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{{Adams
#REDIRECT [[RS-17-172, Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues]]
| number = ML17354A079
| issue date = 12/19/2017
| title = Exelon Generation Co, LLC - Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues
| author name = Barstow J
| author affiliation = Exelon Generation Co, LLC
| addressee name =
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000219, 05000220, 05000237, 05000244, 05000249, 05000254, 05000265, 05000277, 05000278, 05000289, 05000317, 05000318, 05000333, 05000352, 05000353, 05000373, 05000374, 05000410, 05000454, 05000455, 05000456, 05000457, 05000461
| license number = DPR-016, DPR-018, DPR-019, DPR-025, DPR-029, DPR-030, DPR-044, DPR-050, DPR-053, DPR-056, DPR-059, DPR-063, DPR-069, NPF-011, NPF-018, NPF-037, NPF-039, NPF-062, NPF-063, NPF-066, NPF-072, NPF-077, NPF-085
| contact person =
| case reference number = RS-17-172
| document type = Letter
| page count = 18
}}
 
=Text=
{{#Wiki_filter:Exelon Generation 200 Exelon Way l<ennett Square. PA 19348 www.exeloncorp.com RS-17-172 December 19, 2017 U.S. Nuclear Regulatory Commission ATIN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-72 and NPF-77 N RC Docket Nos. STN 50-456 and STN 50-457 Byron Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-37 and NPF-66 N RC Docket Nos. STN 50-454 and STN 50-455 Calvert Cliffs Nuclear Power Plant, Units 1 and 2 Renewed Facility Operating License Nos. DPR-53 and DPR-69 N RC Docket Nos. 50-317 and 50-318 Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 NRC Docket No. 50-461 Dresden Nuclear Power Station, Units 2 and 3 Renewed Facility Operating License Nos. DPR-19 and DPR-25 NRC Docket Nos. 50-237 and 50-249 James A. FitzPatrick Nuclear Power Plant Renewed Facility Operating License No. DPR-59 NRC Docket No. 50-333 LaSalle County Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373 and 50-374 Limerick Generating Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-39 and NPF-85 NRC Docket Nos. 50-352 and 50-353 Nine Mile Point Nuclear Station, Units 1 and 2 Renewed Facility Operating License Nos. DPR-63 and NPF-69 NRC Docket Nos. 50-220 and 50-41 o Oyster Creek Nuclear Generating Station Renewed Facility Operating License No. DPR-16 NRC Docket No. 50-219 U.S. Nuclear Regulatory Commission Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues December 19, 2017 Page2 Peach Bottom Atomic Power Station, Units 2 and 3 Renewed Facility Operating License Nos. DPR-44 and DPR-56 NRC Docket Nos. 50-277 and 50-278 Quad Cities Nuclear Power Station, Units 1 and 2 Renewed Facility Operating License Nos. DPR-29 and DPR-30 NRC Docket Nos. 50-254 and 50-265 R.E. Ginna Nuclear Power Plant Renewed Facility Operating License No. DPR-18 NRC Docket No. 50-244 Three Mile Island Nuclear Station, Unit 1 Renewed Facility Operating License No. DPR-50 NRC Docket No. 50-289
 
==Subject:==
Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues
 
==References:==
1) Letter from William Trafton (Exelon Generation Company, LLC), to U.S. Nuclear Regulatory Commission, Amendment to Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues, dated June 20, 2017 2) BWROG Topical Report TP16-1-112, Revision 4, Recommendations to Resolve Flowserve 1 OCFR Part 21 Notification Affecting Anchor Darling Double Disc Gate Valve Wedge Pin Failures, dated August 2017 3) Letter from Greg Krueger (NEI) to John Lubinski (U.S. Nuclear Regulatory Commission), Anchor Darling Double Disc Gate Valve Industry Resolution Plan Update (Project 689), dated August 4, 2017 4) Letter from James Barstow (Exelon Generation Company, LLC) to U.S. Nuclear Regulatory Commission, Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues, dated August 29, 2017 5) Letter from Joe Pollock (NEI) to Brian Holian (U.S. Nuclear Regulatory Commission), NSIAC Concurrence on Anchor Darling Double Disc Gate Valve Industry Response Actions (Project 689), dated October 26, 2017 In Reference 4, Exelon Generation Company, LLC (EGC) provided a status of the resolution of Anchor Darling Double Disk Gate Valve (ADDDGV) issues specifically related to related Motor Operated Valve (MOV) applications at Oyster Creek Nuclear Generating Station and Quad Cities Nuclear Power Station, Units 1 and 2, in addition to providing commitment to valve repairs at these stations. Additionally, the Reference 4 letter committed to communicating repair schedule commitments by December 31, 2017.
U.S. Nuclear Regulatory Commission Commitments for Resolution of Anchor Darling Double Disc Gate Valve Part 21 Issues December 19, 2017 Page 3 Further review of the EGC fleet has determined that Braidwood Station, Units 1 and 2; Byron Station, Units 1 and 2; Clinton Power Station, Unit 1; and Nine Mile Point Nuclear Station, Units 1 and 2, do not use motor-operated ADDDGVs to support any active safety function and/or utilized in Generic Letter 96-05 MOV program applications. Attached is additional information and updates regarding repair plans for the remainder of the EGC fleet. For each applicable site, Attachments 1 through 1 O contain the following information for each applicable active safety-related MOV: Plant Name, Unit, and Valve ID System Valve Functional Description Valve Size Active Safety Function (Open, Close, Both) Are multiple design basis post-accident strokes required? (Yes/No) Expert Panel Risk Ranking (High, Medium, Low) Result of susceptibility evaluation (susceptible or not susceptible) Is the susceptibility evaluation in general conformance with TP16-1-112R4 where the wedge pin applied torque must bound anticipated design basis operating torque requirements and current maximum total torque? (Yes/No) Does the susceptibility evaluation rely on thread friction? If yes, include rotation criteria (No), (Yes, >0.10), (Yes, S0.10) Was an initial stem-rotation check performed? If yes, include rotation criteria (No), (Yes, S1 O deg.), (Yes, SS deg.) Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? (Yes/No) The valve's repair status (repaired or not repaired) EGC commits to perform all applicable activities identified in Attachment 11. EGC may modify these commitments should additional technical information or repair methods become available to justify such action. Additionally, Exelon has implemented MOV Program requirements for periodic Stem Rotation Checks for all applicable GL 96-05 motor operated ADDDGVs at the Periodic Verification Test (PVT) interval in accordance with TP16-1-112R4, Attachment 10. Should you have any questions or require additional information, please contact Tom Basso, Director of Centralized Program Engineering (Thomas.Basso@Exeloncorp.com, 610-765-5910). Respectfully, James Barstow Director -Licensing & Regulatory Affairs Exelon Generation Company, LLC 
 
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Calvert Cliffs 1 1MOV0403 Reactor Coolant Pressurizer PORV Blocking Valve 2.5 Both Yes Medium Not Applicable (Note 1) N/A N/A N/A N/A N/A Calvert Cliffs 1 1MOV0405 Reactor Coolant Pressurizer PORV Blocking Valve 2.5 Both Yes Medium Not Applicable (Note 1) N/A N/A N/A N/A N/A Calvert Cliffs 1 1MOV2080 Instrument Air Instrument Air Containment Isolation Valve 2.0 Both Yes Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Calvert Cliffs 2 2MOV0403 Reactor Coolant Pressurizer PORV Blocking Valve 2.5 Both Yes Medium Not Applicable (Note 1) N/A N/A N/A N/A N/A Calvert Cliffs 2 2MOV0405 Reactor Coolant Pressurizer PORV Blocking Valve 2.5 Both Yes Medium Not Applicable (Note 1) N/A N/A N/A N/A N/A Calvert Cliffs 2 2MOV2080 Instrument Air Instrument Air Containment Isolation Valve 2.0 Both Yes Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Notes (1): T-Head Connection Stem/Wedge Connection is not applicable to the Flowserve Part 21 (i.e. does not include threaded connection with wedge pin).
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Dresden 2 2-0205-2-4 Nuclear Boiler Reactor Head Spray Outboard Isolation Valve 3.0 Close No Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Dresden 2 2-1001-01A Residual Heat Removal Shutdown Cooling Suction Inboard Containment Isolation  16 Close No Low Not Susceptible Yes No Yes, < 5 deg. Yes Last Tested 2017 Not Repaired Dresden 2 2-1001-01B Residual Heat Removal Shutdown Cooling Suction Inboard Containment Isolation  16 Close No Low Not Susceptible Yes No N/A Yes Last Tested 2009 Not Repaired Dresden 3 3-0205-2-4 Nuclear Boiler Reactor Head Spray Outboard Isolation 2.5 Close No Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Dresden 3 3-1201-1 Reactor Water Cleanup RWCU Inlet Containment Isolation 8 Close No Medium Not Susceptible Yes No Yes, < 10 deg. Yes Last Tested 2016 Not Repaired Dresden 3 3-1201-1-1A Reactor Water Cleanup RWCU Inlet Bypass Containment Isolation 2 Close No Medium Not Applicable (Note 1) N/A N/A N/A N/A N/A Dresden 3 3-1201-2 Reactor Water Cleanup RWCU Aux Pump Bypass  8 Close No Medium Not Susceptible Yes No Yes, < 10 deg. Yes Last Tested 2014 Not Repaired Notes (1): T-Head Connection Stem/Wedge Connection is not applicable to the Flowserve Part 21 (i.e. does not include threaded connection with wedge pin).
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) FitzPatrick 1 02-2MOV-53A Reactor Recirculation Rx Recirc Pump A Discharge 28 Close No Low Susceptible  (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2014 Scheduled  Att.11, Cat. C  FitzPatrick 1 02-2MOV-53B Reactor Recirculation Rx Recirc Pump B Discharge 28 Close No Low Susceptible  (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2014 Scheduled  Att.11, Cat. C  FitzPatrick 1 10MOV-16A Residual Heat Removal RHR A Minimum Flow 4 Both Yes Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2010 Not Repaired  FitzPatrick 1 10MOV-16B Residual Heat Removal RHR B Minimum Flow 4 Both Yes Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2010 Not Repaired  FitzPatrick 1 10MOV-17 Residual Heat Removal RHR Shutdown Cooling OB Isolation 20 Close No Medium Not Susceptible Yes No No, Note 3 Yes Last Tested: 2014 Not Repaired  FitzPatrick 1 10MOV-18 Residual Heat Removal RHR Shutdown Cooling IB Isolation 20 Close No Medium Not Susceptible Yes No No, Note 3 Yes Last Tested: 2017 Not Repaired  FitzPatrick 1 10MOV-26A Residual Heat Removal RHR Train A Containment Spray  10 Both Yes High Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2017 Scheduled  Att. 11, Cat. A  FitzPatrick 1 10MOV-26B Residual Heat Removal RHR Train B Containment Spray  10 Both Yes High Susceptible  (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2014 Scheduled  Att.11, Cat. A  FitzPatrick 1 10MOV-39B Residual Heat Removal RHR Train B Torus Cooling Isolation 16 Both Yes High Not Susceptible (Note 2) See Note 2 Yes < 0.1 No, Note 3 Yes Last Tested: 2013 Not Repaired  FitzPatrick 1 12MOV-15 Rx Water Cleanup RWCU Supply Inboard 6 Close No High Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2017 Scheduled  Att. 11, Cat. B  FitzPatrick 1 12MOV-69 Rx Water Cleanup RWCU Return Containment 4 Close No Low Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2012 Scheduled  Att.11, Cat. C  FitzPatrick 1 13MOV-15 Reactor Core Isolation Cool RCIC Steam Supply Inboard Isolation 3 Close No High Not Applicable (Note 1) N/A N/A N/A N/A N/A  FitzPatrick 1 23MOV-15 High Pressure Coolant  Inject HPCI Steam Supply Isolation 10 Close No High Not Susceptible (Note 2) See Note 2 Yes < 0.1 No, Note 3 Yes Last Tested: 2014 Not Repaired  FitzPatrick 1 20MOV-82 Rad Waste Drywell Floor Drain Sump Isolation 3 Close No Low Not Applicable (Note 1) N/A N/A N/A N/A N/A  FitzPatrick 1 20MOV-94 Rad Waste Drywell Equipment Drain Sump Isolation 3 Close No Low Not Applicable (Note 1) N/A N/A N/A N/A N/A  FitzPatrick 1 29MOV-74 Main Steam MS Line Drain Inboard Isolation 3 Close No Low Not Applicable (Note 1) N/A N/A N/A N/A N/A  FitzPatrick 1 29MOV-77 Main Steam MS Line Drain Outboard Isolation 3 Close No Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Notes: (1): T-Head Connection Stem/Wedge Connection is not applicable to the Flowserve Part 21 (i.e. does not include threaded connection with wedge pin). (2): Initial wedge pin susceptibility evaluation relied on thread friction. Consequently, a re-evaluation performed in 2017 has determined the applicable MOVs to be susceptible and subject to repair if thread COF required is > 0.1.  (3): Until 2017, plant considered all of their MOVs as non-susceptible by wedge pin analysis; consequently no stem rotation check inspections were performed.
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Ginna 1 515 RCS  Pressurizer Pressurizer Relief Stop Valve 3.0 Both Yes Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Ginna 1 516 RCS  Pressurizer Pressurizer Relief Stop Valve 3.0 Both Yes Low Not Applicable (Note 1) N/A N/A N/A N/A N/A Ginna 1 704A Residual Heat Removal RHR Pump 1A Cross Connect 10.0 Close No Low Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2011 Scheduled  Att.11, Cat. C Ginna 1 704B Residual Heat Removal RHR Pump 1B Cross Connect 10.0 Close No Low Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2009 Scheduled  Att.11, Cat. C Ginna 1 841 Safety Injection Accumulator Tank 1A Shutoff 10.0 Close Yes Medium Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2014 Scheduled  Att. 11, Cat. C Ginna 1 850A Residual Heat Removal Sump B to RHR Pumps 10.0 Both Yes High Not Susceptible Yes No  Yes Last Tested: 2017 Not Repaired Ginna 1 850B Residual Heat Removal Sump B to RHR Pumps 10.0 Both Yes High Not Susceptible Yes No  Yes Last Tested: 2017 Not Repaired Ginna 1 856 Residual Heat Removal RWST to RHR Pumps 10.0 Close No Medium Not Susceptible Yes No No, Note 3 Yes Last Tested: 2011 Not Repaired Ginna 1 857A Residual Heat Removal 1A RHR HX to SIP/CSP 6.0 Open No Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2014 Not Repaired Ginna 1 857B Residual Heat Removal 1B RHR HX to SIP/CSP 6.0 Open No Medium Not Susceptible Yes No  Yes Last Tested: 2017 Not Repaired Ginna 1 857C Residual Heat Removal RHR HX to 1A Outlet 6.0 Open No Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2015 Not Repaired Ginna 1 860A Containment Spray 1A CSP Discharge 6.0 Both Yes Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2014 Not Repaired Ginna 1 860B Containment Spray 1A CSP Discharge 6.0 Both Yes Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2015 Not Repaired Ginna 1 860C Containment Spray 1B CSP Discharge 6.0 Both Yes Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2015 Not Repaired Ginna 1 860D Containment Spray 1B CSP Discharge 6.0 Both Yes Low Not Susceptible Yes No No, Note 3 Yes Last Tested: 2015 Not Repaired Ginna 1 865 Safety Injection Accumulator Tank 1B Shutoff 10.0 Close No Medium Susceptible (Note 2) See Note 2 See Note 2 No, Note 3 Yes Last Tested: 2014 Scheduled  Att. 11, Cat. C Notes: (1): T-Head Connection Stem/Wedge Connection is not applicable to the Flowserve Part 21 (i.e. does not include threaded connection with wedge pin). (2): Initial wedge pin susceptibility evaluation relied on thread friction. Consequently, a re-evaluation performed in 2017 has determined the applicable MOVs to be susceptible and subject to repair if thread COF required is > 0.1.  (3): Until 2017, Ginna was not identified as having susceptible valves due to not being included in the 2013 Flowserve Part 21; consequently no stem rotation check inspections were performed prior to 2017.
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) LaSalle 1 1B21-F067A Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 1 1B21-F067B Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 1 1B21-F067C Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 1 1B21-F067D Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 2 2B21-F067A Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 2 2B21-F067B Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 2 2B21-F067C Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A LaSalle 2 2B21-F067D Main Steam Drains MS Drain Line Isolation 1.5 Close No L Not Applicable (Note 1) N/A N/A N/A N/A N/A Notes: (1): T-Head Connection Stem/Wedge Connection is not applicable to the Flowserve Part 21 (i.e. does not include threaded connection with wedge pin).
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) LaSalle 1 1E22-F004 High Pressure Core Spray HPCS Injection Isolation 12 Both Yes Medium Not Susceptible Note 4 N/A Note 4 N/A Repaired June 2017 LaSalle 1 1E22-F012 High Pressure Core Spray HPCS Pump Min Flow 4 Both Yes Medium Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att.11, Cat. A LaSalle 1 1E22-F015 High Pressure Core Spray HPCS Pump Suppress Pool Suction 18 Close No Low Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att.11, Cat. C LaSalle 1 1E51-F008 Reactor Core Isol. Cooling RCIC Steam Outboard Isolation 4 Close No Medium Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att.11, Cat. B LaSalle 1 1E51-F013 Reactor Core Isol. Cooling RCIC Injection Outboard Isolation 6 Both No Low Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att.11, Cat. C LaSalle 1 1E51-F063 Reactor Core Isol. Cooling RCIC Steam Supply Inboard Isolation 10 Close No High Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att. 11, Cat. B LaSalle 1 1G33-F001 Rx Water Cleanup RWCU Inboard Isolation 6 Close No Medium Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att. 11, Cat. B LaSalle 1 1G33-F004 Rx Water Cleanup RWCU Outboard Isolation 6 Close No High Susceptible Yes No  Yes Last Tested: 2016 Scheduled  Att. 11, Cat. B LaSalle 2 2E22-F004 High Pressure Core Spray HPCS Injection Isolation 12 Both Yes Medium Not Susceptible Note 4 N/A Note 4 N/A Repaired February 2017 LaSalle 2 2E22-F012 High Pressure Core Spray HPCS Pump Min Flow 4 Both Yes Medium Susceptible Yes No  Yes Last Tested: 2015 Scheduled  Att. 11,Cat. A LaSalle 2 2E22-F015 High Pressure Core Spray HPCS Pump Suppress Pool Suction 18 Close No Low Susceptible Yes No  Yes Last Tested: 2015 Scheduled  Att. 11, Cat. C LaSalle 2 2E51-F008 Reactor Core Isol. Cooling RCIC Steam Outboard Isolation 4 Close No Medium Susceptible Yes No  Yes Last Tested: 2017 Scheduled  Att. 11, Cat. B LaSalle 2 2E51-F063 Reactor Core Isol. Cooling RCIC Steam Supply Inboard Isolation 10 Close No High Susceptible Yes No  Yes Last Tested: 2015 Scheduled  Att. 11, Cat. B LaSalle 2 2G33-F001 Rx Water Cleanup RWCU Inboard Isolation 6 Close No Medium Susceptible Yes No  Yes Last Tested: 2017 Scheduled  Att. 11, Cat. B LaSalle 2 2G33-F004 Rx Water Cleanup RWCU Outboard Isolation 6 Close No High Susceptible Yes No  Yes Last Tested: 2017 Scheduled  Att. 11, Cat. B Notes: (4): Until repaired in 2017, these valves were identified as being susceptible. 2E22-F004 had a stem-disc separation failure in Feb 2017 during L2R16. 1E22-F004 was identified with a failed wedge pin but with the wedge/stem fully connected during June 2017 Unit 1 Maintenance Outage.
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Limerick 1 HV-052-1F001A Core Spray Core Spray Cooling Pump A Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2016 Not Repaired Limerick 1 HV-052-1F001B Core Spray Core Spray Cooling Pump B Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2014 Not Repaired Limerick 1 HV-052-1F001C Core Spray Core Spray Cooling Pump C Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2014 Not Repaired Limerick 1 HV-052-1F001D Core Spray Core Spray Cooling Pump D Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2015 Not Repaired Limerick 2 HV-052-2F001A Core Spray Core Spray Cooling Pump A Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2015 Not Repaired Limerick 2 HV-052-2F001B Core Spray Core Spray Cooling Pump B Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2016 Not Repaired Limerick 2 HV-052-2F001C Core Spray Core Spray Cooling Pump C Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2015 Not Repaired Limerick 2 HV-052-2F001D Core Spray Core Spray Cooling Pump D Suction 16 Close No Low Not Susceptible Yes No Yes,  Yes Last Tested 2016 Not Repaired Notes: None Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),  deg.)  (Yes/ No) (repaired or  not repaired) Oyster Creek 1 V-14-0030 Isolation Condenser IC NEO1A INLET ISOLATION VALVE 10 Close No Medium Susceptible Yes No  Yes Last Tested 2016 Note 6 Att.11, Cat. B Oyster Creek 1 V-14-0031 Isolation Condenser IC NEO1A INLET ISOLATION VALVE 10 Close No Medium Susceptible Yes No  Yes Last Tested 2012 Note 6 Att. 11, Cat. B Oyster Creek 1 V-14-0032 Isolation Condenser IC NEO1B INLET ISOLATION VALVE 10 Close No Medium Susceptible Yes No  Yes Last Tested 2010 Note 6 Att. 11, Cat. B Oyster Creek 1 V-14-0033 Isolation Condenser IC NEO1B INLET ISOLATION VALVE 10 Close No Medium Susceptible Yes No  Yes Last Tested 2016 Note 6 Att. 11, Cat. B Oyster Creek 1 V-14-0034 Isolation Condenser IC NEO1A Outlet ISOLATION VALVE 10 Both Yes High Susceptible Yes No  Yes Last Tested 2016 Note 5 Att. 11, Cat. A Oyster Creek 1 V-14-0035 Isolation Condenser IC NEO1B Outlet ISOLATION VALVE 10 Both Yes High Susceptible Yes No  Yes Last Tested 2016 Note 5 Att. 11, Cat. A Notes: Note (5): Repair Schedule Commitment for OC1R27 in Aug 29 2017 Exelon Letter to the NRC Note (6): Test/Inspect Schedule Commitment for OC1R17 in Aug 29 2017 Exelon Letter to the NRC Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Quad Cities 1 1-1201-2 Reactor Water Cleanup RWCU Inboard Isolation 6 Close No High Susceptible Yes No  Yes  Last Tested 2015 Note 7  Att. 11, Cat. B Quad Cities 1 1-1201-5 Reactor Water Cleanup RWCU Outboard Isolation 6 Close No Medium Susceptible Yes No  Yes  Last Tested 2017 Note 7  Att. 11, Cat. B Quad Cities 2 2-1201-2 Reactor Water Cleanup RWCU Inboard Isolation 6 Close No High Susceptible Yes No  Yes  Last Tested 2016 Note 7  Att. 11, Cat. B Quad Cities 2 2-1201-5 Reactor Water Cleanup RWCU Outboard Isolation 6 Close No Medium Susceptible Yes No  Yes  Last Tested 2016 Note 7  Att. 11, Cat. B Notes: Note(7): Repair Schedule Commitment for Unit 1 (Q1R25 in 2019) and Unit 2 (Q2R24 in 2018) in Aug 29 2017 Exelon Letter to the NRC.
Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Peach Bottom 2 MO-2-01A-074 Main Steam MSL Drain Inboard Isolation to Condenser 3 Close No Low Not Susceptible Yes No  Yes Last Tested 2014 Not Repaired Peach Bottom 2 MO-2-01A-077 Main Steam MSL Drain Outboard Isolation to Condenser 3 Close No Low Not Susceptible Yes No  Yes Last Tested 2014 Not Repaired Peach Bottom 3 MO-3-01A-074 Main Steam MSL Drain Inboard Isolation to Condenser 3 Close No Low Not Susceptible Yes No  Yes Last Tested 2013 Not Repaired Peach Bottom 3 MO-3-01A-077 Main Steam MSL Drain Outboard Isolation to Condenser 3 Close No Low Not Susceptible Yes No  Yes Last Tested 2017 Not Repaired Peach Bottom 2 MO-2-02-53A Reactor Recirc Reactor Recirc Pump A Discharge 24 Close No Low Susceptible Yes No  Yes Last Tested 2016 Scheduled  Att. 11, Cat. C Peach Bottom 2 MO-2-02-53B Reactor Recirc Reactor Recirc Pump B Discharge 24 Close No Low Susceptible Yes No  Yes Last Tested 2016 Scheduled  Att. 11, Cat. C Peach Bottom 3 MO-3-02-53A Reactor Recirc Reactor Recirc Pump A Discharge 24 Close No Low Susceptible Yes No  Yes Last Tested 2017 Scheduled  Att. 11, Cat. C Peach Bottom 3 MO-3-02-53B Reactor Recirc Reactor Recirc Pump B Discharge 24 Close No Low Susceptible Yes No  Yes Last Tested 2017 Scheduled  Att. 11, Cat. C Notes:  None Plant Name Unit Valve ID System Valve Functional Description Valve Size (inches) Active Safety Function  Are multiple design basis post-accident strokes required? Expert Panel Risk Ranking Result of susceptibility evaluation  Is the susceptibility evaluation in general conformance with TP16-1-112R4? Does the susceptibility evaluation rely on thread friction? If yes, was the COF greater than 0.10? Was an initial stem-rotation check performed?  If yes, include rotation criteria Was the diagnostic test data reviewed for failure precursors described in TP16-1-112R4? Valve repair status      (Open, Close, Both)  (Yes/No) (High, Medium, Low) (susceptible or not susceptible) (Yes/No) (No), (Yes, >0.10),  (No),    (Yes/ No) (repaired or  not repaired) Three Mile Island 1 DH-V-3 Decay Heat DECAY HEAT DROP LINE CONTAINMENT ISOL 12 Open No High Not Susceptible Yes No  deg. Yes,  Last Tested 2017 Not Repaired Notes:  None 
 
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