ML18207A481
| ML18207A481 | |
| Person / Time | |
|---|---|
| Site: | Vogtle  |
| Issue date: | 08/24/2018 |
| From: | NRC/NRO/DLSE/LB4 |
| To: | Southern Nuclear Operating Co |
| KALLAN P/415-2809 | |
| Shared Package | |
| ML18207A488 | List: |
| References | |
| EPID L-2018-LLA-0092, LAR 18-001 | |
| Download: ML18207A481 (8) | |
Text
ATTACHMENT TO LICENSE AMENDMENT NO. 138 TO FACILITY COMBINED LICENSE NO. NPF-92 DOCKET NO.52-026 Replace the following pages of the Facility Combined License No. NPF-92 with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.
Facility Combined License No. NPF-92 REMOVE INSERT 7 7 12 12 Appendix C to Facility Combined License No. NPF-92 REMOVE INSERT C-116 C-116 C-139 C-139 C-142 C-142 C-246 C-246 C-247 C-247
(7) Reporting Requirements (a) Within 30 days of a change to the initial test program described in UFSAR Section 14, Initial Test Program, made in accordance with 10 CFR 50.59 or in accordance with 10 CFR Part 52, Appendix D, Section VIII, Processes for Changes and Departures, SNC shall report the change to the Director of NRO, or the Directors designee, in accordance with 10 CFR 50.59(d).
(b) SNC shall report any violation of a requirement in Section 2.D.(3),
Section 2.D.(4), Section 2.D.(5), and Section 2.D.(6) of this license within 24 hours1 days <br />0.143 weeks <br />0.0329 months <br />. Initial notification shall be made to the NRC Operations Center in accordance with 10 CFR 50.72, with written follow up in accordance with 10 CFR 50.73.
(8) Incorporation The Technical Specifications, Environmental Protection Plan, and ITAAC in Appendices A, B, and C, respectively of this license, as revised through Amendment No. 138, are hereby incorporated into this license.
(9) Technical Specifications The technical specifications in Appendix A to this license become effective upon a Commission finding that the acceptance criteria in this license (ITAAC) are met in accordance with 10 CFR 52.103(g).
(10) Operational Program Implementation SNC shall implement the programs or portions of programs identified below, on or before the date SNC achieves the following milestones:
(a) Environmental Qualification Program implemented before initial fuel load; (b) Reactor Vessel Material Surveillance Program implemented before initial criticality; (c) Preservice Testing Program implemented before initial fuel load; (d) Containment Leakage Rate Testing Program implemented before initial fuel load; (e) Fire Protection Program
- 1. The fire protection measures in accordance with Regulatory Guide (RG) 1.189 for designated storage building areas (including adjacent fire areas that could affect the storage area) implemented before initial receipt 7 Amendment No. 138
plant design objective. Submit this PTS evaluation report to the Director of NRO, or the Directors designee, in writing, at least 18 months before initial fuel load;
- 6. Review differences between the as-built plant and the design used as the basis for the AP1000 seismic margin analysis. SNC shall perform a verification walkdown to identify differences between the as-built plant and the design. SNC shall evaluate any differences and must modify the seismic margin analysis as necessary to account for the plant-specific design and any design changes or departures from the certified design. SNC shall compare the as-built structures, systems, and components (SSC) high confidence, low probability of failures (HCLPFs) with those assumed in the AP1000 seismic margin evaluation, before initial fuel load. SNC shall evaluate deviations from the HCLPF values or assumptions in the seismic margin evaluation due to the as-built configuration and final analysis to determine if vulnerabilities have been introduced;
- 7. Review differences between the as-built plant and the design used as the basis for the AP1000 probabilistic risk assessment (PRA) and UFSAR Table 19.59-18. SNC shall evaluate the plant-specific PRA-based insight differences and shall modify the plant-specific PRA model as necessary to account for the plant-specific design and any design changes or departure from the PRA certified in Rev. 19 of the AP1000 DCD;
- 8. Review differences between the as-built plant and the design used as the basis for the AP1000 internal fire and internal flood analysis. SNC shall evaluate the plant-specific internal fire and internal flood analyses and shall modify the analyses as necessary to account for the plant-specific design and any design changes or departures from the design certified in Rev. 19 of the AP1000 DCD; and
- 9. Perform a thermal lag assessment of the equipment listed in UFSAR Tables 19D-8 and 19D-9 to provide additional assurance that this equipment can perform its severe accident functions during environmental conditions resulting from hydrogen burns associated with severe accidents. SNC shall perform this assessment for equipment used for severe accident mitigation that has not been tested at severe accident conditions. SNC shall assess the ability of the equipment to perform during accident hydrogen burns using the environment enveloping method or the test based thermal analysis 12 Amendment No. 138
a) The PXS provides containment isolation of the PXS lines penetrating the containment.
b) The PRHR HX provides core decay heat removal during design basis events.
c) The CMTs, accumulators, in-containment refueling water storage tank (IRWST) and containment recirculation provide reactor coolant system (RCS) makeup, boration, and safety injection during design basis events.
d) The PXS provides pH adjustment of water flooding the containment following design basis accidents.
- 9. The PXS has the following features:
a) The PXS provides a function to cool the outside of the reactor vessel during a severe accident.
b) The accumulator discharge check valves (PXS-PL-V028A/B and V029A/B) are of a different check valve type than the CMT discharge check valves (PXS-PL-V016A/B and V017A/B).
- 10. Safety-related displays of the parameters identified in Table 2.2.3-1 can be retrieved in the main control room (MCR).
- 11. a) Controls exist in the MCR to cause the remotely operated valves identified in Table 2.2.3-1 to perform their active function(s).
b) The valves identified in Table 2.2.3-1 as having protection and safety monitoring system (PMS) control perform their active function after receiving a signal from the PMS.
c) The valves identified in Table 2.2.3-1 as having diverse actuation system (DAS) control perform their active function after receiving a signal from the DAS.
- 12. a) The squib valves and check valves identified in Table 2.2.3-1 perform an active safety-related function to change position as indicated in the table.
b) After loss of motive power, the remotely operated valves identified in Table 2.2.3-1 assume the indicated loss of motive power position.
- 13. Displays of the parameters identified in Table 2.2.3-3 can be retrieved in the MCR.
C-116 Amendment No. 138
Table 2.2.3-4 Inspections, Tests, Analyses, and Acceptance Criteria No. ITAAC No. Design Commitment Inspections, Tests, Analyses Acceptance Criteria 202 2.2.03.09a.ii 9.a) The PXS provides a function to ii) Inspections of the as-built ii) The combined total flow cool the outside of the reactor vessel reactor vessel insulation will be area of the water inlets is not during a severe accident. performed. less than 6 ft2. The combined total flow area of the steam outlet(s) is not less than 12 ft2.
A report exists and concludes that the minimum flow area between the vessel insulation and reactor vessel for the flow path that vents steam is not less than 12 ft2 considering the maximum deflection of the vessel insulation with a static pressure of 12.95 ft of water.
203 2.2.03.09a.iii 9.a) The PXS provides a function to iii) Inspections will be iii) A flow path with a flow cool the outside of the reactor vessel conducted of the flow path(s) area not less than 6 ft 2 exists during a severe accident. from the loop compartments to from the loop compartment to the reactor vessel cavity. the reactor vessel cavity.
204 2.2.03.09b 9.b) The accumulator discharge check An inspection of the accumulator The accumulator discharge valves (PXS-PL-V028A/B and and CMT discharge check valves check valves are of a different V029A/B) are of a different check is performed. check valve type than the valve type than the CMT discharge CMT discharge check valves.
check valves (PXS-PL-V016A/B and V017A/B).
205 2.2.03.09c 9.c) Not used per Amendment No.
138.
C-139 Amendment No. 138
Table 2.2.3-6 is not used.
C-142 Amendment No. 138
Table 2.3.9-2 Power Group Room Equipment Name Tag Number Function Number Location No.
Hydrogen Igniter 05 VLS-EH-05 Energize 1 Loop compartment 02 11402 Hydrogen Igniter 06 VLS-EH-06 Energize 2 Loop compartment 02 11502 Hydrogen Igniter 07 VLS-EH-07 Energize 2 Loop compartment 02 11402 Hydrogen Igniter 08 VLS-EH-08 Energize 1 Loop compartment 02 11502 Hydrogen Igniter 09 VLS-EH-09 Energize 1 In-containment refueling water storage 11305 tank (IRWST) sparger side Hydrogen Igniter 10 VLS-EH-10 Energize 2 IRWST sparger side 11305 Hydrogen Igniter 11 VLS-EH-11 Energize 2 Loop compartment 01 11401 Hydrogen Igniter 12 VLS-EH-12 Energize 1 Loop compartment 01 11501 Hydrogen Igniter 13 VLS-EH-13 Energize 1 Loop compartment 01 11401 Hydrogen Igniter 14 VLS-EH-14 Energize 2 Loop compartment 01 11501 Hydrogen Igniter 15 VLS-EH-15 Energize 2 IRWST vacuum breaker vents 11305 Hydrogen Igniter 16 VLS-EH-16 Energize 1 IRWST vacuum breaker vents 11305 Hydrogen Igniter 17 VLS-EH-17 Energize 2 Northeast valve room 11207 Hydrogen Igniter 18 VLS-EH-18 Energize 1 Northeast accumulator room 11207 Hydrogen Igniter 19 VLS-EH-19 Energize 2 East valve room 11208 Hydrogen Igniter 20 VLS-EH-20 Energize 2 Southeast accumulator room 11206 Hydrogen Igniter 21 VLS-EH-21 Energize 1 Southeast valve room 11206 Hydrogen Igniter 22 VLS-EH-22 Energize 1 Lower compartment area (core makeup 11400 tank [CMT] and valve area)
Hydrogen Igniter 23 VLS-EH-23 Energize 2 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 24 VLS-EH-24 Energize 2 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 25 VLS-EH-25 Energize 2 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 26 VLS-EH-26 Energize 2 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 27 VLS-EH-27 Energize 1 Lower compartment area (CMT and 11300 valve area)
Hydrogen Igniter 28 VLS-EH-28 Energize 1 Lower compartment area (CMT and 11400 valve area)
C-246 Amendment No. 138
Table 2.3.9-2 Power Group Room Equipment Name Tag Number Function Number Location No.
Hydrogen Igniter 29 VLS-EH-29 Energize 1 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 30 VLS-EH-30 Energize 2 Lower compartment area (CMT and 11403 valve area)
Hydrogen Igniter 31 VLS-EH-31 Energize 1 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 32 VLS-EH-32 Energize 1 Lower compartment area (CMT and 11400 valve area)
Hydrogen Igniter 33 VLS-EH-33 Energize 2 North CVS equipment room 11209 Hydrogen Igniter 34 VLS-EH-34 Energize 1 North CVS equipment room 11209 Hydrogen Igniter 35 VLS-EH-35 Energize 1 IRWST hooded vents 11500 Hydrogen Igniter 36 VLS-EH-36 Energize 2 IRWST hooded vents 11500 Hydrogen Igniter 37 VLS-EH-37 Energize 1 IRWST hooded vents 11500 Hydrogen Igniter 38 VLS-EH-38 Energize 2 IRWST hooded vents 11500 Hydrogen Igniter 39 VLS-EH-39 Energize 1 Upper compartment lower region 11500 Hydrogen Igniter 40 VLS-EH-40 Energize 2 Upper compartment lower region 11500 Hydrogen Igniter 41 VLS-EH-41 Energize 2 Upper compartment lower region 11500 Hydrogen Igniter 42 VLS-EH-42 Energize 1 Upper compartment lower region 11500 Hydrogen Igniter 43 VLS-EH-43 Energize 1 Upper compartment lower region 11500 Hydrogen Igniter 44 VLS-EH-44 Energize 1 Upper compartment lower region 11500 Hydrogen Igniter 45 VLS-EH-45 Energize 2 Upper compartment lower region 11500 Hydrogen Igniter 46 VLS-EH-46 Energize 2 Upper compartment lower region 11500 Hydrogen Igniter 47 VLS-EH-47 Energize 1 Upper compartment lower region 11500 Hydrogen Igniter 48 VLS-EH-48 Energize 2 Upper compartment lower region 11500 Hydrogen Igniter 49 VLS-EH-49 Energize 1 Pressurizer compartment 11503 Hydrogen Igniter 50 VLS-EH-50 Energize 2 Pressurizer compartment 11503 Hydrogen Igniter 51 VLS-EH-51 Energize 1 Upper compartment mid-region 11500 Hydrogen Igniter 52 VLS-EH-52 Energize 2 Upper compartment mid-region 11500 Hydrogen Igniter 53 VLS-EH-53 Energize 2 Upper compartment mid-region 11500 Hydrogen Igniter 54 VLS-EH-54 Energize 1 Upper compartment mid-region 11500 C-247 Amendment No. 138