSTF Traveler

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Status for APR1400

Technical Rationale

TSTF-545-A, Rev. 3 TS Inservice Testing Program Removal &

Clarify SR Usage Rule Application to Section 5.5 Testing Not Incorporated Not applied because this change does not increase operational safety.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 13G III. SYSTEM LEVEL DEVIATIONS AND JUSTIFICATION STS are generally applicable to the APR1400 design. However, system level differences between STS and the APR1400 Technical Specification exist to reflect design features that are different from the reference plant of NUREG-1432. In this section, the differences and technical justification of those systems are described.

1 Instrumentation 1.1 Major Design Features The reactor trip system (RTS) is a safety system which initiates reactor trips. The RTS consists of four channels of sensors, auxiliary process cabinet-safety (APC-S) cabinets, ex-core neutron flux monitoring system (ENFMS) cabinets, core protection calculator system (CPCS) cabinets, the reactor protection system (RPS) portion of plant protection system (PPS) cabinets, and reactor trip switchgear system (RTSS) cabinets.

The RPS function is performed through measurement channels, bistable logics, RPS logics, and the reactor trip circuit breaker (RTCB). Measurement channels consist of the sensor and transmitter providing a process value to bistable logics. Bistable logics provide a trip signal to RPS logic comparing the process value with a predetermined setpoint. There are two bistable racks (including separate input and output modules, data links, one bistable processor, etc.) per channel. The RPS logic provides a trip signal to RTCB after performing 2/4 logic based on bistable trip status of four channels. There are two local coincidence logic racks (including separate input and output modules, data links, four local coincidence logic processors, etc.) per channel. The RTCB opens the trip switchgear based on a trip signal from RPS logic. The RTCB consists of undervoltage trip equipment and shunt trip equipment. The PPS interfaces with the undervoltage trip device of the RTCB. The diverse protection system (DPS) interfaces with the shunt trip device of the RTCB.

The ESFAS function is performed through measurement channels, bistable logics, and ESFAS logics. Measurement channels consist of the sensor and transmitter providing a process value to bistable logics. Bistable logics provide a trip signal to ESFAS logic comparing the process value with a predetermined setpoint. There are two bistable racks (including separate input and output modules, data links, one bistable processor, etc.) per channel. The ESFAS logic consists of coincidence logic, initiation logic, and actuation logic. The four initiation logics in the PPS actuate a two-out-of-four logic in the ESF-CCS. In the actuation logic, each signal also sets a latch when the

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 14G two-out-of-four logic actuates to assure that the signal is not automatically reset once it has been initiated.

1.2 Major differences and justifications 1.2.1 In the APR1400, the Loss of Load RPS trip function is not used so the related contents are deleted. This deviation is related to APR1400 TS LCO 3.3.1.

1.2.2 In the APR1400, the Recirculation Actuation Signal, Containment Cooling Actuation Signal, and the Emergency Feedwater Actuation Signal ESFAS trip functions are not used so the related contents are deleted. The Auxiliary Feedwater Actuation Signal ESFAS trip function that considers only Steam Generator Level - Low is used instead of the Emergency Feedwater Actuation Signal. In addition, the Containment Cooling Actuation Signal ESFAS trip function is included in the Containment Spray Actuation Signal function. This deviation is related to APR1400 TS LCOs 3.3.5 and 3.3.6.

1.2.3 Logarithmic Power Level - High As described in DCD Tier 2, Table 7.2-1, Reactor Protection System Operating Bypass Permissive, the operating bypass permissive and removal setpoints for Logarithmic Power Level - High are 10-3 % RTP and < 10-3 % RTP, respectively. According to NUREG-1432 BASES SR 3.3.1.7, the CHANNEL FUNCTIONAL TEST (CFT) for the logarithmic power level channels is allowed to be performed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reducing THERMAL POWER below 1E-4%

RTP and is required to be performed only if the RTCBs are closed. This means that the CFT is not required until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reducing THERMAL POWER below 1E-4% RTP or if the RTCBs are open. Therefore, the Note 2 of SR 3.3.1.7 has been changed to Not required to be performed for Logarithmic Power Level - High until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reducing logarithmic power below 1E-3% and only if reactor trip circuit breakers (RTCBs) are open. This deviation is related to APR1400 TS LCO 3.3.1.

1.2.4 Pressurizer Pressure - Low The minimum setpoint for Pressurizer Pressure - Low is 100 psia as shown in DCD Tier 2, Table 7.2-4, Note (5). As described in DCD Tier 2, Table 7.2-1, Reactor Protection System Operating Bypass Permissive, the operating bypass permissive and removal setpoints for

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 15G Pressurizer Pressure - Low are 400 psia and 500 psia, respectively. This deviation is related to APR1400 TS LCO 3.3.1.

1.2.5 Coincidence Logic APR1400 RPS has four Coincidence Logic channels instead of six Matrix Logic channels.

This deviation is related to APR1400 TS LCOs 3.3.4 and 3.3.6.

1.2.6 Actuation Logic Some components cannot be tested during power operation since their actuation might lead to plant trip or equipment damage. Actuation Logic subgroups not tested during power operation must be tested in accordance with the Note of SR 3.3.6.2. Subgroup testing of each actuation logic channel A, C and B, D is performed on a STAGGERED TEST BASIS.

The 31-day Frequency on a staggered test basis is consistent with the operating experience of Korean NPPs. The APR1400 ESF-CCS does not have subgroup relays, but contains the logic for subgroup control. This deviation is related to APR1400 TS LCO 3.3.6.

A channel is an arrangement of components and modules as required to generate a single protective action signal when required by a generating station condition. A channel loses its identity where single protective action signals are combined. Chapter 7 in DCD Tier 2, GTS and bases use the word "channel" or "division" for the portion of the circuit from the local coincidence logic to the actuation logic. The words "channel" and "division" are interchangeable regarding the portion from the local coincidence logic to the actuation logic.

1.2.7 Diverse Manual ESF Actuation Signal APR1400 instrumentation and control (I&C) systems provide Diverse Manual ESF Actuation controls and indications to provide protection against accidents and concurrent common cause failure of PPS and/or ESF-CCS. This deviation is related to APR1400 TS LCO 3.3.6.

1.2.8 Control Element Assembly Calculator (CEAC)

In the APR1400 there are two CEACs in each CPCS channel. This change has come from the APR1400 CPCS configuration. In the CPCS configuration in STS, there had been two CEACs total, one at channel B and the other in channel C. In the APR1400 CPCS

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 16G configuration, there are two (2) CEACs in each channel and a total of eight (8) CEACs for the four channels. (See DCD Tier 2 Figure 7.2-4.) This deviation is related to APR1400 TS LCO 3.3.3.

2 Reactor Coolant System 2.1 Major Design Features The reactor coolant system (RCS) is a safety related system which removes the heat generated in the reactor core and transfers the heat to the steam generators. The reactor vessel, steam generators, reactor coolant pumps, pressurizer, and associated piping are the major components of the RCS. Two parallel heat transfer loops, each containing one steam generator and two reactor coolant pumps, are connected to the reactor vessel, and one pressurizer is connected to one of the hot legs. All RCS components are located inside the containment building. Overpressure protection for the reactor coolant pressure boundary is provided by four pilot operated safety relief valves (POSRVs) connected to the top of the pressurizer. These valves discharge to the in-containment refueling water storage tank (IRWST).

2.2 Major differences and justifications 2.2.1 In the APR1400, RCS specific activity specification is revised in accordance with TSTF-490, Rev. 0, Deletion of E Bar Definition and Revision to RCS Specific Activity Tech Spec as discussed in Section II.2.2. This deviation is related to APR1400 definitions and TS LCO 3.4.15.

2.2.2 Pressurizer Pilot Operated Safety Relief Valves (POSRVs) are used in the APR1400. The POSRV setpoint range for this valve type is different than the pressurizer safety valves in the STS. In the APR1400 TS LCO 3.4.10 APPLICABILITY section, the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months exception is based on 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months of outage time for each of the four valves (APR1400 adapts 4 POSRVs).

The 18-hour period is determined based on operating experience. This deviation is related to APR1400 TS LCO 3.4.10.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 17G 3

Emergency Core Cooling System 3.1 Major Design Features The SIS consists of four mechanically separated trains. Each train contains one SI pump and associated suction and discharge paths. The SI pumps take suction from the IRWST, which is located in the containment, and inject borated water into the RCS through DVI nozzles to flood and cool the core following a LOCA. The SIS is initiated automatically upon an SIAS or manually. The SIAS is produced by a two-out-of-four low pressurizer pressure or high containment pressure signal.

The SIS is designed such that two diagonal SI pumps (i.e., SI pumps 1,3 or 2,4) in conjunction with the SITs provide 100 percent of the minimum injection flow rate to the core required to meet the system functions.

The primary function of the SI pumps is to inject borated water into the RCS if a break occurs in the RCPB. For small break LOCA, the RCS pressure remains high for a long period following the accident, and the SI pumps provide reasonable assurance that the injected flow is sufficient to meet the criteria given in DCD Section 6.3.1. If necessary, SI pump flow is throttled to reduce RCS pressure to conditions that allow the initiation of shutdown cooling system operation. During shutdown cooling operations following a small break LOCA, the SI pumps continue injecting into the reactor vessel downcomer to provide makeup for spillage out the break.

3.2 Major differences and justifications 3.2.1 Safety injection tank (SITs) (LCO 3.5.1)

In the APR1400, the SITs are available in MODE 4 with pressurizer pressure 50.3 kg/cm2A (715 psia) which is assumed in the Chapter 15 safety analysis. To implement the applicable range, the EOG and system design is changed. The detailed information is written in DCD Chapter 6.2 and APR1400-E-N-NR-14003-P, Rev. 0 (Section 4.3).

3.2.2 Safety Injection System (SIS) - Operating (LCO 3.5.2 and LCO 3.5.3)

Safety analyses assume four SI trains operable in Mode 1, 2 and 3, but two SI trains operable in Mode 4, 5 and Mode 6 with vessel water level < 39.7 m (130 ft).

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 18G Full flow from two diagonal SIS trains is credited because the safety analysis acceptance criteria cannot be satisfied should a cold leg break occur with the only two operable DVI nozzles being adjacent to the faulted cold leg due to core bypass flow that could occur. Full flow from one SI pump and three SITs is used in safety analysis for a break in a DVI line. Therefore, four trains of SIS operable during Modes 1, 2 & 3 provides sufficient margin considering a failure of an EDG to start.

NUREG-1432 Rev. 4 is based on ECCS consisting of two HPSIPs and two LPSIPs. APR1400 is based on ECCS consisting of four SIPs supported by four EDGs. Two trains located diagonally with respect to the reactor vessel or three trains are assumed operable in the safety analysis.

For LCO 3.5.2 CONDITION B, two inoperable SI trains are allowable only if diagonally positioned in the reactor vessel. SI train #1 is diagonally positioned to SI train #3. SI train #2 is diagonally positioned to SI train #4. If the two inoperable injection lines are in a diagonal position in the reactor vessel, the two injection trains meet the flow requirements (100%) due to the small bypass through the break in the cold leg.

The safety analysis assumes that at least two diagonally located SI trains are operable considering the bypass flow through the break.

This deviation is related to APR1400 TS LCOs 3.5.2 and 3.5.3.

3.2.3 In-Containment Refueling Water Storage Tank (IRWST) (LCO 3.5.4)

The IRWST is the water source of SIS during an accident and the applicable modes for SIS are extended to the modes specified in LCO 3.5.3. Therefore, the applicable modes for the IRWST are extended for providing water to SIS.

Both CONDITIONS A & C in NUREG-1432 are integrated into CONDITION A in APR1400.

Both CONDITIONS B & E which have similar purpose are integrated into CONDITION C in the APR1400. There is no difference between NUREG-1432 and the APR1400 except for the extension of applicable modes.

IRWST water volume is used in the applicable safety analyses and the condition for IRWST volume is considered as an operability condition as specified in the BASES of CONDITION D in 3.5.4 of NUREG-1432. This is CONDITION B in APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 19G Due to the extension of the applicable modes, a CONDITION for these modes is added as CONDITION D.

The REQUIRED ACTION of the APR1400 TS is a conservative approach. There is no difference between NUREG-1432 and the APR1400 because the REQUIRED ACTION B.1, E.1 AND E.2 for CONDITION A and C or D in NUREG-1432 are integrated into the CONDITION A or C not met for the APR1400.

Due to the extension of the applicable modes, REQUIRED ACTIONs for the modes are added.

The NOTE is not necessary for APR1400 since the IRWST is located in reactor containment building and is not affected by changing of the ambient air temperature.

Due to the integrations of the CONDITIONS, related REQUIRED ACTIONs and COMPLETION TIMEs are changed.

G G

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 20G 4

Electrical power systems 4.1 Major Design Features 4.1.1 AC Electric Power Distribution System The AC electric power distribution system consists of the transmission system, the plant switchyard, main transformer (MT), two unit auxiliary transformers (UATs), two standby auxiliary transformers (SATs), a main generator (MG), a generator circuit breaker (GCB), isolated phase bus, switchgears, load centers (LCs), and motor control centers (MCCs). The electric power distribution system also includes the power, control, instrumentation cables and raceways, and electrical protection devices, such as circuit breakers and fuses.

The Class 1E AC electric power distribution system consists of two independent, redundant divisions. Each division consists of two independent trains.

Four emergency diesel generators (EDGs) provide Class 1E power to the four independent Class 1E trains respectively, during a LOOP or a LOOP concurrent with a DBA. One AC generator provides power to the permanent non-safety buses during a LOOP or to one Class 1E train during a SBO.

During plant normal operation, the MG supplies power through the GCB and MT to the transmission system, and to the UATs. When the GCB is open, power is backed from the transmission system through the MT to the UATs. In the event of a loss of preferred power supply through the UATs, medium voltage (non-Class 1E 13.8 kV and Class 1E & non-Class 1E 4.16 kV) buses are powered from the SATs after performing an automatic bus transfer from the normal offsite preferred power supply to the alternate offsite preferred power supply.

4.1.2 DC Power System The Class 1E 125 Vdc system consists of four independent subsystems, trains A, B, C, and D, each corresponding to one of the four reactor protection instrumentation channels A, B, C, and D. The non-Class 1E DC power system is also comprised of two separate subsystems, divisions I and II.

Each Class 1E and non-Class 1E DC power system is provided with its own battery, two battery chargers (normal and standby), a DC control center, and DC distribution panels. The Class 1E DC

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 21G power system supplies reliable continuous power to the plant safety system DC loads and the Class 1E I&C system.

4.1.3 Instrumentation and Control Power System The instrumentation and control (I&C) power system consists of Class 1E and non-Class 1E power systems. The Class 1E 120 Vac I&C power system is separated into four subsystems, trains A, B, C, and D that supply power to the plant protection system channels A, B, C, and D. The Class 1E I&C power system includes four separate and independent 120 Vac power distribution panel, and each system is powered from a 125 Vdc control center via a 125 Vdc/120 Vac static inverter.

4.2 Major differences and justifications 4.2.1 The APR1400 adopts four EDGs (two redundant and independent divisions I and II, but four independent trains A, B, C, and D). Each division of EDGs provides Class 1E power to its respective Class 1E redundant loads. For each EDG, one automatic load sequencer is provided.

The unavailability of either one or two EDGs on one division disables one load group to perform its partial or all of the safety functions.

Because of the divisional approach of the four EDGs in the APR1400 design, the condition with three or more AC sources inoperable is divided into two different cases.

This deviation is related to APR1400 TS LCOs 3.8.1 and 3.8.2.

4.2.2 The term "Train A" and Train B used in NUREG-1432 is replaced by "Division I" and Division II in APR1400. Between divisions, independence and redundancy are maintained.

For DC systems, the term subsystem(s) used in NUREG-1432 is replaced by Division(s) in APR1400.

This deviation is related to APR1400 TS LCOs 3.8.1, 3.8.2, 3.8.4, 3.8.5, 3.8.6, 3.8.7 and 3.8.9.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 22G These changes are not included in Table III-1.

4.2.3 For the following LCOs and SRs, the specific values of the STS enclosed in brackets are changed to APR1400 design values.

- SR 3.8.1.4, 3.8.1.7, 3.8.1.11, 3.8.1.12, 3.8.1.15, 3.8.1.19, 3.8.1.20, 3.8.3.4 and 3.8.4.2

- LCO 3.8.3 5

Refueling Operation 5.1 Major Design Features The shutdown cooling system (SCS) is a safety-related system that is used to reduce the temperature of the reactor coolant system (RCS) in post shutdown periods from the hot shutdown operating temperature to the refueling temperature. The initial phase of a cooldown is accomplished by heat rejection from the steam generators (SGs) to the condenser or atmosphere.

After the reactor coolant temperature and pressure have been reduced to approximately 176.7°C (350°F) and 31.6 kg/cm2A (450 psia), the SCS is put into operation for normal shutdown cooling to reduce the RCS temperature to the refueling temperature, and to maintain this temperature during refueling.

Additionally, the SCS is used in conjunction with the main steam atmospheric dump valves (MSADVs) and the auxiliary feedwater system to cooldown the RCS following a small break loss of coolant accident (LOCA). The SCS is also used subsequent to steam and feedwater line breaks, steam generator tube ruptures, and is used during plant startup prior to RCP restart to maintain flow through the core. After an accident, the SCS can be put into operation when the RCS temperature and pressure are below approximately 193.3°C (380°F) and 28.1 kg/cm2A (400 psia), respectively.

The plant refueling cavity is equipped with devices that monitor the level of the refueling water in the refueling cavity. If the monitoring devices detect an inappropriate decrease in the level of refueling water during the refueling operation, the operator in the main control room (MCR) is alerted, and the operator takes immediate action to prevent water leakage.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 23G 5.2 Major differences and justifications 5.2.1 RCS Loops - MODE 5 A CSP can be realigned to be used as a Shutdown Cooling Pump (SCP) because the SCPs and CSPs are interchangeable.

This deviation is related to APR1400 TS LCOs 3.4.7 and 3.4.8.

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UHOLHIYDOYHVLVQRWUHTXLUHG7KHUHIRUHWKH127(IRUELVGHOHWHGG 5.2.3 Shutdown Cooling (SDC) and Coolant Circulation - Low Water Level (LCO 3.9.5)

CSP can be realigned to be used as SCP because SCP and CSP are interchangeable. CSP operability during reduced inventory operation is required.

G 5.2.4 Refueling Water Level (LCO 3.9.6)

The recently irradiated fuel assemblies in NUREG-1432 are included in the irradiated fuel assemblies described in APR1400. The REQUIRED ACTION is added to exit the LCO condition.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 24G 6

Containment System 6.1 Major Design Features The CS System (CSS) reduces containment pressure and temperature and removes fission products from the containment atmosphere following a DBA, and has two independent divisions including two containment spray (CS) pumps, two CS heat exchangers, two CS mini-flow heat exchangers, two independent spray headers, associated piping, valves, and instrumentation. The spray flow is provided by the CSPs, which start on the receipt of a safety injection actuation signal (SIAS) or containment spray actuation signal (CSAS), and take suction from the IRWST. The CSPs discharge through the CSHXs and the spray header isolation valves to their respective spray nozzle headers and then into the containment atmosphere. Spray flow to the CS nozzle headers is not provided until a CSAS automatically opens the containment spray header isolation valves.

6.2 Major differences and justifications 6.2.1 Containment Spray and Cooling System (LCO 3.6.6)

In APR1400, a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time applies for one containment spray division inoperable instead of the 7 day Completion Time in NUREG-1432, because APR1400 does not adopt CE NPSD-1045-A and does not meet the requirements of the Topical Report and the associated Safety Evaluation.

6.2.2 Spray Additive System (LCO 3.6.7)

Since post-accident pH control of the sprayed fluid is provided using trisodium phosphate (TSP),

which is stored in the holdup volume tank (HVT), the Spray Additive System is not applied to APR1400.

6.2.3 Hydrogen Mixing System (HMS) (LCO 3.6.9)

Since hydrogen mixing is accomplished by the Containment Spray System, the Hydrogen Mixing System is not applied to APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 25G 6.2.4 Iodine Cleanup System (ICS) (LCO 3.6.10)

The removal of fission products (e.g. iodine) is accomplished by the Containment Spray System.

Therefore, the Iodine Cleanup System is not applied to APR1400.

7 Plant System 7.1 Major Design Features 7.1.1 Component Cooling Water System The Component Cooling Water System (CCWS) consists of two safety-related divisions that are separate, independent, redundant, and closed-loop. Either division of the CCWS is capable of supporting 100 percent of the cooling requirements of a safe shutdown following a postulated accident coincident with LOOP. Each CCWS division includes three CCW heat exchangers, a CCW surge tank, two CCW pumps, a CCW chemical addition tank, and CCW radiation monitor, piping, valves, controls, and instrumentations. The CCWS provides cooling water to the essential (safety Class 3) and nonessential (non-nuclear safety class) components.

7.1.2 Essential Service Water System The Essential Service Water System (ESWS) consists of two independent, redundant, once-through, safety-related divisions. Each division of the ESWS consists of two pumps, three debris filters, and associated piping, valves, controls, and instrumentations. The ESW pumps take suction from the ultimate heat sink (UHS) basin, circulate cooling water through the CCW heat exchangers, and return cooling water back to the UHS.

7.1.3 Ultimate Heat Sink (UHS)

The function of the UHS is to dissipate the heat rejected from the ESWS during all modes of operation including accident conditions. The UHS is a site-specific system that interfaces with the ESWS. Based on the conceptual design, the UHS consists of two independent, redundant, safety-related divisions. Each division consists of two 100 percent capacity UHS cooling towers, one common UHS cooling tower basin, piping, valves, controls and instrumentation.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2G KEPCO & KHNP 26G 7.1.4 Spent Fuel Pool The Spent Fuel Pool (SFP) is approximately 7.31 m (42 ft) deep and made of reinforced concrete lined with stainless steel plate. The SFP is sufficiently deep that when a spent fuel assembly is being carried over the spent fuel storage racks by the spent fuel handling machine (SFHM) at its maximum lift height, there is sufficient water coverage to provide reasonable assurance that personnel on the SFHM or on the operating floor around the pool are not exposed to radiation levels exceeding 0.025 mSv (0.0025 rem) per hour. Two safety-related SFP water level transmitters are installed in the SFP to measure the SFP water level from a 100 percent water level to the top level of the spent fuel assemblies. The SFP water level transmitters annunciate high water level, low water level, and low-low water level of the SFP to the MCR, RSR, and locally. The SFP is initially filled with water that has a boron concentration range of 4,000 to 4,400 ppm. The SFP receives normal borated makeup water from the boric acid storage tank (BAST) or from the boric acid makeup pump (BAMP). The SFP boron concentration is checked at local sample points. Local sample connections are provided in the spent fuel pool cooling and cleanup system (SFPCCS) purification return line to check the effectiveness of the filter and the demineralizer or one of them, as well as the boron concentration.

7.2 Major differences and justifications 7.2.1 Ultimate Heat Sink (UHS) (LCO 3.7.9)

Based on the conceptual design, the APR1400 UHS consists of two independent, redundant, safety-related divisions. Each division consists of two 100 percent capacity cooling towers.

CONDITION B of APR1400 is described comprehensively to include CONDITION B, C, and D of NUREG-1432.

G

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 27 Table III-1 Deviations and Justification between Standard Technical Specifications and the APR1400 Technical Specifications Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 1.0 USE AND APPLICATION 1.1 Definitions None CORE ALTERATION See II.2.1 DOSE EQUIVALENT I-131 DOSE EQUIVALENT I-131 Modified See II.2.2

-AVERAGE DISINTEGRATION ENERGY DOSE EQUIVALENT XE-133 See II.2.2 CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY and the CHANNEL FUNCTIONAL TEST.

Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, and trip functions, and shall include the CHANNEL FUNCTIONAL TEST.

Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an in-place cross calibration of the sensing elements and normal calibration of the remaining adjustable devices in the channel. Whenever a sensing element is replaced, the next required in-place cross calibration consists of comparing the other sensing elements with the recently installed sensing element. The CHANNEL CALIBRATION may be performed by means of any series

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 28 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark of sequential, overlapping, or total channel steps so that the entire channel is calibrated.

CHANNEL FUNCTIONAL TEST

a. Analog and bistable channels -

the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY of all devices in the channel required for channel OPERABILITY, and

b. Digital computer channels - the use of diagnostic programs to test digital computer hardware and the injection of simulated process data into the channel to verify OPERABILITY of all devices in the channel required for channel OPERABILITY.

The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps.

CHANNEL FUNCTIONAL TEST

a. Analog and bistable logic channels - the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarms, interlocks, display and trip functions.

b. Digital computer channels - the use of diagnostic programs to test digital computer hardware and the injection of simulated process data into the channel to verify OPERABILITY, including alarms and trip functions.

The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

ENGINEERED SAFETY FEATURE (ESF) RESPONSE TIME The ESF RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, ENGINEERED SAFETY FEATURE (ESF) RESPONSE TIME The ESF RESPONSE TIME shall be the time interval from when the monitored parameter exceeds its ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions,

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 29 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

pump discharge pressures reach their required values, etc.). Times shall include emergency diesel generator starting and sequence loading delays, where applicable.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, reactor coolant cold leg temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in reactor vessel.

Changed from average reactor coolant temperature to reactor coolant cold leg temperature

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 30 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark OPERABLE - OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

OPERABLE - OPERABILITY A system, subsystem, division, train, component or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, train, component, or device to perform its specified function(s) are also capable of performing their related support function(s).

See II.2.3 Response to RAI No. 130-8065 Question 16-30 (Revision 1) committed to add to deviation report and to provide further explanation.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 31 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REACTOR PROTECTION SYSTEM (RPS) RESPONSE TIME The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until electrical power to the CEAs drive mechanism is interrupted. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

REACTOR PROTECTION SYSTEM (RPS) RESPONSE TIME The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the input to the channel sensor until electrical power to the CEAs drive mechanism is interrupted. The response time may be measured by means of any series of sequential, overlapping, or total steps so the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

APR1400 has no methodology for response time verification without measurement.

Table 1.1-1 AVERAGE REACTOR COOLANT TEMPERATURE (°F)

> [200]

Table 1.1-1 REACTOR COOLANT COLD LEG TEMPERATURES

> 99°C (210°F) 99°C (210°F)

See II.3.1 1.2 Logical Connectors Same as NUREG-1432 1.3 Completion Times Same as NUREG-1432 1.4 Frequency Same as NUREG-1432 2.0 SAFETY LIMITS 2.1 SLs 2.1.1.1 In MODES 1 and 2, departure from nucleate 2.1.1.1 In MODES 1 and 2, departure from nucleate

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 32 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark boiling ratio (DNBR) shall be maintained at [1.19].

boiling ratio (DNBR) shall be maintained 1.29.

2.1.1.2 In MODES 1 and 2, the peak fuel centerline temperature shall be maintained at < [5080]°F, decreasing by [58°F per 10,000 MWD/MTU] and adjusted for burnable poison per [CENPD-275-P, Revision 1-P-A or CENPD-382-P-A].

2.1.1.2 In MODES 1 and 2Gthe peak fuel centerline temperature shall be maintained at

< 2,804.4°C (5,080°F),

decreasing by 32.2°C (58°F) per 10,000 MWD/MTU for burnup and adjusted for burnable poison per CENPD-275-P, Revision 1-P-A.

Ref. CENPD-382-P-A is related to Erbium BA. Only Gd BA is considered in APR1400.

2.2 SL Violations Same as NUREG-1432 3.0 LIMITING CONDITIONS FOR OPERATION APPLICABILITY LCO 3.0.1 Same as NUREG-1432 LCO 3.0.2 Same as NUREG-1432 LCO 3.0.3 Same as NUREG-1432 LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time;

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall not be made except when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

Exceptions to this Specification are Risk informed Technical Specification is not applied for APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 33 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

stated in the individual Specifications. These exceptions allow entry into MODES or other specified conditions in the Applicability when the associated ACTIONS to be entered allow unit operation in the MODE or other specified condition in the Applicability only for a limited period of time.

LCO 3.0.4 is only applicable for entry into a MODE or other specified condition in the Applicability in MODES 1, 2, 3, and 4.

LCO 3.0.5 Same as NUREG-1432 LCO 3.0.6 Same as NUREG-1432 LCO 3.0.7 Same as NUREG-1432 LCO 3.0.8 Same as NUREG-1432 LCO 3.0.9 Same as NUREG-1432 3.0 SURVEILLANCE REQUIREMENT APPLICABILITY SR 3.0.1 Same as NUREG-1432 SR 3.0.2 Same as NUREG-1432 SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is less. This delay period is

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 34 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark period is permitted to allow performance of the Surveillance.

A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

permitted to allow performance of the Surveillance.

SR 3.0.4 None SR 3.0.4 is only applicable for entry into a MODE or other specified condition in the Applicability in MODES 1, 2, 3, and 4.

SR 3.0.4 is only applicable for MODE change.

3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be within the limits specified in the COLR.

LCO 3.1.1

a. SDM shall be within the limits specified in the CORE OPERATING LIMITS REPORT (COLR).

b. k effective assuming the inserted control element assembly (CEA) of the highest worth is fully withdrawn (kN-1) shall be < 0.99.

c. With reactor trip circuit breakers (RTCBs) closed: Reactor criticality shall not be achieved with shutdown group CEAs movement.

The SDM specifications according to RTCB condition reflect the assumptions of the safety analyses.

The function of kN-1 is to maintain sufficient subcriticality to preclude inadvertent criticality following ejection of a single control element assembly.

The requirement prohibiting criticality due to shutdown group CEA movement is associated with the assumptions used in the analysis of uncontrolled CEA withdrawal from subcritical condition. Due to the high differential reactivity worth of the shutdown CEA groups, the analysis assumes that the initial shutdown reactivity is such that the reactor will remain subcritical in the event of unexpected or uncontrolled shutdown group withdrawal.

Related CONDITION (with associated REQUIRED ACTION and COMPLETION TIME) and related SURVEILLANCE (and FREQUENCY) are added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 35 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.1.2 Reactivity Balance REQUIRED ACTION A.2 Establish appropriate operating restrictions and SRs.

REQUIRED ACTION A.2 Establish appropriate operating restrictions and SRs for continued operation.

3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR, and a maximum positive limit as specified below:

a. [0.5 E-4 k/k/°F] when THERMAL POWER is 70%

RTP and

b. [0.0 k/k/°F] when THERMAL POWER is > 70% RTP.

LCO 3.1.3 The MTC shall be maintained within the lower limit specified in the CORE OPERATING LIMITS REPORT (COLR) and the upper limit that varies linearly from 0.9E-4 k/k/°C (0.5E-4 k/k/°F) at 0%

RTP to 0.0 k/k/°C (0.0 k/k/°F) at 100% RTP.

See II.4 The actual value of the MTC is dependent on core characteristics such as fuel loading and reactor coolant soluble boron concentrations.

Since positive MTC limits assumed in the safety analysis are not to be challenged or must be met using burnable absorbers for both initial and the reload cores, thus, those are not classified as COLR item in APR1400.

SURVEILLANCE SR 3.1.3.1 Verify MTC is within the upper limit specified in the COLR.

SR 3.1.3.2

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

If the MTC is more negative than the limit specified in the COLR when extrapolated to the end of cycle, SR 3.1.3.2 may be repeated.

Shutdown must occur prior to exceeding the minimum allowable boron concentration at which MTC is projected to exceed the lower limit.

SURVEILLANCE SR 3.1.3.1 Verify MTC is within the upper limit specified in LCO 3.1.3.

SR 3.1.3.2

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

If the MTC is more negative than the COLR limit when extrapolated to the end of cycle, SR 3.1.3.2 may be repeated. Shutdown must occur prior to exceeding the minimum allowable boron concentration at which MTC is projected to exceed the lower limit.

Verify MTC is within the lower See II.4

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 36 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Verify MTC is within the lower limit specified in the COLR.

limit specified in the COLR.

3.1.4 Control Element Assembly Alignment (CEA)

SURVEILLANCE SR 3.1.4.5 Verify each full length CEA drop time [3.5] seconds and the arithmetic average of all full length CEA drop times [3.2] seconds.

SURVEILLANCE SR 3.1.4.5 Verify each full strength CEA drop time from the fully withdrawn position to the 90% insertion position is 4 seconds.

This SR confirms the required CEA drop time assumed in the safety analysis. This CEA drop time is in Figure 4.2-14 of DCD Tier 2.

Figure 3.1.4-1 Specified in COLR

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

When core power is reduced to 60% RTP per this limit curve.

Figure 3.1.4-1 Specified in TS

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

When core power is reduced to 55% RTP per this limit curve.

See II.4 Figure 3.1.4-1 (NUREG-1432) is treated as a non-COLR item in APR1400.

It is not a cycle-dependent item.

Each power plant has a different core power level which requires no further reduction with respect to CEA deviation. The power level depends upon which power level the initial thermal margin is secured to compensate for the thermal margin decrement caused by the long-term xenon redistribution after the operators intervention to counteract the CEA deviation.

For the case of the APR1400 plant, when core power is below 55% RTP, initial thermal margin can encompass the thermal margin decrement by xenon redistribution after the CEA deviation. Further power

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 37 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark reduction is not required when core power is reduced to 55%

RTP.

3.1.5 Shutdown Control Element Assembly (CEA) Insertion Limits FREQUENCY SR 3.1.5.1 None FREQUENCY SR 3.1.5.1

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

SR 3.1.5.1 shall be performed within 15 minutes prior to withdrawal of any CEAs in regulating groups during an approach to reactor criticality.

A NOTE is added to assure that required SDM is maintained by verifying each shutdown CEA is withdrawn greater than or equal to 367.7 cm (144.75 in) (SR 3.1.5.1) within 15 minutes prior to withdrawal of any CEA in regulating groups during an approach to reactor criticality.

3.1.6 Regulating Control Element Assembly (CEA) Insertion Limits LCO 3.1.6

b. With COLSS out of service, the regulating CEA groups shall be limited to the short term steady state insertion limit and associated time restraints specified in the COLR.

LCO 3.1.6

b. With COLSS out of service, the regulating CEA groups shall be limited to the withdrawal sequence, insertion limits, and associated time restraints specified in the COLR.

The withdrawal sequence should be maintained with COLSS out of service, as well as with COLSS in service.

SURVEILLANCE SR 3.1.6.1

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entry into MODE 2.

SURVEILLANCE SR 3.1.6.1

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

Not required to be performed prior to entry into MODE 2.

The time frame, prior to entry into MODE 2 is determined by considering more restrictive operational strategy, based on the STS. That is, this SR requires the surveillance right after entry into MODE 2.

Therefore, from the safety point of view, it is judged that there is no deviation from the STS.

3.1.7 Part Length Control Element Assembly (CEA)

Insertion Limits CONDITION A. Part length CEA groups inserted beyond the transient insertion limit.

CONDITION None The CONDITION is not needed for APR1400 since the transient insertion of part strength CEAs is not restricted up to the full insertion in APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 38 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE None SURVEILLANCE SR 3.1.7.2 Verify the accumulated times during which the part strength CEA groups are inserted beyond the long term steady state insertion limit.

The surveillance requirement for the verification of the accumulated time beyond the long term steady state insertion limits is added to be consistent with CONDITION A of ACTIONS.

Related FREQUENCY is added.

Addition

- Charging Flow None LCO 3.1.8 Charging flow shall be maintained below 581.4 L/min (180 gpm).

APPLICABILITY MODES 1, 2, 3, 4, and 5 Charging flow restriction during MODES 1,2,3,4 and 5 is an assumption of initial condition for safety analysis as described in the APR1400 DCD Tier 2, Section 15.4.6.

Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

3.1.8 Special Test Exceptions (STE)

- SHUTDOWN MARGIN (SDM)

LCO 3.1.8 During performance of PHYSICS TESTS, the requirements of:

LCO 3.1.9 During performance of criticality test or measurement of control element assembly (CEA) worth and SDM, the requirements of:

RPS bypass setpoint change was determined as a STE during a previous plant startup test.

RPS bypass setpoint changes need to prevent unnecessary reactor trip by RPS during criticality test. The criticality test and related SR are added.

None LCO 3.3.1, Reactor Protection System (RPS) Instrumentation -

Operating(Only applied to Trip Functions 2, 14, and 15 in Table 3.3.1-1); and The STE for LCO 3.3.1 for RPS Instrumentation is added.

None LCO 3.3.2, Reactor Protection System (RPS) Instrumentation -

Shutdown (Only applied to Trip Function 1 in Table 3.3.2-1)

The STE for LCO 3.3.2 for RPS Instrumentation is added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 39 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark may be suspended for measurement of CEA worth, provided shutdown reactivity equivalent to at least the highest estimated CEA worth (of those CEAs actually withdrawn) is available for trip insertion.

may be suspended, provided shutdown reactivity equivalent to at least the highest estimated CEA worth (of those CEAs actually withdrawn) is available for trip insertion or the reactor is subcritical by at least the reactivity equivalent of the highest CEA worth.

The last sentence after or is added due to criticality test and dynamic rod worth measurement.

SURVEILLANCE None SURVEILLANCE SR 3.1.9.3

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

Applicable to operation in MODE 3 only.

Verify that when all full strength CEAs are fully inserted, the reactor is subcritical by more than the above required shutdown reactivity equivalent.

SR 3.1.9.3 is added due to the criticality test.

None SR 3.1.9.4 Perform CHANNEL FUNCTIONAL TESTS of each logarithmic and variable overpower neutron flux monitoring channel.

SR 3.1.9.4 is added due to the application of STE for RPS Instrumentation LCO 3.3.1 and 3.3.2.

3.1.9 Special Test Exceptions (STE)

- MODES 1 and 2 (Digital)

LCO 3.1.9 None LCO 3.1.10 LCO 3.2.5, AXIAL SHAPE INDEX (ASI)

The STE for LCO 3.2.5 of ASI is added for initial startup test.

(ex. CPC power distribution test)

Addition

- Special Test Exceptions (STE) -

Reactivity Coefficient Testing None LCO 3.1.11 During performance of PHYSICS TESTS, the requirements of:

LCO 3.1.6, Regulating Control Element Assembly (CEA)

Insertion Limits; LCO 3.1.7, Part Strength CEA The STE for LCO 3.1.7 and LCO 3.1.8 are added for initial core startup test.

The LCO for cold leg temperature is narrow for Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 40 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Insertion Limits; and LCO 3.4.1, RCS Pressure, Temperature and Flow limits (LCOs 3.4.1.b and 3.4.1.c, RCS Cold Leg Temperature only).

may be suspended, provided Linear Heat Rate (LHR) and Departure from Nucleate Boiling Ratio (DNBR) do not exceed the limits specified in:

LCO 3.2.1, Linear Heat Rate (LHR); and LCO 3.2.4, Departure from Nucleate Boiling Ratio (DNBR).

APPLICABILITY MODE 1 with THERMAL POWER

> 20% Rated THERMAL POWER (RTP).

ACTIONS CONDITION A. LHR or DNBR not within limits.

B. Required Action and associated Completion Time not met.

REQUIRED ACTION A.1 Reduce THERMAL POWER to restore LHR and DNBR to within limits.

B.1 Suspend PHYSICS TESTS.

APR1400, so the LCO 3.4.1.b may be suspended.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 41 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark COMPLETION TIME 15 minutes 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SURVEILLANCE SR 3.1.11.1

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

Only required to be performed when Core Operating Limits Supervisory System (COLSS) is out of service. With COLSS in service, LHR is continuously monitored.

Verify LHR, as indicated on any OPERABLE Core Protection Calculator local power density channel, is within the limit specified in the CORE OPERATING LIMITS REPORT (COLR).

SR 3.1.11.2

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

Only required to be performed when COLSS is out of service.

With COLSS in service, DNBR is continuously monitored.

Verify DNBR, as indicated on any OPERABLE Core Protection Calculator DNBR channel, is within the limits of Figure 3.2.4-2 or Figure 3.2.4-3 of the COLR, as applicable.

FREQUENCY

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 42 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 15 minutes 15 minutes Addition

- Unborated Water Source Isolation Valve - MODES 4 and 5 None LCO 3.1.12 The CV-186 valve used to isolate unborated water sources shall be secured in the closed position.

APPLICABILITY MODES 4 and 5 with all RCPs idle.

ACTIONS CONDITION A. Valve not secured in closed position.

REQUIRED ACTION A.1 Suspend all operations involving positive reactivity changes AND A.2 Initiate actions to secure valve in closed position.

AND A.3 Perform SDM verification in accordance with SR 3.1.1.1.

COMPLETION TIME Immediately Immediately 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 43 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.12.1 Verify the valve that isolates unborated water sources is secured in the closed position.

FREQUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Linear Heat Rate (LHR)

CONDITION B. LHR not within region of acceptable operation when the COLSS is out of service.

CONDITION B. One OPERABLE core protection calculator (CPC) calculated LHR not within region of acceptable operation when the COLSS is out of service.

Additional description is inserted to clarify the condition for the LHR. If the COLSS is not available the OPERABLE LPD channels are monitored to ensure that the LHR limit is not exceeded.

SURVEILLANCE SR 3.2.1.1 Verify LHR, as indicated on each OPERABLE local power density channel, is within its limit.

SURVEILLANCE SR 3.2.1.1 Verify LHR, as indicated on any OPERABLE local power density channel, is within its limit.

SR 3.2.1.1 is revised from each to any for clarification.

3.2.2 Planar Radial Peaking Factors (Fxy)

FREQUENCY SR 3.2.2.1 Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70%

RTP

FREQUENCY SR 3.2.2.1 Once after each fuel loading with THERMAL POWER > 40 % RTP but prior to operations above 80 %

RTPG Power ascension test plateaus for the verification of the planar radial peaking factors are 20, 50, 80, and 100% for APR1400.G 3.2.3 Azimuthal Power Tilt (Tq)

REQUIRED ACTION B.2 Reduce Linear Power Level

- High trip setpoints to 55% RTP.

REQUIRED ACTION B.2 Reduce variable overpower trip (VOPT) setpoints to 55% RTP.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 44 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE SR 3.2.3.1

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

Only required to be met when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.

SURVEILLANCE SR 3.2.3.1

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

Only applicable when Core Operating Limits Supervisory System (COLSS) is out of service.

With COLSS in service, this parameter is continuously monitored.

3.2.4 Departure From Nucleate Boiling Ratio (DNBR)

LCO 3.2.4

a. Maintaining Core Operating Limit Supervisory System (COLSS) calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR (when COLSS is in service, and either one or both control element assembly calculators (CEACs) are OPERABLE),

b. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR decreased by the allowance specified in the COLR (when COLSS is in-service and neither CEAC is OPERABLE)

LCO 3.2.4

a. Core Operating Limit Supervisory System (COLSS) In Service:

1. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR when at least one control element assembly calculator (CEAC) is OPERABLE in each OPERABLE core protection calculator (CPC) channel; or

2. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR decreased by the allowance specified in Figure 3.2.4-1 of the CORE OPERATING LIMITS REPORT (COLR) when the CEAC requirements of LCO 3.2.4.a.1 are not met.

COLSS calculated core power operating limit is specified as a function of thermal power in Figure 3.2.4-1 for APR1400.

Thus, figure index is increased compared to NUREG-1432.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 45 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

c. Operating within the region of acceptable operation of Figure 3.2.4-1 specified in the COLR using any operable core protection calculator (CPC) channel (when COLSS is out of service and either one or both CEACs are OPERABLE),

or

b. COLSS Out of Service:

1. Operating within the region of acceptable operation of Figure 3.2.4-2 specified in the COLR using any OPERABLE CPC channel when at least one CEAC is OPERABLE in each OPERABLE CPC channel; or

d. Operating within the region of acceptable operation of Figure 3.2.4-2 specified in the COLR using any operable CPC channel (when COLSS is out of service and neither CEAC is OPERABLE).

2. Operating within the region of acceptable operation of Figure 3.2.4-3 specified in the COLR using any OPERABLE CPC channel (with both CEACs inoperable) when the CEAC requirements of LCO 3.2.4.b.1 are not met.

SURVEILLANCE SR 3.2.4.1 Verify DNBR, as indicated on all OPERABLE DNBR channels, is within the limit of Figure 3.2.4-1 or 3.2.4-2 of the COLR, as applicable.

SURVEILLANCE SR 3.2.4.1 Verify DNBR, as indicated on any OPERABLE DNBR channel, is within the limit of Figure 3.2.4-2 or 3.2.4-3 of the COLR, as applicable.

COLSS calculated core power operating limit is specified as a function of thermal power in Figure 3.2.4-1 for APR1400.

Thus, figure index is increased compared to NUREG-1432.

3.3 INSTRUMENTATION 3.3.1 Reactor Protective System (RPS)

Instrumentation -

Operating LCO 3.3.1 Four RPS trip and bypass removal channels for each Function in Table 3.3.1-1 shall be OPERABLE.

LCO 3.3.1 Four RPS trip and automatic operating bypass removal channels for each Function in Table 3.3.1-1 shall be OPERABLE.

The LCO is changed to clarify the bypass function and clarify the meaning of the bypass removal.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 46 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark CONDITION C. One or more Functions with one automatic bypass removal channel inoperable.

REQUIRED ACTION C.1 Disable bypass channel.

C.2.2 Restore bypass removal channel and associated automatic trip channel to OPERABLE status.

CONDITION C.GOne or more Functions with one automatic operating bypass removal channel inoperable.

REQUIRED ACTION C.1 Disable affected bypass channel.

C.2.2 Restore automatic operating bypass removal channel and associated automatic trip channel to OPERABLE status.

The Condition and Required Action are changed to clarify the bypass function and clarify the meaning of the bypass removal.

CONDITION D. One or more Functions with two automatic bypass removal channels inoperable.

REQUIRED ACTION D.1 Disable bypass channels.

CONDITION One or more Functions with two automatic operating bypass removal channels inoperable.

REQUIRED ACTION D.1 Disable affected bypass channels.

CONDITION E. One or more core protection calculator (CPC) channels with a cabinet high temperature alarm.

None Due to the platform change, channel function test is not performed in APR1400, when high temperature alarm of CPC is generated. The Common-Q platform has the compensation feature for temperature changes.

For example, the analog module which is used in APR1400 has auto-calibration features against the temperature changes. Even if the high temperature alarm occurs, the system in the CPCS is able to perform its safety functions.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 47 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark F. One or more CPC channels with three or more autorestarts during a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months period.

None Due to the platform change, there is no auto restart function in APR 1400. If processor has severe failure, the processor will be shut down and this will initiate the watchdog timer to generate the DNBR and LPD trips.

Instead of the check for auto restart, the CPC System Event Log is checked every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to monitor the CPCS channel performance.

G. Required Action and associated Completion Time not met.

E. Required Action and associated Completion Time not met.

SURVEILLANCE SR 3.3.1.1 Perform a CHANNEL CHECK of each RPS instrument channel except Loss of Load.

SURVEILLANCE SR 3.3.1.1 Perform CHANNEL CHECK of each RPS instrument channel.

See III.1.2.1 The function is not contained in DCD Tier 2, Table 7.2-4, Reactor Protective System Design Input.

Tier 2, Table 7.2-4 SR 3.3.1.2

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 70% RTP.

SR 3.3.1.2

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 80% RATED THERMAL POWER (RTP).

THERMAL POWER for heat balance calibration is considered.

SR 3.3.1.3 Check the CPC auto restart count.

SR 3.3.1.3 Check CPC System event log.

Due to the platform change, there is no auto restart function in APR1400. Instead of the check for auto restart, the CPC System Event Log is checked every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to monitor the CPCS channel performance.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 48 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SR 3.3.1.4

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

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 20% RTP.

2. The daily calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.

Perform calibration (heat balance only) and adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC T power and CPC nuclear power calculations agree with the calorimetric, if the absolute difference is [2]%.

SR 3.3.1.4

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

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 15% RTP.

2. The daily power calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.

Perform the daily power calibration by calculating the core THERMAL POWER from the daily secondary heat balance measurement (a calorimetric) and adjusting the linear power, CPC T power, and CPC neutron flux power channels to agree with the calculated THERMAL POWER if any channel indicated more than 0.5% RTP less than the calculated THERMAL POWER.

The SR is changed to clarify the meaning, considering operability and safety.

SR 3.3.1.5

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 70% RTP.

SR 3.3.1.5

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER 80% RTP.

THERMAL POWER for heat balance calibration is considered.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 49 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SR 3.3.1.7

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

2. Not required to be performed for logarithmic power level channels until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reducing logarithmic power below 1E-4% and only if reactor trip circuit breakers (RTCBs) are closed.

Perform CHANNEL FUNCTIONAL TEST on each channel except Loss of Load and power range neutron flux in accordance with the Setpoint Control Program.

SR 3.3.1.7

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

2. Not required to be performed for Logarithmic Power Level - High until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reducing logarithmic power below 1E-3%

and only if reactor trip circuit breakers (RTCBs) are open.

Perform CHANNEL FUNCTIONAL TEST for each RPS instrumentation channel in accordance with the Setpoint Control Program.

See III.1.2.3 See III.1.2.1 The function is not contained in DCD Tier 2, Table 7.2-4, Reactor Protective System Design Input.

Tier 2, Table 7.2-1 Tier 2, Table 7.2-4 SR 3.3.1.8

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

Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION of the power range neutron flux channels in accordance with the Setpoint Control Program.

SR 3.3.1.8

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

Excore neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION of linear power of excore neutron flux channel in accordance with Setpoint Control Program.

SR 3.3.1.9

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

[ Not required to be performed until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after THERMAL POWER 55% RTP.

Perform CHANNEL FUNCTIONAL TEST for Loss of Load Function in accordance with the Setpoint None

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 50 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Control Program.

SR 3.3.1.10

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

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION on each channel, including bypass removal functions in accordance with Setpoint Control Program.

SR 3.3.1.9

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

Excore neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION on each trip channel, including automatic operating bypass removal functions in accordance with Setpoint Control Program.

SR 3.3.1.11 SR 3.3.1.10 SR 3.3.1.12 Using the incore detectors, verify the shape annealing matrix elements to be used by the CPCs SR 3.3.1.11 Using incore detectors, verify shape annealing matrix elements to be used by the CPCs in accordance with Setpoint Control Program.

SR 3.3.1.13 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.

SR 3.3.1.12 Perform CHANNEL FUNCTIONAL TEST on each automatic operating bypass removal channel.

SR 3.3.1.14

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

Neutron detectors are excluded.

SR 3.3.1.9

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

Excore neutron detectors are excluded.

Table 3.3.1-1

1. Linear Power Level - High

8. Steam Generator #1 Level - Low Table 3.3.1-1

1. Variable Overpower

8. Steam Generator #1 Water Level

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 51 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

9. Steam Generator #2 Level - Low 10 Reactor Coolant Flow, Steam Generator #1 - Low(c)

11. Reactor Coolant Flow, Steam Generator #2 - Low(c)

12. Loss of Load (turbine stop valve control oil pressure) (d)

13. Local Power Density - High

14. Departure From Nucleate(c)

Boiling Ratio (DNBR) - Low(c)

- Low

9. Steam Generator #2 Water Level

- Low

10. Steam Generator #1 Water Level - High

11. Steam Generator #2 Water Level - High

12. Reactor Coolant Flow, Steam Generator #1 Water Level -

Low

13. Reactor Coolant Flow, Steam Generator #2 Water Level -

Low

14. Local Power Density - High(c)(d)

15. Departure From Nucleate Boiling Ratio (DNBR) -

Low(c)(d)

Table 3.3.1-1 Note (a)

Bypass may be enabled when logarithmic power is > [1E-4]% and shall be capable of automatic removal whenever logarithmic power is > [1E-4]%. Bypass shall be removed prior to reducing logarithmic power to a value

[1E-4]%. Trip may be manually bypassed during physics testing pursuant to LCO 3.4.17, "RCS Loops - Test Exceptions."

Table 3.3.1-1 Note (a)

Trip may be bypassed when logarithmic power is 10E-3%.

Operating bypass shall be automatically removed when logarithmic power is 10E-3%.

Trip may be manually bypassed during PHYSICS TESTS pursuant to LCO 3.1.9, Special Test Exception (STE)

- SHUTDOWN MARGIN (SDM).

See III.1.2.3 LCO 3.1.9 states that trip function 2, Logarithmic Power Level - High, in Table 3.3.1-1 is applied to the special test exception.

Pointers to SURVEILLANCE REQUIREMENTS are updated.

Note (b)

The setpoint may be decreased to Note (b)

Pressurizer Pressure - Low trip See III.1.2.4

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 52 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark a minimum value of [300] psia, as pressurizer pressure is reduced, provided the margin between pressurizer pressure and the setpoint is maintained [400] psi.

Bypass may be enabled when pressurizer pressure is < [500] psia and shall be capable of automatic removal whenever pressurizer pressure is < [500] psia. Bypass shall be removed prior to raising pressurizer pressure to a value

[500] psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

setpoint may be decreased as pressurizer pressure is reduced to 7.0 kg/cm2A (100 psia). The margin between pressurizer pressure and the setpoint shall be maintained at 28.1 kg/cm2A (400 psia). The operating bypass shall be removed automatically at 35.2 kg/cm2A (500 psia). The setpoint shall be increased automatically to the normal setpoint as pressurizer pressure is increased.

Note (c)

Bypass may be enabled when logarithmic power is < [1E-04]%

and shall be capable of automatic removal whenever logarithmic power is < [1E-4]%. Bypass shall be removed prior to raising logarithmic power to a value

[1E-4]%. During testing pursuant to LCO 3.4.17, bypass may be enabled when THERMAL POWER is < [5]% RTP and shall be capable of automatic removal whenever THERMAL POWER is <

[5]% RTP. Bypass shall be removed above 5% RTP.

Note (c)

Trip may be manually bypassed when logarithmic power is

< 1E-4%. Operating bypass shall be automatically removed when THERMAL POWER is 1E-4%.

During testing pursuant to LCO 3.1.9, trip may be bypassed below 5% RTP. Operating bypass shall be automatically removed when logarithmic power is > 5% RTP.

LCO 3.1.9 states that trip function 2, Logarithmic Power Level - High, in Table 3.3.1-1 is applied to the special test exception.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 53 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Note (d)

Bypass may be enabled when THERMAL POWER is < [55]%

RTP and shall be capable of automatic removal whenever THERMAL POWER is < [55]%

RTP. Bypass shall be removed prior to raising THERMAL POWER to a value [55]% RTP.

Note (d)

The OPERABILITY of the Local Power Density - High and DNBR -

Low Functions include the CPC auxiliary trips.

3.3.2 Reactor Protective System (RPS)

Instrumentation -

Shutdown LCO 3.3.2 Four RPS Logarithmic Power Level

- High trip channels and associated instrument and bypass removal channels shall be OPERABLE.

LCO 3.3.2 Four RPS trip and automatic operating bypass removal channels for each Function in Table 3.3.2-1 shall be OPERABLE.

The LCO is changed to reflect the functions listed in Table 3.3.2-1.

APPLICABILITY MODES 3, 4, and 5, with any reactor trip circuit breakers (RTCBs) closed and any control element assembly capable of being withdrawn.

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

Bypass may be enabled when logarithmic power is > [1E-4]% and shall be capable of automatic removal whenever logarithmic power is > [1E-4]%. Bypass shall be removed prior to reducing logarithmic power to a value

[1E-4]%.

APPLICABILITY According to Table 3.3.2-1 Since Table 3.3.2-1 includes corresponding trip functions, applicability modes or other specified conditions, and surveillance requirements, the applicability is simplified.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 54 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark ACTIONS None ACTIONS

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

Separate Condition entry is allowed for each RPS Function.

NOTE is added to clarify the application of the Completion Time rules. The Conditions of this Specification may be entered independently for each function. The Completion Times of each inoperable function will be tracked separately for each function starting from the time the Condition was entered for that function.

CONDITION A. One RPS logarithmic power level trip channel inoperable.

B. Two RPS logarithmic power level trip channels inoperable.

C. One automatic bypass removal channel inoperable.

D. Two automatic bypass removal channels inoperable.

CONDITION A. One or more Functions with one automatic RPS trip channel inoperable.

B. One or more Functions with two automatic RPS trip channels inoperable.

C. One automatic operating bypass removal channel inoperable.

D. Two automatic operating bypass removal channels inoperable.

Trip functions are described in detail as shown in Table 3.3.2-1.

REQUIRED ACTION A.1 Place channel in bypass or trip.

A.2 Restore channel to OPERABLE status.

B.1 Place one channel in bypass and place the other in trip C.1 Disable bypass channel.

REQUIRED ACTION A.1 Place trip channel in bypass or trip.

A.2 Restore trip channel to OPERABLE status.

B.1 Place one trip channel in bypass and the other in trip.

C.1 Disable affected bypass channel.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 55 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark C.2.2 Restore bypass removal channel and associated automatic trip channel to OPERABLE status.

D.1 Disable bypass channels.

C.2.2 Restore automatic operating bypass removal channel and associated automatic trip channel to OPERABLE status.

D.1 Disable affected bypass channels.

SURVEILLANCE None SR 3.3.2.1 Perform a CHANNEL CHECK of each logarithmic power channel.

SR 3.3.2.2 Perform a CHANNEL FUNCTIONAL TEST on each logarithmic power channel in accordance with the Setpoint Control Program.

SR 3.3.2.3 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.

SR 3.3.2.4 Perform a CHANNEL CALIBRATION on each logarithmic power channel, including bypass removal function in accordance SURVEILLANCE

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

Refer to Table 3.3.2-1 to determine which SR shall be performed for each RPS Function.

SR 3.3.2.1 Perform CHANNEL CHECK of each RPS instrument channel.

SR 3.3.2.2 Perform CHANNEL FUNCTIONAL TEST on each RPS trip channel in accordance with Setpoint Control Program.

SR 3.3.2.3 Perform CHANNEL FUNCTIONAL TEST on each automatic operating bypass removal function.

SR 3.3.2.4 Perform CHANNEL CALIBRATION on each RPS trip channel, including automatic operating bypass removal function in Note is added to refer to table 3.3.2-1 for each SR.

Table 3.3.2-1 is added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 56 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark with the Setpoint Control Program accordance with Setpoint Control Program.

None Table 3.3.2-1 3.3.3 Control Element Assembly Calculators (CEACs)

LCO 3.3.3 Two CEACs shall be OPERABLE.

LCO 3.3.3 Two CEACs shall be OPERABLE in each Core Protection Calculator System (CPCS) channel.

See III.1.2.8 See III.1.2.8 The NOTE is added to allow CEAC inoperable in each channel.

ACTIONS None ACTIONS

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

Separate Condition entry is allowed for each CPCS channel.

CONDITION A. One CEAC inoperable.

CONDITION A. One CEAC inoperable in one or more CPCS channels.

REQUIRED ACTION A.1 Perform SR 3.1.4.1 AND A.2 Restore CEAC to OPERABLE status.

REQUIRED ACTION A.1 Declare affected CPCS channel(s) inoperable OR A.2.1 Verify indicated position of each full and part strength CEA is within 16.8 cm (6.6 in) of all other CEAs in its group.

AND A.2.2 Restore CEAC to OPERABLE status.

See III.1.2.8 A.1 action is added to declare the affected channel inoperable.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 57 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark CONDITION B. Both CEACs inoperable.

CONDITION B. Both CEACs inoperable in one or more CPCS channels.

See III.1.2.8 REQUIRED ACTION None B.1 Verify the departure from nucleate boiling ratio requirement of LCO 3.2.4, "Departure from nucleate boiling ratio (DNBR)", is met

[and the Reactor Power Cutback System is disabled].

AND B.2 Verify all full strength and part strength CEA groups are fully withdrawn and maintained fully withdrawn, except during Surveillance testing pursuant to SR 3.1.4.3[or for control, when CEA group #6 may be inserted to a maximum of 127.5 inches.

AND B.3 Verify the "RSPT/CEAC Inoperable" addressable constant in each core protection calculator (CPC) is set to indicate that both REQUIRED ACTION B.1 Declare affected channel(s) inoperable.

OR B.2.1 Verify indicated position of each full and part strength CEA is within 16.8 cm (6.6 in) of all other CEAs in its group.

AND B.2.2 Verify departure from nucleate boiling ratio requirement of LCO 3.2.4 is met and Reactor Power Cutback System (RPCS) is disabled.

AND B.2.3 Verify all full strength and part strength CEA groups are fully withdrawn and maintained fully withdrawn, except during Surveillance testing pursuant to SR 3.1.4.3, or for power control, when CEA group #5 may be inserted to a maximum of See III.1.2.8.

B.1 is added to specify the case both CEACs inoperable in one or more CPCS channels.

Same action as in SR 3.1.4.1.

Completion time 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months used instead of 7 inches and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months See II.5

6 is changed into #5 which is the last control group in APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 58 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark CEACs are inoperable.

AND B.4 Verify the Control Element Drive Mechanism Control System is placed in "OFF" and maintained in "OFF", except during CEA motion permitted by Required Action B.2.

AND B.5 Perform SR 3.1.4.1 323.9 cm (127.5 in).

AND B.2.4 Verify addressable constant in each affected CPC is set to indicate that both CEACs are inoperable and "RSPT/CEAC inoperable" status is indicated.

AND B.2.5 Verify Digital Rod Control System (DRCS) is placed in "standby" and maintained in "standby", except during CEA motion permitted by Required Action B.2.2.

See III.1.2.8 "Standby" in APR1400 is "OFF" in CEDMCS of STS.

Current TS value used CONDITION C. Receipt of a CPC channel B or C cabinet high temperature alarm.

CONDITION C. Required Action and associated Completion Time of Condition B not met.

Same as in TS 3.3.2, it is not necessary to include high temperature alarm.

Auto restart function has been removed.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 59 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION C.1 Perform CHANNEL FUNCTIONAL TEST on affected CEAC(s).

REQUIRED ACTION C.1 Be in MODE 3.

Due to the platform change, channel function test is not performed in APR1400, when high temperature alarm of CPC is generated.

Due to the platform change, there is no auto restart function in APR1400. Instead of the check for auto restart, the CPC System Event Log is checked every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to monitor the CPCS channel performance.

COMPLETION TIME C.1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMPLETION TIME C.1 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Due to the platform change, channel function test is not performed in APR1400, when high temperature alarm of CPC is generated.

Due to the platform change, there is no auto restart function in APR1400. Instead of the check for auto restart, the CPC System Event Log is checked every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to monitor the CPCS channel performance.

CONDITION D. One or two CEACs with three or more auto restarts during a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months period.

REQUIRED ACTION D.1 Perform CHANNEL FUNCTIONAL TEST on affected CEAC.

COMPLETION TIME 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months CONDITION E. Required Action and associated Completion Time of Condition B, C, or D not met.

REQUIRED ACTION E.1 Be in MODE 3.

CONDITION None CONDITION None

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 60 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark COMPLETION TIME 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE SR 3.3.3.2 Check the CEAC auto restart count.

FREQUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR In accordance with the Surveillance Frequency Control Program SURVEILLANCE SR 3.3.3.2 Check CPC system event log.

FREQUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Due to the platform change, there is no auto restart function in APR1400. Instead of the check for auto restart, the CPC System Event Log is checked every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to monitor the CPCS channel performance.

SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST in accordance with the Setpoint Control Program.

SR 3.3.3.5 Perform CHANNEL FUNCTIONAL TEST in accordance with the Setpoint Control Program (including annunciation and trip function test).

The contents are clarified.

SR 3.3.3.6 Verify the isolation characteristics of each CEAC isolation amplifier and each optical isolator for CEAC to CPC data transfer in accordance with the Setpoint Control Program.

None Due to the platform change, there is no amplifier and optical isolator for CEAC to CPC.

Fiber optic high speed datalink is used to interface for CEAC to CPC

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 61 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.3.4 Reactor Protective System (RPS)

Logic and Trip Initiation LCO 3.3.4 Six channels of RPS Matrix Logic, four channels of RPS Initiation Logic, [four channels of reactor trip circuit breakers (RTCBs),] and four channels of Manual Trip shall be OPERABLE.

LCO 3.3.4 Four RPS logic channels (Coincidence, Initiation Logic), four channels of reactor trip circuit breakers (RTCBs), and four channels of Manual Trip shall be OPERABLE.

See III.1.2.5 CONDITION A. One Matrix Logic channel inoperable.

OR Three Matrix Logic channels inoperable due to a common power source failure de-energizing three matrix power supplies.

CONDITION None See III.1.2.5 B. One channel of manual Trip, RTCBs, or Initiation Logic inoperable in MODE 1 or 2.

A. --------------NOTE--------------

RTCBs associated with one inoperable channel may be closed for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for the performance of an RPS CHANNEL FUNCTIONAL TEST.

One channel of Manual Trip, RTCB, or RPS logic inoperable in MODE 1 or 2.

The RTCB condition for channel function test is added.

Testing on the OPERABLE channels cannot be performed without causing a reactor trip, unless the RTCBs in the inoperable channels are closed to permit testing. Therefore, the Note has been added specifying that the RTCBs associated with one inoperable channel may be closed for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for the performance of an RPS CHANNEL FUNCTIONAL TEST.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 62 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark C. One channel of manual Trip, RTCBs, or Initiation Logic inoperable in MODE 3, 4, or 5.

B. --------------NOTE--------------

RTCBs associated with one inoperable channel may be closed for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for the performance of an RPS CHANNEL FUNCTIONAL TEST.

One channel of Manual trip, RTCB, or RPS logic inoperable in MODE 3, 4, or 5.

The RTCB condition for channel function test is added.

Testing on the OPERABLE channels cannot be performed without causing a reactor trip, unless the RTCBs in the inoperable channels are closed to permit testing. Therefore, the Note has been added specifying that the RTCBs associated with one inoperable channel may be closed for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for the performance of an RPS CHANNEL FUNCTIONAL TEST.

D. Two channels of Manual Trip, RTCBs, or Initiation Logic affecting the same trip leg inoperable.

None E. Required Action and associated Completion Time of Condition A, B, or D not met.

OR One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.

C. Required Action and associated Completion Time of Condition A not met.

OR One or more Functions with more than one channel of Manual Trip, RTCB, or RPS logic inoperable.

See III.1.2.5

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 63 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE SR 3.3.4.1 Perform a CHANNEL FUNCTION TEST on each RTCB channel.

SR 3.3.4.2 Perform a CHANNEL FUNCTION TEST on each RPS Logic channel.

SURVEILLANCE SR 3.3.4.1 Perform a CHANNEL FUNCTION TEST on each RPS logic channel and RTCB channel.

The SRs for RPS logic channel and RTCB channel are merged into SR 3.3.4.1.

SR 3.3.4.3 SR 3.3.4.4 SR 3.3.4.2 SR 3.3.4.3 The SRs for RPS logic channel and RTCB channel are merged into SR 3.3.4.1, subsequent SRs are renumbered and APR1400 SR 3.3.4.4 shall be deleted.

3.3.5 Engineered Safety Features Actuation System (ESFAS)

Instrumentation LCO 3.3.5 Four ESFAS trip and bypass removal channels for each Function in Table 3.3.5-1 shall be OPERABLE.

LCO 3.3.5 Four ESFAS trip and automatic operating bypass removal channels for each Function in Table 3.3.5-1 shall be OPERABLE.

CONDITION C.GOne or more Functions with one automatic bypass removal channel inoperable.

D.GOne or more Functions with two automatic bypass removal channels inoperable.

None CONDITION C. One or more Functions with one automatic operating bypass removal channel inoperable.

D.GOne or more Functions with two automatic operating bypass removal channels inoperable.

F.GRequired Action and associated Completion Time not met.

REQUIRED ACTION A.1 Place channel in bypass or trip.

A.2 Restore channel to OPERABLE status.

B.1 Place one channel in bypass REQUIRED ACTION A.1 Place trip channel in bypass or trip.

A.2 restore trip channel to OPERABLE status.

B.1 Place one trip channel in

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 64 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark and the other in trip.

C.1 Disable bypass channel.

C.2.2 Restore bypass removal channel and associated automatic trip channel to OPERABLE status.

D.1 Disable bypass channels.

None None bypass and the other in trip.

C.1 Disable affected bypass channel.

C.2.2 Restore automatic operating bypass removal channel and associated automatic trip channel to OPERABLE status.

D.1 Disable affected bypass channels.

F.1 Be in MODE 3.

F.2 Be in MODE 4.

None (For Item E.1)

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

Only applicable to the Functions 3, 5 and 6 of Table 3.3.5-1.

Applicable Modes for ESFAS functions such as SIAS, CSAS, and MSIS are extended from Modes 1, 2, and 3 to Modes 1, 2, 3, and 4 in order to enhance the safety of nuclear power plants.

None (For Item F.1)

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

Only applicable to the Functions 1, 2 and 4 of Table 3.3.5-1 Applicable Modes for ESFAS functions such as SIAS, CSAS, and MSIS are extended from Modes 1, 2, and 3 to Modes 1, 2, 3, and 4 in order to enhance the safety of nuclear power plants.

Tier 2, Table 7.2-4, Note (5)

Tier 2, Table 7.2-1 SURVEILLANCE SR 3.3.5.3 Perform a CHANNELG CALIBRATION of each ESFAS channel, including bypass removal functions in accordance with the Setpoint Control Program.

SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits.

SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each SURVEILLANCE SR 3.3.5.3 Perform CHANNELG CALIBRATION of each ESFAS channel, including automatic operating bypass removal functions in accordance with the Setpoint Control Program.

SR 3.3.5.4 Verify ESFAS RESPONSE TIME is within limits.

SR 3.3.5.5 Perform CHANNEL FUNCTIONAL TEST on each

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 65 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark automatic bypass removal channel.

automatic operating bypass removal channel.

Table 3.3.5-1 APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS: 1,2,3 Table 3.3.5-1 APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS: 1,2,3,4 Applicable Modes for ESFAS functions such as SIAS, CSAS, and MSIS are extended from Modes 1, 2, and 3 to Modes 1, 2, 3, and 4 in order to enhance the safety of nuclear power plants.

In APR1400 notes (b) and (d) are related to the Applicable Modes.

Tier 2, Table 7.2-4, Note (5)

Table 3.3.5-1

1. Safety Injection Actuation Signal(a) 1.b. Pressurizer Pressure - low(b) 2.b. Automatic SIAS 3.b. Pressurizer Pressure - low(b)

Table 3.3.5-1

1. Safety Injection Actuation Signal 1.b. Pressurizer Pressure - low(a)

None 3.b. Pressurizer Pressure - low(a)

Table 3.3.5-1 None Table 3.3.5-1 4.c Steam Generator Level - High Table 3.3.5-1

5. Recirculation Actuation Signal Table 3.3.5-1 None See III.1.2.2 Table 3.3.5-1

6. Emergency Feedwater Actuation Signal SG #1 (EFAS-1)

b. SG Pressure Difference -

High

[c. Steam Generator Pressure

- Low

7. Emergency Feedwater Actuation Signal SG #2 (EFAS-2)

b. SG Pressure Difference -

High

[c. Steam Generator Pressure

- Low Table 3.3.5-1

5. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)

None None

6. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2)

None None See III.1.2.2 Table 3.3.5-1 Note (a) Automatic SIAS also initiates a N/A See III.1.2.2

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 66 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Containment Cooling Actuation Signal (CCAS).

Tier 2, Table 7.2-1 Table 3.3.5-1 Note (b) The setpoint may be decreased to a minimum value of [300]

psia, as pressurizer pressure is reduced, provided the margin between pressurizer pressure and the setpoint is maintained

[400] psia. Trips may be bypassed when pressurizer pressure is < [400] psia.

Bypass shall be automatically removed when pressurizer pressure is [500] psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

Table 3.3.5-1 Note (a) The setpoint may be manually decreased to a minimum value of 7.0 kg/cm2A (100 psia), as pressurizer pressure is reduced, provided the margin between pressurizer pressure and the setpoint is maintained 28.1 kg/cm2 (400 psi). Trips may be bypassed when pressurizer pressure is < 28.1 kg/cm2A (400 psia). Bypass shall be automatically removed when pressurizer pressure is 35.2 kg/cm2A (500 psia). The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

See III.1.2.2 Table 3.3.5-1 Note (d) The Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure - Low and Containment Pressure - High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed and [de-activated].

Table 3.3.5-1 Note (b) Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure - Low, Containment Pressure - High, and Steam Generator Level -

High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed and de-activated.

Table 3.3.5-1 Table 3.3.5-1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 67 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Note None Note (d) When a steam generator is relied upon for heat removal.

3.3.6 Engineered Safety Features Actuation System (ESFAS) Logic and Manual Trip LCO 3.3.6 Six channels of ESFAS Matrix Logic, four channels of ESFAS Initiation Logic, two channels of Actuation Logic, and two channels of Manual Trip shall be OPERABLE for each Function in Table 3.3.6-1.

LCO 3.3.6 The ESFAS Coincidence Logic, Initiation Logic, Actuation Logic, Manual Trip and Diverse Manual ESF Actuation channels required for each Function in Table 3.3.6-1 shall be OPERABLE.

See III.1.2.5 ACTIONS

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

Separate Condition entry is allowed for each Function.

ACTIONS

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

Separate Condition entry is allowed for each ESFAS Function and for each Diverse Manual ESF Actuation Function.

CONDITION A. ------------------NOTE-----------------

This action also applies when three Matrix Logic channels are inoperable due to a common power source failure de-energizing three matrix power supplies.

One or more Functions with one Matrix Logic channel inoperable.

B. One or more Functions with one Manual Trip or Initiation Logic channel inoperable CONDITION A. One or more Functions with one Coincidence Logic channel, Initiation Logic channel, or Manual Trip channel inoperable.

See III.1.2.5 CONDITION A and B of NUREG-1432 are integrated into CONDITION A of APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 68 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark E. Two Actuation Logic channels inoperable.

OR Required Action and associated Completion Time no met.

D. One or more Diverse Manual ESF Actuation Functions with one channel inoperable.

E. Required Action and associated Completion Time of Condition A, B, C, or D not met.

When two Actuation Logic channels are inoperable, the action for this condition is taken in accordance with Condition C that covers one Actuation Logic channel inoperable status.

Therefore, APR1400 Tech.

Spec. does not address specifically the Condition of two Actuation Logic channels inoperable.

SURVEILLANCE SR 3.3.6.1 SR 3.3.6.3 SURVEILLANCE SR 3.3.6.1 (merged)

NUREG-1432 SR 3.3.6.1 and SR 3.3.6.3 are merged into APR1400 SR 3.3.6.1.

SURVEILLANCE SR 3.3.6.2

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

Relays exempt from testing during operation shall be tested during each MODE 5 entry exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless tested during the previous 6 months.

Perform a subgroup relay test of each Actuation Logic channel, which includes the de-energization of each subgroup relay and verification of the OPERABILITY of each subgroup relay.

SURVEILLANCE SR 3.3.6.2

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

1. Components exempt from testing during operation shall be tested once every 18 months (MODE

6) or in MODE 5 if not tested within the previous 62 days.

2. The pair of Actuation Logic subgroup channels A and C and the pair of Actuation Logic subgroup channels B and D shall be tested on a staggered basis.

Perform a verification of the OPERABILITY of subgroup for See III.1.2.6

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 69 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Actuation signal of each Actuation Logic channel.

SR 3.3.6.3 Perform a CHANNEL FUNCTIONAL TEST on each ESFAS Manual Trip channel.

SR 3.3.6.3 Perform CHANNEL FUNCTIONAL TEST on each Diverse Manual ESF Actuation channel.

See III.1.2.7 SR 3.3.6.3 does not include a Channel Functional Test on each ESFAS manual trip channel because CONDITION A and B of NUREG-1432 are integrated into CONDITION A of APR1400.

Table 3.3.6-1 FUNCTION

1. Safety Injection Actuation Signal

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

2. Containment Isolation Actuation Signal

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

3. Containment Cooling Actuation Signal(a)

a. Initiation Logic

b. Actuation logic

c. Manual trip

4. Recirculation Actuation Signal

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip Table 3.3.6-1 FUNCTION

1. Safety Injection Actuation Signal

a. Coincidence Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

2. Containment Spray Actuation Signal

a. Coincidence Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

3. Containment Isolation Actuation Signal

a. Coincidence Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip See III.1.2.2 In APR1400 REQUIRED CHANNELS are listed for each FUNCTION and APPLICABLE MODES are updated.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 70 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

5. Containment Spray Actuation Signal(b)

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

6. Main Steam Isolation Signal

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

7. Emergency Feedwater Actuation Signal SG #1 (EFAS-1)

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

8. Emergency Feedwater Actuation Signal SG #2 (EFAS-2)

a. Matrix Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip (a) Automatic SIAS also initiates CCAS (b) Automatic SIAS also required for

4. Main Steam Isolation Signal

a. Coincidence Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

5. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)

a. Coincidence Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

6. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2)

a. Coincidence Logic

b. Initiation Logic

c. Actuation logic

d. Manual trip

7. Diverse Manual ESF Actuation Signal

a. Safety Injection

b. Containment Spray

c. Auxiliary Feedwater (SG #1)

d. Auxiliary Feedwater (SG #2)

e. Main Steam Isolation per main steam isolation valve (MSIV)

f. Containment Isolation

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 71 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark automatic CSAS initiation.

3.3.8 Containment Purge Isolation Signal (CPIS)

LCO 3.3.8 One CPIS channel shall be OPERABLE.

LCO 3.3.8 One CPIAS instrument division with two area radiation monitor channels, one Manual Actuation division, and one Actuation Logic division shall be OPERABLE.

APPLICABILITY MODES 1, 2, 3, and 4, During movement of [recently]

irradiated fuel assemblies within containment.

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

Only required when the penetration is not isolated by at least one closed and de-activated automatic valve, closed manual valve, or blind flange.

APPLICABILITY MODES 1, 2, 3, and 4, MODE 5 with RCS loops not filled when relying on LCO 3.6.7.c.2, MODE 6 when relying on LCO 3.6.7.c.2 or LCO 3.9.3.c.2.

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

Only required when the associated containment purge or exhaust line penetration flow path is not isolated by at least one closed and deactivated automatic valve, closed manual valve, or blind flange.

CONDITION A. CPIS Manual Trip, Actuation Logic, or one or more required channels of radiation monitors inoperable in MODES 1,2,3, and 4.

CONDITION A. CPIAS required Manual Actuation division, required Actuation Logic division, or required instrument division with one or more required area radiation monitor channels inoperable in MODES 1, 2, 3, and 4.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 72 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION B.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION B.2 Be in MODE 5.

See II.3.3 Related COMPLETION TIME is changed.

CONDITION C. CPIS Manual Trip, Actuation Logic, or one or more required channels of radiation monitors inoperable during movement of

[recently] irradiated fuel assemblies within containment.

CONDITION C. CPIAS required Manual Actuation division, Actuation Logic division, or required instrument division with one or more required area radiation monitor channels inoperable during CORE ALTERATIONS or movement of irradiated fuel assemblies within containment, or in MODE 5 with LCO 3.6.7.c.2 not met or in MODE 6 with LCO 3.6.7.c.2 or LCO 3.9.3.c.2 not met.

See II.2.1 REQUIRED ACTION C.2G Suspend movement of

[recently] irradiated fuel assemblies in containment REQUIRED ACTION C.2.1 Suspend CORE ALTERATIONS.

AND C.2.2G Suspend movement of irradiated fuel assemblies in containment.

See II.2.1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 73 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE SR 3.3.8.1 Perform a CHANNEL CHECK on required containment area and gaseous radiation monitor channel.

SURVEILLANCE SR 3.3.8.1 Perform CHANNEL CHECK on required containment upper operating area radiation monitor channel and operating area radiation monitor channel.

SR 3.3.8.2 Perform a CHANNEL CHECK on required containment particulate and iodine radiation monitor channel.

N/A SR 3.3.8.3

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

Only required to be met in MODES 1, 2, 3, and 4.

Perform a CHANNEL FUNCTIONAL TEST on each required containment radiation monitor channel in accordance with the Setpoint Control Program.

SR 3.3.8.2

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

Only required to be met in MODES 1, 2, 3, and 4.

G Perform CHANNEL FUNCTIONAL TEST on each required upper operating area radiation monitor channel and each required operating area radiation monitor channel in accordance with Setpoint Control Program.

SR 3.3.8.4

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

Only required to be met during movement of irradiated fuel assemblies within containment.

Perform a CHANNEL FUNCTIONAL TEST on required containment radiation monitor channel in accordance with the Setpoint Control Program.

SR 3.3.8.3

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

Only required to be met during CORE ALTERATIONS and during movement of irradiated fuel assemblies within containment, and in MODE 5 with RCS loops not filled when relying on LCO 3.6.7.c.2, and in MODE 6 when relying on LCO 3.6.7.c.2 or LCO 3.9.3.c.2.

See II.2.1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 74 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Perform CHANNEL FUNCTIONAL TEST on each required upper operating area radiation monitor channel and each required operating area radiation monitor channel in accordance with Setpoint Control Program.

SR 3.3.8.5

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

Surveillance of Actuation Logic shall include the actuation of each initiation relay and verification of the proper operation of each initiation relay.

Perform a CHANNEL FUNCTIONAL TEST on required CPIS Actuation Logic channel.

SR 3.3.8.4

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

Surveillance of Actuation Logic shall include actuation of each initiation circuit and verification of proper operation of each initiation circuit.

Perform CHANNEL FUNCTIONAL TEST on required CPIAS Actuation Logic division.

SR 3.3.8.8 Perform CHANNEL FUNCTIONAL TEST on required CPIS Manual Trip channel.

SR 3.3.8.7 Perform CHANNEL FUNCTIONAL TEST on required CPIAS Manual Actuation division.

3.3.9 Control Room Isolation Signal (CRIS)

LCO 3.3.9 One CRIS channel shall be OPERABLE.

LCO 3.3.9 One CREVAS instrument division with one radiation monitor channel, one Manual Actuation division, and one Actuation Logic division shall be OPERABLE.

APPLICABILITY MODES 1, 2, 3, 4, [5, and 6],

During movement of [recently]

irradiated fuel assemblies.

APPLICABILITY MODES 1, 2, 3, and 4, During CORE ALTERATIONS, During movement of irradiated fuel assemblies.

See II.2.1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 75 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark CONDITION A. CRIS Manual Trip, Actuation Logic, or [one or more required channels of particulate/iodine or gaseous] radiation monitors inoperable in MODES 1, 2, 3, or 4.

CONDITION A. CREVAS required Manual Actuation division, required Actuation Logic division, or required instrument division with one required radiation monitor channel inoperable in MODE 1, 2, 3, or 4.

REQUIRED ACTION A.1 ---------------NOTE--------------

Place Control Room Emergency Air Cleanup System (CREACS) in toxic gas protection mode if automatic transfer to toxic gas protection mode inoperable.

Place one CREACS train in emergency radiation protection mode.

REQUIRED ACTION A.1 Place one Control Room Area heating, ventilation, and air conditioning (HVAC) System train in emergency operation mode.

The REQUIRED ACTION reflects APR1400 design feature.

APR1400 does not have toxic gas protection mode.

B.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

B.2 Be in MODE 5.

See II.3.3 Related COMPLETION TIME is changed.

CONDITION C. CRIS Manual Trip, Actuation Logic, or required particulate/iodine or gaseous radiation monitors inoperable

[in MODE 5 or 6], or during movement of [recently]

irradiated fuel assemblies.

CONDITION C. CREVAS required Manual Actuation division, required Actuation Logic division, or required instrument division with one required radiation monitor channel inoperable during CORE ALTERATIONS or movement of irradiated fuel assemblies.

See II.2.1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 76 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION C.1 ---------------NOTE--------------

Place CREACS in toxic gas protection mode if automatic transfer to toxic gas protection mode inoperable.

Place one CREACS train in emergency radiation protection mode.

C.2.2 -------------NOTE-------------

Limited plant cooldown or boron dilution is allowed provided the change is accounted for in the calculated SDM.

Suspend positive reactivity additions.

REQUIRED ACTION C.1 Place one Control Room Area HVAC System train in emergency operation mode.

C.2.2 Suspend positive reactivity additions.

The REQUIRED ACTION reflects APR1400 design feature.

None C.2.3 Suspend CORE ALTERATIONS.

See II.2.1 SURVEILLANCE SR 3.3.9.3

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

1. Surveillance of Actuation Logic shall include the verification of the proper operation of each initiation relay.

2. Relays associated with plant equipment that cannot be operated during plant operation are required to be tested during each MODE 5 entry exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless tested within the previous 6 months.

SURVEILLANCE SR 3.3.9.3

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

Surveillance of Actuation Logic shall include verification of proper operation of each initiation circuit.

Perform CHANNEL FUNCTIONAL TEST on required CREVAS Actuation Logic division.

The SR reflects APR1400 design feature.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 77 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Perform a CHANNEL FUNCTIONAL TEST on required CRIS Actuation Logic channel.

SR 3.3.9.5 Perform a CHANNEL FUNCTIONAL TEST on required CRIS Manual Trip channel.

SR 3.3.9.5G Perform CHANNEL FUNCTIONAL TEST on required CREVAS Manual Actuation division.

SR 3.3.9.6

[ Verify that response time of required CRIS channel is within limits.

SR 3.3.9.6G Verify that the response time of required CREVAS division is within limits.

3.3.10 Fuel Handling Isolation Signal (FHIS)

LCO 3.3.10 One FHIS channel shall be OPERABLE.

LCO 3.3.10 One FHEVAS instrument division with one radiation monitor channel, one Manual Actuation division, and one Actuation Logic division shall be OPERABLE.

APPLICABILITY

[MODES 1, 2, 3, and 4,]

During movement of [recently]

irradiated fuel in the fuel building.

APPLICABILITY During movement of irradiated fuel in the fuel handling area.

ACTION

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

LCO 3.0.3 is not applicable.

CONDITION A. [ Actuation Logic, Manual Trip, or [one or more required channels of particulate/iodine and gaseous] radiation monitors inoperable in MODE 1, 2, 3, or 4.]

B. [ Required Action and ACTION None CONDITION None The deviations reflect APR1400 design feature. Area radiation monitor is designed for APR1400. Particulate/iodine or gaseous radiation monitors is not applicable to APR1400.

FHEVAS is not applicable to Modes 1, 2, 3, and 4.

Tier 2, 7.3.1.3 Item name is changed.

See II.5

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 78 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark associated Completion Time of Condition A not met.]

C. Actuation Logic, Manual Trip, or

[one or more required channels of particulate/iodine and gaseous] radiation monitors inoperable during movement of

[recently] irradiated fuel Assemblies.

A. Required Manual Actuation division, required Actuation Logic division, or required instrument division with required radiation monitor channel inoperable.

REQUIRED ACTION C.1 Place one OPERABLE FBACS train in operation.

OR C.2. Suspend movement of

[recently] irradiated fuel assemblies in the fuel building.

REQUIRED ACTION A.1 Place one OPERABLE Fuel Handling Area heating, ventilation, and air conditioning (HVAC) System train in emergency operation mode.

OR A.2. Suspend movement of irradiated fuel assemblies in fuel handling area.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 79 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE SR 3.3.10.3

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

Testing of Actuation Logic shall include the actuation of each initiation relay and verification of the proper operation of each ignition relay.

Perform a CHANNEL FUNCTIONAL TEST on required FHIS Actuation Logic channel.

SR 3.3.10.4 Perform a CHANNEL FUNCTIONAL TEST on required FHIS Manual Trip logic.

SR 3.3.10.6

[ verify response time of required FHIS channel is within limits.

SURVEILLANCE SR 3.3.10.3

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

Testing of Actuation Logic shall include actuation of each initiation circuit and verification of proper operation of each initiation circuit.

Perform CHANNEL FUNCTIONAL TEST on required FHEVAS Actuation Logic division.

SR 3.3.10.4 Perform CHANNEL FUNCTIONAL TEST on required FHEVAS Manual Actuation division.

SR 3.3.10.6 Verify that the response time of required FHEVAS division is within limits.

3.3.11 Post Accident Monitoring (PAM)

Instrumentation LCO 3.3.11 The PAM instrumentation for each Function in Table 3.3.11-1 shall be OPERABLE.

LCO 3.3.11 The AMI measurement channel for each Function in Table 3.3.11-1 shall be OPERABLE.

Changed to measurement channel throughout.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 80 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark ACTION

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

Separate Condition entry is allowed for each Function.

ACTION

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

1. LCO 3.0.4 is not applicable.

2. Separate Condition entry is allowed for each Function.

Note 1 has been added in the ACTIONS to exclude the MODE change restriction of LCO 3.0.4.

This exception allows entry into the applicable MODE while relying on the ACTIONS, even though the ACTIONS may eventually require plant shutdown. This exception is acceptable due to the passive function of the instruments, the operator's ability to monitor an accident using alternate instruments and methods, and the low probability of an event requiring these instruments.

Tier 2, 7.5.1.1 Item name is changed.

See II.5 COMPLETION TIME A.1 30 days COMPLETION TIME A.1 31 days See II.3.2 Tier 2, 7.5.1.1 Table 3.3.11-1 FUNCTION

1. [Wide Range] Neutron Flux

2. Reactor Coolant System Hot Leg Temperature

3. Reactor Coolant System Cold Leg Temperature

4. Reactor Coolant System Pressure (wide range)

5. Reactor Vessel Water Level

6. Containment Sump Water Level (wide range)

7. Containment Pressure (wide range)

8. Penetration Flow Path Table 3.3.11-1 FUNCTION

1. Logarithmic Reactor Power (neutron flux)

2. Cold Leg temperature (Wide Range)

3. Hot Leg temperature (Wide Range)

4. Reactor Coolant System Pressure

5. Reactor Vessel Level (RV Closure Head Level/RV Plenum Level)

6. Reactor Cavity Level

7. Containment Pressure (Wide Range)

8. Containment Pressure NUREG-1432 Rev. 4 had followed RG 1.97 Rev. 3 (1983).

On the other hand, APR1400 DCD is adapted in accordance with RG 1.97 Rev. 4 (2006). A few variations are added in APR1400 DCD.

Added FUNCTIONS and associated requirements.

Tier 2, Table 7.5-1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 81 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Containment Isolation Valve Position

9. Containment Area Radiation (high range)

10. Pressurizer Level

11. Steam Generator Water Level (wide range)

12. Condensate Storage Tank Level

13. Core Exit Temperature -

Quadrant [1]

14. Core Exit Temperature -

Quadrant [2]

15. Core Exit Temperature -

Quadrant [3]

16. Core Exit Temperature -

Quadrant [4]

17. Emergency Feedwater Flow (Extended Wide Range)

9. Containment Isolation Valve Position

10. Containment Upper Operating Area Radiation

11. Pressurizer Level

12. Steam Generator Level (Wide Range)

13. Holdup Volume Tank Level

14. Core Exit Temperature -

Quadrant 1

15. Core Exit Temperature -

Quadrant 2

16. Core Exit Temperature -

Quadrant 3

17. Core Exit Temperature -

Quadrant 4

18. Steam Generator Pressure

19. RCS Saturation Margin

20. Core Exit Temperature Saturation Margin

21. Reactor Vessel Upper Head Saturation Margin

22. Pressurizer Pressure (Wide Range)

23. In-containment Refueling Water Storage Tank (IRWST) Level

24. IRWST Temperature

25. Containment Water Level

26. Containment Operating Area Radiation (For Fuel Handling Accident)

27. Spent Fuel Pool Radiation

28. Safety Injection Pump (SIP)

Direct Vessel Injection (DVI)

Flow Rate

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 82 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

29. Main Steam Atmospheric Steam Dump Valve Position

30. Auxiliary Feedwater Flow

31. Hydrogen Concentration

32. Containment Atmosphere Temperature

33. 4.16 kV Switchgear Voltage

34. DC Bus Voltage

35. Instrument Power Bus Voltage 3.3.12 Remote Shutdown System LCO 3.3.12 The Remote Shutdown System Functions shall be OPERABLE.

LCO 3.3.12 The Remote Shutdown Display and Control Functions in Table 3.3.12-1 shall be OPERABLE.

The deviations reflect APR1400 design feature.

Table 3.3.12-1 is added to describe the list for Remote Shutdown Display and Control in APR1400.

Tier 2, 7.5.1.1 ACTION

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

Separate Condition entry is allowed for each Function.

ACTION

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

1. LCO 3.0.4 is not applicable

2. Separate Condition entry is allowed for each Function.

Added a Note "LCO 3.0.4 is not applicable" so as not to prohibit or hinder operator to enter the other MODES or other specified condition during safe shutdown executing the unsatisfied required action based on the referenced plants.

SURVEILLANCE SR 3.3.12.2 Verify each required control circuit and transfer switch is capable of performing the intended function.

SR 3.3.12.4

[Perform CHANNEL FUNCTIONAL TEST of the reactor trip circuit SURVEILLANCE SR 3.3.12.2 Verify that the required indication, control circuit, and transfer switch is capable of performing the intended function.

SR 3.3.12.4 Perform CHANNEL FUNCTIONAL TEST of reactor trip switch gear Changed instrument channel to measurement channel.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 83 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark breaker open/closed indication.

open/closed indication.

None Table 3.3.12-1 Table 3.3.12-1 is added to describe the list for Remote Shutdown Display and Control in APR1400.

3.3.13 [Logarithmic]

Power Monitoring Channels Same as NUREG-1432 Addition

- Boron Dilution Alarms None LCO 3.3.14 Two Boron Dilution Alarm System (BDAS) channels shall be OPERABLE.

The OPERABILITY of BDAS channels is necessary to meet the assumptions of the safety analyses as described in the APR1400 DCD Tier 2, Section 15.4.6.

Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

APPLICABILITY MODE 3Gwithin 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after the neutron flux is within the startup range following a reactor

shutdown, MODES 4 and 5.

3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow [Departure from Nucleate Boiling (DNB)]

Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, cold leg temperature, and RCS total flow rate shall be within the limits specified in the COLR.

LCO 3.4.1 RCS departure from nucleate boiling (DNB) parameters for pressurizer pressure, cold leg temperature (Tcold), and RCS total flow rate shall be within the limits specified below.

a. Pressurizer pressure 154.7 kg/cm2A (2,201 psia) and 161.6 kg/cm2A (2,299 psia);

b. Tcold 286.7¶C (548¶F) and The RCS DNB parameters are the APR1400 plant specific values.

LCO is to maintain the operation data within data specified in DCD Table 15.0-3.

APR1400 specific value used (DCD 15.0.3)

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 84 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 293.3¶C (560¶F) for THERMAL POWER < 90%

RATED THERMAL POWER (RTP)

c. Tcold 289.4¶C (553¶F) and 293.3¶C (560¶F) for THERMAL POWER 90%

RTP; and

d. RCS total flow rate 75.6E6 kg/hr (166.6E6 lb/hr).

APPLICABILITY MODE 1

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

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp > 5%

RTP per minute or

b. THERMAL POWER step > 10%

RTP.

APPLICABILITY MODES 1 and 2 for pressurizer

pressure, MODE 1 for Tcold, MODE 2 with keff 1 for Tcold, MODE 1 for RCS total flow rate.

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

Pressurizer pressure limit in MODE 1 does not apply during:

a. THERMAL POWER ramp > 5%

RTP per minute or

b. THERMAL POWER step > 10%

RTP.

Core power as an initial condition of safety analyses for APR1400 is specified in DCD Table 15.0-3.

Mode 2 includes the core power of 0 %.

APR1400 specific value used (DCD 15.0.3)

CONDITION A. Pressurizer Pressure or RCS flow rate not within limit CONDITION A. RCS total flow rate not within limits.

LCO for RCS flow rate is only applied to MODE 1 in APPLICABILITY. So, the condition for the flow rate is separated from the pressurizer (PZR) pressure.

C. RCS cold leg temperature not within limits.

C. Pressurizer pressure or RCS Tcold not within limit LCOs for PZR pressure and cold leg temperature are applied to MODES 1 and 2 in APPLICABILITY. So, PZR pressure is merged into the cold

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 85 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark leg temperature. When the LCOs are not met, the condition shall be changed into the not-applicable MODE.

REQUIRED ACTION A.1 Restore parameter(s) to within limit.

C.1 Restore cold leg temperature to within limits.

D.1 Reduce THERMAL POWER to

[30]% RTP.

REQUIRED ACTION A.1 Restore RCS total flow rate to within limits.

C.1 Restore parameter(s) to within limit.

D.1 Be in Mode 3.

LCO 3.4.1 is applicable to MODEs 1 & 2. If LCO 3.4.1 is not met, plant condition shall not be in MODEs 1 & 2.

SURVEILLANCE SR 3.4.1.1 Verify pressurizer pressure is within the limits specified in the COLR.

SURVEILLANCE SR 3.4.1.1 Verify pressurizer pressure 154.7 kg/cm2A (2,201 psia) and 161.6 kg/cm2A (2,299 psia).

See II.4G APR1400 specific value used SR 3.4.1.2 Verify RCS cold leg temperature is within the limits specified in the COLR.

SR 3.4.1.2 Verify RCS cold leg temperature 286.7¶C (548¶F) and 293.3¶C (560¶F) for

< 90% RTP or 289.4¶C (553¶F) and 293.3¶C (560¶F) for 90% RTP.

APR1400 specific value used SR 3.4.1.3

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

Only required to be met in MODE 1.

Verify RCS total flow rate is greater than or equal to the limits specified in the COLR.

SR 3.4.1.3 Verify RCS total flow rate 75.6E6 kg/hr (166.6E6 lb/hr)

APR1400 specific value used SR 3.4.1.4

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

Not required to be performed until

[24] hours after [90]% RTP.

Verify by precision heat balance SR 3.4.1.4

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

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after 95% RTP.

Verify by precision heat balance Higher power is desirable for more accurate measurements Current TS value used

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 86 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark that RCS total flow rate is within limits specified in the COLR.

that RCS total flow rate 75.6E6 kg/hr (166.6E6 lb/hr).

3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (Tavg) shall be [520]¶F.

LCO 3.4.2 Each RCS cold leg temperature (Tcold) shall be 286.7¶C (548¶F).

See II.3.1 APPLICABILITY MODE 1 with Tavg in one or more RCS loops < [535]¶F, MODE 2 with Tavg in one or more RCS loops < [535]¶F and Keff 1.0.

APPLICABILITY MODE 1, MODE 2 with keff 1.0.

See II.3.1 CONDITION A. Tavg in one or more RCS loops not within limit.

CONDITION A. RCS Tcold in one or more RCS loops not within limit.

To enter a MODE out of APPLICABILITY REQUIRED ACTION A.1 Be in MODE 2 with Keff < 1.0.

REQUIRED ACTION A.1 Be in MODE 3.

SURVEILLANCE SR 3.4.2.1 Verify RCS Tavg in each loop [520]¶F.

FREQUENCY SR 3.4.2.1 [ 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR In accordance with the Surveillance Frequency Control Program ]

SURVEILLANCE SR 3.4.2.1 Verify RCS Tcold in each loop is 286.7¶C (548¶F).

FREQUENCY SR 3.4.2.1 Once within 15 minutes prior to achieving criticality AND 30 minutes with the reactor critical and Tcold < 289.4°C (553°F).

AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months The first FREQUENCY is to verify LCO more vigilantly when approaching core critical. The second FREQUENCY of 30 minutes is to reduce possibility of inadvertent violation of LCO by frequent surveillance when the reactor is critical.

12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is added for consistency with STS.

RITS not applied.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 87 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.4.3 RCS Pressure and Temperature (P/T)

Limits REQUIRED ACTION B.2. Be in MODE 5 with RCS pressure < [500] psig.

REQUIRED ACTION B.2. Be in MODE 5 with RCS pressure < 33.7 kg/cm2A (479 psia).

3.4.4 RCS Loops -

MODES 1 and 2 LCO 3.4.4 Two RCS loops shall be OPERABLE and in operation.

LCO 3.4.4 Two RCS loops shall be OPERABLE and in operation with two reactor coolant pumps operating in each loop.

More specific information is described for "in operation".

3.4.5 RCS Loops -

MODE 3 LCO 3.4.5 LCO 3.4.5 Same as NUREG-1432 CONDITION C Two RCS loops inoperable.

CONDITION C No RCS loop OPERABLE.

The meaning of the CONDITION C is practically the same.

REQUIRED ACTION C.1. Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1.

REQUIRED ACTION C.1. Suspend all operations that would cause reduction of the RCS boron concentration below that required to meet the SDM of LCO 3.1.1.

The meaning of the REQUIRED ACTION is practically the same.

SURVEILLANCE SR 3.4.5.1 Verify one RCS loop is in operation.

SR 3.4.5.2 Verify secondary side water level in each steam generator [25]%.

SURVEILLANCE SR 3.4.5.1 Verify required RCS loop is in operation.

SR 3.4.5.2 Verify secondary side water level in each steam generator 25% wide range indications.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 88 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.4.6 RCS Loops -

MODE 4 LCO 3.4.6

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

2. No RCP shall be started with any RCS cold leg temperature less than or equal to the LTOP enable temperature specified in the PTLR unless:

a. Pressurizer water level is

< [60]% or

b. Secondary side water temperature in each steam generator (SG) is < [100]¶m above each of the RCS cold leg temperatures.

LCO 3.4.6

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

2. No RCP shall be started with any RCS cold leg temperatures less than or equal to the Low Temperature Overpressure Protection (LTOP) enable temperature specified in the PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR), unless secondary side water temperature in each steam generator (SG) is < 55.6°C (100°F) above each of the RCS cold leg temperatures.

The LTOP analyses in FSAR Section 5.2.2.10 is performed with the pressurizer in a water solid condition with a temperature difference of 139°C (250°F) between RCS cold leg and secondary side in each steam generator. There are no analyses performed with the pressurizer at a lower water level. Therefore, the option in NUREG-1432 is not utilized and this is conservative and consistent with the analyses.

There is no PZR level limit for RCP operation since LTOP analysis assumes the PZR is filled solid. Thus, the level limit is eliminated.

CONDITION A. One required loop inoperable.

CONDITION A. One required RCS loop inoperable.

AND Two SC trains inoperable.

LCO requires that two RCS loops or two SC trains are operable and one loop or train is in operation.

One RCS loop inoperable is not LCO violation if another RCS loop and one of two SC trains are operable and any one of them is in operation.

Therefore, combination for LCO violation is defined exactly.

REQUIRED ACTION A.2

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

LCO 3.0.4.a is not applicable when entering MODE 4.

REQUIRED ACTION None Natural circulation cooldown in Mode 4 is not analyzed.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 89 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Initiate action to make at least one steam generator available for decay heat removal via natural circulation.

CONDITION None CONDITION B. One required SC train inoperable.

AND Two required RCS loops inoperable.

LCO requires that two RCS loops or SC trains are operable and one loop or train is in operation.

This condition is for defining combination for LCO violation exactly.

REQUIRED ACTION None REQUIRED ACTION B.1 Be in MODE 5.

LCO requires that two RCS loops or SC trains are operable and one loop or train is in operation.

This condition is for defining combination for LCO violation exactly.

With only one SC train OPERABLE, redundancy for decay heat removal is lost and then, in the event of a loss of the remaining SC train, it would be safer to be in MODE 5 rather than MODE 4.

CONDITION B. Two required loops or trains inoperable.

OR Required loop or train not in operation.

CONDITION C. Two required RCS loops or SC trains inoperable OR Required RCS loop or SC train not in operation.

The meanings of the conditions are practically the same.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 90 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION B.1 Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1.

REQUIRED ACTION C.1 Suspend all operations that would cause introduction of coolant into the RCS with boron concentration below that required to meet the SDM of LCO 3.1.1.

SURVEILLANCE SR 3.4.6.1 Verify required RCS loop or SDC train is in operation.

SURVEILLANCE SR 3.4.6.1 Verify one RCS loop or SC train is in operation The meaning of the Surveillance Requirement is practically the same.

SR 3.4.6.2 Verify secondary side water level in required SG(s) is [25]%.

SR 3.4.6.2 Verify secondary side water level in required SG(s) is 25% wide range indication.

SR 3.4.6.4 None SR 3.4.6.4

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering Mode 4.

Verify required SC train locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY 31 days TSTF-523 (Managing Gas Accumulation) is applied to APR1400 Technical Specifications.

3.4.7 RCS Loops -

MODE 5, Loops Filled LCO 3.4.7

b. The secondary side water level of each steam generator SG shall be 25%.

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

1. The SDC pump of the train in operation may be removed from operation for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

LCO 3.4.7

b. The secondary side water level of each steam generator SG shall be 25% wide range indication.

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

1. The SC pump of the train in operation may be de-energized 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 91 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1 and

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and LCO 3.4.7

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

3. No reactor coolant pump (RCP) shall be started with any RCS cold leg temperature less than or equal to the LTOP enable temperature specified in the PTLR unless:

a. Pressurizer water level is

< [60]% or

b. The secondary side water temperature in each SG is

< [100]°F above each of the RCS cold leg temperatures.

4. All SDC trains may not be in operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

LCO 3.4.7

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

3. No reactor coolant pump (RCP) shall be started with one or more of the RCS cold leg temperatures less than or equal to the Low Temperature Overpressure Protection (LTOP) enable temperature specified in the PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR), unless secondary water temperature of each SG is < 55.6°C (100°F) above each of the RCS cold leg temperatures.

4. All SC trains may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

The LTOP analyses in FSAR Section 5.2.2.10 is performed with the pressurizer in a water solid condition with a temperature difference of 139°C (250°F) between RCS cold leg and secondary side in each steam generator. There are no analyses performed with the pressurizer at a lower water level. Therefore, the option in NUREG-1432 is not utilized and this is conservative and consistent with the analyses.

LCO 3.4.7 None LCO 3.4.7

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

5. A containment spray pump can be manually realigned to meet the requirement of a SC pump.

See III.5.2.1.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 92 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION C.1 Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1.

REQUIRED ACTION C.1 Suspend all operations involving reduction in RCS boron concentration.

SURVEILLANCE SR 3.4.7.1 Verify required SDC train is in operation.

SURVEILLANCE SR 3.4.7.1 Verify one SC train is in operation with circulating reactor coolant at a flow rate of 15,710 L/min (4,150 gpm).

SR 3.4.7.2 Verify required SG secondary side water level is [25]%.

SR 3.4.7.2 Verify required SG secondary side water level 25% wide range indication.

None SR 3.4.7.4 Verify required Shutdown Cooling System train locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY 31 days TSTF-523 (Managing Gas Accumulation) is applied to APR1400 Technical Specifications.

3.4.8 RCS Loops -

MODE 5, Loops Not Filled LCO 3.4.8 Two shutdown cooling (SDC) trains shall be OPERABLE and one SDC train shall be in operation.

LCO 3.4.8 The heat removal system shall be in the following status:

a. Two shutdown cooling (SC) trains shall be OPERABLE and one SC train shall be in operation; and

b. The containment spray pump in the same electrical division as the operating SC train shall be

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 93 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark OPERABLE.

None.

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

3. The containment spray pump in the same electrical division as the SC train in operation may be manually realigned to meet the requirements of its associated SC pump.

4. Operation in the mid-loop condition (RCS level 36.30 m (119 ft 1 in)) is allowed if the time after reactor shutdown is 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months and core exit temperature is maintained 57.2°C (135°F).

See III.5.2.1 CONDITION B. No Required SDC train OPERABLE.

OR Required SDC train not in operation.

CONDITION B. Two SC trains inoperable.

OR No SC train in operation.

The meanings of the CONDITION are practically the same.

None C. Containment Spray pump in the same electrical division as the operating SC train inoperable.

D. Required Action and associated Completion Time of Required Action C.3 not met.

E. Core exit temperature > 57.2°C (135°F) during mid-loop operation.

OR

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 94 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark RCS level 36.30 m (119 ft 1 in) with < 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months after reactor shutdown.

REQUIRED ACTION None REQUIRED ACTION AND B.3 Initiate action to establish 7 m (23 ft) of water above the top of the reactor vessel flange.

If shutdown cooling pump cannot be restored, RCS level should be raised. This will place the plant in a conservative position with respective to decay heat removal.

None C.1 If the containment spray pump in the same electrical division as the alternate SC train is OPERABLE, initiate action to place the alternate SC train in operation.

AND C.2 Monitor SC System performance.

AND C.3 Restore containment spray pump to OPERABLE statusU None D.1 Raise RCS level > 38.72 m (127 ft 1/4 in).

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 95 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark None E.1 Initiate action to restore core exit temperature to 57.2°C (135°F).

AND E.2 Initiate action to raise RCS level above mid-loop condition

(> 36.30 m (119 ft 1 in)).

SURVEILLANCE None SURVEILLANCE SR 3.4.8.1

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

Only required to be met when in mid-loop operation.

Verify core exit temperature is 57.2°C (135°F).

FREQUENCY 15 minutes SR 3.4.8.1 Verify required SDC train is in operation.

SR 3.4.8.2 Verify one SC train is in operation with circulating reactor coolant at a flow rate of 14,385 L/min (3,800 gpm) and < 15,710 L/min (4,150 gpm).

SR 3.4.8.2 Verify correct breaker alignment and indicated power available to each required SDC pump.

SR 3.4.8.3 Verify correct breaker alignment and indicated power available to the required SC pump.

None SR 3.4.8.4 Verify correct breaker alignment and indicated power available to the required containment spray pump that is not in operation.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 96 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark FREQUENCY 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months None SR 3.4.8.5 Verify required SC train locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY 31 days TSTF-523 (Managing Gas Accumulation) is applied to APR1400 Technical Specifications.

3.4.9 Pressurizer LCO 3.4.9

a. Pressurizer water level < [60]%

and

b. [Two groups of] pressurizer heaters OPERABLE with the capacity [of each group] [150 kw

[and capable of being powered from an emergency power supply].

LCO 3.4.9

a. Pressurizer water level 25%

and 56%, and

b. Two groups of pressurizer backup heaters OPERABLE with the capacity of each group 200 kw and capable of being powered from an emergency power supply.

The pressurizer water level of 25% is determined by considering the water level to prevent heater's burn-up from low water level. The pressurizer water level of 56% is to provide steam space for controlling pressurizer pressure.

Heater capacity is determined by considering heat loss from pressurizer insulation. The value of 200 kW is sufficient to add heat for controlling pressurizer pressure for APR1400.

APR1400 specific value used CONDITION None.

CONDITION B. Required Action and associated Completion Time of Condition A not met.

The deviations reflect the APR1400 plant specific operating practice.

B. One [required] group of pressurizer heaters inoperable.

C. One required group of pressurizer backup heaters inoperable.

C. Required Action and associated Completion Time of Condition B not met.

D. Required Action and associated Completion Time of Condition C not met.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 97 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION None.

REQUIRED ACTION A.1 Restore pressurizer water level within limit.

COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months The deviations reflect the APR1400 plant specific operating practice.

With PZR water level outside the limits, ACTION is taken within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to restore the plant to be operated within the bounds of the safety analyses. If PZR water level cannot be restored to within the limits in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , the plant is placed in MODES 3 with the reactor trip circuit breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

A.1 Be in MODE 3 with reactor trip breakers open.

AND A.2 Be in MODE 4.

B.1 Be in MODE 3 with reactor trip switch gears open.

AND B.2 Be in MODE 4.

The deviations reflect the APR1400 plant specific operating practice.

With PZR water level outside the limits, ACTION is taken within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to restore the plant to be operated within the bounds of the safety analyses. If PZR water level cannot be restored to within the limits in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , the plant is placed in MODES 3 with the reactor trip circuit breakers open within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

B.1 Restore [required] group of pressurizer heaters to OPERABLE status.

C.1 Be in MODE 3.

AND C.1 Restore required group of pressurizer backup heaters to OPERABLE status.

D.1 Be in MODE 3.

AND

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 98 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark C.2 Be in MODE 4.

D.2 Be in MODE 4.

SURVEILLANCE SR 3.4.9.1 Verify pressurizer water level is

< [60]%.

SURVEILLANCE SR 3.4.9.1 Verify pressurizer water level is 25% and 56%.

REVIEWERS NOTE---------

The frequency for performing pressurizer heater capacity testing shall be either 18 months or 92 days, depending on whether or not the plant has dedicated safety-related heaters. For dedicated safety-related heaters, which do not normally operate, 92 days is applied. For nondedicated safety-related heaters, which normally operate, 18 months is applied.

SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters [150] kW.

SR 3.4.9.2 Verify capacity of each required group of pressurizer backup heaters 200 kW.

SR 3.4.9.3 [ Verify required pressurizer heaters are capable of being powered from an emergency power supply.

SR 3.4.9.3 Verify that on an engineered safety features actuation test signal concurrent with a loss of offsite power:

a. Pressurizer backup heaters are automatically shed from emergency power sources.

b. Pressurizer backup heaters can be reconnected to their respective buses manually from the control room.

APR1400 pressurizer backup heaters can be manually transferred to be energized by emergency power supply.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 99 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.4.10 Pressurizer Safety Valves LCO 3.4.10

[Two] pressurizer safety valves shall be OPERABLE with lift settings [2475] psia and [2525]

psia.

LCO 3.4.10 Four pressurizer POSRVs shall be OPERABLE such that:

a. Two spring-loaded pilot valves shall be OPERABLE with lift settings 171.1 kg/cm2A (2,433 psia) and 176.3 kg/cm2A (2,507 psia).

b. The opening time of pressurizer POSRV shall be 0.5 seconds, including dead time.

The setpoint range is a APR1400 specific characteristic and the valve type is different.

Pressurizer Pilot Operated Safety Relief Valve (POSRV) is applied in APR1400.

The opening time is specified in the Design Specification and verified by test for APR1400 plant.

APPLICABILITY

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

The lift settings are not required to be within LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for [36] hours following entry into MODE 3 provided a preliminary cold setting was made prior to heatup APPLICABILITY

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

The opening time measurement and lift pressure setting of each POSRV are not required to be within LCO limits during MODES 3 and 4 for the purpose of setting the POSRVs under ambient (hot) conditions. This exception is allowed for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

The meanings of the APPLICABILITY are practically the same. The 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months exception is based on 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months outage time for each of the four valves (APR1400 adapts 4 POSRVs). The 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months period is determined based on operating experience.

See III.2.2.2 REQUIRED ACTION B.2 Be in MODE 4 with any RCS cold leg temperature less than or equal to the LTOP enable temperature specified in the PTLR.

REQUIRED ACTION B.2.1 Be in MODE 4 with all RCS cold leg temperatures less than or equal to LTOP enable temperature specified in PTLR.

OR B.2.2 Be in MODE 4 on shutdown cooling with requirements of LCO 3.4.11 met.

The REQUIRED ACTIONs reflect the APR1400 design.

When the POSRV(s) are inoperable, LTOP relief valves shall be aligned for OPP.

Alignment of LTOP relief valves can be allowed by meeting conditions by reducing the cold leg temperature down to the LTOP enable temperature and by opening SCS isolation valves.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 100 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SURVEILLANCE SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in accordance with the inservice Testing Program. Following testing, lift settings shall be within +/-1%.

SURVEILLANCE SR 3.4.10.1 Verify open and close positions for the following valves in the main control room (MCR):

a. Main valves - close,

b. Motor-operated isolation valves and manual isolation valves - open,

c. Spring-loaded pilot valves -

close, and

d. Motor-operated pilot valves

- close.

The SRs reflect POSRV characteristics.

The testing and inspection for POSRVs are given in DCD Section 5.2.2.10.

None SR 3.4.10.2 Verify electric power disconnections of the following motor-operated valves:

a. Motor-operated isolation valves and

b. Upstream valve of motor-operated pilot valves.

None SR 3.4.10.3 For each pressurizer POSRV:

a. Verify lift pressure settings of each of the two spring-loaded pilot valves are set 171.1 kg/cm2A (2,433 psia) and 176.3 kg/cm2A (2,507 psia).

b. Adjust each spring-loaded pilot valve, as necessary, so that the lift pressure settings are 172.4 kg/cm2A (2,451.4 psia) and 175.0 kg/cm2A (2,488.5 psia).

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 101 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

c. Verify opening time of pressurizer POSRV is 0.5 seconds, including dead time.

None SR 3.4.10.4 Verify alarm devices for valve positions and electric power connections of the following valves:

G

a. Motor-operated isolation valves - power connection

alarm,

b. Upstream valve of motor-operated pilot valves

- power connection alarm, and

c. Manual isolation valves -

not fully open alarm.

None SR 3.4.10.5 Verify position indicators of the following valves are operated normally:

a. Main valves,

b. Spring-loaded pilot valves,

c. Motor-operated pilot valves, and

d. Motor-operated isolation valves and manual isolation valves.

None SR 3.4.10.6 Verify downstream manual valves of spring-loaded pilot valves are locked in open position.

3.4.11 Pressurizer Power Operated Relief Valves The LCO is for PORV.

None There is no PORV in APR1400 (plant specific).

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 102 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark (PORVs) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12 An LTOP System shall be OPERABLE with a maximum of one high pressure safety injection (HPSI) pump and one charging pump capable of injecting into the RCS and the safety injection tanks (SITs) isolated, and:

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

1. [Two charging pumps] may be made capable of injecting for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for pump swap operations.

2. SIT may be unisolated when SIT pressure is less than the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

a. Two OPERABLE power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR or

b. The RCS depressurized and an RCS vent of [1.3] square inches.

LCO 3.4.11 LTOP System shall be OPERABLE as follows:

a. Two OPERABLE shutdown cooling system (SCS) suction line relief valves with lift settings specified in the pressure and temperature limits report (PTLR), or

b. RCS depressurized and an RCS vent of 180.6 cm2 (28 in2) established.

See III.5.2.2 ACTIONS

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

LCO 3.0.4.b is not applicable to ACTIONS None See III.5.2.2

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 103 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark PORVs when entering MODE 4.

CONDITION A. Two or more HPSI pumps capable of injecting into the RCS.

CONDITION None See III.5.2.2 B. Two or more charging pumps capable of injecting into the RCS.

None See III.5.2.2 C. A SIT not isolated when SIT pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

None See III.5.2.2 D. Required Action and associated Completion Time of Time of Condition C not met.

None See III.5.2.2 E. One required PORV inoperable in MODE 4.

A. One required SCS suction line relief valve inoperable in MODE 4.

Different valve name is used for APR1400.

F. One required PORV inoperable in MODE 5 or 6.

B. One required SCS suction line relief valve inoperable in MODE 5 or 6.

Different valve name is used for APR1400.

G. Two required PORVs inoperable.

OR Required Action and associated Completion Time of Condition A, [B], D, E, or F not met.

OR C. Required Action and associated Completion Time not met.

D. Two required SCS suction line relief valves inoperable.

C. When one SCS suction isolation valve is inoperable and the required action and associated completion time are not met in ACTION A or B, an additional action for preventing RCS pressurization should be taken such as establishing a vent.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 104 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark LTOP System inoperable for any reason other than Condition A, [B], C, D, E, or F.

D. If two LTOP relief valves are inoperable, an action for preventing RCS pressurization should be taken such as establishing a vent immediately.

Different valve name is used in APR1400.

SURVEILLANCE SR 3.4.12.1 Verify a maximum of one HPSI pump is capable of injecting into the RCS.

SURVEILLANCE None See III.5.2.2 SR 3.4.12.2 Verify a maximum of one charging pump is capable of injecting into the RCS.

None SR 3.4.12.3 Verify each SIT isolated.

None SR 3.4.12.4 Verify required RCS vent [1.3] square inches is open.

SR 3.4.11.1

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

Not required to be met if SR 3.4.11.2 is satisfied for LCO 3.4.11.b requirement.

Verify RCS vent of 180.6 cm2 (28 in2) is established.

RCS vent path is not required because LTOP relief valve setpoint is already adjusted for overpressure protection.

SR 3.4.12.5 Verify PORV block valve is open for each required PORV.

None During MODE 4~6, at least one SC train shall be in operation.

Therefore SCS suction line isolation valves (PORV block valves) are open.

SR 3.4.12.6

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

Not required to be performed until

[12] hours after decreasing RCS None LTOP relief valves are not a PORV but self-actuating type.

Therefore this SR is not required.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 105 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark cold leg temperature to less than or equal to the LTOP enable temperature specified in the PTLR.

Perform CHANNEL FUNCTIONAL TEST on each required PORV, excluding actuation.

SR 3.4.12.7 Perform CHANNEL CALIBRATION on each required PORV actuation channel.

SR 3.4.11.2

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

Not required to be met if SR 3.4.11.1 is satisfied for LCO 3.4.11.a requirement.

Verify set-point setting for each required SCS suction line relief valve is within limits.

LTOP relief valves are not a PORV but self-actuating type.

Therefore this SR is not required to prevent RCS over-pressurization.

3.4.13 RCS Operational LEAKAGE Same as NUREG-1432 3.4.12 for APR1400.

3.4.14 RCS Pressure Isolation Valve (PIV) Leakage APPLICABILITY MODE 4, except valves in the shutdown cooling (SDC) flow path when in, or during the transition to or from, the SDC mode of operation APPLICABILITY MODE 4, except valves in the shutdown cooling (SC) flow paths when in SC operation or during the transition to or from SC operation.

3.4.13 for APR1400.

REQUIRED ACTION

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

Each valve used to satisfy Required Action A.1 and Required Action A.2 must have been verified to meet SR 3.4.14.1 and be on the RCS pressure boundary [or the high pressure portion of the system].

A.2 [Isolate the high pressure REQUIRED ACTION

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

Each valve used to satisfy Required Actions A.1 and A.2 must have been verified to meet the Surveillance and Frequency of SR 3.4.13.1 and be on the reactor coolant pressure boundary.

A.2 An isolation may cause a loss of Residual Heat Removal (RHR).

The (automatic) isolation function is not used in APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 106 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.

[or]

Restore RCS PIV to within limits.

Restore RCS PIV leakage to within limits.

CONDITION C. Shutdown Cooling (SDC)

System autoclosure interlock function inoperable.

CONDITION C. SC System open permissive interlock function inoperable.

There is no auto-closure interlock in APR1400. OPP for SCS is performed by LTOP relief valves.

REQUIRED ACTION C.1 Isolate the affected penetration by use of one closed manual or deactivated automatic valve.

REQUIRED ACTION C.1 Depressurize RCS pressure below open permissive interlock setpoint.

An isolation may cause a loss of RHR. Therefore RCS should be depressurized for connecting SCS operation for residual heat removal.

SURVEILLANCE SR 3.4.14.1 Verify leakage from each RCS PIV is equivalent to 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure [2215] psia and [2255]

psia.

SURVEILLANCE SR 3.4.13.1 Verify leakage from each RCS PIV is equivalent to 1.89 L/min (0.5 gpm) per nominal 2.54 cm (1 in) of valve size up to a maximum of 18.9 L/min (5 gpm) at an RCS pressure 156.8 kg/cm2A (2,230 psia) and 159.6 kg/cm2A (2,270 psia).

FREQUENCY SR 3.4.14.1 In accordance with the Inservice Testing Program, and ((18] months AND FREQUENCY SR 3.4.13.1 18 months AND The valve leakage rate shall be verified for in-service after any maintenance, repair or replacement work.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 107 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Prior to entering MODE 2 determine the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months AND Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve Prior to entering MODE 2 whenever unit has been in MODE 5 for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or more, if leakage testing has not been performed in previous 9 months AND Prior to returning valve to service following maintenance, repair, or replacement work on valve AND Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve SURVEILLANCE SR 3.4.14.2

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

[ Not required to be met when the SDC System autoclosure interlock is disabled in accordance with SR 3.4.12.7.

Verify SDC System autoclosure interlock prevents the valves from being opened with a simulated or actual RCS pressure signal [425]

psig.

SURVEILLANCE SR 3.4.13.2

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

Not required if SC suction line isolation valves are open for Low Temperature Overpressure Protection (LTOP) by LCO 3.4.11.a.

Verify SC system open permissive interlock prevents the SC system suction line isolation valve from being opened with a simulated or actual RCS pressure signal 31.6 kg/cm2A (450 psia).

There is no auto closure interlock in APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 108 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SR 3.4.14.3

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

[ Not required to be met when the SDC System autoclosure interlock is disabled in accordance with SR 3.4.12.7.

Verify SDC System autoclosure interlock causes the valves to close automatically with a simulated or actual RCS pressure signal [600]

psig.

None There is no auto closure interlock in APR1400.

3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15

[Two of] the following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump monitor

b. One containment atmosphere radioactivity monitor (gaseous or particulate), and

c. One containment air cooler condensate flow rate monitor.]

LCO 3.4.14 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump level monitor,

b. One containment atmosphere radioactivity (particulate) monitor, and

c. One containment atmosphere humidity monitor.

1. For item 'a', Containment sump means containment sump level. Therefore they are the same.

2. For item 'c', the method used in APR1400 is one of the methods described in RG 1.45 Rev. 1.

CONDITION A. Containment sump monitor inoperable.

B. Required containment atmosphere radioactivity monitor inoperable.

C. [ Containment air cooler condensate flow rate monitor inoperable.

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

Only applicable when the CONDITION A. Required containment sump (level) monitor inoperable.

B. Required containment atmosphere radioactivity (particulate) monitor inoperable C. Required containment atmosphere humidity monitor inoperable.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 109 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark containment atmosphere gaseous radiation monitor is the only OPERABLE monitor.

D. Containment sump monitor inoperable.

AND

[ Containment air cooler condensate flow rate monitor inoperable. ]

E. [ Required containment atmosphere radioactivity monitor inoperable.

AND

[ Containment air cooler condensate flow rate monitor inoperable. ]

F. Required Action and associated Completion Time not met.

G. All required monitors inoperable.

D. Required containment sump (level) monitor inoperable.

AND Required containment atmosphere humidity monitor inoperable.

E. Required containment atmosphere radioactivity (particulate) monitor inoperable.

AND Required containment atmosphere humidity monitor inoperable.

F. Required containment sump (level) monitor inoperable.

AND Required containment atmosphere radioactivity (particulate) monitor inoperable.

G. Required Action and associated Completion Time not met.

H. All required monitors inoperable.

REQUIRED ACTION A.2 Restore containment sump monitor to OPERABLE status.

REQUIRED ACTION A.2 Restore required containment sump (level) monitor to OPERABLE status.

B.2.1 Restore required containment atmosphere radioactivity monitor to OPERABLE status.

B.2 Restore required containment atmosphere radioactivity (particulate) monitor to OPERABLE status.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 110 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark OR

[ B.2.2 Verify containment air cooler condensate flow rate monitor is OPERABLE.

C.1 Perform SR 3.4.15.1.

OR C.2 ---------------NOTE--------------

Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Perform SR 3.4.13.1.

C.1.1 Perform SR 3.4.14.1.

OR C.1.2 ---------------NOTE--------------

Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Perform SR 3.4.12.1.

AND C.2 Restore required containment atmosphere humidity monitor to OPERABLE status.

D.1 Analyze grab samples of the containment atmosphere.

AND D.2.1 Restore containment sump monitor to OPERABLE status.

OR

[ D.2.2 Restore containment air cooler condensate flow rate monitor to OPERABLE status. ]

D.1 Restore required containment sump (level) monitor to OPERABLE status.

OR D.2 Restore required containment atmosphere humidity monitor to OPERABLE status.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 111 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark E.1 Restore required containment atmosphere radioactivity monitor to OPERABLE status.

OR E.2 Restore containment air cooler condensate flow rate monitor to OPERABLE status.

E.1 Restore required containment atmosphere radioactivity (particulate) monitor to OPERABLE status.

OR E.2 Restore required containment atmosphere humidity monitor to OPERABLE status.

None F.1 Restore required containment sump (level) monitor to OPERABLE status.

OR F.2 Restore required containment atmosphere radioactivity (particulate) monitor to OPERABLE status.

F.1 Be in MODE 3.

AND F.2 Be in MODE 5.

G.1 Be in MODE 3.

AND G.2 Be in MODE 5.

G.1 Enter LCO 3.0.3.

H.1 Enter LCO 3.0.3.

SURVEILLANCE None SURVEILLANCE 3.4.14.2 Perform CHANNEL CHECK of the required containment atmosphere humidity monitor.G None 3.4.14.4 Perform CHANNEL FUNCTIONAL TEST of the required containment atmosphere humidity monitorG None 3.4.14.7

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 112 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Perform CHANNEL CALIBRATION of the required containment atmosphere humidity monitor.

3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

LCO 3.4.15 The specific activity of the reactor coolant shall be limited to:

a. DOSE EQUIVALENT I-131 specific activity 3.7E4 Bq/g (1.0 Ci/g) and

b. DOSE EQUIVALENT XE-133 specific activity 1.11E7 Bq/g (297.3 Ci/g).

See II.2.2 APPLICABILITY MODES 1 and 2, MODE 3 with RCS average temperature (Tavg) 500¶F APPLICABILITY MODES 1, 2, 3 and 4.

CONDITION B. Required Action and associated Completion Time of Condition A not met.

OR DOSE EQUIVALENT I-131 in the unacceptable region of Figure 3.4.16-1 C. Gross specific activity of the reactor coolant not within limit.

CONDITION B. DOSE EQUIVALENT XE-133 133 > 1.11E7 Bq/g (297.3 Ci/g).

C. Required Action and associated Completion Time of Condition A or B not met.

OR DOSE EQUIVALENT I-131

> 2.22E6 Bq/g (60 Ci/g).

See II.2.2

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 113 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION

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

LCO 3.0.4.c is applicable.

A.1 Verify DOSE EQUIVALENT I-131 within the acceptable region of Figure 3.4.16-1.

AND A.2 Restore DOSE EQUIVALENT I-131 to within limit.

REQUIRED ACTION

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

LCO 3.0.4 is not applicable.

A.1 Verify DOSE EQUIVALENT I-131 2.22E6 Bq/g (60 Ci/g)

AND A.2 Restore DOSE EQUIVALENT I-131 to within limit.

In order to be consistent with TSTF-490, Rev. 0, the relevant phrases are modified.

B.1 Be in MODE 3 with Tavg < 500¶F.

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

LCO 3.0.4 is not applicable.

B.1 Restore DOSE EQUIVALENT XE-133 to within limit.

In order to be consistent with TSTF-490, Rev. 0, the relevant phrases are modified.

- Related COMPLETION TIME is changed.

C.1 Be in MODE 3 with Tavg < 500¶F C.1 Be in MODE 3.

AND C.2 Be in MODE 5.

In order to be consistent with TSTF-490, Rev. 0, the relevant phrases are modified.

- Related COMPLETION TIME is changed.

SURVEILLANCE SR 3.4.16.1 Verify reactor coolant gross specific activity 100/ Ci/gm.

SURVEILLANCE SR 3.4.15.1

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

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT XE-133 specific activity 1.11E7 Bq/g (297.3 Ci/g).

In order to be consistent with the TSTF-490, Rev. 0, the contents are modified.

SR 3.4.16.3

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

Not required to be performed until 31 days after a minimum of 2 None In order to be consistent with the TSTF-490, Rev. 0, this item is deleted.

- The definition of is deleted in

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 114 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

"1.1 Definitions".

Figure 3.4.16-1 None In order to be consistent with TSTF-490, Rev. 0, the figure is deleted.

Addition

- Reactor Coolant Gas Vent (RCGV)

Function None LCO 3.4.16 The following RCGV flow paths shall be OPERABLE:

a. Two flow paths from the reactor vessel closure head to the in-containment refueling water storage tank (IRWST), and

b. Two flow paths from the pressurizer steam space to the IRWST.

APPLICABILITY MODES 1,2 and 3, MODE 4 with Shutdown Cooling (SC) System not aligned for Low Temperature Overpressure Protection (LTOP) of the reactor coolant pressure boundary (RCPB).

BTP RSB 5-4 requires as follows:

1. The design shall be such that the reactor can be taken from normal operating conditions to cold shutdown using only safety-grade systems.

2. RCGVS is a safety-grade means in order to use for pressure control during RCS cooling from the hot zero power to the entry condition of SCS.

Therefore it is controlled by LCO for operability.

Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 115 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.4.17 Special Test Exceptions (STE)-RCS Loops LCO 3.4.17 The requirements of LCO 3.4.4, "RCS Loops - MODES 1 and 2,"

and the listed requirements of LCO 3.3.1, "Reactor Protective System (RPS) Instrumentation -

Operating," for the [(Analog) RC flow low, thermal margin or low pressure, and asymmetric steam generator transient protective trip functions] [(Digital) high log power, high local power density, low departure from nucleate boiling ratio protective trip functions] may be suspended provided:

a. THERMAL POWER 5% RTP and

b. The reactor trip setpoints of the OPERABLE power level channels are set 20% RTP.

None These STEs are needed during a startup & PHYSICS TESTS in MODE 2 which means actually a Natural Circulation test at a criticality condition. APR1400 performs Natural Circulation test at Hot Standby condition, so these STEs are not required.

3.4.18 Steam Generator (SG) Tube Integrity LCO 3.4.18 SG tube integrity shall be maintained.

AND All SG tubes satisfying the tube repair criteria shall be plugged [or repaired] in accordance with the Steam Generator Program.

LCO 3.4.17 SG tube integrity shall be maintained.

AND All SG tubes satisfying the tube plugging criteria shall be plugged in accordance with the Steam Generator Program.

APR1400 does not have a repair method approved by NRC.

CONDITION A. One or more SG tubes satisfying the tube repair criteria and not plugged [or repaired] in accordance with the Steam CONDITION A. One or more SG tubes satisfying the tube plugging criteria and not plugged in accordance with the Steam Generator Program.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 116 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Generator Program.

SURVEILLANCE A. verify that each SG tube that satisfies the tube repair criteria is plugged [or repaired] in accordance with the Steam Generator Program.

SURVEILLANCE A. Verify each inspected SG tube that satisfies tube plugging criteria is plugged in accordance with Steam Generator Program.

3.5 EMERGENCY CORE COOLING SYSTEM (ECCS) 3.5.1 Safety Injection Tanks (SITs)

APPLICABILITY MODES 1 and 2, MODE 3 with pressurizer pressure

[700] psia.

APPLICABILITY MODES 1 and 2, MODES 3 and 4 with pressurizer pressure 50.3 kg/cm2A (715 psia).

See III.3.2.1 CONDITION A. One SIT inoperable due to boron concentration not within limits.

OR One SIT inoperable due to the inability to verify water level or pressure.

CONDITION A. One SIT inoperable due to boron concentration not within limits.

OR One SIT inoperable due to B-10 isotopic concentration not within limits.

OR One SIT inoperable due to the inability to verify water level or pressure.

Second part of condition added by RAI 496-8630, Question 6.03-10, Revision 2.

REQUIRED ACTION C.2 Reduce with pressurizer pressure to < [700] psia.

REQUIRED ACTION C.2 Reduce with pressurizer pressure to < 50.3 kg/cm2A (715 psia)

See III.3.2.1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 117 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark COMPLETION TIME 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 12 hours from NUREG-1432 Rev. 2 is used rather than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months from NUREG-1432 Rev. 3, 4. According to the NUREG-1432 Rev 04 Bases, the 12 hr is used as a pressure reduction time. Therefore, it seems appropriate to use 12 hr rather than 2 hr.

SURVEILLANCE SR 3.5.1.2 Verify borated water volume in each SIT is [28% narrow range (1802 cubic feet) and 72%

narrow range (1914 cubic feet)].

SURVEILLANCE SR 3.5.1.2 Verify borated water volume in each SIT is 29% and 69%

(% narrow range).

SR 3.5.1.3 Verify nitrogen cover pressure in each SIT is [615] psig and [655]

psig.

SR 3.5.1.3 Verify nitrogen cover-pressure in each SIT is 40.6 kg/cm2G (578 psig) and 43.9 kg/cm2G (624 psig).

SR 3.5.1.4 Verify boron concentration in each SIT is [1500] ppm and [2800]

ppm.

SR 3.5.1.4 Verify boron concentration in each SIT is 2,300 ppm and 4,400 ppm SR 3.5.1.3 Verify power is removed from each SIT isolation valve operator when pressurizer pressure is

[2000] psia.

SR 3.5.1.5 Verify power is removed from each SIT isolation valve operator when pressurizer pressure is 50.3 kg/cm2A (715 psia).

None SR 3.5.1.6 Verify isotopic concentration of B-10 in each SIT is within the limit specified in the COLR.

FREQUENCY 24 months Periodic verification that the isotopic concentration of Boron-10 in each SIT is within the limit specified in the COLR ensures that the Boron-10 isotopic concentration assumed Added by RAI 496-8630, Question 6.03-10, Revision 2.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 118 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark in the safety analysis is available. Since Boron-10 in the SITs is not directly exposed to a significant neutron flux and the IRWST water used as inventory for the SITs is only mixed with the reactor coolant during refueling outages, the Frequency of 24 months is considered conservative. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk.

3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains Shall be OPERABLE.

LCO 3.5.2 Four trains of SIS shall be OPERABLE.

See Section III.3.1 APPLICABILITY MODES 1, 2, and 3, with pressurizer pressure 1700 psia APPLICABILITY MODES 1, 2, and 3 See Section III.3.2.2 CONDITION

REVIEWERS NOTE-----

The adoption of this Condition is contingent upon implementation of a program to perform a contemporaneous assessment of the overall impact on safety of proposed plant configurations prior to performing and during performance of maintenance activities that remove equipment from service.

A. One LPSI subsystem Inoperable.

CONDITION A. One train inoperable

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 119 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark B. One or more trains inoperable for reasons other than Condition A.

C. Required Action and associated Completion Time not met.

D. Less than 100% of the ECCS flow equivalent to a single OPERABLE train available.

B. Two trains inoperable and diagonally oriented with respect to the reactor vessel (Trains 1 and 3, or Trains 2 and 4).

C. Required Action and associated Completion Time of Condition A or B not met.

D. Two or more trains inoperable for reasons other than Condition B.

REQUIRED ACTION A.1 Restore subsystem to OPERABLE status.

REQUIRED ACTION A.1 Restore train(s) to OPERABLE status.

See III.3.2.2 B.1 Restore train(s) to OPERABLE status.

B.1. Verify two trains diagonally oriented with respect to the reactor vessel are OPERABLE.

AND B.2. Restore trains to OPERABLE status.

C.2 Reduce pressurizer pressure to < [1700] psia.

C.2 Be in Mode 4.

See III.3.2.2 SURVEILLANCE SR 3.5.2.1 Verify the following valves are in the listed position with power to the valve operator removed [and key locked in position].

SURVEILLANCE SR 3.5.2.1 Verify the following hot leg injection isolation valves are locked in the close position: SI-321, SI-331, SI-604, and SI-609.

The valves with power to the valve operator removed are not applicable for APR1400.

SR 3.5.2.2 SR 3.5.2.2

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

Not required to be met for system vent flow paths opened under Activities for gas accumulation management are considered.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 120 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Verify each ECCS manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

administrative control.

Verify each SISGmanual, power-operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in correct position.

SR 3.5.2.3 Verify ECCS piping is full of water.

SR 3.5.2.3 Verify SIS piping locations susceptible to gas accumulation are sufficiently filled with water.

TSTF-523 (Managing Gas Accumulation) is applied to APR1400 Technical Specification SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow point is greater than or equal to the required developed head.

SR 3.5.2.4 Verify each safety injection pump develops required differential pressure on minimum flow of 123.8 kg/cm2D (1,761 psid).

SR 3.5.2.5

[ Verify each charging pump develops a flow of [36] gpm at a discharge pressure of [2200]

psig.

SR 3.5.2.5 Verify each SIS pump develops a flow of 3,407 L/min (900 gpm) at a differential pressure 86.9 kg/cm2D (1,236 psid).

The SI pumps are tested at rated flow condition (in addition to the miniflow condition) during power operations to enhance the capability of monitoring pump performance degradation.

SR 3.5.2.6 Verify each ECCS automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.6 Verify each SIS train automatic valve in the flow path actuates to the correct position on an actual or simulated actuation signal.

Not locked, sealed, or otherwise secured in position is unnecessary in SR 3.5.2.6.

SR 3.5.2.8 Verify each LPSI pump stops on an actual or simulated actuation signal.

None There is no LPSI pump in APR1400 plant design.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 121 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SR 3.5.2.9

[ Verify, for each ECCS throttle valve listed below, each position stop is in the correct position.

None The automatic valve and the part of the power operated valves which have throttling function are included in SR 3.5.2.2.

SR 3.5.2.10 Verify, by visual inspection, each ECCS train containment sump suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.

SR 3.5.2.8 Verify, by inspection, that the IRWST, holdup volume tank (HVT), IRWST strainers, HVT trash racks and IRWST spillways are not restricted by debris and strainers and trash racks show no evidence of structural distress or abnormal corrosion.

3.5.3 ECCS - ShutdownG LCO 3.5.3 One high pressure safety injection (HPSI) train shall be OPERABLE.

LCO 3.5.3 Two trains of SIS diagonally oriented with respect to the reactor vessel shall be OPERABLE.

See III.3.1 APPLICABILITY MODE 3 with pressurizer pressure

< [1700] psia, MODE 4.

APPLICABILITY MODES 4 and 5, MODE 6 with RCS level < 39.7 m (130 ft 0 in).

See III.3.2.2 ACTIONS

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

LCO 3.0.4.b is not applicable to ECCS High Pressure Safety Injection subsystem when entering MODE 4.

ACTIONS None See III.3.2.2 A. Required HPSI train inoperable.

A. Required SIS trains inoperable.

B. Required Action and associated Completion Time not met.

B. Required Action and associated Completion Time of Condition A not met.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 122 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION A.1 Restore required HPSI train to OPERABLE status.

B.1 Be in MODE 5 REQUIRED ACTION A.1 Restore required SIS trains to OPERABLE status.

B.1 Initiate actions to restore RCS level 39.7 m (130 ft 0 in)

AND B.2 Reduce RCS cold leg temperature to < 57.2¶C (135¶F)

See III.3.2.2 SURVEILLANCE SR 3.5.3.1 The following SRs are applicable:

[SR 3.5.2.1]

SR 3.5.2.2

[SR 3.5.2.3]

SR 3.5.2.4 SR 3.5.2.6 SR 3.5.2.7

[SR 3.5.2.9]

SR 3.5.2.10 SURVEILLANCE SR 3.5.3.1 The following SRs are applicable:

SR 3.5.2.1 SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 SR 3.5.2.6 SR 3.5.2.7, and SR 3.5.2.8 3.5.4 Refueling Water Tank (RWT)

LCO 3.5.4 The RWT shall be OPERABLE.

LCO 3.5.4 The IRWST shall be OPERABLE.

See II.5 APPLICABILITY MODES 1, 2, 3, and 4.

APPLICABILITY MODES 1, 2, 3, 4 and 5, MODE 6 with RCS level < 39.7 m (130 ft 0 in)

See III.3.2.3

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 123 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark CONDITION A. RWT boron concentration not within limits.

C. RWT borated water temperature not within limits.

CONDITION A. IRWST boron concentration not within limits.

OR IRWST B-10 isotopic concentration not within limits.

OR IRWST water temperature not within limits.

See III.3.2.3 Related REQUIRED ACTIONs and COMPLETIONs are changed.

B. Required Action and associated Completion Time of Condition A not met.

E. Required Action and associated Completion Time of Condition C or D not met.

C. Required Action and associated Completion Time of Condition A or B not met in MODES 1, 2, 3, or 4.

See III.3.2.3 D. RWT inoperable for reasons other than Condition A or C.

B. IRWST water volume not within limits.

See III.3.2.3 None D. Required Action and associated Completion Time of Condition A or B not met in MODE 5 or MODE 6 with RCS level < 39.7 m (130 ft 0 in).

See III.3.2.3 REQUIRED ACTION B.1

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

LCO 3.0.4.a is not applicable when entering MODE 3 or MODE 4.

Be in MODE 3.

E.1 Be in MODE 3.

REQUIRED ACTION None C.1 Be in MODE 3.

See III.3.2.3

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 124 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark AND E.2 Be in MODE 5.

AND C.2 Be in MODE 5.

None D.1 Initiate action to restore RCS level to 39.7 m (130 ft 0 in).

AND D.2 Reduce RCS cold leg temperature to < 57.2¶C (135¶F).

See III.3.2.3 SURVEILLANCE SR 3.5.4.1

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

[ Only required to be performed when ambient air temperature is

[40]¶F or [100]¶F. ]

Verify RWT borated water temperature is [40]°F and

[100]°F.

SR 3.5.4.2 Verify RWT borated water volume is [362,800 gallons, (88)%]

[above the ECCS suction connection].

SR 3.5.4.3 Verify RWT boron concentration is

[1720] ppm and [2500] ppm.

None SURVEILLANCE SR 3.5.4.1 None Verify IRWST water temperature is 10°C (50°F) and 49°C (120°F).

SR 3.5.4.2 Verify IRWST water volume is 2,373.5 m3 (627,000 gal) and 2,540.6 m3 (671,162 gal) (i.e.,

74.43% and 79.67%).

SR 3.5.4.3 Verify IRWST boron concentration is 4,000 ppm and 4,400 ppm.

SR 3.5.4.4 Verify isotopic concentration of B-10 in the IRWST is within the limit specified in the COLR.

The NOTE is not necessary for APR1400 since the IRWST is located in the reactor containment building and is not affected by changing the ambient air temperature.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 125 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark FREQUENCY 24 months 3.5.5 Trisodium Phosphate (TSP)

LCO 3.5.4 The TSP baskets shall contain

[291] ft3 of active TSP.

SURVEILLANCE SR 3.5.5.1 Verify the TSP baskets contain

[291] ft3 of trisodium phosphate.

LCO 3.5.4 The TSP baskets shall contain 29.5 m3 (1,042 ft3) of active TSP.

SURVEILLANCE SR 3.5.5.1 Verify the TSP baskets contain 29.5 m3 (1,042 ft3) of TSP.

This is an intrinsic design characteristic of APR1400.

The required volume of TSP for APR1400 is presented in Table 6.5-4 of Tier 2.

See II.5 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment Same as NUREG-1432 3.6.2 Containment Air Locks REQUIRED ACTION D.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in Mode 4.

REQUIRED ACTION D.2 Be in Mode 5.

See II.3.3 COMPLETION TIME D.2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMPLETION TIME D.2 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months See II.3.3 3.6.3 Containment Isolation Valves ACTIONS

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

1. Penetration flow paths [except for [24] inch purge valve penetration flow paths] may be unisolated intermittently under administrative controls.

ACTIONS

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

1. Penetration flow paths (except for 1219.2 mm (48 in) purge valve penetration flow paths) may be unisolated intermittently under administrative controls.

The NOTE reflects APR1400 plant specific design.

- NUREG-1432 : 42 inch

- APR1400 : 48 inch CONDITION A. ---------------NOTE---------------

Only applicable to the

[containment sump supply valves to the ECCS and CONDITION A. ---------------NOTE---------------

Only applicable to penetration flow paths with two or more containment isolation valves.

Condition A of NUREG-1432 only applicable to the containment isolation valves that do not meet the conditions to Related REQUIRED ACTION and COMPLETION

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 126 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark containment spray pumps].

One or more penetration flow paths with one containment isolation valve inoperable One or more penetration flow paths with one containment isolation valve inoperable (except for purge valve leakage not within limit).

extend the Completion Time to 7 days. APR1400 does not adopt NUREG-1432.

TIME are changed.

B. ---------------NOTE---------------

Only applicable to penetration flow paths with two [or more]

containment isolation valves.

One or more penetration flow paths with one containment isolation valve inoperable [for reasons other than Condition[s]

A, E, [and F)).

REQUIRED ACTION AND B.2 ------NOTES-------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected penetration flow path is isolated.

COMPLETION TIME B. ---------------NOTE---------------

Only applicable to those penetration flow paths with two or more containment isolation valves.

One or more penetration flow paths with two containment isolation valves inoperable (except for purge valve leakage not within limit).

REQUIRED ACTION None COMPLETION TIME See II.3.3 See II.3.3

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 127 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark B.1 [7 days]

B.2 Once per 31 days for isolation devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment]

B.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months None C. ---------------NOTE---------------

Only applicable to penetration flow paths with two [or more]

containment isolation valves.

One or more penetration flow paths with two [or more]

containment isolation valves inoperable [for reasons other than Condition[s] E [and F)).

REQUIRED ACTION None C. ---------------NOTE---------------

Only applicable to those penetration flow paths with only one containment isolation valve and a closed system.

One or more penetration flow paths with one containment isolation valve inoperable.

REQUIRED ACTION AND C.2 -------------NOTE------------

Isolation devices in high radiation areas may be verified by use of administrative means.

Verify affected penetration flow path is isolated.

APR1400 does not adopt NUREG-1432.

However APR1400 Condition-C is similar to NUREG-1432, Condition-D except the bracketed options and Completion Time is more conservative.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 128 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark COMPLETION TIME C.1 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months None COMPLETION TIME C.1 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months C.2 Once per 31 days See II.3.3 D. ---------------NOTE---------------

Only applicable to penetration flow paths with only one containment isolation valve and a closed system.

One or more penetration flow paths with one containment isolation valve inoperable.

REQUIRED ACTION D.1 Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, or blind flange.

None COMPLETION TIME D.1 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for those D. None One or more penetration flow paths with one or more containment purge valves not within purge valve leakage limits.

REQUIRED ACTION D.1 Isolate the affected penetration flow path by use of at least one closed and deactivated automatic valve with resilient seals, closed manual valve with resilient seals, or blind flange.

AND D.3 Perform SR 3.6.3.6 for resilient seal purge valves closed to comply with Required Action D.1.

COMPLETION TIME D.1 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months See II.3.3

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 129 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark penetrations that do not met the 7 day criteria AND 7 days for those penetrations that meet the 7 day criteria D.2 Once per 31 days None D.2 Once per 31 days for isolation devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment D.3 Once per 92 days E. [ One or more secondary containment bypass leakage [or purge valve leakage] not within limit.

None F. [ One or more penetration flow paths with one or more containment purge valves not within purge valve leakage limits.

None G. Required Action and associated Completion Time not met.

REQUIRED ACTION G.1 Be in Mode 3.

E. Required Action and associated Completion Time not met.

REQUIRED ACTION E. 1 Be in MODE 3.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 130 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark AND G.2 -------------NOTE------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

COMPLETION TIME G.2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C.2 Be in MODE 5.

COMPLETION TIME G.2 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE SR 3.6.3.1 [Verify each [42] inch purge valve is sealed closed except for one purge valve in a penetration flow path while in Condition E of this LCO.

SURVEILLANCE SR 3.6.3.1 Verify each 1219.2 mm (48 inch) purge valve is sealed closed except for one purge valve in a penetration flow path while in Condition D of this LCO.

The SR reflects APR1400 plant specific design.

- NUREG-1432 : 42 inch

- APR1400 : 48 inch SR 3.6.3.8 [ Verify each [ ] inch containment purge valve is blocked to restrict the valve from opening > [50]%.

None Design concept for containment purge valve is different between NUREG-1432 and APR1400.

SR 3.6.3.9 [ Verify the combined leakage rate for all secondary containment bypass leakage paths is [La] when pressurized to [ psig].

None The SR is not applicable because it deals with dual containments.

3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be

-0.3 psig and 1.5 psig.

LCO 3.5.3 Containment pressure shall be

-0.007 kg/cm2G (-0.1 psig) and

0.07 kg/cm2G (1.0 psig).

REQUIRED ACTION B.2 ------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

REQUIRED ACTION B.2 None For application of Mode 4, the guidance, as specified in Section 11 of NUMARC 93-01 and WCAP-16364-NP, shall be followed.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 131 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Be in MODE 4.

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

COMPLETION TIME B.2 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (Same reason described in LCO 3.6.2)

Same reason described in LCO 3.6.2 (See LCO 3.6.2) 3.6.5 Containment Air Temperature REQUIRED ACTION B.2 ------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

COMPLETION TIME B.2 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sG REQUIRED ACTION B.2 None Be in MODE 5.

COMPLETION TIME B.2 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months See II.3.3 3.6.6 Containment Spray and Cooling System LCO 3.6.6 Two containment spray trains and two containment cooling trains shall be OPERABLE.

LCO 3.6.6 Two Containment Spray divisions shall be OPERABLE.

Containment Cooling function is included in the Containment Spray System.

"Train" is changed to "Division".

Item name is changed.

- Containment Spray and Cooling System Containment Spray System Containment Spray System provides the heat removal function from containment atmosphere following a LOCA.

Containment Cooling System does not apply for APR1400.

COMPLETION TIME A.1 [7] days COMPLETION TIME A.1 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months See III.6.2.1

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 132 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION B.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION B.2 None Be in MODE 5.

See II.3.3 CONDITION C. One containment cooling train inoperable.

CONDITION None Containment Cooling function is included in the Containment Spray System.

D. One containment spray and one containment cooling train inoperable.

None E. Two containment cooling trains inoperable.

None F. Required Action and associated Completion Time of Condition C, D, or E not met.

None G. Two containment spray trains inoperable.

OR Any combination of three or more trains inoperable.

C. Two containment spray divisions inoperable.

"Train" is changed to "Division".

SURVEILLANCE SR 3.6.6.1 None SR 3.6.6.2 Operate each containment cooling train fan SURVEILLANCE SR 3.6.6.1

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

Not required to be met for system vent flow paths opened under administrative control.

None Containment Cooling function is included in the Containment Spray System.

NOTE was added to SR 3.6.6.1 by RAI 478-8568, Question 16-140, Revision 1.

Activities for gas accumulation management are considered.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 133 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark unit for 15 minutes.

SR 3.6.6.3 Verify each containment cooling train cooling water flow rate is [2000] gpm to each fan cooler.

SR 3.6.6.4 [ Verify the containment spray piping is full of water to the [100] ft level in the containment spray header.

SR 3.6.6.8 Verify each containment cooling train starts automatically on an actual or simulated actuation signal.

None None SR 3.6.6.6 Verify the containment spray piping is full of water to the 26.213 m (86 ft) level in the containment spray header None SR 3.6.6.7 Verify containment spray locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.6.6.7 added by RAI 478-8568, Question 16-140, Revision 1.

3.6.7 Spray Additive System LCO 3.6.7 The Spray Additive System shall be OPERABLE.

None See III.6.2.2 Addition

- Containment Penetrations -

Shutdown Operations None 3.6.7 Containment Penetrations -

Shutdown Operations LCO The containment building penetrations shall be in the following status:

a. The equipment hatch closed and held in place by a minimum of [four bolts,]

b. One door in each airlock During reduced RCS inventory operation, a release of fission products within the containment to the environment is restricted.

Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 134 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

closed,

c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere is either:

1. Closed by a manual or automatic isolation valve, or blind flange, or

2. Exhausting through OPERABLE Containment Purge System air cleaning units (ACUs), and is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.

APPLICABILITY MODE 5 with any Reactor Coolant System (RCS) loop not filled, MODE 6 with water level < 7.0 m (23 ft) above the top of the reactor vessel flange.

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

The equipment hatch shall be closed and held in place by a minimum of [four bolts] before opening the pressurizer manway in MODE 5.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 135 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.6.8 Shield Building Exhaust Air Cleanup System (SBEACS)

None APR1400 does not have this system.

3.6.9 Hydrogen Mixing System (HMS)

None See III.6.2.3 3.6.10 Iodine Cleanup System (ICS)

None See III.6.2.4 3.6.11 Shield Building None APR1400 does not have this system.

3.6.12 Vacuum Relief Valves None APR1400 does not have this system.

3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)

CONDITION BGRequired Action and associated Completion Time not met.

OR One or more steam generators with less than [two] MSSVs OPERABLE.

CONDITION BGRequired Action and associated Completion Time not met.

OR One or more steam generators with less than five MSSVs OPERABLE.

REQUIRED ACTION A.2 Reduce the [variable overpower trip - high] setpoint

[ceiling] in accordance with Table 3.7.1-1.

REQUIRED ACTION A.2 Reduce maximum variable overpower trip setpoint in accordance with Table 3.7.1-1.

SURVEILLANCE SR 3.7.1.1 Verify each required MSSV lift setpoint per Table 3.7.1-2 in accordance with the Inservice Testing Program. Following testing, lift settings shall be within

+/- 1%.

SURVEILLANCE SR 3.7.1.1 Verify each required MSSV is within +/-3% of the lift setting value stated in Table 3.7.1-2, in accordance with the In-service Testing Program. If the lift setting is found to be outside the calibration There is no difference of bases for surveillance requirements between NUREG-1432 and APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 136 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark tolerance of +/-1% of the lift setting value stated in Table 3.7.1-2, the valve lift setting shall be reset to within the calibration tolerance.

Table 3.7.1-2 LIFT SETTING (psig +/- [3]%)

None Table 3.7.1-2 LIFT SETTING (psig +/-1%)

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

Each MSSVs as-found lift setting shall be within +/-3% of the lift setting value stated in Table 3.7.1-2 for the valve to be considered OPERABLE.

The valves lift setting shall be reset to within the calibration tolerance of

+/-1% of the lift setting value stated in Table 3.7.1-2 if the lift setting is found to be outside the calibration tolerance.

3.7.2 Main Steam Isolation Valves (MSIVs)

LCO 3.7.2

[Two] MSIVs shall be OPERABLE.

LCO 3.7.2 Four MSIVs shall be OPERABLE.

3.7.3 Main Feedwater Isolation Valves (MFIVs) [and

[MFIV] Bypass Valves]

Same as NUREG-1432 MFIV bypass valves not included in APR1400.

3.7.4 Atmospheric Dump Valves (ADVs)

REQUIRED ACTION None A.1 Restore MSADV line to OPERABLE status REQUIRED ACTION

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

LCO 3.0.4 is not applicable.

A.1 Restore MSADV line to OPERABLE status In order to be consistent with the justification of LCO 3.0.4 in the APR1400 DCD Tier 2.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 137 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.7.5 Auxiliary Feedwater (AFW)

System LCO 3.7.5

[Three] AFW trains shall be OPERABLE

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

Only one AFW train, which includes a motor driven pump, is required to be OPERABLE in MODE 4.

LCO 3.7.5 Two auxiliary feedwater (AFW) divisions, each with one motor driven train and one turbine driven train, shall be OPERABLE

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

Only the motor driven train of one AFW division is required to be OPERABLE in MODE 4.

Design concept and configuration for AFWS are different between NUREG-1432 and APR1400.

- NUREG-1432 : 3 trains (Two motor driven pump trains and one turbine driven pump train)

- APR1400 : 4 trains (Two motor driven pump trains and two turbine driven pump trains)

ACTION

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

LCO 3.0.4.b is not applicable.

ACTION None Risk informed Technical Specification is not applied for APR1400. (Refer to the justification of LCO 3.0.4.)

CONDITION A. [ Turbine driven AFW train inoperable due to one inoperable steam supply.

OR

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

Only applicable if MODE 2 has not been entered following refueling.

One turbine driven AFW pump inoperable in MODE 3 following refueling.

REQUIRED ACTION A.1 Restore affected equipment to OPERABLE status.

CONDITION A. One AFW division with one train inoperable in MODE 1, 2, or 3.

REQUIRED ACTION A.1 Restore train to OPERABLE status.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 138 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark B. One AFW train inoperable in MODE 1, 2, or 3 [for reasons other than Condition A].

REQUIRED ACTION B.1 Restore AFW train to OPERABLE status.

B. Two AFW divisions with one train inoperable in MODE 1, 2, or 3.

REQUIRED ACTION B.1 Restore two trains of an AFW division to OPERABLE status.

C. Turbine driven AFW train inoperable due to one inoperable steam supply.

AND One motor driven AFW train inoperable.

REQUIRED ACTION C.1 Restore the steam supply to the turbine driven train to OPERABLE status.

OR C.2 Restore the motor driven AFW train to OPERABLE status.

C. One AFW division with two trains inoperable in MODE 1, 2, or 3.

REQUIRED ACTION C.1 Restore one train of affected AFW division to OPERABLE status.

D. Required Action and associated Completion Time of Condition A

[,B, or C] not met.

[ OR

[Two] AFW trains inoperable in MODE 1, 2, or 3 for reasons other than Condition C. ]

D. Required Action and associated Completion Time of Condition A, B, or C not met.

OR Three AFW trains inoperable in MODE 1, 2, or 3.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 139 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark E. ((Three] AFW trains inoperable in MODE 1, 2, or 3.

REQUIRED ACTION E.1 Initiate action to restore one AFW train to OPERABLE status.

E. Four AFW trains inoperable in MODE 1, 2, or 3.

REQUIRED ACTION E.1 Initiate action to restore one AFW train to OPERABLE status.

F. Required AFW train inoperable in MODE 4.

REQUIRED ACTION F.1 ------------NOTE------------

LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.

Initiate action to restore one AFW train to OPERABLE status.

F. Two AFW motor driven trains inoperable in MODE 4.

REQUIRED ACTION

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

LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW motor driven train is restored to OPERABLE status.

F.1 Initiate action to restore one AFW motor driven train to OPERABLE status.

SURVEILLANCE SR 3.7.5.1 Verify each AFW manual, power operated, and automatic valve in each water flow path and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SURVEILLANCE SR 3.7.5.5 Verify each manual, power-operated, and automatic valve in the flow path of each AFW train and in the steam supply flow path of each AFW turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.5.2

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

Not required to be performed for the turbine driven AFW pump until SR 3.7.5.2

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

Not required to be performed for AFW turbine driven pumps until

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 140 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

[24] hours after reaching [800] psig in the steam generators.

Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching 69.25 kg/cm2G (985 psig) in steam generators.

Verify developed head of each AFW pump at flow test point is greater than or equal to required developed head.

SR 3.7.5.3

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

1. Not required to be performed for the turbine driven AFW pump until [24] hours after reaching

[800] psig in the steam generators.

2. Not required to be met in MODE 4 when steam generator is relied upon for heat removal.

SR 3.7.5.3

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

Not required to be met in MODE 4 when steam generator is relied upon for heat removal.

SR 3.7.5.4

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

1. Not required to be performed for the turbine driven AFW pump until [24] hours after reaching

[800] psig in the steam generators.

2. Not required to be met in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW pump starts automatically on an actual or simulated actuation signal when in MODE 1, 2, or 3.

SR 3.7.5.4

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

1. Not required to be performed for AFW turbine driven pumps until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching 69.25 kg/cm2G (985 psig) in steam generators.

2. Not required to be met in MODE 4 when steam generator is relied upon for heat removal.

Verify each AFW pump starts automatically on an actual or simulated actuation signal.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 141 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark SR 3.7.5.5 Verify the proper alignment of the required AFW flow paths by verifying flow from the condensate storage tank to each steam generator.

SR 3.7.5.5 Verify the proper alignment of required AFW flow paths of each train of each AFW division by verifying flow from the associated auxiliary feedwater storage tank to the associated steam generator.

AFW is supplied from its exclusive AFWST in APR1400 design.

3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 The CST shall be OPERABLE.

LCO 3.7.6 Two AFWSTs shall be OPERABLE.

Design concept and configuration for AFWS are different between NUREG-1432 and APR1400.

- NUREG-1432: A common CST is used.

- APR1400: Two 100% capacity Auxiliary Feedwater Storage Tanks (AFWSTs) are installed.

If one AFWST is not operable, the other AFWST as backup water source provides water to the steam generators.

CONDITION A. CST inoperable.

CONDITION A. One AFWST inoperable.

REQUIRED ACTION A.1 Verify OPERABILITY of backup water supply.

AND A.2 Restore CST to OPERABLE status.

REQUIRED ACTION A.1 Verify OPERABILITY of backup water supply and the other AFWST.

AND A.2 Restore AFWST to OPERABLE status.

SURVEILLANCE SR 3.7.6.1 Verify CST level is [350,000] gal.

SURVEILLANCE SR 3.7.6.1 Verify each AFWST level is

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 142 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 1,524,165 L (400,000 gal).

3.7.7 Component Cooling Water (CCW)

System LCO 3.7.7 Two CCW trains shall be OPERABLE.

LCO 3.7.7 Two component cooling water (CCW) divisions shall be OPERABLE.

"Train" is changed to "Division".

REQUIRED ACTION A.1 -------------NOTE--------------

Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops -

MODE 4," for shutdown cooling made inoperable by CCW.

Restore CCW train to OPERABLE status.

REQUIRED ACTION

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

1. Enter applicable Conditions and Required Actions of LCO 3.8.1, AC Sources - Operating, for emergency diesel generator made inoperable by CCW.

2. Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4," for shutdown cooling made inoperable by CCW.

A.1 Restore CCW division to OPERABLE status.

This is an intrinsic design characteristic of APR1400.

"Train" is changed to "Division".

B.2 -------------NOTES--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

B.2 None Be in MODE 5.

See II.3.3 3.7.8 Service Water System (SWS)

LCO 3.7.8 Two SFS trains shall be OPERABLE.

LCO 3.7.8 Two ESWS divisions shall be OPERABLE.

"Train" is changed to "Division".

REQUIRED ACTION B.2 -------------NOTE---------------

LCO 3.0.4.a is not applicable when entering MODE 4.

REQUIRED ACTION B.2 None See II.3.3

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 143 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Be in MODE 4.

Be in MODE 5.

3.7.9 Ultimate Heat Sink (UHS)

LCO 3.7.9 The UHS shall be OPERABLE.

LCO 3.7.9

[Two] UHS [divisions] shall be OPERABLE.

See III.7.2.1 CONDITION A. [One or more cooling towers with one cooling tower fan inoperable.

CONDITION A. [One UHS cooling tower inoperable.]

See III.7.2.1 Related REQUIRED ACTIONs and COMPLETION TIMEs are changed.

B. Required Action and associated Completion Time of Condition A or B not met.

B. [Required Action and associated Completion Time of Condition A not met.

OR]

UHS inoperable [for reasons other than condition A.]

See III.7.2.1

REVIEWERS NOTES--------

The [ ]°F is the maximum allowed UHS temperature value and is based on temperature limitations of the equipment that is relied upon for accident mitigation and safe shutdown of the unit.

C. [Water temperature of the UHS

> [90]°F and [ ]°F None CONDITION C of NUREG-1432 is included in CONDITION B of APR1400.

D. [Required Action and associated Completion Time of Condition C not met.

None CONDITION D of NUREG-1432 is included in CONDITION B of APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 144 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark OR]

UHS inoperable [for reasons other than condition A or C.]

REQUIRED ACTION B.2 -------------NOTES--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4 REQUIRED ACTION B.2 None Be in MODE 5 See II.3.3 SURVEILLANCE SR 3.7.9.1 [ Verify water level of UHS is [562] ft [mean sea level].

SURVEILLANCE SR 3.7.9.1 Verify water level of UHS is [7.90 m (25.93 ft) from the bottom of the basin].

The SR reflects design characteristic of APR1400.

SR 3.7.9.2 [Verify average water temperature of UHS is

[90]°F.

SR 3.7.9.2 Verify water temperature of UHS [basin] is

[33.2°C (91.8°F)].

None None SR 3.7.9.4

[Verify each UHS manual, power-operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed or otherwise secured in position, is in the correct position.]

SR 3.7.9.5

[Verify each UHS automatic valve and each control valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to correct position on an actual or simulated actuation signal.]

Other SRs are added because of an intrinsic design characteristic of APR1400.

- SR 3.7.9.4

- SR 3.7.9.5

- SR 3.7.9.6

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 145 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark None SR 3.7.9.6

[Verify each cooling tower fan starts automatically on an actual or simulated actuation signal.]

3.7.10 Essential Chilled Water (ECW) 3.7.10 Essential Chilled Water (ECW) 3.7.10 Essential Chilled Water System (ECWS)

"Train" is changed to "Division".

REQUIRED ACTION B.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION B.2 None Be in MODE 5.

See II.3.3 3.7.11 Control Room Emergency Air Cleanup System (CREACS) 3.7.11 Control Room Emergency Air Cleanup System (CREACS) 3.7.11 Control Room Heating, Ventilation, and Air Conditioning HVAC System (CRHS) 3.7.11 CREACS and 3.7.12 CREATCS of NUREG-1432 are combined into 3.7.11 Control Room HVAC System (CRHS) of APR1400.

LCO 3.7.11 Two CREACS trains shall be OPERABLE.

LCO 3.7.11 Two Control Room Emergency Makeup Air Cleaning System (CREACS) divisions and two Control Room Supply and Return System (CRSRS) divisions of the CRHS shall be OPERABLE.

LCO 3.7.11 and LCO 3.7.12 of NUREG-1432 are combined into LCO 3.7.11 of APR1400.

APPLICABILITY During movement of [recently]

irradiated fuel assemblies.

APPLICABILITY During movement of irradiated fuel assemblies.

CONDITION A. One CREACS train inoperable for reasons other than Condition B.

CONDITION A. One CREACS division inoperable for reasons other than Condition C.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 146 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark None B. One CRSRS division inoperable.

REQUIRED ACTION B.1 Restore CRSRS division to OPERABLE status.

COMPLETION TIME 7 days B. One or more CREACS trains inoperable due to inoperable CRE boundary in MODE 1, 2, 3, or 4.

REQUIRED ACTION B.2 Verify mitigating actions ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

C. One or two CREACS divisions inoperable due to inoperable CRE boundary in MODE 1, 2, 3, or 4 REQUIRED ACTION C.2 Verify mitigating actions to ensure CRE occupant exposures to radiological, [toxic gas,] and smoke hazards will not exceed limits.

C. Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, 3, or 4.

REQUIRED ACTION C.2 -------------NOTE-------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

D. Required Action and associated Completion Time of Condition A, B, or C not met in MODE 1, 2, 3 or 4.

REQUIRED ACTION D.2 None Be in MODE 5.

See II.3.3 D. Required Action and associated Completion Time of Condition A not met [in MODE 5 or 6, or]

during movement of [recently]

irradiated fuel assemblies.

E. Required Action and associated Completion Time of Condition A or B not met [in MODE 5 or 6, or] during movement of irradiated fuel assemblies.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 147 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION D.1 ---------------NOTE--------------

Place in toxic gas protection mode if automatic transfer to toxic gas protection mode is inoperable.

Place OPERABLE CREACS train in emergency radiation protection mode.

OR D.2 Suspend movement of

[recently] irradiated fuel assemblies.

REQUIRED ACTION

[----------------NOTE-------------------

Place CRHS in toxic gas isolation mode if automatic transfer to toxic gas isolation mode is inoperable.

]

E.1 Place CREACS and CRSRS of an OPERABLE CRHS division in emergency mode.

OR E.2[.1] Suspend movement of irradiated fuel assemblies.

[AND E.2.2 Suspend operations with a potential for releasing radioactivity from the Gaseous Radwaste System.

The NOTE for toxic gas isolation mode is enclosed in brackets as a COL action item in APR1400.

The bracketed Required ACTION E.2.2 is added as a COL action item in APR1400.

E. Two CREACS trains inoperable

[in MODE 5 or 6, or] during movement of [recently]

irradiated fuel assemblies.

OR One or more CREACS trains inoperable due to an inoperable CRE boundary [in MODE 5 or 6, or] during movement of

[recently] irradiated fuel assemblies.

F. Two CREACS divisions inoperable [in MODE 5 or 6, or]

during movement of irradiated fuel assemblies.

OR One or two CREACS divisions inoperable due to inoperable CRE boundary [in MODE 5 or 6, or] during movement of irradiated fuel assemblies.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 148 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION E.1 Suspend movement of

[recently] irradiated fuel assemblies.

REQUIRED ACTION F.1 Suspend movement of irradiated fuel assemblies.

[AND F.2 Suspend operations with a potential for releasing radioactivity from the Gaseous Radwaste System.

The bracketed Required ACTION F.2 is added as a COL action item in APR1400.

F. Two CREACS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.

G. Two CREACS divisions inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition C.

OR Two CRSRS divisions inoperable in MODE 1, 2, 3, or 4.

SURVEILLANCE SR 3.7.11.1 Operate each CREACS train for

[ 10 continuous hours with heaters operating or (for systems without heaters) 15 minutes].

SURVEILLANCE SR 3.7.11.1 Operate each CREACS division for 15 minutes with heaters operating.

TSTF-522-A, Rev. 0 (Revise Ventilation System Surveillance Requirements to Operate for 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months per Month) is applied to APR1400 NRC DCD Technical Specifications.

SR 3.7.11.3 Verify each CREACS train actuates on an actual or simulated actuation signal.

SR 3.7.11.3 Verify active components in each CRHS division actuate on an actual or simulated actuation signal.

None SR 3.7.11.5 Verify each CRSRS division has the capacity to remove design heat load.

SR 3.7.11.5 from combining 3.7.11 (CREACS) and 3.7.12 (CREATCS) of NUREG-1432 into 3.7.11 (CRHS) of APR1400

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 149 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark and reflects SR 3.7.12.1 of NUREG-1432.

3.7.12 Control Room Emergency Air Temperature Control System (CREATCS) 3.7.12 Control Room Emergency Air Temperature Control System (CREATCS) 3.7.11 Control Room Heating, Ventilation, and Air Conditioning (HVAC) System (CRHS) 3.7.11 CREACS and 3.7.12 CREATCS of NUREG-1432 are combined into 3.7.11 Control Room HVAC System (CRHS) of APR1400.

LCO 3.7.12 Two CREATCS trains shall be OPERABLE.

LCO 3.7.11 Two Control Room Emergency Makeup Air Cleaning System (CREACS) divisions and two Control Room Supply and Return System (CRSRS) divisions of the CRHS shall be OPERABLE.

LCO 3.7.11 and LCO 3.7.12 of NUREG-1432 are combined into LCO 3.7.11 of APR1400.

3.7.13 Emergency Core Cooling System (ECCS) Pump Room Exhaust Air Cleanup System (PREACS) 3.7.13 Emergency Core Cooling System (ECCS) Pump Room Exhaust Air Cleanup System (PREACS) 3.7.12 Auxiliary Building Controlled Area Emergency Exhaust System (ABCAEES) 3.7.12 ABCAEES of APR1400 has both functions of 3.7.13 ECCS PREACS and 3.7.15 PREACS of NUREG-1432.

LCO 3.7.13 Two ECCS PREACS trains shall be OPERABLE.

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

The ECCS pump room boundary may be opened intermittently under administrative control.

LCO 3.7.12 Two ABCAEES divisions shall be OPERABLE.

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

The mechanical penetration room and safety-related mechanical equipment room boundary may be opened intermittently under administrative control.

3.7.12 ABCAEES of APR1400 serves all areas which are served by 3.7.13 ECCS PREACS and 3.7.15 PREACS of NUREG-1432.

The ECCS pump rooms of NUREG-1432 are included in the safety-related mechanical equipment rooms of APR1400.

CONDITION A. One ECCS PREACS train inoperable.

CONDITION A. One ABCAEES division inoperable.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 150 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark B. Two ECCS PREACS trains inoperable due to inoperable ECCS pump room boundary.

B.GTwo ABCAEES divisions inoperable due to inoperable mechanical penetration room or safety-related mechanical equipment room boundary.

REQUIRED ACTION A.1 Restore ECCS PREACS train to OPERABLE status.

B.1 Restore ECCS pump room boundary to OPERABLE status.

C.2.---------NOTE-----------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION A.1 Restore inoperable ABCAEES division to OPERABLE status.

B.1 Restore mechanical penetration room and safety-related mechanical equipment room boundary.

C.2. None Be in MODE 5.

See II.3.3 SURVEILLANCE SR 3.7.13.1 Operate each ECCS PREACS train for [ 10 continuous hours with heaters operating or (for systems without heaters) 15 minutes].

SURVEILLANCE SR 3.7.12.1 Operate each ABCAEES division for 15 minutes with heaters operating.

TSTF-522-A, Rev. 0 (Revise Ventilation System Surveillance Requirements to Operate for 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months per Month) is applied to APR1400 NRC DCD Technical Specifications.

SR 3.7.13.4 Verify one ECCS PREACS train can maintain a negative pressure

[ ] inches water gauge relative to atmospheric pressure during the

[post accident] mode of operation at a flow rate of [20,000] cfm.

SR 3.7.12.4 Verify the mechanical penetration rooms and the safety-related mechanical equipment rooms can be maintained at a pressure of

-6.35 mm (-0.25 inches) water gauge with respect to the adjacent areas using one ABCAEES division during post accident mode of operation at a flow rate of 5,097 cmh (3,000 cfm) within 300

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 151 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark seconds after a start signal.

SR 3.7.13.5 [Verify each ECCS PREACS filter bypass damper can be opened.

None The filter bypass damper is not used in ABCAEES of APR1400.

3.7.14 Fuel Building Air Cleanup System (FBACS)

LCO 3.7.14 Two FBACS trains shall be OPERABLE.

APPLICABILITY

[MODES 1, 2, 3, and 4,]

During movement of [recently]

irradiated fuel assemblies.

LCO 3.7.13 Two FHAEES divisions shall be OPERABLE APPLICABILITY During movement of irradiated fuel assemblies in the fuel handling area.

"Train" is changed to "Division".

CONDITION A. One FBACS train inoperable.

B. Two FBACS trains inoperable due to inoperable fuel building boundary in MODE 1, 2, 3, or 4.

C. [ Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, 3, or 4.

OR Two FBACS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.

D. Required Action and Associated Completion Time [of Condition A] not met during movement of

[recently] irradiated fuel assemblies in the fuel building.

CONDITION A. One FHAEES division inoperable.

None None B. Required Action and associated Completion Time of Condition A not met during movement of irradiated fuel assemblies in fuel handling area.

Related REQUIRED ACTIONs and COMPLETION TIMEs are deleted.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 152 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark E. Two FBACS trains inoperable during movement of [recently]

irradiated fuel assemblies in the fuel building.

C. Two FHAEES divisions inoperable during movement of irradiated fuel assemblies in fuel handling area.

SURVEILLANCE SR 3.7.14.1 Operate each FBACS train for

[ 10 continuous hours with heaters operating or (for systems without heaters) 15 minutes].

SURVEILLANCE SR 3.7.13.1 Operate each FHAEES division for 15 minutes with heaters operating.

TSTF-522-A, Rev. 0 (Revise Ventilation System Surveillance Requirements to Operate for 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months per Month) is applied to APR1400 NRC DCD Technical Specifications.

SR 3.7.14.4 Verify one FBACS train can maintain a negative pressure [ ]

inches water gauge with respect to atmospheric pressure, during the

[post accident] mode of operation at a flow rate [3000] cfm.

SR 3.7.13.4 Verify one FHAEES division can maintain a slightly negative pressure with respect to atmospheric pressure during post-accident mode of operation at a flow rate of 8,495 cmh (5,000 cfm).

SR 3.7.14.5 [Verify each FBACS filter bypass damper can be opened.

None The filter bypass damper is not used in FHAEES of APR1400.

3.7.15 Penetration Room Exhaust Air Cleanup System (PREACS) 3.7.15 Penetration Room Exhaust Air Cleanup System (PREACS) 3.7.12 Auxiliary Building Controlled Area Emergency Exhaust System (ABCAEES) 3.7.12 ABCAEES of APR1400 has both function of 3.7.13 ECCS PREACS and 3.7.15 PREACS of NUREG-1432.

LCO 3.7.15

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

The penetration room boundary may be opened intermittently under administrative control.

LCO 3.7.12

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

The mechanical penetration room and safety-related mechanical equipment room boundary may be opened intermittently under administrative control.

3.7.12 ABCAEES of APR1400 serves all areas those are served by 3.7.13 ECCS PREACS and 3.7.15 PREACS of NUREG-1432.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 153 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark REQUIRED ACTION C.2.---------NOTE-----------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION B.2. None Be in MODE 5.

See II.3.3 CONDITION B. Two PREACS trains inoperable due to inoperable penetration room boundary CONDITION None To adopt condition B, the licensee should have guidance available describing compensatory measures to be taken in the event of an intentional and unintentional entry into condition B.

However, APR1400 does not have any guidance describing compensatory measures to be taken in the event of entry into condition B.

For that reason, APR1400 does not adopt condition B.

SURVEILLANCE SR 3.7.15.4 [Verify each PREACS filter bypass damper can be opened.

SURVEILLANCE None The filter bypass damper is not used in ABCAEES of APR1400.

3.7.16 Fuel Storage Pool Water Level Same as NUREG-1432 This item is equivalent to 3.7.14 Spent Fuel Pool Water Level (SFPWL) of APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 154 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.7.17 Fuel Storage Pool Boron Concentration LCO 3.7.17 The fuel storage pool boron concentration shall be [2000]

ppm.

ACTIONS CONDITION A. Spent fuel pool boron concentration not within limit.

REQUIRED ACTION

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

LCO 3.0.3 is not applicable.

A.1 Suspend movement of fuel assemblies in the fuel storage pool.

AND A.2.1 Initiate action to restore fuel storage pool boron concentration to within limit.

OR LCO 3.7.15 The spent fuel pool (SFP) boron concentration shall be 2,150 ppm and the SFP B-10 isotopic concentration shall be 19.9%

(atomic percent).

ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION A. Spent fuel pool boron concentration not within limit.

OR Spent fuel pool B-10 isotopic concentration not within limits.

REQUIRED ACTION A.1 Suspend movement of fuel assemblies in spent fuel pool.

AND A.2.1 Initiate action to restore spent fuel pool boron concentration and B-10 isotopic concentration to within limits.

OR This is an intrinsic design characteristic of APR1400.

This item is equivalent to 3.7.15 Spent Fuel Pool Boron Concentration of APR1400.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 155 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark A.2.2 Initiate action to perform a fuel storage pool verification.

SURVEILLANCE None A.2.2 Initiate action to perform a spent fuel pool verification.

SURVEILLANCE SR 3.7.15.2 Verify isotopic concentration of B-10 in the SFP is 19.9%

(atomic percent).

3.7.18 Spent Fuel Pool Storage REQUIRED ACTION A.1 -------------NOTE-------------

LCO 3.0.3 is not applicable.

Initiate action to move the noncomplying fuel assembly from

[Region 2].

REQUIRED ACTION A.1 -------------NOTE-------------

LCO 3.0.3 is not applicable.

Initiate action to move the noncomplying fuel from Region II to Region I.

The action is defined for the storage location or moving destination of noncomplying fuel.

This item is equivalent to 3.7.16 Spent Fuel Assembly Storage of APR1400.

3.7.19 Secondary Specific Activity Same as NUREG-1432 This item is equivalent to 3.7.17 Secondary Specific Activity of APR1400.

3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources Operating LCO 3.8.1

b. Two diesel generators (DGs) each capable of supplying one train of the onsite Class 1E AC Electrical Power Distribution System, and LCO 3.8.1

b. Division I and division II emergency diesel generators (EDGs), each division capable of supplying one division of the onsite Class 1E AC Electrical Power Distribution System and consisting of two EDGs (EDG A and EDG C for division I, and EDG B and EDG D for division II),

and See III.4.2.1.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 156 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

[c. Automatic load sequencers for Train A and Train B.]

c. Four automatic load sequencers for EDG A, EDG B, EDG C, and EDG D.

ACTIONS

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

LCO 3.0.4.b is not applicable to DGs.

ACTIONS None See III.4.2.1.

CONDITION B. One [required] DG inoperable.

CONDITION B. One or two EDGs in one division inoperable.

See III.4.2.1.

D. One [required] offsite circuit inoperable.

AND One [required] DG inoperable.

D. One offsite circuit inoperable.

AND One or two EDGs in one division inoperable.

See III.4.2.1.

E. Two [required] DGs inoperable.

E. One or two EDGs in each division inoperable.

See III.4.2.1.

F. ------------NOTE------------

[ This Condition may be deleted if the unit design is such that any sequencer failure mode will only affect the ability of the associated DG to power its respective safety loads following a loss of offsite power independent of, or coincident with, a Design Basis Event.

One [required] [automatic load sequencer] inoperable.

F. None One automatic load sequencer inoperable.

H. Three or more [required] AC sources inoperable.

H. Two offsite circuits and one or more EDGs inoperable.

OR See III.4.2.1.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 157 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark One offsite circuit and one or two EDGs in each division inoperable.

REQUIRED ACTION G.2.---------NOTE-----------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION G.2. None Be in MODE 5.

See II.3.3 SURVEILLANCE SR 3.8.1.2 Verify each DG starts from standby conditions and achieves steady state voltage [3740] V and

[4580] V, and frequency [58.8]

Hz and [61.2] Hz.

SURVEILLANCE SR 3.8.1.2 Verify each EDG starts from standby conditions and achieves steady state voltage 3,744 V and 4,576 V, and frequency 58.8 Hz and 61.2 Hz.

SR 3.8.1.3 Verify each DG is synchronized and loaded, and operates for 60 minutes at a load [4500] kW and

[5000] kW.

SR 3.8.1.3 Verify each EDG is synchronized and loaded, and operates for 60 minutes at a load 90% rating and 100% rating.

SR 3.8.1.4 Verify each day tank [and engine mounted tank] contains [220] gal of fuel oil.

SR 3.8.1.4 Verify each day tank contains

[2,404 L (635 gal)] of fuel oil.

See III.4.2.3.

The capacity of day tank may vary depending on manufacturers recommendations. However, the capacity of 635 gal is the value that has been validated to be an actual one through long-term applications in local nuclear plants.

SR 3.8.1.5 Check for and remove accumulated water from each day SR 3.8.1.5 Check for and remove accumulated water and sediment

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 158 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark tank [and engine mounted tank].

from each day tank and engine mounted tank.

SR 3.8.1.7

a. In [10] seconds, voltage

[3740] V and frequency [58.8]

Hz and

b. Steady state voltage [3740] V and [4580] V, and frequency

[58.8] Hz and [61.2] Hz SR 3.8.1.7

a. In 17 seconds, voltage 3,744 V and frequency 58.8 Hz and

b. Steady state voltage 3744 V and 4,576 V, and frequency

[58.8] Hz and [61.2] Hz See III.4.2.3.

SR 3.8.1.9

b. Within [3] seconds following load rejection, the voltage is

[3740] V and [4580] V, and SR 3.8.1.9

b. Within 3 seconds following load rejection, the voltage is 3,744 V and 4,576 V, and SR 3.8.1.10 Verify each DG does not trip, and voltage is maintained [5000] V during and following a load rejection of [4500] kW and

[5000] kW.

SR 3.8.1.10 Verify each EDG does not trip, and voltage is maintained 4,576 V during and following a load rejection of 90% rating and 100% rating.

SR 3.8.1.11

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

2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

c. 1. Energizes permanently connected loads in [10]

SR 3.8.1.11

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

2. This Surveillance shall not be performed in MODE 1, 2, 3, or

4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

c. 1. energizes permanently-connected loads in See III.4.2.3.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 159 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

seconds,

c. 3. Maintains steady state voltage

[3740] V and [4580] V, 19 seconds,

c. 3. maintains steady state voltage 3744 V and 4576 V, SR 3.8.1.12

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

2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

a. In [10] seconds after auto-start and during tests, achieves voltage [3740] V and frequency

[58.8] Hz,

b. Achieves steady state voltage

[3740] V and [4580] V and frequency [58.8] Hz and

[61.2] Hz, SR 3.8.1.12

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

2.G[This Surveillance shall not be performed in MODE 1 or 2.

However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.]

a. In 17 seconds after auto-start and during tests, achieves voltage 3,744 V and frequency 58.8 Hz,

b. Achieves steady state voltage 3744 V and 4576 V and frequency 58.8 Hz and 61.2 Hz, See III.4.2.3.

SR 3.8.1.13

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

[ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for SR 3.8.1.13

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

[This Surveillance shall not be performed in MODE 1 or 2.

However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 160 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark unplanned events that satisfy this SR. ]

unplanned events that satisfy this SR.].

SR 3.8.1.14

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

2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

a. For [2] hours loaded [5250]

kW and [5500] kW and

b. For the remaining hours of the test loaded [4500] kW and

[5000] kW.

SR 3.8.1.14

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

2.GThis Surveillance shall not be performed in MODE 1 or 2.

However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.

a. For 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 105%

rating and 110% rating and;

b. For the remaining hours of the test loaded 90% rating and 100% rating.G SR 3.8.1.15

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

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated [2] hours loaded [4500] kW and

[5000] kW.

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

SR 3.8.1.15

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

1.GThis Surveillance shall be performed within 5 minutes of shutting down the EDG after the EDG has operated in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 90% rating and 100% rating. Momentary transients outside of load range do not invalidate this test.

See III.4.2.3.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 161 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

a. In [10] seconds, voltage

[3740] V and frequency

[58.8] Hz and

b. Steady state voltage [3740] V and [4580] V, and frequency

[58.8] Hz and [61.2] Hz.

a. In 17 seconds, voltage 3,744 V and frequency 58.8 Hz.

b. Steady state voltage 3,744 V and 4,576 V, and frequency 58.8 Hz and 61.2 Hz.

SR 3.8.1.19

c. 1. energizes permanently connected loads in [10]

seconds,

c. 3. achieves steady state voltage

[3740] V and [4580] V, SR 3.8.1.19

c. 1. energizes permanently connected loads in 19 seconds,

c. 3. achieves steady state voltage 3,744 V and 4,576 V, See III.4.2.3.

SR 3.8.1.20

a. In [10] seconds, voltage

[3740] V and frequency

[58.8] Hz and

b. Steady state voltage [3740] V and [4580] V, and frequency

[58.8] Hz and [61.2] Hz.

SR 3.8.1.20

a. In 17 seconds, voltage 3,744 V and frequency 58.8 Hz and

b. Steady state voltage 3,744 V and 4,576 V, and frequency 58.8 Hz and 61.2 Hz.

See III.4.2.3.

3.8.2 AC Sources -

Shutdown LCO 3.8.2

b. One diesel generator (DG) capable of supplying one train of the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10.

APPLICABILITY During movement of [recently]

irradiated fuel assemblies.

LCO 3.8.2

b. One division of emergency diesel generators (EDGs) capable of supplying one division of the onsite Class 1E AC Electrical Power Distribution System required by LCO 3.8.10.

APPLICABILITY During movement of irradiated fuel assemblies.

See III.4.2.1.

[recently] irradiated changed to irradiated.

CONDITION B. One required DG inoperable.

CONDITION B. One or two required EDGs in one division inoperable.

See III.4.2.1.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 162 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air CONDITION E. One or more DGs with starting air receiver pressure < [225]

psig and [125] psig.

CONDITION E. One or more EDGs with starting air receiver pressure

< [40.77 kg/cm2G (580 psig)]

and [8.78 kg/cm2G (125 psig)].

See III.4.2.3.

The air pressure of starting air receiver may vary depending on manufacturers recommendations. However, the pressure of 580 psig is the value that has been validated to be an actual one through long-term applications in local nuclear plants.

SURVEILLANCE SR 3.8.3.4 Verify each DG air start receiver pressure is [225] psig.

SURVEILLANCE SR 3.8.3.4 Verify each DG air start receiver pressure is [40.77 kg/cm2G (580 psig)].

See III.4.2.3.

The air pressure of starting air receiver may vary depending on manufacturers recommendations. However, the pressure of 580 psig is the value that has been validated to be an actual one through long-term applications in local nuclear plants.

3.8.4 DC Sources -

Operating REQUIRED ACTION D.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

Be in MODE 4.

REQUIRED ACTION D.2 None Be in MODE 5.

See II.3.3 SURVEILLANCE SR 3.8.4.2 Verify each battery charger supplies [400] amps at greater than or equal to the minimum established float voltage for [8] hours.

SURVEILLANCE SR 3.8.4.2 Verify battery chargers A and B supply 700 amps and battery chargers C and D supply 1,200 amps at greater than or equal to the minimum established float voltage for 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

See III.4.2.3.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 163 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.8.5 DC Sources -

Shutdown LCO 3.8.5

[One DC electrical power subsystem shall be OPERABLE.]

REVIEWERS NOTE----------

This second option above applies for plants having a pre-ITS licensing basis (CTS) for electrical power requirements during shutdown conditions that required only one DC electrical power subsystem to be OPERABLE.

Action A and the bracketed optional wording in Condition B are also eliminated for this case. The first option above is adopted for plants that have a CTS requiring the same level of DC electrical power subsystem support as is required for power operating conditions.

APPLICABILITY During movement of [recently]

irradiated fuel assemblies.

LCO 3.8.5 None APPLICABILITY During movement of irradiated fuel assemblies.

[recently] irradiated changed to irradiated.

3.8.6 Battery Parameters Same as NUREG-1432 Train A and Train B electrical power Subsystem changed to Division I and Division II 3.8.7 Inverters -

Operating REQUIRED ACTION B.2 --------------NOTE--------------

LCO 3.0.4.a is not applicable when entering MODE 4.

REQUIRED ACTION B.2 None See II.3.3 Train A and Train B changed to Division I and Division II

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 164 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark Be in MODE 4.

Be in MODE 5.

3.8.8 Inverters -

Shutdown LCO 3.8.8

[One] inverter[s] shall be OPERABLE.]

REVIEWERS NOTE----------

This second option above applies for plants having a pre-ITS licensing basis (CTS) for electrical power requirements during shutdown conditions that required only [one] inverter to be OPERABLE. The "[or more]"

optional wording in Condition A is also eliminated for this case. The first option above is adopted for plants that have a CTS requiring the same level of DC electrical power subsystem/inverter support as is required for power operating conditions.

APPLICABILITY During movement of [recently]

irradiated fuel assemblies.

REQUIRED ACTION A.1 Declare affected required feature(s) inoperable.

LCO 3.8.8 None APPLICABILITY During movement of irradiated fuel assemblies.

REQUIRED ACTION A.1 Declare affected required feature(s) with no offsite power available inoperable.

[recently] irradiated changed to irradiated.

3.8.9 Distribution Systems - Operating Same as NUREG-1432 Train A and Train B changed to Division I and Division II

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 165 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 3.8.10 Distribution Systems - Shutdown APPLICABILITY During movement of [recently]

irradiated fuel assemblies.-

APPLICABILITY During movement of [recently]

irradiated fuel assemblies.

[recently] irradiated changed to irradiated.

3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration Same as NUREG-1432 Refueling cavity changed to refueling pool 3.9.2 Nuclear Instrumentation LCO 3.9.2 Two source range monitors (SRMs) shall be OPERABLE.

LCO 3.9.2 Two startup channels of the Ex-core Neutron Flux Monitoring System (ENFMS) shall be OPERABLE.

SRM changed to startup channels of ENFMS 3.9.3 Containment Penetrations LCO 3.9.3

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

Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

APPLICABILITY None During movement of [recently]

irradiated fuel assemblies within containment.

LCO 3.9.3 None APPLICABILITY During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.

REQUIRED ACTION None A.1 Suspend movement of recently irradiated fuel assemblies REQUIRED ACTION A.1 Suspend CORE ALTERATIONS.

AND A.2 Suspend movement of irradiated fuel assemblies

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 166 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark within containment.

within containment.

SURVEILLANCE SR 3.9.3.2

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

Not required to be met for containment purge and exhaust valve(s) in penetrations closed to comply with LCO 3.9.3.c.1.

SURVEILLANCE SR 3.9.3.2 None FREQUENCY SR 3.9.3.1 None 7 days FREQUENCY SR 3.9.3.1 Within 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior to the start of movement of irradiated fuel within containment AND Once per 7 days during CORE ALTERATIONS or movement of irradiated fuel within containment Conservative surveillance frequency is used in APR1400.

3.9.4 Shutdown Cooling (SDC) and Coolant Circulation - High Water Level REQUIRED ACTION A.4 Close equipment hatch and secure with [four] bolts.

AND A.5 Close one door in each air lock.

AND A.6.1 Close each penetration providing direct access from REQUIRED ACTION A.4 Place the containment building penetrations in the required status as specified in LCO 3.6.7.

None Details about actions of containment building penetrations exist in LCO 3.6.7.

Therefore Required Action A.4 refers to LCO 3.6.7.

For better coordination between TS 3.9.4 and TS 3.6.7, the required action is described briefly.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 167 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.

OR A.6.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.

SURVEILLANCE SR 3.9.4.1 Verify one SCS loop is in operation and circulating reactor coolant at a flow rate of

[2200] gpm.

SURVEILLANCE SR 3.9.4.1 Verify one SCS train is in operation and circulating reactor coolant at a flow rate of 15,710 L/min (4,150 gpm).

The flow rate is specific for APR1400. The flow rate for decay heat removal, boron mixing and prevention of boron stratification is evaluated and specified.

The flow rate is specific for APR1400.

SURVEILLANCE None SURVEILLANCE SR 3.9.4.2 Verify required SCS train piping locations susceptible to gas accumulation are sufficiently filled with water.

TSTF-523 (Managing Gas Accumulation) is applied to APR1400 Technical Specification.

3.9.5 Shutdown Cooling (SDC) and Coolant Circulation - Low Water Level LCO 3.9.5 Two SDC loops shall be OPERABLE, and one SDC loop shall be in operation.

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

1. All SDC pumps may be removed from operation for 15 minutes when switching from one train to another provided:

a. The core outlet temperature is maintained >10 degrees F LCO 3.9.5 The heat removal system shall be in the following status:

a. Two SC trains shall be OPERABLE and one SC train shall be in operation.

b. When RCS level is < 38.72 m (127 ft 1/4 in), the containment spray pump in the same

1. For item 'a', the intent of APR1400 is the same as that of NUREG-1432.

2. For item 'b', APR1400 is more conservative. This ensures two forced circulation loops are available for decay heat removal if the operating SC pump becomes inoperable for any

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 168 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark below saturation temperature,

b. No operations are permitted that would cause introduction of coolant into the Reactor Coolant System with boron concentration less than that required to meet the minimum required boron concentration of LCO 3.9.1, and

c. No draining operations to further reduce RCS water volume are permitted.

2. One required SDC loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing, provided that the other SDC loop is OPERABLE and in operation.

electrical division as an operating SC train shall be OPERABLE.

reason and improves a reliability of SC operation during reduced inventory operation.

CONDITION B.G No SDC loop OPERABLE or in operation.

CONDITION B.GTwo SC trains inoperable.

OR No SC train in operation.

REQUIRED ACTION B.3 Close equipment hatch and secure with [four] bolts.

AND B.4 Close one door in each air lock.

AND REQUIRED ACTION B.3 Initiate action to raise RCS level to > 38.72 m (127 ft 1/4 in).

AND B.4 Place the containment building penetrations in the required This enhances safety and prevents boron dilution event during reduced inventory operation.

Details about actions of containment building penetrations exist in LCO 3.6.7.

Therefore Required Action B.4 refers to LCO 3.6.7.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 169 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark B.5.1 Close each penetration providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.

OR B.5.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.

status as specified in LCO 3.6.7.

CONDITION None CONDITION C. Containment spray pump in the same electrical division as an operating SC train inoperable with RCS level 38.72 m (127 ft 1/4 in).

See III.5.2.3 REQUIRED ACTION None REQUIRED ACTION C.1 If the containment spray pump in the same electrical division as the alternate SC train is OPERABLE, initiate action to place the alternate SC train in operation.

COMPLETION TIME Immediately AND REQUIRED ACTION C.2 Monitor SC System See III.5.2.3

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 170 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark performance.

COMPLETION TIME Every 30 minutes AND REQUIRED ACTION C.3 Restore containment spray pump to OPERABLE status.

COMPLETION TIME 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months CONDITION None CONDITION D. Required Action and associated Completion Time of Required Action C.3 not met.

See III.5.2.3 REQUIRED ACTION None REQUIRED ACTION D.1 Raise RCS level to EL 38.72 m (127 ft 1/4 in).

COMPLETION TIME 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months This places the plant in a conservative position with respect to providing decay heat removal.

SURVEILLANCE SR 3.9.5.1 Verify required SDC loops are OPERABLE and one SDC loop is in operation.

SURVEILLANCE SR 3.9.5.1 Verify required SC trains are OPERABLE and one SC train is in operation with circulating reactor coolant at a flow rate of 15,709 L/min (4,150 gpm) at RCS level 38.72 m (127 ft 1/4 in) or 14,385 L/min (3,800 gpm) and

< 15,710 L/min (4,150 gpm) at RCS level < 38.72 m (127 ft 1/4 in).

This flow value is established to ensure adequate decay heat removal and to prevent boron mixing and also to address the air ingestion in the hot leg when the RCS water inventory is maintained at the lowest permitted level on safety/accident analysis.

An explicit numerical value for SC pump flow is added.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 171 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark None SR 3.9.5.3 Verify correct breaker alignment and indicated power available to the required CS pump.

FREQUENCY 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months at RCS level < 38.72 m (127 ft 1/4 in)

This ensures forced circulation is available for decay heat removal if the operating SC pump becomes inoperable for any reason and improves a reliability of SC operation during reduced inventory operation.

None SR 3.9.5.4 Verify required SC train piping locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY 31 days TSTF-523 (Managing Gas Accumulation) is applied to APR1400 Technical Specification.

TSTF-523 is incorporated.

3.9.6 Refueling Water Level APPLICABILITY:

None During movement of [recently]

irradiated fuel assemblies within containment.

APPLICABILITY:

During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts,G G G

During movement of irradiated fuel assemblies within containment.

See II.2.1 See III.5.2.4 REQUIRED ACTION None A.1 Suspend movement of

[recently] irradiated fuel assemblies within containment.

None REQUIRED ACTION A.1 Suspend CORE ALTERATIONS.

AND A.2 Suspend movement of irradiated fuel assemblies within containment.

AND See II.2.1 See III.5.2.4

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 172 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark A.3 Initiate actions to restore refueling water level to within limits.

See III.5.2.4 Addition

- Unborated Water Source Isolation Valve -

MODE 6 None LCO 3.9.7 The CV-186 valve used to isolate unborated water sources shall be secured in the closed position.

APPLICABILITY MODE 6 This operating restriction is an assumption of initial condition for safety analysis as described in the APR1400 DCD Tier 2, Section 15.4.6.

Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

Addition

- Decay Time None LCO 3.9.8 The reactor shall be subcritical for 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months .

APPLICABILITY During movement of irradiated fuel assemblies in the reactor pressure vessel.

Related ACTIONS and SURVEILLANCE REQUIREMENTS are added.

4.0 DESIGN FEATURES 4.1 Site Location Same as NUREG-1432 4.2 Reactor Core 4.2.1 The reactor shall contain [217] fuel assemblies.GEach assembly shall consist of a matrix of [Zircalloy or ZIRLO] fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO2) as fuel material.

4.2.1 The reactor shall contain 241 fuel assemblies. Each assembly shall consist of a matrix of zirconium alloy clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO2) as fuel material.

The items reflect APR1400 design.

4.2.2 The reactor core shall contain [91]

control element assemblies (CEAs). The control material shall be [silver indium cadmium, boron 4.2.2 The reactor core shall contain 81 full strength and 12 part strength control element assemblies (CEAs). The control material of full strength and The items reflect APR1400 design.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 173 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark carbide, or hafnium metal] as approved by the NRC.

part strength CEA shall be boron carbide and Inconel Alloy 625, respectively.

4.3 Fuel Storage 4.3.1.1

a. Fuel assemblies having a maximum U-235 enrichment of

[4.5] weight percent,

b. Keff 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in [Section 9.1 of the FSAR],

[c. A nominal [9] inch center to center distance between fuel assemblies placed in [the high density fuel storage racks], ]

[d. A nominal [10.4] inch center to center distance between fuel assemblies placed in [the low density fuel storage racks], ]

[ e. New or partially spent fuel assemblies with a discharge burnup in the acceptable range of Figure [3.7.18-1] may be allowed unrestricted storage in

[either] fuel storage rack(s), and ]

[f. New or partially spent fuel assemblies with a discharge burnup in the "unacceptable range" of Figure [3.7.18-1] will be stored in compliance with the NRC approved [specific document containing the 4.3.1.1

a. Fuel assemblies having a maximum U-235 enrichment of 5 weight percent;

b. keff < 1.0 if fully flooded with unborated water and keff 0.95 if flooded with water borated to 1231 ppm enriched, which includes an allowance for uncertainties;

c. A nominal (27.5 cm (10.83 in))

center-to-center distance between fuel assemblies placed in Region I of the spent fuel storage racks;

d. A nominal (22.5 cm (8.86 in))

center-to-center distance between fuel assemblies placed in Region II of the spent fuel storage racks;

e. Fuel assemblies with a discharge burnup in the "acceptable domain" of Figure 3.7.16-1 may be allowed unrestricted storage in Region I or Region II of Figure 4.3-1; and

f. New or partially spent fuel assemblies with a discharge burnup in the "unacceptable domain" of Figure 3.7.16-1 shall be stored only in Region I of Figure 4.3-1.

4.3.1.1

a. The item is specific for APR1400 design.

(DCD Tier 2, Section 9.1.1)

b. This change is to incorporate SRP 9.1.1 Rev. 3.

(DCD Tier 2, Section 9.1.1)

c. Based on the result of the criticality analysis and the detailed design of the fuel storage racks for APR1400.

d. Based on the result of the criticality analysis and the detailed design of the fuel storage racks for APR1400.

f. Refer to the response to RAI 12-7977, Question 16-24, Item 14.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 174 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark analytical methods, title, date, or specific configuration or figure].]

4.3.1.2

a. Fuel assemblies having a maximum U-235 enrichment of

[4.5] weight percent,

b. Keff 0.98 if fully flooded with unborated water, which includes an allowance for uncertainties as described in [Section 9.1 of the FSAR],

d. A nominal [10] inch center to center distance between fuel assemblies placed in the storage racks.

4.3.2 The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation [23 ft].

4.3.3 The spent fuel pool is designed and shall be maintained with a storage capacity limited to no more than

[1542] fuel assemblies.

None 4.3.1.2

a. Fuel assemblies having a maximum U-235 enrichment of 5 weight percent;

b. keff 0.95 if fully flooded with unborated water, or mist, which includes an allowance for uncertainties as described in Section 9.1 Fuel Storage and Handling.;

d. A nominal center-to-center distance between fuel assemblies placed in the new fuel storage racks of 35.5 cm (14 in).

4.3.2 The spent fuel pool is designed and shall be maintained above 7 m (23 ft) from the top of the spent fuel storage rack to prevent inadvertent draining.

4.3.3 The spent fuel pool is designed and shall be maintained with a storage capacity limited to no more than 1,792 fuel assemblies.

Figure 4.3-1 4.3.1.2

a. The item is specific for APR1400 design.

(DCD Tier 2, Section 9.1.1)

b. APR1400 criterion is more conservative than that of NUREG-1432.

(DCD Tier 2, Section 9.1.1)

d. Based on the result of the criticality analysis and the detailed design of the fuel storage racks for APR1400.

4.3.3 The item is specific for APR1400 design.

(DCD Tier 2, Section 9.1.1)

Figure is added for 4.3.1.1.e. and 4.3.1.1.f.

5.0 ADMINISTRATIVE CONTROLS

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 175 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 5.1 Responsibility Same as NUREG-1432 5.2 Organization Same as NUREG-1432 5.3 Unit Staff Qualifications Same as NUREG-1432 5.4 Procedures Same as NUREG-1432 5.5 Programs and Manuals 5.5.2 Primary Coolant Sources Outside Containment The systems include [Low Pressure Injection, Reactor Building Spray, Makeup and Purification, and Hydrogen Recombiner].

5.5.2 Primary Coolant Sources Outside Containment The systems include Containment Spray System, Safety Injection System, Chemical and Volume Control System, Gaseous Waste Management System and Containment Hydrogen Control System.

APR1400 design characteristics are reflected.

5.5.9 Steam Generator (SG)

Program b.2. ~ Leakage is not to exceed

[1 gpm] per SG.

5.5.9.d.1 Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

5.5.9.d.2

[Inspect 100% of the tubes at sequential periods of 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. No SG shall operate for more than 24 effective full power months or one 5.5.9 Steam Generator (SG)

Program b.2. ~ Leakage is not to exceed 1.14 L/min (0.3 gpm) per SG.

5.5.9.d.1 Inspect 100% of the tubes in each SG during the first refueling outage following SG installation.

5.5.9.d.2 After the first refueling outage following SG installation, inspect each SG at least every 72 effective full power months or at least every third refueling outage (whichever results in more frequent inspections). In addition, the minimum number of tubes APR1400 design characteristics are reflected.

APR1400 doesnt have a repair method approved by NRC.

TSTF-510 Rev. 2 (Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection) is applied to APR1400 NRC DC Technical Specifications.

Plugging, not repair, is specified for APR1400.

Operational leakage is specified in LCO 3.4.12 for APR1400.

Alternate tube repair criteria are not listed.

Inspection descriptions differ.

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 176 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark refueling outage (whichever is less) without being inspected.]

Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50%

of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.]

inspected at each scheduled inspection shall be the number of tubes in all SGs divided by the number of SG inspection outages scheduled in each inspection period as defined in a, b, c and d below. If a degradation assessment indicates the potential for a type of degradation to occur at a location not previously inspected with a technique capable of detecting this type of degradation at this location and that may satisfy the applicable tube plugging criteria, the minimum number of locations inspected with such a capable inspection technique during the remainder of the inspection period may be prorated. The fraction of locations to be inspected for this potential type of degradation at this location at the end of the inspection period shall be no less than the ratio of the number of times the SG is scheduled to be inspected in the inspection period after the determination that a new form of degradation could potentially be occurring at this location divided by the total number of times the SG is scheduled to be inspected in the inspection period. Each inspection period defined below may be extended up to 3 effective full power months to include a SG inspection outage in an inspection

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 177 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 5.5.9.d.3

~(whichever is less) 5.5.9.f Provisions for SG tube repair methods.

[etc.]

period and the subsequent inspection period begins at the conclusion of the included SG inspection outage.

a) After the first refueling outage following SG installation, inspect 100% of the tubes during the next 144 effective full power months. This constitutes the first inspection period; b) During the next 120 effective full power months, inspect 100% of the tubes. This constitutes the second inspection period; c) During the next 96 effective full power months, inspect 100% of the tubes. This constitutes the third inspection period; and d) During the remaining life of the SGs, inspect 100% of the tubes every 72 effective full power months. This constitutes the fourth and subsequent inspection periods.

5.5.9.d.3

~(whichever results in more frequent inspections)

None

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 178 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark 5.5.16

b. The calculated peak containment internal pressure for the design basis loss of coolant accident, Pa is [45 psig]. The containment design pressure is [50 psig].

c. The maximum allowable containment leakage rate, La, at Pa, shall be [ ]% of containment air weight per day.

5.5.16 b.GThe calculated peak containment internal pressure for the design basis loss of coolant accident, Pa is 3.59 kg/cm2G (51.09 psig). The containment design pressure is 60 psig.

c. The maximum allowable containment leakage rate, La at Pa, shall be 0.1% of containment air weight per day.

5.5.19 None None 5.5.19

f. The difference between the instrument channel trip setting as-found value and the previously recorded as-left value for each Technical Specification required automatic protection instrumentation function shall be trended and evaluated to verify that the instrument channel is functioning in accordance with its design basis.

g. The program shall establish a document containing the current value of the specified NTSP, AV, AFT, and ALT for each Technical Specification required automatic protection instrumentation function and references to the calculation documentation. Changes to this document shall be governed by

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 179 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark the regulatory requirement of 10 CFR 50.59. In addition, changes to the specified NTSP, AV, AFT, and ALT values shall be governed by the approved setpoint methodology. This document, including any revisions or supplements, shall be provided upon issuance to the NRC.

5.5.20 [ Surveillance Frequency Control Program None The Surveillance Frequency Control Program of the NUREG-1432 has not been applied to the APR1400 plants.

5.6 Reporting Requirements 5.6.3 CORE OPERATING LIMITS REPORT

REVIEWERS NOTE-----------

Licensees that have received prior NRC approval to relocate Topical Report revision numbers and dates to licensee control need only list the number and title of the Topical Report, and the COLR will contain the complete identification for each of the Technical Specification referenced Topical Reports used to prepare the COLR (i.e., report number, title, revision, date, and any supplements). See NRC ADAMS Accession No:

ML110660285 for details.

5.6.3 CORE OPERATING LIMITS REPORT None 5.6.4 RCS Pressure and Temperature Limits Report 5.6.4 Reactor Coolant System (RCS) PRESSURE AND 2 changed to 2

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 180 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

REVIEWERS NOTE-----------

Licensees that have received prior NRC approval to relocate Topical Report revision numbers and dates to licensee control need only list the number and title of the Topical Report, and the PTLR will contain the complete identification for each of the Technical Specification referenced Topical Reports used to prepare the PTLR (i.e., report number, title, revision, date, and any supplements). See NRC ADAMS Accession No:

ML110660285 for details.

3. Low Temperature Overpressure Protection (LTOP) System lift setting limits for the Power Operated Relief Valves (PORVs), developed using NRC approved methodologies may be included in the PTLR.

7.

~where the predicted increase in RTNDT is based on the mean shift in RTNDT plus the two standard deviation value (2) specified in Regulatory Guide 1.99, Revision 2.

If the measured value exceeds the predicted value (increase in RTNDT TEMPERATURE LIMITS REPORT (PTLR)

None

3. Low Temperature Overpressure Protection (LTOP) System lift setting limits for the Pilot Operated Safety Relief Valves (POSRVs), developed using NRC approved methodologies may be included in the PTLR.

7.

~where the predicted increase in RTNDT is based on the mean shift in RTNDT plus the two standard deviation value (2) specified in Regulatory Guide 1.99, Revision 2.

If the measured value exceeds the predicted value (increase in RTNDT

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 181 Number (NUREG-1432 Contents)

Standard Technical Specifications (NUREG-1432, Rev. 4)

APR1400 Technical Specifications (Rev. 2)

Justification Remark

2),

5.6.5 Post Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.[11],

"Post Accident Monitoring (PAM)

Instrumentation, 5.6.5 Accident Monitoring Report When a report is required by Condition B or F of LCO 3.3.11, "Accident Monitoring Instrumentation (AMI),

The name for the instrumentation is changed according to RG 1.97 Rev. 4.

5.6.7 Steam Generator Tube Inspection Report

b. Active degradation mechanisms

found,

d. Location, orientation (if linear),

and measured sizes (if available) of service induced indications,

f. Total number and percentage of tubes plugged [or repaired] to

date,

[h. The effective plugging percentage for all plugging [and tube repairs] in each SG, and]

[i. Repair method utilized and the number of tubes repaired by each repair method.]

5.6.7 Steam Generator Tube Inspection Report

b. Degradation mechanisms found,

d. Location, orientation (if linear),

and measured sizes (if available) of service induced indications,

f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator, and None None TSTF-510 Rev. 2 (Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection) is applied to APR1400 NRC DCD Technical Specifications.

NUREG-1432 5.6.7.f. and h.

combined into f. for APR1400.

Indications changed to degradations 5.7 High Radiation Area Same as NUREG-1432

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 182

IV. CONCLUSIONS The APR1400 Technical Specifications satisfies 10 CFR 50.36, Technical specifications. The APR1400 Technical Specifications are compared with NUREG-1432, Rev. 4.0, and the justifications for the deviation from NUREG-1432 are described in this report.

G

Deviation Report between NUREG-1432 Rev. 4.0 and APR1400 Technical Specifications APR1400-K-O-NR-14001-NP, Rev. 2 G

KEPCO & KHNP 183

V. REFERENCE

[1] Title 10 Code of Federal Regulations Part 50.36, Technical Specifications

[2] NUREG-1432, Standard Technical Specifications - Combustion Engineering Plants, Vol. 1, Rev. 4.0, April 2012

[3] NUREG-0800, Branch Technical Position 5-4, Design Requirements of the Residual Heat Removal System, Rev. 4.0, March 2007

[4] NUMARC 93-01, Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants, Rev. 4.0, December 2010

[5] WCAP-16364-NP, Implementation Guidance for Risk Informed Modification to Selected Required Action End States at Combustion Engineering NSSS Plants (TSTF-422), Rev. 2.0, May 2010

[6] NRC RG 1.97, Criteria for Accident Monitoring Instrumentation for Nuclear Power Plants, Rev. 4.0, June 2006

[7] NUREG-0800, 9.1.1 Criticality Safety of Fresh and Spent Fuel Storage and Handling, Rev. 3.0, March 2007

ML18102B338

Text

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