NRC-16-0049, Response to Request for Additional Information Regarding License Amendment Request to Revise Integrated Leak Rate Test - Type a and Type C Test Intervals

Response to Request for Additional Information Regarding License Amendment Request to Revise Integrated Leak Rate Test - Type a and Type C Test Intervals

ML16225A493
Person / Time
Site:	Fermi
Issue date:	08/11/2016
From:	Polson K DTE Electric Company, DTE Energy
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NRC-16-0049
Download: ML16225A493 (28)

Text

Keith J. Poison Site Vice President DTE Energy Company 6400 N. Dixie Highway, Newport, MI 48166 Tel: 734.586.4849 Fax: 734.586.4172 Email: poisonk@dteenergy.com August 11, 2016 NRC-16-0049 U. S. Nuclear Regulatory Commission Attention: Document Control Desk Washington, D.C. 20555-0001

References:

1) Fermi 2 NRC Docket No. 50-341 NRC License No. NPF-43

2) DTE Electric Letter to NRC, "License Amendment Request to Revise Integrated Leak Rate Test (Type A) and Type C Test Intervals," NRC-16-0006, dated March 22, 2016 (ML16082A309)

Subject:

Response to Request for Additional Information Regarding License Amendment Request to Revise Integrated Leak Rate Test - Type A and Type C Test Intervals In Reference 2, DTE Electric Company (DTE) submitted a license amendment request (LAR) to revise the Integrated Leak Rate Test Type A and Type C test intervals at Fermi 2. In an email from Ms. Sujata Goetz to Mr. Jason Haas dated July 14, 2016, the NRC sent DTE a request for additional information (RAI) regarding this LAR. The response to the RAI is enclosed.

No new commitments are being made in this submittal.

Should you have any questions or require additional information, please contact Mr. Scott A. Maglio, Manager - Nuclear Licensing, at (734) 586-5076.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on August 11, 2016 Keith J. Polson Site Vice President

Enclosure:

Response to Request for Additional Information

USNRC NRC-16-0049 Page 2 cc: NRC Project Manager NRC Resident Office Reactor Projects Chief, Branch 5, Region III Regional Administrator, Region III Michigan Public Service Commission Regulated Energy Division (kindschl@michigan.gov)

Enclosure to NRC-16-0049 Fermi 2 NRC Docket No. 50-341 Operating License No. NPF-43 Response to Request for Additional Information

Enclosure to NRC-16-0049 Page 1 Response to Request for Additional Information SBPB RAI-1 The staff notes that the Fermi 2 containment has been in service for approximately 35 years.

Please provide a history of repairs and modifications made to the containment structure, so that the NRC staff can verify that Fermi is in compliance with Final safety evaluation for nuclear energy institute (NEI) Topical report (TR) 94-01, revision 2, industry guideline for Implementing performance-based option of 10 CFR part 50, Appendix j and electric power research institute (EPRI) Report no. 1009325, revision 2, august 2007, risk impact Assessment of extended integrated leak rate testing intervals, Section 3.1.4, Major and Minor Containment Repairs and Modifications (ADAMS Accession No. ML081140105).

RESPONSE

DTE Electric Company (DTE) is currently committed to NEI 94-01, Revision 0. This License Amendment Request (LAR) will revise the Fermi 2 Technical Specifications (TS) to follow NEI 94-01, Revision 3-A. NEI 94-01, Revision 3-A, did not include the six conditions and limitations from Section 4.1 of the NRCs Safety Evaluation Report (SER) for Revision 2-A.

Therefore, as discussed in Section 3.1 and Table 2 of Enclosure 1 to the original LAR, DTE is adopting NEI 94-01, Revision 3-A, with the six conditions and limitations from the NRCs SER for Revision 2-A.

Per Section 3.1.4 of the NRCs SER for NEI 94-01, Revision 2-A:

The NRC staff considers the cutting of a large hole in the containment for replacement of steam generators or reactor vessel heads, replacement of large penetrations, as major repair or modifications to the containment structure.

There have been no repairs or modifications to the containment structure. The history of coating repairs and moisture seal replacement was provided in Section 3.3.1 of Enclosure 1 of the original LAR (pages 18-20 of Enclosure 1). The following excerpts describing conditions are provided with their corresponding page numbers from Enclosure 1 of the original LAR. The pits noted in the excerpts below are all well within design tolerances.

During the examination of containment that was completed during the seventh refueling outage (RF07), in the spring of 2000, visual inspections identified a small (0.02 x 0.04 x 0.093 inch deep) pit at the interface of an I-beam with the containment steel liner. The corrosion was attributed to a screw and uncoated washer that were in contact with an uncoated portion of the drywell shell in a beam seat area. The screw and washer were removed and the drywell shell in the area of the pit was coated in 2003. (page 19)

In RF07, during the first containment inspection interval, the moisture seal at the interface between the drywell concrete floor and the steel shell was removed.

Enclosure to NRC-16-0049 Page 2 This was done to perform a detailed inspection of the liner in the seal area, repair areas of degradation in the seal, and as a preventive maintenance task. The inspection found no degradation to the drywell shell. The area was repainted and a new moisture seal was installed. In accordance with ASME Section XI, 2001 Edition with 2003 Addenda, the moisture barrier is inspected 100 percent each inspection period. (page 19)

One 0.25 inch diameter pit has been identified in the torus wetted area during the history of the plant. The pit, a corrosion pit 0.0285 inches in depth, was identified under a coating blister in 2001. The depth of the pit left the remaining shell thickness well within design tolerances. The coating was repaired. (page 20)

Coating condition continues to be monitored during inspections. In RF15, broken blisters, mechanical damage, and pinpoint rust areas were identified and repaired in the wetted areas of the torus. In the vapor region, all flaking paint was removed from the torus ring header, torus vacuum breaker valves, nitrogen supply lines, monorail rail, and torus walkway and handrail (not primary containment pressure boundary). Flaking or cracked coating was removed and protective coating was re-applied to the torus shell. As stated above, no pitting of the torus was identified during the 2012 (RF15) inspections. (page 20)

Enclosure to NRC-16-0049 Page 3 SBPB RAI-2 Your letter, dated March 22, 2016, provided the following table:

Table 3: DTE Electric Company Type A Test Historical Results Since 1989 Test Completion Date Upper Confidence Limit Measured Leakage

(%/day)

Correction for Type B and C Tests

(%/day)

Total Leakage

(%/day)

Acceptance Criteria

(%/day) 11/29/1989 0.285 0.033 0.318 0.375 11/01/1992 0.212 0.032 0.244 0.375 11/10/2007 0.1168 0.0964 0.2132 0.375 Fermi, Unit 2 Technical Specification (TS), Section, 5.5.12, Primary Containment Leakage Rate Testing Program (ADAMS Accession ML053060228) states:

b. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 56.5 psig.

c. The maximum allowable containment leakage rate, La at Pa, shall be 0.5% of containment air weight per day.

d. Leakage Rate acceptance criteria are:

1. Containment leakage rate acceptance criteria is 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are 0.60 La for the required Type B and Type C tests and 0.75 La for Type A tests.

The staff requests the test pressures used during the two most recent Type A tests, so that it can confirm that at least one of the actual test pressures bound the TS 5.5.12b Pa value of 56.5 psig.

Please provide the Type A test pressure values in terms of absolute pressure along with the atmospheric pressure, since BN-TOP-1, Revision 1, Testing Criteria for Integrated Leakage Rate Testing of Primary Containment Structures for Nuclear Power Plants, Section 4.1, Parameters Monitored (ADAMS Accession No. ML083540173), states:

During the primary containment leakage rate tests, measurements are made of absolute pressure.

The licensees response must supply sufficient information to demonstrate compliance with NEI 94-01 Revision 0, Industry Guideline for Implementing Performance -Based Option of 10 CFR Part 50, Appendix J, (ADAMS Accession No. ML11327A025), Section 9.2.3 Extended Test Intervals and the test requirements of ANSI/ANS 56.8-1994, American National Standard for Containment System Leakage Testing Requirements, (Adams Accession No. ML11327A024),

Section 3.2.11, Type A Test Pressure.

Enclosure to NRC-16-0049 Page 4

RESPONSE

The test pressures used during the two most recent Type A tests are contained in the table below.

Test Completion Date Gauge Pressure (psig)

Absolute Pressure (psia)

Atmospheric Pressure (atm) 11/1/1992 57.51 72.21 14.70 11/10/2007 57.025 71.552 14.527 NEI 94-01 Revision 0, Industry Guideline for Implementing Performance-Based Option of 10 CFR 50, Appendix J, Section 9.2.3, Extended Test Intervals, states that:

Type A testing shall be performed during a period of reactor shutdown at a frequency of at least once per 10 years based on acceptable performance history. Acceptable performance history is defined as completion of two consecutive periodic Type A tests where the calculated performance leakage rate was less than 1.0 La.

It also states that:

In the event where previous Type A tests were performed at reduced pressure, at least one of the two consecutive periodic Type A tests shall be performed at peak accident pressure (Pac).

The test requirements of ANSI/ANS 56.8-1994, American National Standard for Containment System Leakage Testing Requirements, Section 3.2.11, Type A Test Pressure, state that:

The Type A test pressure shall not be less than 0.96Pac (psig) nor exceed Pd. For those plants with a Pac of 25 psig or less, Pac minus 1 psi shall be the minimum test pressure for the duration of the Type A test. The test pressure shall be established relative to the external pressure of the primary containment measured at the start of the Type A test.

Fermi 2 Pac (the calculated peak containment internal pressure related to the DBA) is 56.5 psig, and the Pd (the containment allowable design limit) is 62.0 psig. Therefore, as indicated by the results in the table above, all of the criteria discussed above were met.

Enclosure to NRC-16-0049 Page 5 SBPB RAI-3 In order for the staff to confirm that the Type A tests performed on November 10, 2007 and November 1, 1992 meet the criteria in NEI 94-01 Revision 3-A, Industry Guideline for Implementing Performance - Based Option of 10 CFR Part 50, Appendix J (ADAMS Accession No. ML12221A202), Section 9.2.3, Extended Test Intervals, please provide the following information:

(a) Provide the as-left minimum pathway leakage rate (MNPLR) for all Type B and Type C pathways that were in service, isolated, or not lined up in their test position (i.e., drained and vented to containment atmosphere) prior to performing the Type A test, (b) List all the pathways and the associated leakage rate that contribute to MNPLR in item (a),

above.

(c) Provide the performance Leakage Rate (PLR) (= UCL+MNPLR) where UCL is the upper confidence limit, (d) Determine if the as-found Type A test meet the performance criterion by showing if PLR 1.0 La (e) Cite the calculation method for UCL, i.e. Mass Point method from ANSI/ANS-56.8-1994, Total Time, or Point-to-Point etc.

RESPONSE

(a) The requested data for the 2007 and 1992 tests are provided on the following pages in Table 3-1 and Table 3-2, respectively.

Enclosure to NRC-16-0049 Page 6 Table 3-1: 2007 ILRT Penetration Number Description Leakage (SCFH)

Penalty

(%/day)

T2301-X100A Drywell Electrical Penetration 0.05 0.000084 T2301-X100B Drywell Electrical Penetration 0.05 0.000084 T2301-X100C Drywell Electrical Penetration 0.05 0.000084 T2301-X100E Drywell Electrical Penetration 0.05 0.000084 T2301-X100F Drywell Electrical Penetration 0.05 0.000084 T2301-X100G Drywell Electrical Penetration 0.05 0.000084 T2301-X101A Drywell Electrical Penetration 0.05 0.000084 T2301-X101B Drywell Electrical Penetration 0.05 0.000084 T2301-X101C Drywell Electrical Penetration 0.05 0.000084 T2301-X101D Drywell Electrical Penetration 0.05 0.000084 T2301-X101E Drywell Electrical Penetration 0.05 0.000084 T2301-X101F Drywell Electrical Penetration 0.05 0.000084 T2301-X102A Drywell Electrical Penetration 0.05 0.000084 T2301-X102B Drywell Electrical Penetration 0.05 0.000084 T2301-X102C Drywell Electrical Penetration 0.05 0.000084 T2301-X102D Drywell Electrical Penetration 0.05 0.000084 T2301-X103A Drywell Electrical Penetration 0.05 0.000084 T2301-X103B Drywell Electrical Penetration 0.05 0.000084 T2301-X104A Drywell Electrical Penetration 0.05 0.000084 T2301-X104B Drywell Electrical Penetration 0.05 0.000084 T2301-X104C Drywell Electrical Penetration 0.05 0.000084 T2301-X104D Drywell Electrical Penetration 0.05 0.000084 T2301-X104E Drywell Electrical Penetration 0.05 0.000084 T2301-X104F Drywell Electrical Penetration 0.05 0.000084 T2301-X105A Drywell Electrical Penetration 0.05 0.000084 T2301-X105D Drywell Electrical Penetration 0.05 0.000084 T2301-X106A Drywell Electrical Penetration 0.05 0.000084 T2301-X106B Drywell Electrical Penetration 0.05 0.000084 T2302-X209A Torus Electrical Penetration 0.05 0.000084 T2302-X209C Torus Electrical Penetration 0.05 0.000084 T2302-X228A Torus Electrical Penetration 0.05 0.000084 T2302-X228B Torus Electrical Penetration 0.06 0.000101 T2302-X228C Torus Electrical Penetration 0.06 0.000101 T2302-X228D Torus Electrical Penetration 0.05 0.000084 X-8 Main Steam Line Drains 0.05 0.000084 X-9A FW, HPCI, Injection 0.12 0.000202 X-9B FW, RCIC, RWCU, Injection 0.40 0.000675 X-10 RCIC Steam Supply 0.05 0.000084 X-11 HPCI Steam Supply 0.34 0.000574 X-17 RHR Head Spray 0.09 0.000152 X-18 Floor Drain Sump 0.22 0.000371

Enclosure to NRC-16-0049 Page 7 Table 3-1: 2007 ILRT Penetration Number Description Leakage (SCFH)

Penalty

(%/day)

X-19 Equipment Drain Sump 0.05 0.000084 X-20 Demineralized Water 0.09 0.000152 X-22 Division 1 Drywell Nitrogen 0.05 0.000084 X-27b PASS P34F404A & F403A 0.08 0.000135 X-28Cf PASS Division 1 0.05 0.000084 X-29Aa Vessel Sample 0.05 0.000084 X-35B TIP 0.05 0.000084 X-35C TIP 0.05 0.000084 X-35D TIP 0.05 0.000084 X-35E TIP 0.05 0.000084 X-35F TIP 0.05 0.000084 X-36 Division 2 Drywell Nitrogen 0.05 0.000084 X-39B RHR Flange 0.05 0.000084 X-40Dd PASS Division 2 0.05 0.000084 X-42 Standby Liquid Control 0.05 0.000084 X-43 RWCU Suction 0.33 0.000557 X-48a-e Rad Monitor T50F450, T5000F456 0.05 0.000084 X-48f PASS P34F403B & F404B 0.08 0.000135 X-49a Recirc Seal B 0.05 0.000084 X-51a Recirc Seal A 0.05 0.000084 X-214 HPCI Vacuum Breakers 1.18 0.001991 X-214 RCIC Vacuum Breakers 0.05 0.000084 X-215 PASS P34F408 & F410 0.05 0.000084 X-215 PCRM T50F451 & T5000F455 0.05 0.000084 X-230 PASS P34F405B & F406B 0.17 0.000287 X-231 PASS P34F405A & F406A 0.08 0.000135 X-23 Division 1 EECW Leakage Division 1 Drywell Supply 0.05 0.000084 X-24 Division 1 EECW Leakage Division 1 Drywell Return 0.17 0.000287 X-34A Division 2 EECW Leakage Division 2 Drywell Supply 0.05 0.000084 X-34B Division 2 EECW Leakage Division 2 Drywell Return 0.06 0.000101 X-12 RHR LPCI Suction 0.05 0.000084 X-16B Core Spray Division 1 0.05 0.000084 X-39A RHR Division 1 Containment Spray 1.24 0.002096 X-211B RHR Division 1 Torus Spray 2.23 0.003769 X-15 X-215 X-218 Division 1 Post LOCA Thermal Recombiner System Leakage Test 0.05 0.000084

Enclosure to NRC-16-0049 Page 8 Table 3-1: 2007 ILRT Penetration Number Description Leakage (SCFH)

Penalty

(%/day)

X-44 X-218 X-219 Division 2 Post LOCA Thermal Recombiner System Leakage Test 0.13 0.000220 X-48a-e X-215 X-230 Division 1 Primary Containment Monitoring System (PCMS) Leakage Test 1.09 0.001842 X-27a-e X-219 X-231 Division 2 Primary Containment Monitoring System (PCMS) Leakage Test 0.25 0.000422 X-37 & X-38 Scram Discharge Volume (SDV) Vents 0.14 0.000237 X-37 & X-38 Scram Discharge Volume (SDV) Drains 0.05 0.000084 Table 3-2: 1992 ILRT Penetration Number Description Leakage (SCFH)

Penalty

(%/day)

T2301-X100A Drywell Electrical Penetration 0.137 0.0002329 T2301-X100B Drywell Electrical Penetration 0.28 0.000476 T2301-X100C Drywell Electrical Penetration 0.047 0.0000799 T2301-X100E Drywell Electrical Penetration 0.047 0.0000799 T2301-X100F Drywell Electrical Penetration 0.138 0.0002346 T2301-X100G Drywell Electrical Penetration 0.094 0.0001598 T2301-X101A Drywell Electrical Penetration 0.047 0.0000799 T2301-X101B Drywell Electrical Penetration 0.047 0.0000799 T2301-X101C Drywell Electrical Penetration 0.047 0.0000799 T2301-X101D Drywell Electrical Penetration 0.047 0.0000799 T2301-X101E Drywell Electrical Penetration 0.047 0.0000799 T2301-X101F Drywell Electrical Penetration 0.076 0.0001292 T2301-X102A Drywell Electrical Penetration 0.15 0.000255 T2301-X102B Drywell Electrical Penetration 0.047 0.0000799 T2301-X102C Drywell Electrical Penetration 0.05 0.000085 T2301-X102D Drywell Electrical Penetration 0.047 0.0000799 T2301-X103A Drywell Electrical Penetration 0.151 0.0002567 T2301-X103B Drywell Electrical Penetration 0.057 0.0000969 T2301-X104A Drywell Electrical Penetration 0.049 0.0000833 T2301-X104B Drywell Electrical Penetration 0.054 0.0000918 T2301-X104C Drywell Electrical Penetration 0.0513 0.00008721 T2301-X104D Drywell Electrical Penetration 0.047 0.0000799 T2301-X104E Drywell Electrical Penetration 0.047 0.0000799 T2301-X104F Drywell Electrical Penetration 0.065 0.0001105 T2301-X105A Drywell Electrical Penetration 0.054 0.0000918

Enclosure to NRC-16-0049 Page 9 Table 3-2: 1992 ILRT Penetration Number Description Leakage (SCFH)

Penalty

(%/day)

T2301-X105D Drywell Electrical Penetration 0.047 0.0000799 T2301-X106A Drywell Electrical Penetration 0.215 0.0003655 T2301-X106B Drywell Electrical Penetration 0.047 0.0000799 T2302-X209A Torus Electrical Penetration 0.047 0.0000799 T2302-X209C Torus Electrical Penetration 0.127 0.0002159 T2302-X228A Torus Electrical Penetration 0.047 0.0000799 T2302-X228B Torus Electrical Penetration 0.047 0.0000799 T2302-X228C Torus Electrical Penetration 0.047 0.0000799 T2302-X228D Torus Electrical Penetration 0.047 0.0000799 X-9A FW, HPCI, Injection 0.26 0.000442 X-9B FW, RCIC, RWCU, Injection 0.16 0.000272 X-18 Floor Drain Sump 0.57 0.000969 X-19 Equipment Drain Sump 0.047 0.0000799 X-43 RWCU Suction 0.047 0.0000799 X-23 Division 1 EECW Leakage Division 1 Drywell Supply 1.93 0.003281 X-24 Division 1 EECW Leakage Division 1 Drywell Return 0.047 0.0000799 X-39A RHR Division 1 Containment Spray 0.557 0.0009469 X-13B RHR Division 1 LPCI 0.18 0.000306 X-211B RHR Division 1 Torus Spray 0.786 0.0013362 X-39B RHR Division 2 Core Spray 1.29 0.002193 X-13A RHR Division 3 LPCI 0.047 0.0000799 X-211A RHR Division 2 Torus Spray 0.054 0.0000918 X-17 RHR Division 2 Head Spray 0.047 0.0000799 X-48a-e Division 1 Primary Containment Monitoring System (PCMS) Leakage Test 0.427 0.0007259 X-215 Division 1 Primary Containment Monitoring System (PCMS) Leakage Test 0.459 0.0007803 X-230 Division 1 Primary Containment Monitoring System (PCMS) Leakage Test 0.11 0.000187 X-27a-e Division 2 Primary Containment Monitoring System (PCMS) Leakage Test 0.67 0.001139 X-231 Division 2 Primary Containment Monitoring System (PCMS) Leakage Test 0.143 0.0002431 X-219 Division 2 Primary Containment Monitoring System (PCMS) Leakage Test 0.52 0.000884 X-37 & X-38 Control Rod Drive Scram Discharge Volume 2.027 0.0034459

Enclosure to NRC-16-0049 Page 10 (b) The requested data for the 2007 and 1992 tests are provided below in Table 3-3 and Table 3-4, respectively.

Table 3-3: 2007 ILRT Total Leakage (SCFH)

Penalty

(%/day)

Electrical Penetrations 1.72 0.002906 Mechanical Penetrations 4.23 0.007148 EECW Penetrations 0.22 0.000371 EECS Divisional Leakage 3.57 0.006033 Post LOCA Thermal Recombiner (TRS) System Div 2 Leakage 0.13 0.000220 Post LOCA Thermal Recombiner (TRS) System Div 1 Leakage 0.05 0.000084 Primary Containment Monitoring (PCMS) Division 1 1.09 0.001842 Primary Containment Monitoring (PCMS) Division 2 0.25 0.000422 Control Rod Drive Scram Discharge Volume 0.19 0.000321 Total Penalty Leakage 11.45 0.019351 Table 3-4: 1992 ILRT Total Leakage (SCFH)

Penalty

(%/day)

Electrical Penetrations 2.5943 0.00441031 Mechanical Penetrations 1.084 0.0018428 EECW Penetrations 1.977 0.0033609 EECS Division Leakage (Worst) 2.961 0.0050337 Primary Containment Monitoring (PCMS) Division 1 0.996 0.0016392 Primary Containment Monitoring (PCMS) Division 2 1.333 0.0022661 Control Rod Drive Scram Discharge Volume 2.027 0.0034459 Total Penalty Leakage 12.9723 0.0220529 (c) In 2007, the performance leakage rate (PLR) (=UCL+MNPLR), where UCL is the upper confidence limit, was 0.213 (%/day). The BN-TOP-1 UCL was 0.1166 (%/day). The MNPLR was 0.0194 (%/day) for Type B and Type C penalty leakage, 0.029 (%/day) for Nitrogen In-Leakage correction, and the water level correction was 0.048 (%/day). All of these added together equaled 0.213 (%/day).

Enclosure to NRC-16-0049 Page 11 In 1992, the performance leakage rate (PLR) (=UCL+MNPLR), where UCL is the upper confidence limit, was 0.244 (%/day). The BN-TOP-1 UCL was 0.2116 (%/day). The MNPLR was 0.0221 (%/day) for Type B and Type C penalty leakage, 0.0097 (%/day) for Nitrogen In-leakage correction, and the water level correction was 0.0 (%/day). All of these added together equaled 0.244 (%/day).

(d) NEI 94-01, Revision 3-A, Section 9.2.3, Extended Test Intervals, states:

For purposes of determining an extended test interval, the performance leakage rate is as defined in Section 5.0 and repeated here for completeness: The performance leakage rate is calculated as the sum of the Type A upper confidence limit (UCL) and as-left minimum pathway leakage rate (MNPLR) leakage rate for all Type B and Type C pathways that were in service, isolated, or not lined up in their test position (i.e., drained and vented to containment atmosphere) prior to performing the Type A test. In addition, leakage pathways that were isolated during performance of the test because of excessive leakage must be factored into the performance determination. If the pathway leakage can be determined by a local leakage rate test, the as-left MNPLR for that leakage path must also be added to the Type A UCL. If an excessively leaking containment penetration barrier pathway is discovered during the Type A test, and the pathway is neither a Type B or a Type C tested pathway, it shall still be tested to Type B or Type C test requirements after the Type A test and its as-left MNPLR added to the Type A test UCL. In this case the Type A test performance criterion is not met unless that pathway is subsequently added to the Type B or Type C test program. If the excessive leakage is from a source that can be tested only during a Type A test, the Type A test performance criterion is not met.

NEI 94-01, Revision 3-A, Section 5.0, Definitions, states that:

the performance leakage rate is calculated as the sum of the Type A upper confidence limit (UCL) and as-left minimum pathway leakage rate (MNPLR) leakage rate for all Type B and Type C pathways that were in service, isolated, or not lined up in their test position (i.e., drained and vented to containment atmosphere) prior to performing the Type A test. In addition, leakage pathways that were isolated during performance of the test because of excessive leakage must be factored into the performance determination.

The performance criterion for Type A tests is a performance leak rate of less than 1.0La.

In 2007, the performance leakage rate (PLR) (=UCL+MNPLR), where UCL is the upper confidence limit, was 0.213 (%/day), as discussed in the response to part (c) above. In 1992, the performance leakage rate (PLR) (=UCL+MNPLR), where UCL is the upper confidence limit, was 0.244 (%/day), as discussed in the response to part (c) above. Based on the definition for PLR contained within NEI 94-01, Revision 3-A, the performance criterion for PLR 1.0 La (0.5 %/day) has been met.

(e) The calculation method is the Total Time Method (BN-TOP-1).

Enclosure to NRC-16-0049 Page 12 SBPB RAI-4 NEI 94-01, Revision 3-A, states that prior to determining and implementing extended test intervals for Type B and Type C components, an assessment of the plants containment penetration and valve performance should be performed and documented. Factors that should be considered during the assessment include (but not limited to) past component performance, service, design, safety impact; and cause determination. In addition, Section 11.3.2, Programmatic Controls, require additional considerations if the test interval is greater than 60 months such as As-found tests, schedule, and review. Your [[letter::05000341/LER-2015-005-01, Regarding Secondary Containment Inoperable Due to RBHVAC Damper Malfunction|letter dated March 22, 2016]], does not address how these factors are incorporated into the current Fermi 2 plant specific 10 CFR 50, Appendix J, testing program.

The staff requests that the licensee provide a summary of how Fermi 2 incorporates these factors and considerations in its current 10 CFR 50, Appendix J, testing program and whether any significant program enhancements will be required after the staffs approval of the proposed amendment.

RESPONSE

Fermi 2 assesses and documents the plants containment penetrations and valve performance in a post-outage test report. The outage report contains the results of all Type B and Type C tests performed during the previous operating cycle and the results of Type B and Type C tests performed during the outage. The report includes evaluations that take into account the past test performance, service, frequency, design, and safety impact for Type B and Type C tested components that are evaluated for frequency extension. The evaluations include containment isolation valve failures, the failure cause and corrective actions, and valves that exceeded established repair guidelines.

Fermi 2 will continue to assess and document the plants containment penetrations and valve performance in post-outage evaluations. Per NEI 94-01, Revision 3-A, Section 11.3.2, Programmatic Controls, for extending test intervals of greater than 60 months for a Type B or a Type C tested component, the post-outage report will also include an estimate of the amount of understatement in the minimum pathway Type B & C summation, and the reasoning and determination of the acceptability of the extension. Fermi 2 procedures will be enhanced to incorporate the amount of understatement in the minimum pathway Type B and Type C summation.

Enclosure to NRC-16-0049 Page 13 SBPB RAI-5 Per the guidance of NEI 94-01 Revision 0, Section 10.2.3.2 and subject to the four exemptions identified in NRC Regulatory Guide 1.163, (Draft was DG-1037) Performance-Based Containment Leak-Rate Testing program, (ADAMS Accession No. ML11327A025), Fermi 2 is currently allowed to extend the test intervals for Type C containment isolation valves (CIVs) up to 60 months.

Section 10.2.3.2, Extended Test Interval of NEI 94-01, of both Revision 0 and Revision 3-A states in part:

Test intervals for Type C valves may be increased based upon completion of two consecutive periodic As-found Type C tests where the result of each test is within a licensee's allowable administrative limits.

The staff requests that the licensee provide additional information regarding:

1) The two most recent individual As-Found Type C test results, including administrative limits, for Fermi 2 containment isolation valves. Also provide a brief valve description and any required corrective actions.

Your letter, dated March 22, 2016, details repetitive Type C Local Leak Rate Test (LLRT) failures for valves associated with Penetrations X-42 and X-19. Please provide a summary about the causes of these failures and what long term corrective actions have been or will be implemented to prevent recurrence.

2) Also in your [[letter::05000341/LER-2015-005-01, Regarding Secondary Containment Inoperable Due to RBHVAC Damper Malfunction|March 22, 2016 letter]], you indicate a valve seat condition failure for Penetration X-9B (i.e. Valve B2100F076B). Have there been other failures of LLRTs associated with Penetrations X-9A and X-9B since RF12 in 2007 that would suggest the corrective actions associated with LER 2007-001 may need further enhancement? (If there had been other failures, it would have been in this table. Also referencing an LER we are getting into inspection space.

RESPONSE

1) The two most recent test results are provided at the end of this response in Table 5-1 (and associated notes following the table) for the Type C air tests and Table 5-2 for the Type C water tests. In both tables, the most recent As-Found test result is in the far-right column (labeled as T1) and the next most recent As-Found test result is in the second column from the right (labeled as T2). Correction actions were discussed in Tables 4.1-1 and 4.1-2 of of the original LAR. Additional details regarding the corrective actions for penetrations X-42 and X-19 are provided as follows.

Enclosure to NRC-16-0049 Page 14 The cause of the failures for penetration X-42 (C4100F006 Standby Liquid Control Injection Line Outboard Check Valve and C4100F007 Standby Liquid Control Injection Line Inboard Check Valve) was that the valve soft seats were degraded. The corrective actions for these components included the valves being disassembled, inspected, cleaned, and the valve soft seats were replaced. The Preventive Maintenance (PM) events were also reviewed for proper alignment. Based on the review, the frequencies of the PM events to disassemble the valve, inspect, clean, and replace soft seats for the C4100F006 and C4100F007 valves were changed from 9 years to 6 years. Currently, these valves are tested on a one refuel (1R) frequency.

In RF16, penetration X-19, (G1154F018 Drywell Equipment Drain Sump Inboard Containment Isolation Valve and G1100F019 Drywell Equipment Drain Sump Outboard Containment Isolation Valve) valves G1154F018 and G1100F019 were above their acceptance criteria. The acceptance criterion for both G1154F018 and G1100F019 is 2.0 SCFH. The measured As-Found leakage rates in RF16 were 5.75 SCFH for G1154F018 and 2.30 SCFH for G1100F019. The cause was determined to be seat degradation attributed to poor water quality. As part of the corrective actions, an evaluation was performed to document and accept the RF16 measured leakage rate of these components, as there was minimal impact to the overall primary containment leakage rate. Based on the minimal impact of the measured leakage rates, they were accepted for Cycle 17 and these components were required to be tested again in RF17. Contingent work orders were planned for maintenance in RF17 and a 1R test frequency was put into place based on the measured As-Found leakage rate.

In RF17, Penetration X-19, the As-Found measured leakage rates were 1.06 SCFH for G1154F018 and 7.32 SCFH for G1100F019. The cause of failure of G1100F019 was that the wedge had linear markings. The corrective actions taken included disassembly of the G1100F019 and the wedge was polished, as stated in Table 4.1-2 of the original LAR. The As-Left measured leakage for G1100F019 was 0.05 SCFH.

2) Since 2007 there have been no valve failures on penetration X-9A. There have been two valve failures on penetration X-9B. During RF13 (2009), B2100F010B was above the allowable leakage limit of 10.0 SCFH. The measured leakage rate was 55.20 SCFH. During RF16 (2014), B2100F076B was above the allowable leakage limit of 10.0 SCFH. The measured leakage rate was 11.66 SCFH. The corrective action to replace the soft seat every refuel on B2100F076A/B has been successful with only the one marginal failure. The inboard feedwater check valves (B2100F010A/B) had their soft seats removed and were hard seated in RF14 (2010). All subsequent as found tests have been successful. The hard seating was discussed in Section 3.2.2 of the original LAR. As required by NEI 94-01, these penetrations are tested every refuel outage.

Enclosure to NRC-16-0049 Page 15 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-8 B2103-F016 Main Steam Line Inboard Drain Isolation Valve 2.5 0.05 0.05 B2130-F019 Main Steam Line Outboard Drain Isolation Valve 2

0.05 0.05 X-9A B2100-F010A Feedwater Supply Line A Inboard Check Valve 10 0.05 0.05 B2100-F076A Feedwater Supply Line A Outboard Check Valve 10 0.05 0.12 E4150-F006 HPCI Main Pump Discharge Inboard Isolation Valve X-9B B2100-F010B Feedwater Supply Line B Inboard Check Valve 10 0.07 0.05 B2100-F076B Feedwater Supply Line B Outboard Check Valve 10 11.66 0.17 E5150-F013 RCIC Discharge to FW Inboard Isolation Valve G3352-F220 RWCU to FW Outboard Containment Isolation Valve X-10 E5150-F007 RCIC Turbine Steam Supply Inboard Containment Isolation Valve 3

0.05 0.05 E5150-F008 RCIC Turbine Steam Supply Outboard Containment Isolation Valve 2

(See Note 1) 0.05 X-11 E4150-F002 HPCI Turbine Steam Supply Inboard Containment Isolation Valve 6.5 0.05 0.05 E4150-F003 HPCI Turbine Steam Supply Outboard Containment Isolation Valve 5

0.34 0.33 E4150-F600 HPCI Turbine Steam Supply Outboard Isolation Bypass Valve X-12 E1150-F009 RHR Shutdown Cooling Inboard Suction Isolation Valve 20 0.38 0.05 E1150-F608 RHR Shutdown Cooling Inboard Suction Valve Bypass Valve E1100-F408 RHR Shutdown Cooling Suction Thermal Relief Line Check Valve 2

0.05 0.05 E1150-F008 RHR Shutdown Cooling Outboard Suction Isolation Valve 20 0.98 1.2 X-15 T4804-F603A Division 1 TRS Drywell Suction Inboard Isolation Valve 4

0.14 0.52 T4804-F605A Division 1 TRS Drywell Suction Outboard Isolation Valve X-16A E2150-F005B Division 2 Core Spray Inboard Isolation Valve 12 0.29 0.08 E2100-F006B Division 2 Core Spray Testable Check Valve 12 0.05 0.05 X-16B E2150-F005A Division 1 Core Spray Inboard Isolation Valve 12 0.05 0.16 E2100-F006A Division 1 Core Spray Testable Check Valve 12 0.05 0.05

Enclosure to NRC-16-0049 Page 16 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-17 E1150-F022 RHR RPV Head Spray Inboard Containment Isolation Valve 6

0.09 0.1 E1150-F023 RHR RPV Head Spray Outboard Containment Isolation Valve 6

1.05 1.09 X-18 G1154-F600 Drywell Floor Drain Sump Inboard Containment Isolation Valve 4.5 0.05 10.69 G1100-D077 Drywell Floor Drain Discharge Piping Rupture Disc 0.5 0.05 0.05 G1100-F003 Drywell Floor Drain Sump Outboard Containment Isolation Valve 2

0.15 15.55 X-19 G1154-F018 Drywell Equipment Drain Sump Inboard Containment Isolation Valve 2

5.75 1.06 G1100-D078 Drywell Equipment Drain Discharge Piping Rupture Disc 0.5 0.05 0.05 G1100-F019 Drywell Equipment Drain Sump Outboard Containment Isolation Valve 2

2.3 7.32 X-20 P1100-F126 CSAT Drywell Supply Header Inboard Isolation Valve 6

0.69 2.25 P1100-D013 CSAT Demin Water Line to Drywell LLRT Spectacle Flange 6

0.07 0.05 X-22 T4901-F601 Division 1 Drywell Pneumatics Supply Inboard Isolation Valve 3

0.05 1.14 T4901-F465 Division 1 Drywell Pneumatics Supply Outboard Isolation Valve T4901-F007 Division 1 Drywell Pneumatics Supply Outboard Isolation Valve Bypass Valve X-23 P4400-F282A EECW Division 1 Supply to Drywell Check Valve 3.5 0.05 0.05 P4400-F606A Division 1 EECW Drywell Outboard Supply Valve 3

0.05 0.2 X-24 P4400-F616 Division 1 EECW Drywell Inboard Return Valve 4

3.46 0.05 P4400-F607A Division 1 EECW Drywell Outboard Return Valve 3

0.6 0.17 X-25 T4803-F602 CAC N2 Inerting Drywell Inboard Exhaust Isolation Valve 14.87 1.36 Leakage off scale (See Note 2)

T4600-F402 SGTS Drywell Purge Isolation Valve T4600-F411 SGTS Drywell Purge Line Isolation Bypass Valve X-26 T4803-F601 CAC N2 Inerting Drywell Air Purge Inlet Supply Isolation Valve 14.87 1.66 1.44 (See Note 2)

T4800-F407 CAC N2 Inerting Drywell Air Purge Inlet Supply Vent Valve T4800-F408 CAC N2 Inerting Drywell N2 Supply Isolation Valve

Enclosure to NRC-16-0049 Page 17 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-27a-e T5000-F401B PCAM T50L400B Containment Outboard Sample Valve 2

0.05 0.09 T5000-F403B PCAM T50L402B Containment Outboard Sample Valve T5000-F404B PCAM T50L403B Containment Outboard Sample Valve T5000-F405B PCAM T50L404B Containment Outboard Sample Valve X-27b T5000-F402B PCAM T50L401B Containment Outboard Sample Valve 1

0.05 0.05 P34-F404A Division 2 PASS Drywell Atm Inboard Isolation Valve X-27f T5000-F402B PCAM T50L401B Containment Outboard Sample Valve 1

0.05 0.16 P34-F403A Division 2 PASS Drywell Atm Inboard Isolation Valve T50-F458 Division 2 PCMS Level Instrument Isolation Valve 2

0.05 0.05 X-28Cf P34-F401A Division 2 PASS Jet Pump #5 Reactor Water Sample Isolation Valve 1

0.05 0.05 X-29Aa B3100-F019 Reactor Recirc Reactor Water Sample Line Inboard Containment Isolation Valve 2

0.05 0.1 B3100-F020 Reactor Recirc Reactor Water Sample Line Outboard Containment Isolation Valve 2

0.05 0.05 X-29Bb E11-F412 Division 2 RHR Drywell Pressure Isolation Valve 2

0.05 0.05 X-29Bc E11-F413 Division 2 RHR Drywell Press Isolation Valve 2

0.05 0.09 X-29Be T5000-F420B PCAM PC Pressure Monitor T50L406B PT Outboard Sample Valve 2

0.05 0.05 X-31B T4800-F453 CAC N2 Inerting Drywell Pressure Control Vent Isolation Valve 2

0.05 0.7 T4800-F454 CAC N2 Inerting Drywell N2 Makeup Outboard Isolation Valve T4800-F455 CAC N2 Inerting Drywell N2 Makeup Inboard Isolation Valve X-34A P4400-F282B EECW Division 2 Supply to Drywell Equipment Check Valve 3.5 0.05 0.05 P4400-F606B EECW Division 2 Supply to Drywell Equipment Outboard Isolation Valve 3

0.05 0.12 X-34B P4400-F615 EECW Division 2 Drywell Equipment Inboard Return Isolation Valve 4

1.7 0.05 P4400-F607B EECW Division 2 Drywell Equipment Outboard Return Isolation Valve 3

0.06 1.47

Enclosure to NRC-16-0049 Page 18 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-35B C5100-F002B Channel B TIP System Ball Valve 2

0.05 0.05 X-35C C5100-F002A Channel A TIP System Ball Valve 2

0.05 0.05 X-35D C5100-F002C Channel C TIP System Ball Valve 2

0.05 0.05 X-35E C5100-F002E Channel E TIP System Ball Valve 2

0.05 0.05 X-35F C5100-F002D Channel D TIP System Ball Valve 2

0.05 0.05 X-36 T4901-F602 Division 2 Drywell Pneumatics Supply Inboard Isolation Valve 3

0.39 0.42 T4901-F468 Division 2 Drywell Pneumatics Supply Outboard Isolation Valve T4901-F016 Division 2 Drywell Pneumatics Supply Outboard Isolation Valve Bypass Valve X-37 & 38 C1100-F010 CRD Scram Discharge Volume Vent Valve 5.5 0.1 0.13 C1100-F180 CRD Scram Discharge Volume Vent Valve 5.5 1.59 0.05 C1100-F011 CRD Scram Discharge Headers Clean RW Drain Valve 5.5 3.58 0.94 C1100-F181 CRD Scram Discharge Volume to Torus Room Sump D065 Drain Valve 5.5 0.1 3.23 X-39A E1150-F021A RHR Division 1 Drywell Spray Inboard Isolation Valve 12 6.01 0.98 E1150-F016A RHR Division 1 Drywell Spray Outboard Isolation Valve 12 1.44 1.72 X-39B E1150-F021B RHR Division 2 Drywell Spray Inboard Isolation Valve 12 0.21 0.08 E1150-F016B RHR Division 2 Drywell Spray Outboard Isolation Valve 12 0.23 0.05 X-40Dd P34-F401B Division 1 PASS Jet Pump #15 Reactor Water Sample Isolation Valve 1

0.05 0.05 X-42 C4100-F007 Standby Liquid Control Inboard Check Valve 3

Leakage off scale 16.3 C4100-F006 Standby Liquid Control Outboard Check Valve 3

0.05 Leakage off scale X-43 G3352-F001 Reactor Water Cleanup Inboard Containment Isolation Valve (MOV) 10 5.81 6.03 G3352-F004 Reactor Water Cleanup Outboard Containment Isolation Valve (MOV) 6 0.33 0.27

Enclosure to NRC-16-0049 Page 19 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-44 T4804-F603B CAC H2 Recombiner Division 2 Drywell Suction Inboard Isolation Valve (MOV) 4 0.1 0.14 T4804-F605B CAC H2 Recombiner Division 2 Drywell Suction Outboard Isolation Valve (MOV)

X-47a E11-F414 RHR Primary Containment Monitoring Division 1 (RHR Drywell Pressure Isolation Valve) 2 0.05 0.08 X-47b E11-F415 RHR Primary Containment Monitoring Division 1 (RHR Drywell Pressure Isolation Valve) 2 0.11 0.07 X-47e T5000-F420A PCAM PC Pressure Monitoring T50L406A Pressure Outboard Isolation Valve (AOV) 2 0.92 0.16 X-48a-e T5000-F401A PCAM T50L400A CT Outboard Sample (AOV) 2 0.41 0.43 T5000-F402A PCAM T50L401A CT Outboard Sample (AOV)

T5000-F403A PCAM T50L402A CT Outboard Sample (AOV)

T5000-F404A PCAM T50L403A CT Outboard Sample (AOV)

T5000-F405A PCAM T50L404A CT Outboard Sample (AOV)

X-48a-e T50-F450 PCAM Primary Containment Radiation Monitoring System Inlet Outboard Isolation Valve (SOV) 2 0.05 0.05 T5000-F456 PCAM Primary Containment Radiation Monitoring System Inlet Inboard Isolation Valve (SOV) 2 0.05 0.05 X-48f P34-F403B Division 1 PASS Drywell ATM Inboard Isolation Valve (SOV) 1 0.05 0.07 P34-F404B Division 1 PASS Drywell ATM Outboard Isolation Valve (SOV) 1 0.17 0.14 X-49a B3100-F016B Reactor Recirc Supply to Division 2 Inboard Seal Cavity Outboard Containment Isolation Valve (AOV) 2 0.08 0.05 B3100-F014B Reactor Recirc Supply to Division 2 Inboard Seal Cavity Inboard Containment Isolation Valve (AOV) 2 0.16 0.05

Enclosure to NRC-16-0049 Page 20 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-51a B3100-F016A Reactor Recirc CRD Supply to Division 1 Inboard Seal Cavity Outboard Containment Isolation (AOV) 2 0.05 0.13 B3100-F014A Reactor Recirc CRD Supply to Division 1 Inboard Seal Cavity Inboard Containment Isolation (AOV) 2 0.05 0.07 X-204A T4800-F416 CAC N2 Inerting to Vacuum Breaker Valve T23-F400A N2 Supply Isolation Valve (AOV) 2 0.05 0.05 X-204B T4800-F417 CAC N2 Inerting to Vacuum Breaker Valve T23-F400B N2 Supply Isolation Valve (AOV) 2 0.05 0.05 X-204C T4800-F418 CAC N2 Inerting to Vacuum Breaker Valve T23-F400C N2 Supply Isolation Valve (AOV) 2 0.52 0.19 X-204D T4800-F419 CAC N2 Inerting to Vacuum Breaker Valve T23-F400D N2 Supply Isolation Valve (AOV) 2 0.05 0.05 X-204E T4800-F420 CAC N2 Inerting to Vacuum Breaker Valve T23-F400E N2 Supply Isolation Valve (AOV) 2 0.05 0.07 X-204F T4800-F421 CAC N2 Inerting to Vacuum Breaker Valve T23-F400F N2 Supply Isolation Valve (AOV) 2 0.05 0.05 X-204G T4800-F422 CAC N2 Inerting to Vacuum Breaker Valve T23-F400G N2 Supply Isolation Valve (AOV) 2 0.15 0.11 X-204H T4800-F423 CAC N2 Inerting to Vacuum Breaker Valve T23-F400H N2 Supply Isolation Valve (AOV) 2 0.62 0.09 X-204J T4800-F424 CAC N2 Inerting to Vacuum Breaker Valve T23-F400J N2 Supply Isolation Valve (AOV) 2 0.05 0.11 X-204K T4800-F425 CAC N2 Inerting to Vacuum Breaker Valve T23-F400K N2 Supply Isolation Valve (AOV) 2 0.05 0.53 X-204L T4800-F426 CAC N2 Inerting to Vacuum Breaker Valve T23-F400L N2 Supply Isolation Valve (AOV) 2 0.05 0.05 X-204M T4800-F427 CAC N2 Inerting to Vacuum Breaker Valve T23-F400M N2 Supply Isolation Valve (AOV) 2 0.05 0.05

Enclosure to NRC-16-0049 Page 21 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-205A T2300-F450B Primary Containment Suppression Chamber Reactor Building Vacuum Breaker Check Valve (AOV) 20 11.52 13.69 T2300-F410 Primary Containment Suppression Chamber Reactor Building Vacuum Breaker Isolation Valve (AOV)

X-205B T2300-F450A Primary Containment Suppression Chamber Reactor Building Vacuum Breaker Check Valve (AOV) 20 2.4 32.03 T2300-F409 Primary Containment Suppression Chamber Reactor Building Vacuum Breaker Isolation Valve (AOV)

X-205C T4800-F404 CAC N2 Inerting Suppression Pool N2 Supply Inlet Isolation (AOV) 14.87 0.91 1.98 (See Note 2)

T4800-F405 CAC N2 Inerting Suppression Pool Vent Valve (AOV)

T4800-F409 CAC N2 Inerting Suppression Pool N2 Supply Isolation AOV X-205D T4600-F400 SGTS Suppression Chamber Purge Isolation Valve (AOV) 14.87 6.35 3.79 (See Note 2)

T4600-F401 SGTS Suppression Chamber Purge Line Isolation Valve (AOV)

T4600-F412 SGTS Suppression Chamber Purge Line Isolation Bypass Valve (AOV)

T4800-F410 CAC N2 Inerting N2 Supply to Standby Gas Treatment (N2 Supply to Torus Exhaust Isolation Valve)

T4800-F456 CAC N2 Inerting to SGTS N2 Supply Bypass (Torus Pressure Control N2 Supply) Isolation Valve (AOV) 2 0.05 0.05 T4800-F457 CAC N2 Inerting to SGTS N2 Supply Bypass (Torus Pressure Control Inboard) Isolation Valve (AOV)

T4800-F458 CAC N2 Inerting to SGTS N2 Supply Bypass (Torus Pressure Control Vent) Isolation Valve (AOV)

X-206A E41-F402 HPCI PCM Suppression Pool (Division 2 Torus Level Instrument Isolation Valve) (SOV) 2 0.2 0.17 X-206D E41-F400 HPCI PCM Suppression Pool (Division 1 Torus Level Instrument Isolation Valve) (SOV) 2 0.15 0.05

Enclosure to NRC-16-0049 Page 22 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-211A E1150-F024B RHR Division 2 Containment Cooling/Test (Division 2 RHR Torus Cooling) Isolation Valve (MOV) 18 0.05 0.05 E1150-F027B RHR Division 2 Suppression Pool Containment Spray Inboard Containment (Division 2 RHR Torus Spray) Isolation Valve (MOV)

E1150-F028B RHR Division 2 Suppression Pool Containment Spray / Test (Division 2 RHR Torus) Isolation Valve (MOV)

X-211B E1150-F024A RHR Division 1 Containment Cooling/Test (Division 1 RHR Cooling) Isolation Valve (MOV) 18 3

3.57 E1150-F027A RHR Division 1 Suppression Pool Containment Spray Inboard Containment (Division 1 RHR Torus Spray) Isolation Valve (MOV)

E1150-F028A RHR Division 1 Suppression Pool Containment Spray / Test (Division 1 RHR Torus) Isolation Valve (MOV)

X-214 E5150-F062 RCIC Turbine Exhaust Line Vacuum Breaker Outboard Isolation Valve (MOV) 4.5 1.57 2.7 E5150-F084 RCIC Turbine Exhaust Line Vacuum Breaker Inboard Isolation Valve (MOV) 4.5 1.93 0.18 E4150-F075 HPCI Turbine Exhaust Line Vacuum Breaker Outboard Isolation Valve (MOV) 4.5 1.4 0.23 E4150-F079 HPCI Turbine Exhaust Line Vacuum Breaker Inboard Isolation Valve (MOV) 4.5 1.66 1.21

Enclosure to NRC-16-0049 Page 23 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-215 T4804-F602A CAC H2 Recombiner Division 1 H2 Control Torus Suction Inboard Isolation Valve (MOV) 4 0.1 0.19 T4804-F606A CAC H2 Recombiner Division 1 Torus Outboard Suction Isolation Valve (MOV)

T5000-F408A PCAM T50L411A CT Outboard Sample Return Valve (AOV) 2 0.05 0.05 P34-F408 Division 1 PASS Gaseous Sample Return Outboard Isolation Valve 1

0.18 0.22 P34-F410 Division 1 PASS Gaseous Sample Inboard Isolation Valve 1

0.05 0.09 T50-F451 PCMS Radiation Monitor Outlet Outboard Isolation Valve (SOV) 2 0.21 0.05 T5000-F455 PCMS Radiation Monitor Outlet Inboard Isolation Valve (AOV) 2 0.05 0.05 X-218 T4804-F601A CAC H2 Recombiner to Torus Division 1 H2 Control Return Inboard Isolation Valve (MOV) 8 0.1 0.05 T4804-F604A CAC H2 Recombiner Division 1 H2 Control Return Outboard Isolation Valve (MOV)

T4804-F016A CAC H2 Recombiner Return Line for Division 1 F601A and F604A Bypass Relief Valve 4

0.05 0.33 T4804-F601B CAC H2 Recombiner to Torus Division 2 H2 Control Return Inboard Isolation Valve (MOV) 8 0.52 0.21 T4804-F604B CAC H2 Recombiner Division 2 H2 Control Return Outboard Isolation Valve (MOV)

T4804-F016B CAC H2 Recombiner Return Line for Division 2 F601B and F604B Bypass Relief Valve 4

0.09 0.19 X-219 T4804-F602B CAC H2 Recombiner Division 2 H2 Control Torus Suction Inboard Isolation Valve (MOV) 4 0.13 0.1 T4804-F606B CAC H2 Recombiner Division 2 Torus Outboard Suction Isolation Valve (MOV)

T5000-F408B PCAM T50L411B Containment Outboard Sample Return Valve (AOV) 2 0.05 0.05

Enclosure to NRC-16-0049 Page 24 Table 5-1: Type C Air Penetration PIS Description Allowable Leakage (SCFH)

T2* As-Found (SCFH)

T1* As-Found (SCFH)

X-230 T5000-F407A PCAM T50L410A Containment Outboard Sample Valve (AOV)

(Division 1 PCAM Torus Sample Valve) 2 0.05 0.05 P34-F405B Division 1 PASS Torus Atmosphere Inboard Isolation Valve (SOV) 1 0.12 0.14 P34-F406B Division 1 PASS Torus Atmosphere Outboard Isolation Valve (SOV) 1 0.1 0.15 X-231 T5000-F407B PCAM T50L410B Containment Outboard Sample Valve (AOV)

(Division 2 PCAM Torus Sample Valve) 2 0.06 0.05 P34-F405A Division 2 PASS Torus Atmosphere Inboard Isolation Valve (SOV) 1.5 0.18 0.68 P34-F406A Division 2 PASS Torus Atmosphere Outboard Isolation Valve (SOV) 1 0.61 0.49

• T1 is the most recent test and T2 is the next most recent test.

Note 1: During the RF16 Reactor Pressure Vessel (RPV) Pressure Test, a leak was identified on E5150F008 RCIC Turbine Steam Supply Outboard Containment Isolation Valve, and a Corrective Action Resolution Document (CARD) was generated. Upon further investigation (via VT-3), a steam cut on the bonnet sealing surface that resulted in the leakage was identified, and another CARD was generated which recommended generating a work order to have the bonnet replaced. The bonnet was replaced and an As-Left test was performed. The As-Left leakage rate was measured at 0.05 SCFH versus a 2.0 SCFH total maximum leakage criteria per the Local Leakage Rate Testing (LLRT) procedure. At the time that this leak was identified, the E5150F008 was on a performance-based extended frequency and therefore, was not scheduled to be tested in RF16. An As-Found test was not completed on E5150F008 prior to maintenance. As a result of not performing the As-Found LLRT, the As-Found test was credited as a failure, and returned to its baseline testing frequency of every 30 months (or every refuel). This was in accordance with Fermi 2s LLRT Conduct Manual, MES28 Leakage Reduction and Primary Containment Leakage Rate Programs, which states in Section 4.7.9, If a pre-maintenance as-found test is not performed and the valve is on an extended test interval (i.e. > 30 months), the test interval must be returned to 30 months until acceptable performance is reestablished. This valve was identified as a failure and has been returned to its base line testing frequency of every 30 months (or every refuel), until acceptable performance is re-established.

Note 2: The penetrations X-25 (T4803F602, T4600F402, T4600F411), X-26 (T4803F601, T4800F407, T4800F408), X-205C (T4800F404, T4800F405, T4800F409), and X-205D (T4600F400, T4600F401, T4600F412, T4800F410) were tested in January 2016, and the As-Found Results were as follows: X-25 (0.32 SCFH), X-26 (0.74 SCFH), X-205C (0.53 SCFH), and X-205D (0.39 SCFH).

Enclosure to NRC-16-0049 Page 25 Table 5-2: Type C Water PIS Description Acceptance (ml/min)

T1* As-Found (ml/min)

T2* As-Found (ml/min)

E41-F403 HPCI PCM - Suppression Pool Division 2 Torus Level Instrument Isolation Valve (SOV) 3785.00 0.00 0.00 E41-F401 HPCI PCM - Suppression Pool Division 1 Torus Level Instrument Isolation Valve (SOV) 3785.00 0.00 0.00 T50-F412A PCAM Primary Containment Torus Level Monitoring Division 1 Isolation Valve (SOV) 3785.00 0.00 16.24 T50-F412B PCAM Primary Containment Torus Level Monitoring Division 2 Isolation Valve (SOV) 3785.00 2.32 0.00 G5100-F604 Torus Water Management to RHR Test Line Inboard Isolation Valve (MOV) 2672.00 0.00 3.87 G5100-F605 Torus Water Management to RHR Test Line Outboard Isolation Valve (MOV) 2672.00 11.60 0.00 P34-F407 Division 2 PASS Liquid Sample Return Outboard Isolation Valve (SOV) 500.00 0.00 0.00 P34-F409 Division 2 PASS Liquid Sample Inboard Isolation Valve (SOV) 500.00 0.00 0.00 G5100-F600 Torus Water Management (South TWMS Pump Inboard Suction)

Isolation Valve (MOV) 3785.00 30.90 232.00 G5100-F601 Torus Water Management (South TWMS Pump Outboard Suction)

Isolation Valve (MOV) 3785.00 11.60 46.40 G5100-F602 Torus Water Management (North TWMS Pump Inboard Suction)

Isolation Valve (MOV) 3785.00 293.90 132.24 G5100-F603 Torus Water Management (North TWMS Pump Outboard Suction)

Isolation Valve (MOV) 3785.00 7.70 0.00 G5100-F606 Torus Water Management Return to Core Spray Test Line Inboard Isolation Valve (MOV) 1514.00 29.00 46.40 G5100-F607 Torus Water Management Return to Core Spray Test Line Outboard Isolation Valve (MOV) 1514.00 1406.10 1137.70

• T1 is the most recent test and T2 is the next most recent test.