CP-201700904, Response to Request for Additional Information Regarding Relief Request 1/2B3-2 for the Units 1 and 2 Third Ten Year Inservice Inspection Interval
| ML17313A454 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 11/01/2017 |
| From: | Hope T Vistra Energy |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| CP-201700904, TXX-17092 | |
| Download: ML17313A454 (8) | |
Text
CP-201700904 TXX-17092 U.S. Nuclear Regulatory Commission ATIN: Document Control Desk Washington, DC 20555-0001 11/01/2017 V!S'!!!.'\\
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- energy Luminant
SUBJECT:
COMANCHE PEAK NUCLEAR POWER PLANT DOCKET NOS. 50-445 AND 50-446 Timothy A. Hope Manager, Regulatory Affairs Luminant P.O. Box 1002 6322 North FM 56 Glen Rose, TX 76043 0 254.897.6370 m 817.360.6882 Ref: 10 CFR 50.55a(z)(2)
RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING RELIEF REQUEST 1/2B3-2 FOR THE UNIT 1 AND UNIT 2 THIRD TEN YEAR INSERVICE INSPECTION INTERVAL (2007 EDITION OF ASME CODE, SECTION XI, 2008 ADDENDA UNIT 1 THIRD INTERVAL END DATE: AUGUST 12, 2020 UNIT 2 THIRD INTERVAL END DATE: AUGUST 2, 2024)
REFERENCES:
- 1. Letter logged TXX-17090 dated October 30, 2017, from Steven K. Sewell to the NRC submitting Relief Request 1/2B3-2 for the Unit 1 and Unit 2 Third Ten Year lnservice Inspection Interval
- 2. Email dated October 31, 2017, from Lisa Regner of the NRC to Jack Hicks of Vistra Operations Company LLC regarding additional information regarding Relief Request No. 1/2B3-2
Dear Sir or Madam:
Per Reference 1, Vistra Operations Company LLC ("VistraOpCo"), submitted Relief Request 1/2B3-2 for Comanche Peak Nuclear Power Plant Units 1 and 2 (herein referred to as CPNPP) for the third ten year inservice inspection interval. VistraOpCo is proposing an alternative to perform the examination bf selected Class 1 piping and valves at plant conditions other than those required by IWB-5220 in accordance with 10 CFR 50.55a(z)(2) due to hardship without a compensating increase in quality and safety.
Per Reference 2, the NRC provide a request for additional information regarding the subject relief request.
Attached is the VistraOpCo response to the request for additional information.
1601 BRYAN STREET DALLAS, TEXAS 7520'i 0 214-812-4600 VISTRAENERGY.COM
TXX-17092 Page 2 of 2 This communication contains no new licensing basis commitments regarding CPNPP Units 1 and 2.
Should you have questions concerning this submittal, please contact Jack C. Hicks at 254-897-6725, or e-mail at jack.hicks@luminant.com.
Attachment c-Sincerely,
~4-k Timothy A. Hope Response to Request for Additional Information Regarding Relief Request 1/283-2 System Leakage Test Conducted At or Near the End of Interval Kriss Kennedy, Region IV Margaret W. O'Banion, NRR Lisa Regner, NRR Resident Inspectors, Comanche Peak Brandon Kneupper, ANll, Comanche Peak
Attachment to TXX-17092 Page 1of6 COMANCHE PEAK NUCLEAR POWER PLANT UNITS 1 AND 2 RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING RELIEF REQUEST 1/2B3-2 SYSTEM LEAKAGE TEST CONDUCTED AT OR NEAR THE END OF INTERVAL (UNIT 1 THIRD INTERVAL END DATE: AUGUST 12, 2020; UNIT 2 THIRD INTERVAL END DATE: AUGUST 2, 2024)
NRC Request 1:
The licensee did not address reasons for a request for an NRC verbal authorization (e.g., the licensee has failed to comply with IWB-5220(b) required system leakage test in the first and second 10-year ISi intervals).
VistraOpCo Response to Request 1:
VistraOpCo is requesting a NRC verbal authorization for failing to comply with IWB-5220(b) required system leakage test in the first and second 10-year ISi intervals for both Units without an approved Relief Request. This is documented in the CPNPP corrective action program under CR-2017-010530 and CR-2017-011968.
NRC Request 2:
Were there any system leakage test performed during past (i.e., during 1st and 2"d) intervals and with what pressure?
VistraOpCo Response to Request 2:
Yes, system leakage tests have been performed during the 1st and 2nd intervals. See the following Tables 1 and 2 for pressures associated with the most recent tests.
Table 1: Unit 1 Class 1 Pressure Testing DescriQtion of Location TestLCondition Pressure Main RCS Loop Piping Mode3
> 2200 psi Charging/ Alt. Charging Mode3
> 2200 psi Aux Spray Line RCS System Fill 48 psi Cold Leg Injection OPT-614A
> 150 psi (990 psi in 1RF18)
Hot Leg Injection OPT-611A
> 150 psi (985 psi in 1RF18)
LHSI and IHSI Cold Leg Injection Mode3
> 600 psi (630 psi in 1RF18)
RHR Pump Suction from RCS HL RHR Shutdown 325 psi
. Attachment to TXX-17092 Page 2 of 6 Table 2: Unit 2 Class 1 Pressure Testing Descri~tion of Location TestLCondition Pressure Main RCS Loop Piping Mode3
> 2200 psi Charging/ Alt. Charging Mode3
> 2200 psi Aux Spray Line RCS System Fill 48 psi Cold Leg Injection OPT-614A
> 150 psi (1000 psi in 2RF16)
Hot Leg Injection OPT-611A
> 150 psi (1000 psi in 2RF16)
LHSi'and IHSI Cold Leg Injection Mode3
> 600 psi (630 psi in 2RF16)
RHR Pump Suction from RCS HL RHR Shutdown 325 psi NRC Request 3:
Were the previous system leakage tests performed with visual examination in accordance with IWA-5240 and IWA-5213 (pressure hold time)?
VistraOpCo Response to Request 3:
Yes, the previous system leakage tests were performed with visual examination in accordance with IWA-5240 and IWA-5213. Per IWA-5213 no hold time is required for Class 1 components after attaining test pressure.
NRC Request 4:
Discuss any operating experience regarding thermal fatigue in the subject piping segments.
VistraOpCo Response to Request 4:
Thermal Fatigue is addressed at CPNPP through the Thermal Fatigue Program which follows MRP-146.
The subject piping welds are outside the scope of MRP-146 as Thermal Fatigue is not credible upstream of the first isolation device. To date there have been no relevant indications found through the MRP-146 required exams on either unit.
Attachment to TXX-17092 Page 3 of 6 NRC Request 5:
The NRC staff notes that NRC Information Notice {IN) 2011-04, "Contaminants and Stagnant Conditions Affecting Stress Corrosion Cracking in Stainless Steel Piping in Pressurized water Reactors," discusses potential stress corrosion cracking (SCC) in the stainless steel piping. Discuss any operating experience regarding IN 2011-04 in the subject piping segments.
VistraOpCo Response to Request 5:
CPNPP has previously evaluated IN-2011-04 "Contaminants and Stagnant Conditions Affecting Stress Corrosion Cracking in Stainless Steel Piping in Pressurized Water Reactors". Awareness of the issue was presented to Operations, Quality Control, System Engineering and Maintenance. There have been no instances of sec reported in the subject piping segments or anywhere else at CPNPP.
NRC Request 6:
Provide the maximum test pressure for the proposed system leakage test for each pipe segment.
VistraOpCo Response to Request 6:
See Tables 3 and 4 for maximum test pressures for each pipe segment, for both Units.
Attachment to TXX-17092 Page 4 of 6 Table 3: Unit 1 Class 1 Piping Segments Maximum Pressure Flow Diagram Line Function First Isolation Affected Second Isolation No.
Valve Line Device Ml-0253 Sh. A Pressurizer Aux. Spray lCS-8377 CS-1-112 1-8145 1Sl-8900B Sl-1-200 1-8815 High Pressure Safety 1Sl-8900B Sl-1-026 1-8815 Injection - Loop 2 1Sl-8900B Sl-1-033 1-8815 1Sl-8900B Sl-1-303 1-8815 1Sl-8900A Sl-1-199 1-8815 Ml-0261 Sh. -
High Pressure Safety 1Sl-8900A Sl-1-025 1-8815 Injection - Loop 1 1Sl-8900A Sl-1-339 1-8815 High Pressure Safety 1Sl-8900D Sl-1-202 1-8815 Injection - Loop 4 1Sl-8900D Sl-1-028 1-8815 High Pressure Safety 1Sl-8900C Sl-1-201 1-8815 Injection - Loop 3 1Sl-8900C Sl-1-027 1-8815 1-8949B Sl-1-101 1-8841A Hot Leg Injection - Loop 2 1-8949B Sl-1-301 1Sl-8905B 1-8949C Sl-1-102 1-8841B Hot Leg Injection - Loop 3 1-8949C Sl-1-302 1Sl-8905C Ml-0263 Sh. -
1-8949A Sl-1-148 1Sl-8905A Hot Leg Injection - Loop 1 1-8949A Sl-1-059 1Sl-8905A 1-8949D Sl-1-172 1Sl-8905D Hot Leg Injection - Loop 4 1-8949D Sl-1-086 1Sl-8905D 1-8948A Sl-1-179 1-8956A 1-8948A Sl-1-089 1-8818A Cold Leg Injection - Loop 1 1-8948A Sl-1-063 1Sl-8819A lSl-0049 Sl-1-910 1-8956A 1-8948B Sl-1-180 1-8956B 1-8948B Sl-1-090 1-8818B I
Cold Leg Injection - Loop 2 1-8948B Sl-1-328 1-8818B 1-8948B Sl-1-065 1Sl-8819B Ml-0262 Sh. -
lSl-0050 Sl-1-908 1-8956B Ml-0263 Sh. -
1-8948C Sl-1-181 1-8956C 1-8948C Sl-1-091 1-8818C Cold Leg Injection - Loop 3 1-8948C Sl-1-330 1-8818C 1-8948C Sl-1-067 1Sl-8819C lSl-0051 Sl-1-911 1-8956C 1-8948D Sl-1-182 1-8956D 1-8948D Sl-1-092 1-8818D Cold Leg Injection - Loop 4 1-8948D Sl-1-069 1Sl-8819D lSl-0052 Sl-1-909 1-8956D RHR Suction - Train A 1-8702A RH-1-001 1-8701A Ml-0260 Sh. -
RHR Suction - Train B 1-8702B RH-1-002 1-8701B Max Pressure (psig) 55 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 440 440
Attachment to TXX-17092 Page 5 of 6 Table 4: Unit 2 Class 1 Piping Segments Maximum Pressure Flow Diagram Line Function First Isolation Affected Second Isolation No.
Valve Line Device M2-02S5 Sh. -
Pressurizer Aux. Spray 2CS-8377 CS-2-112 2-8145 2Sl-8900B Sl-2-200 2-8815 High Pressure Safety 2Sl-8900B Sl-2-026 2-8815 Injection - Loop 2 2Sl-8900B Sl-2-033 2-8815 2Sl-8900B Sl-2-303 2-8815 2Sl-8900A Sl-2-199 2-8815 M2-0261 Sh. -
High Pressure Safety 2Sl-8900A Sl-2-025 2-8815 Injection - Loop 1 2Sl-8900A Sl-2-339 2-8815 High Pressure Safety 2Sl-8900D Sl-2-202 2-8815 Injection - Loop 4 2Sl-8900D Sl-2-028 2-8815 High Pressure Safety 2Sl-8900C Sl-2-201 2-8815 Injection - Loop 3 2Sl-8900C Sl-2-027 2-8815 2-8949B Sl-2-101 2-8841A Hot Leg Injection - Loop 2 2-8949B Sl-2-301 2Sl-8905B 2-8949C Sl-2-102 2-8841B Hot Leg Injection - Loop 3 2-8949C Sl-2-302 2Sl-8905C M2-0263 Sh. -
2-8949A Sl-2-148 2Sl-8905A Hot Leg Injection - Loop 1 2-8949A Sl-2-059 2Sl-8905A 2-8949D Sl-2-172 2Sl-8905D Hot Leg Injection - Loop 4 2-8949D Sl-2-086 2Sl-8905D 2-8948A Sl-2-179 2-8956A 2-8948A Sl-2-089 2-8818A Cold Leg Injection - Loop 1 2-8948A Sl-2-063 2Sl-8819A 2-8948A 3/4-2501R-1 2Sl-0049 2-8948B Sl-2-180 2-8956B 2-8948B Sl-2-090 2-8818B Cold Leg Injection - Loop 2 2-8948B Sl-2-328 2-8818B 2-8948B Sl-2-065 2Sl-8819B M2-0263 Sh. B 2-8948B 3/4-2501R-1 2Sl-0050 M2-0263 Sh. -
2-8948C Sl-2-181 2-8956C 2-8948C Sl-2-091 2-8818C Cold Leg Injection - Loop 3 2-8948C Sl-2-330 2-8818C 2-8948C Sl-2-067 2Sl-8819C 2-8948C 3/4-2501R-1 2Sl-0051 2-8948D Sl-2-182 2-89560 2-89480 Sl-2-092 2-8818D Cold Leg Injection - Loop 4 2-8948D Sl-2-069 2Sl-8819D 2-8948D 3/4-2501R-1 2Sl-0052 RHR Suction - Train A 2-8702A RH-2-001 2-8701A M2-0260 Sh. -
RHR Suction - Train B 2-8702B RH-2-002 2-8701B Max Pressure (psig) 55 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 1800 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 644 440 440
Attachment to TXX-17092 Page 6 of 6 NRC Request 7:
Will the proposed system leakage tests be performed with visual examination in accordance with IWA-5240 and IWA-5213 (pressure hold time)?
VistraOpCo Response to Request 7:
Yes, system leakage tests performed with visual examination will be performed in accordance with IWA-5240 and IWA-5213. Per IWA-5213 no hold time is required for Class 1 components after attaining test pressure.
NRC Request 8:
Provide an estimate for person-roentgen equivalent man (rem) exposure with consideration of an as low as reasonably achievable (ALARA).
VistraOpCo Response to Request 8:
It is estimated (with consideration of ALARA) that extending the boundary to the second isolation valve for all Class 1 components would result in a total dose of 1.926 REM and would require an estimated 147 man hours for Unit 1. The estimate for Unit 2 is 1.767 REM and would require an estimated 136 man hours. The estimate is based on discussions with Operations, Radiation Protection, Maintenance, and Scaffolding about the associated activity durations and local dose rates for the following activities; scaffold erection, insulation removal, valve manipulations, blind flange work, freeze seals, exams, re-installation of insulation and scaffold removal.