ML16342C520

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Exam Folder 1, Post-Exam Comments, Resolution and Tech References
ML16342C520
Person / Time
Site: Beaver Valley
Issue date: 11/21/2016
From:
NRC Region 1
To:
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ML16076A16 List:
References
U01922
Download: ML16342C520 (49)
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{{#Wiki_filter:NRC Resolution of Post-Exam Comments 2016 Beaver Valley Unit 1 Initial Exam Question 35 NRC Resolution: Accept two answers. Choice B and original Key Choice A are both correct answers. No other choices are correct. Discussion: Eight applicants chose the original Key Answer A whereas 13 applicants chose Choice B. One applicant chose Choice C and none chose D. There was only one question asked by the applicants on Question 35 and it was about whether Choice A was referring to one feedwater pump or two. There were no questions asked about Choice B. This was a new question. The licensee proposed accepting two answers (Choices A and B), based upon the fact that if the turbine lube oil cooler outlet temperature was 177°F, then the turbine bearing lube oil temperature would be approximately 207°F. This would be above the 195°F limit which would require immediate action to trip the reactor according to 1 OM-53C.4.1.28.1, Loss of Secondary Component Cooling Water, step 4 and the AOP Left Hand Page "Parameter Limits for Immediate Action" Table. The NRC agrees that both Choices A and B are correct answers because both choices describe conditions requiring actions directed by AOP 1.28.1 in response to a high secondary component cooling water temperature condition. Justification for Choice A as a correct answer: Choice A was the originally designated correct choice based upon the criteria set forth in AOP 1.28.1. Specifically, with main feedwater pump bear temperature at 224°F, it exceeds the 220°F limit and therefore requires the immediate action of tripping the affected pump. Tripping the pump is supported by 1 OM-53C.4.1.28.1, Loss of Secondary Component Cooling Water, step 8 and the AOP Left Hand Page "Parameter Limits for Immediate Action" Table. Justification for Choice B as a correct answer: If the turbine lube oil cooler outlet temperature was 177°F, then the corresponding turbine bearing lube oil temperature would be approximately 207°F. This is substantiated by plant data

provided by the licensee. The average delta-T between the turbine lube oil cooler outlet temperature and the turbine bearing oil temperature is about 29. 7°F based upon data from the recent Unit 1 power ascension following 1 R24. Thus, with the turbine lube oil cooler outlet temperature at 177°F, the corresponding bearing lube oil temperature would be approximately 207°F ( 177°F + 30°F). This exceeds the 195°F limit as stated in 1 OM-53C.4.1.28.1, Loss of Secondary Component Cooling Water, step 4 and the AOP Left Hand Page "Parameter Limits for Immediate Action" Table. The required immediate action is to trip the turbine. According to NOP-OP-1002, Conduct of Operations, operators are to "Anticipate automatic trips and equipment protective features, and take manual actions, if possible without haste, to avoid challenging automatic actuations." With the plant conditions provided in the question (65% power), with reactor power above the P-9 setpoint ( 49% ), the automatic actuation that the operator is to avoid would be the automatic Reactor Trip caused by the Turbine Trip. Thus, although the AOP directs the operators to trip the turbine, the operators would trip the reactor in accordance with their conduct of operations procedure. Therefore, Choice B, which directs tripping the reactor, contains the correct actions for the conditions provided in the question. Summary: The NRC has determined that Question 35 has two valid answers, Choices A and B, given that both choices provide correct actions for the given conditions.

References:

1 OM-53C.4.1.28.1, Loss of Secondary Component Cooling Water, Rev 3 NOP-OP-1002 Conduct of Operations, Rev 11 Various plant data logs and trends Question 42 NRC Resolution: Accept two answers. Choice B and original Key Choice C are both correct answers. No other choices are correct. Discussion: Seventeen applicants chose the original Key Choice C while four applicants chose Choice B. One applicant chose Choice A and none chose D. There were no questions asked by the applicants on Question 42. This was a new question.

The licensee proposed accepting two answers (Choices C and B), based upon the fact that, in addition to C being correct, Choice B was a condition that did not meet an LCO. Specifically, LCO 3.7.3, Main Feedwater Isolation Valves and Main Feedwater Regulation Valves and MFRV Bypass Valves, is only applicable in Modes 1, 2, and 3, whereas LCO 3.6.3, Containment Isolation Valves, is applicable in Modes 1, 2, 3, and 4. Thus, a main feed water containment isolation valve with a broken stem while in Mode 4, would not meet the LCO for TS 3.6.3. while LCO 3.7.3 is not applicable. The NRC agrees that both Choices C and B are correct answers because both choices describe conditions that fail to meet an LCO. Justification for Choice C as a correct answer: The question tested an applicant's knowledge of determining which of the four provided conditions would not meet an LCO. The condition in Choice C of "SV-1MS-105 A, 'A' Steam Generator Safety Valve lift setpoint is out of tolerance in Mode 3" does not meet LCO 3. 7.1 as five main steam safety valves per steam generator shall be operable in Modes 1, 2, and 3. With a safety valve lift setpoint out of tolerance in Mode 3, it is inoperable and thus the LCO is not met. Justification for Choice B as a correct' answer: When Choice B (HYV-1 FW-1 OOB, 1 B Main Feedwater CNMT Isolation Valve has a broken stem in Mode 4) was developed as a replacement distractor, it was recognized that LCO 3.7.3 was not applicable in Mode 4 as a feedwater isolation valve. However, it was not recognized that the condition in Choice B was applicable in Mode 4 for LCO 3.6.3 for containment isolation. HYV-1 FW-1 OOB, 1 B Main Feedwater CNMT Isolation Valve is specifically listed as a containment isolation valve in Licensirig Requirements Manual Table 3.6.1-1. Summary: The NRC has determined that Question 42 has two valid answers, Choices C and B, given that both choices provide conditions that do not meet LCOs.

References:

Beaver Technical Specifications 3.6.3, Containment Isolation Valves Beaver Technical Specifications 3. 7.1, Main Steam Safety Valves Beaver Technical Specifications 3.7.3, Main Feedwater Isolation Valves and Main Feedwater Regulation Valves and MFRV Bypass Valves Licensing Requirements Manual Table 3.6.1-1, Rev 56

Question 71 NRC Resolution: Change the answer key from Choice A to Choice C because, upon further review, it was determined that Choice C is the only correct answer. No other choices are correct. Discussion: Seventeen applicants chose Choice C while three chose the original Key Choice A. Two applicants chose Choice D and none chose B. There was only one question asked by the applicants on this question. The applicant asked if Rad Pro did an assessment of the entry. This was a bank question that was used on Question 71 of the 2015 Beaver Valley Unit 2 NRC Exam. The licensee proposed changing the correct answer to Choice C. This is because when airborne contamination concentrations exceed 1.0 DAC, 1.h-ADM-1601, Radiation Protection Standards, section 7.4, requires the donning of respirators. The airborne contamination concentration provided in the question was 10 DAC. Thus, the originally designated correct answer (Choice A) is incorrect because it stated that one should NOT wear a respirator. The NRC agrees that Choice A is incorrect and that Choice C is the correct answer. Justification for Choice A being incorrect: The intent of the question was to have the applicants assess the given conditions and then perform a calculation to determine whether wearing a respirator or not wearing a respirator would result in a lower TEDE. However, the airborne contamination concentration provided in the question (10 DAC) exceeded the limit (1.0 DAC) set forth in 1.h-ADM-1601, section 7.4. Therefore, it was a requirement to wear a respirator. Thus, because Choice A (and B) stated that one should NOT wear a respirator, it is not a correct response. Justification for Choice C being the correct answer: Due to the clear requirement in 1.h-ADM-1601, Radiation Protection Standards, section 7.4, a respirator must be worn if the airborne contamination concentrations exceed a value/limit of 1.0 DAC. With the airborne contamination concentration of 1 O DAC as stated in the question, it is a requirement to wear a respirator even though for the given conditions the TEDE would be lower (993 mRem vs 998 mRem) if a respirator was not worn. Choice D also stated that one must wear a respirator but the reason provided is incorrect. Thus, Choice C is the only correct answer.

Summary: The NRC has determined that Question 71 has only one valid answer. Choices C is the correct answer instead of A given the requirements of Y2-ADM-1601, Radiation Protection Standards, section 7.4.

References:

Y2-ADM-1601, Radiation Protection Standards, Rev 23

ATTACHMENT A Proposed Answer Key Changes Question 35

Question 35 Recommendation: The facility recommends accepting two correct answers for question #35. Reason: Technical information and actual plant operation data available that supports an additional answer.

35. The plant is at 65% power with all systems in normal alignment for this power level when the crew enters AOP 1.28.1, Loss of Secondary Component Cooling Water.

Which of the following conditions, and required action will be directed by AOP 1.28.1 due to the high Secondary Component Cooling Water temperature condition? A. Main Feedwater Pump Bearing temperature is 224°F, trip the Main Feedwater pump. B. Turbine Lube Oil Cooler Outlet temperature is 177°F, trip the Reactor. C. Turbine Journal Bearing Metal temperature is 221°F, trip the Turbine. D. Main Condensate Pump Bearing temperature is 175°F, trip the Condensate pump. Question 35 tested knowledge of component operating temperature limits as listed in Abnormal Operating Procedure (AOP) 1.28.1 "Loss of Secondary Component Cooling Water" (attached). AOP 1.28.1, Continuous Action Step 8, and AOP Left Hand Page "Parameter Limits for Immediate Action" Table both support securing a Main Feedwater Pump with bearing temperatures greater than 220°F. This supports original answer 'A' as being correct. Answer 'B', Turbine Lube Oil Cooler Outlet temperature of 177°F, is also correct, as this would result in Turbine Bearing Oil return temperatures of "'207°F. This exceeds the Main Bearing Lube Oil temperature limit of 195°F in both AOP-1.28.1, Continuous Action Step 4, and the AOP Left Hand Page "Parameter Limits for Immediate Action" Table. The average delta T between Turbine Lube Oil Cooler Outlet temperature and Turbine Bearing Oil temperature is "'29.7°F. This is supported by the attached data as summarized below. Note this data is taken with the Unit at 100% power. The question initial conditions are at 65% power. Turbine Lube Oil Cooler Outlet and Turbine Bearing Oil temperatures do not change appreciably from 65% to 100% Power. This is validated by the attached Pl Data from the recent Unit 1 power ascension following 1R24. Per operator rounds data taken on 11/16/16 at 0800 (attached), the difference between Turbine Lube Oil Cooler Outlet temperature (119.9°F) and Turbine Bearing Oil return temperatures, ranged between 22.1°F (142°F return temp) and 34.1°F (154°F return temp), with an average of 29.7°F. All of which, if added to Answer 'B' Turbine Lube Oil Cooler Outlet temperature of 177°F results in Turbine Bearing Oil return temperatures exceeding trip criteria. Additional supporting data was obtained by conducting Beaver Valley Simulator scenarios with a Loss of Secondary Component Cooling Water. When Turbine Lube Oil Cooler temperature was allowed to rise to 177°F, all Turbine Bearing Oil return temperatures exceeded trip criteria of 195°F. (See Attached) With Turbine Bearing Oil return temperatures of "'207°F, AOP-1.28.1, Continuous Action Step 4, Response Not Obtained (RNO) column, requires verification of a Turbine Trip. Question initial conditions of 65% (>P-9 setpoint of 49%), requires a Reactor Trip prior to a Turbine Trip. Therefore, Answer 'B' Turbine Lube Oil Cooler Outlet temperature is 177°F, trip the Reactor, is also a correct answer to this question. Based on the above information the facility recommends accepting two answers for question 35, the original correct answer "A", and answer "B".

BVPS-AOP 1 OM-53C.4.1.28.1 Number Title 1.28.1 Loss of Secondary Component Cooling Water Revision 3 STEP 11 ACTION/EXPECTED RESPONSE 11 Main Feedwater Pump Bearing Temperatures - LESS THAN 220F

  • [T2320A through T2325A], Main Feedwater Pump lA bearing temperatures.
  • [T2380A through T2385A], Main Feedwater Pump lB bearing temperatures.

Main Condensate Pump Bearing Temperatures - LESS THAN 180F

  • [T2508A, T2509A], CN-P-lA MTR INBD (OUT) BRG T/C-1CN-200Al(A2)

[T2518A, T2519A], CN-P-lB MTR INBD (OUT) BRG T/C-1CN-200B1(82) Heater Drain Pump Bearing Temperatures - LESS THAN 180F

  • [T2360A, T2361A], HD-P-lA MTR INBD (OUT) BRG T/C-1SD-200Al (A2)
  • [T2370A, T2371A], HD-P-18 MTR INBD (OUT) BRG T/C-1SD-200Bl (B2) 1AOP1281 7116/2013 7 of24 RESPONSE NOT OBTAINED Secure affected pump(s).

IF all main feedwater is lost, THEN perform the following:

1) Trip the reactor.
2) GO TO E-0, "Reactor Trip Or Safety Injection"
3) WHEN immediate actions of E-0 are complete, perform this procedure in parallel with EOPs.

Secure affected pump(s). IF all main condensate is lost, THEN perform the following:

1) Trip the reactor.
2) GO TO E-0, "Reactor Trip Or Safety Injection"
3) WHEN immediate actions of E-0 are complete, perform the foll owing:

a) Open [MOV-lAS-100], Main Cnds Vac Break MOV. b) Perform this procedure in parallel with EOPs. Secure affected pump{s).

Step 3 3 3 3 4 4 8 9 10 PARAMETER LIMITS FOR IMMEDIATE ACTION AOP 1.28.1 (Revision 3) Parameter Turbine Lube Oil Cooler Outlet Temperature Turbine Journal & Thrust Bearing Metal Temperature Main Generator Cold Gas Temperatures Turbine Vibration Main Bearing Lube Oil Temperatures Both Main Condensate Pumps Main Feedwater Pump Bearing Temperatures Main Condensate Pump Temperatures Heater Drain/Separator Drain Pump Temperatures Limit '180F 225F 56C 14 mils 195F OFF 220F 180F 180F

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Unlt1CRO RECORD IPC POINT T2053A Min: <EXPR> Max: 160 Units: F 11/14/2016 08:00 11/14/2016 00:00 149.8 149.3 RECORD IPC POINT T2054A Librich, Michael N Hart,Sean M Min: <EXPR> Max: <EXPR> Units: F 11/16/2016 08:00 119.9 11/16/2016 00:00 119.5 11/15/2016 16:00 119.1 11/15/2016 08:00 119.8 11/15/2016 00:00 119.4 11/14/2016 16:00 119.1 11/14/2016 08:00 120.3 11/14/2016 00:00 119.8 TURBINE LUBE OIL COOLERS D/T Units: F 11/16/2016 08:00 29.4 11/16/2016 00:00 29.S 11/15/2016 16:00 29.4 11/15/2016 08:00 29.6 11/15/2016 00:00 29.6 11/14/2016 16:00 29.4 11/14/2016 08:00 29.5 11/14/2016 00:00 29.5 VERIFY VCT LEVELS WITHIN 5% Snodgrass, Steven W Hart,Sean M Mandich,Pete (Jr) Williams,Jonathan D MCCrory,limothy W Snodgrass, Steven w Librich, Michael N Hart,Sean M Snodgrass, Steven w Hart,Sean M Mandlch,Pete (Jr) Willlams,Jonathan D McCrory,limothy W Snodgrass, Steven W librich, Michael N Hart,Sean M Min: y Max: y Units: y OR N 11/16/2016 08:00 y Snodgrass, Steven W 11/16/2016 00:00 y Hart,Sean M 11/15/2016 16:00 y Mandich,Pete {Jr) 11/15/2016 08:00 y Williams,Jonathan D 11/15/2016 00:00 y MCCrory,limothy W 11/14/2016 16:00 y Snodgrass, Steven W 11/14/2016 08:00 y Librich, Michael N 11/14/2016 00:00 y Hart,Sean M TEST ALL ANNUNCIATOR ALARMS 11/16/2016 00:00 11/15/2016 00:00 11/14/2016 00:00 y y y Min: Y Max: Y Units: Y OR N Hart,Sean M McCrory,limothy W Hart,Sean M ENSURE ALL CR CHARTS HAVE ADVANCED Min: y Max: y Units: y OR N 11/16/2016 04:00 y Hart,Sean M 11/15/2016 20:00 y Mandich,Pete {Jr) 11/15/2016 12:00 y Williams,Jonathan D 11/15/2016 04:00 y McCrory,Timothy W 11/14/2016 20:00 y Hart,Sean M 11/14/2016 12:00 y Librich, Michael N 11/14/2016 04:00 y Hart,Sean M REQUEST 2ND VERIFY CONTAINMENT VAC PP 11/16/2016 00:00 y 11/15/2016 00:00 y 11/14/2016 00:00 y Min: <EXPR> Max: Y Units: Y OR N Hart,Sean M McCrory,Timothy W Hart,Sean M REQUEST 2ND VERIFY CONTAINMENT VAC PP 11/16/2016 00:00 11/15/2016 00:00 y y Min: <EXPR> Max: Y Units: YORN Hart,Sean M McCrory,Timothy W 10M-54.3.CR01 RTL No: A9.340J TURB LUBE OIL CLR IN T/C-lTB-212 Seq: 288 STA: 166 Seq: 289 STA: 167 us informed. Seq: 290 STA: 247 VERIFY vcr LEVELS INDICATE WITHIN 5% OF EACH OTHER Seq: 291 STA: 346 Seq: 292 STA: 159 SEE INSTRUCTIONS Seq: 293 STA: 345 1CV-P-1A. SEE INSTRUCTIONS Seq: 294 STA: 339 lCV-P-18. SEE INSTRUCTIONS Seq: 296 STA: 342 ....,.. ~ l"'lllft4//!.

Unit 1 Turbine .. CHECK FIRE DOOR 535-24 CLOSED AND LATCHED 1535-24 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 Y Pratchenko,Fred A CHECK FIRE DOOR 535-26 CLOSED AND LATCHED 1S35-26 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 Y Pratchenko,Fred A VERIFY APPROPRIATE UNIT 1 PROTECTED TRAIN SIGN POSTED IN THI Min: Y Max: Y Units: Y OR N 11/16/2016 08:00 Y Seligsohn,William 11/15/2016 08:00 Y Cotter,William G 11/14/2016 08:00 Y Cotter,WHliam G VERIFY APPROPRIATE UNIT 2 PROTECTED TRAIN SIGN POSTED IN SHJ Min: y Max: y Units: y OR N 11/16/2016 08:00 Y Seligsohn,William 11/15/2016 08:00 Y Cotter,Wilfiam G 11/14/2016 08:00 Y Cotter,William G CHECK FIRE DOOR 535-29 CLOSED AND LATCHED 1535-29 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 y Pratchenko,Fred A CCT SURGE TANK LEVEL LG-1CC-103A Min: 20 Max: 70 Units:% 11/16/2016 08:00 11/16/2016 00;00 11/15/2016 08:00 70 55 40 11/15/2016 00:00 40 11/14/2016 08:00 45 11/14/2016 00:00 45 6!JLLL.-.W2WG~ Seligsohn, William Pratchenko,Fred A Cotter, William G Pratchenko,Fred A Cotter,William G Pratchenko,Fred A TI-lTB-210 Min: 100 Max: 160 Units: F 11/16/2016 08:00 146 Seligsohn,William 11/16/2016 Pratchenko,Fred A 00:00 146 11/15/2016 Quaka,Daniel 16:00 145 11/15/2016 Cotter,William G 08:00 146 11/15/2016 Pratchenko,Fred A 00:00 146 11/14/2016 Quaka,Daniel 16:00 147 11/14/2016 Cotter,William G 08:00 147 11/14/2016 00:00 146 Pratchenko,Fred A \\GEN AIR SIDE SEAL OIL PRESS EXCITR END Pl-1TB-300A Units: PSIG 11/16/2016 08:00 88 11/16/2016 00:00 88 11/15/2016 16:00 87 11/15/2016 08:00 87 11/15/2016 00:00 87 11/14/2016 16:00 87 11/14/2016 08:00 87 11/14/2016 00:00 87 GEN COLD GAS H2 TEMP TIC-lCC-201 Max: 120 Units: F 11/16/2016 08:00 117.5 11/16/2016 00:00 117.5 11/15/2016 16:00 117.5 11/15/2016 08:00 117.5 11/15/2016 00:00 120 11/14/2016 16:00 120 11/14/2016 08:00 117.5 5 / 67 Seligsohn,William Pratchenko,Fred A Quaka,Daniel Cotter,William G Pratchenko,Fred A Quaka,Daniel Cotter,William G Pratchenko,Fred A Seligso.tm,William Pratchenko,Fred A Quaka,Daniel Cotter,William G Pratchenko,Fred A Quaka,Daniel Cotter,William G lOM-54.3. TURBINE! RTL No: A9.3405 l-TRBB-735-TURB BLDG TO EFFWENT CO Seq: 41 STA: 592 l-TRBB-735 - -MEN'S LOCKER RI' Seq: 42 STA: 593 Seq: 43 STA: 660 Seq: 44 STA: 661 l-TRBB-735 - -TURB BLDG TO SI Seq: 45 STA: 594 -CCT Seq: 46 STA: 6 1-TURB--- Seq: 47 STA: 7 Seq: 48 STA: 362 Seq: 49 STA: 361 11/16/2016

r Unit 1 Turbine 10M*54.3.TURBINE1 RTL No: A9.3405 GEN COLD GAS H2 TEMP TIC-lCC-201 Max: 120 Units: F Seq: 49 STA: 361 11/14/2016 00:00 117.5 Pratchenko,Fred A GEN AIR SIDE SEAL OIL PRESS TURB END PI-lTB-3008 Units: PSIG seq: 50 STA: 360 11/16/2016 08:00 87.5 Seligsohn, William 11/16/2016 00:00 87.5 Pratchenko,Fred A 11/15/2016 16:00 87.5 Quaka,Daniel 11/15/2016 08:00 87.5 Cotter,William G 11/15/2016 00:00 87.5 Pratchenko,Fred A 11/14/2016 16:00 87.5 Quaka,Daniel 11/14/2016 08:00 87.5 Cotter,William G 11/14/2016 00:00 87.5 Pratchenko,Fred A aiii'ibRINGroeJ:liCREWRNiiFEMPERATURlj TI-lTB-209 Min: 100 Max: 160 Units: F Seq: 51 STA: 363 11/16/2016 08:00 152 5eligsohn, Wiffiam 11/16/2016 00:00 151 Pratchenko,Fred A 11/15/2016 16:00 150 Quaka,Daniel 11/15/2016 08:00 151 Cotter,William G 11/15/2016 00:00 151 Pratchenko,Fred A 11/14/2016 16:00 150 Quaka,Daniel 11/14/2016 08:00 151 Cotter,William G 11/14/2016 00:00 151 Pratchenko,Fred A --*1111*-**lll&1Ul'E. TI-lTB-208 Min: 100 Max: 160 Units: F Seq: 52 STA: 364 11/16/2016 08:00 152 Seligsohn, William 11/16/2016 00:00 152 Pratchenko,Fred A 11/15/2016 16:00 152 Quaka,Daniel 11/15/2016 08:00 152 Cotter,William G 11/15/2016 00:00 152 Pratchenko,Fred A 11/14/2016 16:00 152 Quaka,Daniel 11/14/2016 08:00 153 Cotter,William G 11/14/2016 00:00 153 Pratchenko,Fred A TURNING GEAR OIL SUPPLY PRESSURE PI-lTB-235 Min: 10 Max: 30 Units: PSIG Seq: 53 STA: 365 11/16/2016 08:00 17.8 Seligsohn, William 11/16/2016 00:00 17.8 Pratchenko,Fred A 11/15/2016 16:00 17.8 Quaka,Daniel 11/15/2016 08:00 17.8 Cotter,William G 11/15/2016 00:00 17.8 Pratchenko,Fred A 11/14/2016 16:00 17.8 Quaka,Oaniel 11/14/2016 08:00 17.8 Cotter, William G 11/14/2016 00:00 17.8 Pratchenko,FredA

  1. 2 LP TURB GEN END GLAND STEAM PRESSURE PI-lMS-2058 Min: 1 Max: 5 Units: PSIG Seq: 54 STA: 366 11/16/2016 08:00 4.0 Seligsohn,William 11/16/2016 00:00 4.0 Pratchenko,Fred A 11/15/2016 16:00 4.0 Quaka,Daniel 11/15/2016 08:00 4.0 Cotter,Wiiliam G 11/15/2016 00:00 4.0 Pratchenko,Fred A 11/14/2016 16:00 4.0 Quaka,Daniel 11/14/2016 08:00 3.8 Cotter,William G 11/14/2016 00:00 4

Pratchenko,Fred A tuR'itebRING"#S'Oitrlfmiif;tEMPERATtiRE TI-lTB-207 Min: 100 Max: 160 Units: F Seq: 55 STA: 8 11/16/2016 08:00 150 Seligsohn,William 11/16/2016 00:00 150 Pratchenko,Fred A I> I 1>7

    • ,. #:!'..... ft.,.

Unit*l Turbine 10M-54.3.TURBINE1 RTL No: A9.340S "t)VPIMll9'..G.f)IURETl.IRN'FEMPERM\\JR& THTB-207 Min: 100 Max: 160 Units: F Seq: 55 STA: 8 11/15/2016 16:00 150 Quaka,Daniel 11/15/2016 08:00 150 Cotter, William G 11/15/2016 00:00 150 Pratchenko,Fred A 11/14/2016 16:00 150 Quaka,Daniel 11/14/2016 08:00 150 Cotter,William G 11/14/2016 00:00 150 Pratchenko,Fred A

  1. 2 LP TURB GOVERNOR END GLAND STM PRESS PI-1MS-205A Min: 1 Max: 5 Units: PSIG Seq: 56 STA: 9 11/16/2016 08:00 4.25 Seligsohn, William 11/16/2016 00:00 4.25 Pratchenko,Fred A 11/15/2016 16:00 4.5 Quaka,Daniel 11/15/2016 08:00 4.1 Cotter,Wllliam G 11/15/2016 00:00 4.4 Pratchenko,Fred A 11/14/2016 16:00 4.5 Quaka,Daniel 11/14/2016 08:00 4.0 Cotter,William G 11/14/2016 00:00 4.25 Pratchenko,Fred A

~ ~ Tl-lTB-202 Min: 100 Max: 160 Units: F Seq: 57 STA: 10 11/16/2016 08:00 141 Seligsohn, William 11/16/2016 00:00 141 Pratdlenko,Fred A 11/15/2016 16:00 141 Quaka,Daniel 11/15/2016 08:00 141 Cotter,Willfam G 11/15/2016 00:00 141 Pratchenko,Fred A 11/14/2016 16:00 141 Quaka,Danfel 11/14/2016 08:00 142 Cotter, William G 11/14/2016 00:00 142 Pratchenko,Fred A ........... ~- TI-lTB-201 Min: 100 Max: 160 Units: F Seq: 58 STA: 11 11/16/2016 08:00 141 Seligsohn,William 11/16/2016 00:00 141 Pratchenko,Fred A 11/15/2016 16:00 141 Quaka,Daniel 11/15/2016 08:00 142 Cotter,William G 11/15/2016 00:00 141 Pratchenko,Fred A 11/14/2016 16:00 140 Quaka,Danfel 11/14/2016 08:00 142 Cotter,William G 11/14/2016 00:00 141 Pratchenko,Fred A 11fJUllE'AIUNGrlf4f(j11JREififlfi4EMRERA'FURE TI-lTB-206 Min: 100 Max: 160 Units: F Seq: 59 STA: 12 11/16/2016 08:00 154 Seligsohn,William 11/16/2016 00:00 153 Pratchenko,Fred A 11/15/2016 16:00 154 Quaka,Daniel 11/15/2016 08:00 154 Cotter,William G 11/15/2016 00:00 154 Pratchenko,Fred A 11/14/2016 16:00 154 Quaka,oaniel 11/14/2016 08:00 154 Cotter,William G 11/14/2016 00:00 154 Pratchenko,Fred A

  1. 1 LP TURB GLAND STM PRESS GENERATOR END PI-1MS-204B Min: 1 Max: S Units: PSIG Seq: 60 STA: 13 11/16/2016 08:00 3.3 Seligsohn, William 11/16/2016 00:00 3.3 Pratchenko,Fred A 11/15/2016 16:00 3.5 Quaka,Daniel 11/15/2016 08:00 3.2 Cotter,William G 11/15/2016 00:00 3.4 Pratchenko,Fred A 11/14/2016 16:00 3.5 Quaka,Daniel 11/14/2016 08:00 3.0 Cotter,William G 11/14/2016 00:00 3.3 Pratchenko,Fred A

'7 I C'7 11/16/2016

Unit 1 Turbine 10M*54.3.TURBINE1 RTL No: A9.340S-iDURE' lHTB-205 Min: 100 Max: 160 Units: F Seq: 61 STA: 14 11/16/2016 08:00 155 Seligsohn,William 11/16/2016 00:00 155 Pratchenko,Fred A 11/15/2016 16:00 155 Quaka,Daniel 11/15/2016 08:00 155 Cotter,William G 11/15/2016 00:00 155 Pratchenko,Fred A 11/14/2016 16:00 154 Quaka,Daniel 11/14/2016 08:00 155 Cotter,William G 11/14/2016 00:00 155 Pratchenko,Fred A 'litJRIPaEftiNGJ#2ioif.iiifu.W.'FEMPERATURE TI-lTB-204 Min: 100 Max: 160 Units: F Seq: 62 STA: 15 11/16/2016 08:00 146 Seligsohn, William 11/16/2016 00:00 146 Pratchenko,Fred A 11/15/2016 16:00 146 Quaka,Daniel 11/15/2016 08:00 147 Cotter,William G 11/15/2016 00:00 147 Pratchenko,Fred A 11/14/2016 16:00 147 Quaka,Daniel 11/14/2016 08:00 147 Cotter, William G 11/14/2016 00:00 147 Pratchenko,Fred A

  1. 1 LP TURB GLAND STM PRESS GOVENOR END Pl-1MS-204A Min: 1 Max: 5 Units: PSIG Seq: 63 STA: 16 11/16/2016 08:00 3.4 Seligsohn,William 11/16/2016 00:00 3.5 Pratchenko,Fred A 11/15/2016 16:00 3.5 Quaka,Daniel 11/15/2016 08:00 3.5 Cotter,William G 11/15/2016 00:00 3.5 Pratchenko,Fred A 11/14/2016 16:00 3.4 Quaka,Daniel 11/14/2016 08:00 3.4 Cotter,William G 11/14/2016 00:00 3.4 Pratchenko,Fred A HIGH PRESS TURBINE GLAND STEAM PRESSURE Pl-lTB-232 Min: 1 Max: 5 Units: PSIG Seq: 64 STA: 17 11/16/2016 08:00 2.6 Seligsohn, William 11/16/2016 00:00 2.7 Pratchenko,FredA 11/15/2016 16:00 2.7 Quaka,Daniel 11/15/2016 08:00 2.5 Cotter, William G 11/15/2016 00:00 2.6 Pratchenko,Fred A 11/14/2016 16:00 2.6 Quaka,Daniel 11/14/2016 08:00 2.4 Cotter, William G 11/14/2016 00:00 2.5 Pratchenko,Fred A GLAND STEAM SYSTEM SUPPLY PRESSURE PI-1MS-206A Min: 100 Max: 150 Units: PSIG Seq: 65 STA: 18 11/16/2016 08:00 150 Seligsohn, William 11/16/2016 00:00 149 Pratchenko,Fred A 11/15/2016 16:00 149 Quaka,Daniel 11/15/2016 08:00 149 Cotter,William G 11/15/2016 00:00 150 Pratchenko,Fred A 11/14/2016 16:00 150 Quaka,Daniel 11/14/2016 08:00 150 Cotter, William G 11/14/2016 00:00 150 Pratchenko,Fred A iftliiiiEARJNG:i~lit>l!IRHURNi!'UM9EDruRE TI-llB-203 Min: 100 Max: 160 Units: F Seq: 66 STA: 19 11/16/2016 08:00 142 Seligsohn, William 11/16/2016 00:00 142 Pratchenko,Fred A 11/15/2016 16:00 142 Quaka,Danlel 11/15/2016 08:00 142 Cotter,William G 11/15/2016 00:00 143 Pratchenko,Fred A 11/14/2016 16:00 142 Quaka,Daniel 0

I C'll'

Unit. :I. Turbine lOM-54.3.TURBINEl RTL No: A9.340S illl~dli -~*I BIBeal N .E"' ll-lTB-203 Min: 100 Max: 160 Units: F Seq: 66 STA: 19 11/14/2016 08:00 143 Cotter,William G 11/14/2016 00:00 143 Pratchenko,Frecl A MAIN TURBINE BEARING LUBE OIL SUPPLY PRE Pl-lTB-1 Min: 10 Max: 30 Units: PSIG Seq: 67 STA: 20 11/16/2016 08:00 17.6 Seligsohn, William 11/16/2016 00:00 17.6 Pratchenko,Fred A 11/15/2016 16:00 17.6 Quaka,Danlel 11/15/2016 08:00 17.6 Cotter,Wllllam G 11/15/2016 00:00 17.6 Pratchenko,Frecl A 11/14/2016 16:00 17.6 Quaka,Daniel 11/14/2016 08:00 17.6 Cotter, William G 11/14/2016 00:00 17.6 Pratchenko,Fred A MAIN LUBE OIL PUMP SUCTION PRESSURE Pl-lTB-2 Min: 10 Max: 45 Units: PSIG Seq: 68 STA: 21 11/16/2016 08:00 27 Seligsohn, William 11/16/2016 00:00 27 Pratchenko,Fred A 11/15/2016 16:00 27 Quaka,Danlel 11/15/2016 08:00 27 Cotter,William G 11/15/2016 00:00 27 Pratchenko,Fred A 11/14/2016 16:00 27 Quaka,Daniel 11/14/2016 08:00 27 Cotter, William G 11/14/2016 00:00 27 Pratchenko,Fred A MAIN LUBE OIL PUMP DISHARGE PRESSURE Pl-lTB-3 Min: 320 Max: 390 Units: PSIG Seq: 69 STA: 22 11/16/2016 08:00 382.5 Seligsohn, William 11/16/2016 00:00 382.5 Pratchenko,Fred A 11/15/2016 16:00 382.5 Quaka,Daniel 11/15/2016 08:00 382.5 Cotter,Willlam G 11/15/2016 00:00 382.5 Pratchenko,Fred A 11/14/2016 16:00 382.5 Quaka,Daniel 11/14/2016 08:00 382.5 Cotter,William G 11/14/2016 00:00 382.5 Pratchenko,Fred A TURBINE AUTO STOP OIL PRESSURE NOTIFY US OF A DOWNWARD TREND PI-1TB-231A Min: 100 Max: 125 Units: PSIG Seq: 70 STA: 452 11/16/2016 08:00 113 Seligsohn,William 11/16/2016 00:00 113 Pratchenko,Fred A 11/15/2016 16:00 113 Quaka,Daniel 11/15/2016 08:00 113 Cotter, William G 11/15/2016 00:00 113 Pratchenko,Fred A 11/14/2016 16:00 113 Quaka,Daniel 11/14/2016 08:00 113 Cotter,William G 11/14/2016 00:00 113 Pratchenko,Fred A CHECK FIRE DOOR 535-35 CLOSED AND LATCHED 1S35-35 Min: Y Max: Y Units: Y or N 1-SRVB-735 -MECH SHOP -TURB BLDG Seq: 75 STA: 595 11/14/2016 00:00 Y Pratchenko,Fred A FIRE DOOR 535*38 CHECK 1S35-38 Min: Y Max: Y Units: Y or N 1-SRVB-735 - -SLIDING DOOR TI Seq: 76 STA: 596 11/14/2016 00:00 Y Pratchenko,Fred A CHECK FIRE DOOR 535-40 CLOSED AND LATCHED 1535-40 Min: Y Max: Y Units: Y or N 1-SRVB-735 - -<:LEAN SHOP TO II Seq: n STA: 597 11/14/2016 00:00 Y Pratchenko,Fred A CHECK FIRE DOOR 535-45 CLOSED AND LATCHED 1S35-45 Min: Y Max: Y Units: Y or N 1-TRBB-735 - -TURB BLDG TO W Seq: 78 STA: 598 11/14/2016 00:00 Y Pratchenko,Fred A Q / #1.7 11/16/2016

Unit 1 Turbine CHECK FIRE DOOR 535'"46 CLOSED 1S35-46 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 y Pratchenko,Fred A FIRE DOOR 535-52 CHECK 1S35-52 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 y Pratchenko,Fred A FIRE DOOR 535-54 CHECK 1S35-54 Min: Y Max: Y UnitS: Y or N 11/14/2016 00:00 y Pratchenko,Fred A CHECK FIRE DOOR 535-55 CLOSED AND LATCHED 1535-55 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 y Pratchenko,Fred A FIRE DOOR 535*56 CHECK 1535-56 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 Y Pratchenko,Fred A CHECK FIRE DOOR 535-53 CLOSED AND LATCHED 1S35-53 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 Y Pratchenko,Fred A FIRE DOOR 535-65 CHECK 1S35-65 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 y Pratchenko,Frecl A FIRE DOOR S35-66 CHECK 1535-66 Min: Y Max: Y Units: Y or N 11/14/2016 00:00 y Pratchenko,Fred A DIESEL AIR COMP ALIGNED FOR AUTO START lIA-C-4 Min: Y Max: Y Units: Y or N 11/16/2016 00:00 11/15/2016 00:00 11/14/2016 00:00 Y Pratchenko,Frecl A Y Pratchenko,Fred A Y Pratchenko,Frecl A DIESEL AIR COMP BATTERY CHARGER BAT-CHG-1IA-1 11/16/2016 00:00 11/15/2016 00:00 11/14/2016 00:00 26.1 26.1 26.1 Min: 24 Units: Volts DIESEL AIR COMPRESSOR AIR RECEIVER PI-lIA-233 Min: 95 UnitS: PSIG 11/16/2016 00:00 104 11/15/2016 00:00 104 11/14/2016 00:00 104 DIESEL AIR COMPRESSOR AIR DRYER Pratchenko,Fred A Pratchenko,Frecl A Pratchenko,Frecl A Pratchenko,Fred A Pratchenko,Fred A Pratchenko,Frecl A 1IA-D-1C Min: Y Max: Y Units: Y or N 11/16/2016 00:00 11/15/2016 00:00 11/14/2016 00:00 Y Pratchenko,Fred A Y Pratchenko,Fred A Y Pratchenko,Fred A DIESEL AIR COMPRESSOR AIR DRYER TOWER 1 PI-lIA-234 Min: 80 Units: PSIG 11/16/2016 00:00 97.5 11/15/2016 00:00 95 11/14/2016 00:00 95 DIESEL AIR COMPRESSOR AIR DRYER TOWER 2 PI-lIA-235 11/16/2016 00:00 11/15/2016 00:00 97.5 95 11/14/2016 00:00 95 4 ft I C., Min: 80 Units: PSIG Pratchenko,Frecl A Pratchenko,Fred A Pratchenko,Fred A Pratchenko,Fred A Pratchenko,Fred A Pratchenko,Fred A 10M-54.3.TURBINE1 RTL No: A9.340S.. 1-SRVB-735 - -TURB BLDG TOW Seq: 79 1-TRBB- -SLIDING DOOR TUF Seq; 80 1-TRBB- - -SLIDING DOOR TUF Seq: 81 1-5RVB-735 - -STOREROOM TO J Seq: 82 1-SRVB-735 - -SLIDING DOOR TI Seq: 83 1-5RVB-735 - -CORRIDOR TO AU Seq: 84 1-SRVB-735 - -SLIDING DOOR TI Seq: 85 1-TRBB- -SLIDING DOOR TUF Seq: 86 SEE SPECIAL INSTRUCTIONS 1-WTBX-735 -AUX BlR ROOM Record Battery Charger Voltage 1-WTBX-735 -AUX SLR ROOM Record lIA-TK-2 pressure Seq: 87 Seq: 88 1-WTBX-735 -AUX SLR ROOM Seq: 89 Air Dryer "STAND-BY" Light Illuminated. l*WTBX-735 -AUX BLR ROOM Seq: 91 "AUTO START STOP" "AUTO START STOP" "AUTO START STOP" Record the Diesel Air Compressor Air Dryer Tower Pressure STA: 599 STA: 600 STA: 601 STA: 602 STA: 603 STA: 604 STA: 605 STA: 606 STA: 579 STA: 580 STA: 581 STA: 583 1-WTBX-735-AUX BLR ROOM Seq: 92 STA: 585 Record the Diesel Air Compressor Air Dryer Tower Pl"e$Ure 1-WTBX-735 -AUX BLR ROOM Seq: 93 STA: 584

't A9.330B Beaver Valley Power Station Unit 1 1 OM-28.4.AAC Secondary Comp Cool Water Heat Exchanger Disch Temp High GENERAL SKILL REFERENCE Revision 1 Prepared by Date Pages Issued Effective Date C. Eberle 08/13/09 1through3 10/23/09 Reviewed by Date Validated by Date J.P. Keegan 08/20/09 PORC Meeting No. Date PORC not required PAF-09-01759

BVPS - GSR Unit 1 Turbine Plant Component Cooling Water System Operating Procedures Secondary Comp Cool Water Heat Exchanger Disch Temp High SECONDARY COMP COOL WATER HEAT EXCHANGER DISCH TEMP HIGH A6-59 SETPOINTS: 100 F DISCONNECT SWITCH: 2-1067, BAY 3 SER POINT NUMBER: 0354 SER POINT ID: TP COMP COOL WTR HX DISCH TEMP HIGH INITIATING DEVICE: TS-CCT-200 PROBABLE CAUSE NO. 1 Overload of CCT system or high river water temperature. CORRECTIVE ACTIONS 1 OM-28.4.AAC Revision 1 Page 2of3

1.

GO TO 1 OM-53C.4.1.28.1, Loss of Secondary Component Cooling Water. PROBABLE CAUSE NO. 2 Inoperative Temperature Control Valve. CORRECTIVE ACTIONS

1.

GO TO 1 OM-53C.4.1.28.1, Loss of Secondary Component Cooling Water. PROBABLE CAUSE NO. 3 Malfunction of [TS-CCT-200], CCT HX Discharge Temp Switch. CORRECTIVE ACTIONS

1.

Verify actual temperature on [Tl-1CC-200B], Combined CCT Heat Exchangers Outlet Temp. (SE Turb Bsmt Ovhd)

2.

Initiate corrective maintenance on [TS-CCT-200], CCT HX Discharge Temp Switch.

BVPS - GSR Unit 1 Turbine Plant Component Cooling Water System Operating Procedures Secondary Comp Cool Water Heat Exchanger Disch Temp High

REFERENCES:

A. TECHNICAL SPECIFICATIONS None B. UPDATED FINAL SAFETY ANALYSIS REPORT None C. COMMITMENTS None D. ADMINISTRATIVE None E. VENDOR INFORMATION None F. DRAWING

1.

8700-RM-130A VOND Turbine Plant Component Cool Water

2.

11700-LSK-12-1 B - Secondary Component Cooling Water Pump

3.

8700-RE-21-PZ-Elementary Diagram Annunciator A6 G. OPERATING MANUAL

1.

1 OM Turbine Plant Component Cooling Water System

2.

10M-28.4.D - Placing Standby Heat Exchangers in Service H. PLANT MODIFICATION None I. OTHER 10M-28.4.AAC Revision 1 Page 3of3

1.

PAF-09-01759, RAD 09-03394-00. The following changes were made: (Revision 1)

a.

Added level-of-use, General Skill Knowledge, in accordance with NOP-LP-2601, Procedure Use and Adherence.

b.

Replaced instructions with direction to "GO TO 1 OM-53C.4.1.28.1, Loss of S9condary Component Cooling Water.

Title:

NUCLEAR OPERATING PROCEDURE Procedure Number: NOP-OP-1002 Use Category: Conduct of Operations General Skill Reference Revision: I Pag27 of 101 11 Maintain systems and parameters within established limits to ensure systems are not operated outside of the intended design and that operating margins are not eroded. Clearly establish parameters and limits, and control parameters within the specified bands and at specified rates. Use sound judgment when deciding to take manual actions prior to automatic actions in response to parameter trends. Take manual actions (in accordance with procedure direction, if available) when automatic actions do not occur. Verify and report automatic system actuations or response, which include operator actions if the plant has not responded as expected. Anticipate automatic trips and equipment protective features, and take manual actions, if possible without haste, to avoid challenging automatic; actuations. Examples of protective features are turbine trips, reactor scrams, and other features intended to prevent dan1age to equipment. Manual action of safety system operation.such as clo,sing isolation valves and starting safety systems, should be governed by emergency and abnormal operating procedures. Set limits, establish supplemental monitoring, and determine contingent actions when operating automatic systems in manual.

3.

Teamwork - The operating crew works together effectively to monitor and control the plant. Maintain broad awareness of plant conditions through all members of the crew. Communicate clearly and regularly to share important information and clarify priorities. Communicate the status of parameters to the operating crew when needed by describing the parameter, value, and trend, including any action taken or needed. Perform shift briefings and updates to keep all crewmembers aware of plant conditions and upcoming operations. Coordinate field and Control Room activities to achieve intended results.

Beaver Valley Power Station Unit 1/2 Conduct of Operations Organization and Responsibilities of the Operations Group Reactor Protection and Safety System Philosophy VI. INSTRUCTIONS A. Reactor Protection and Safety System Philosophyv.A.1 1/20M-48.1.B Revision 8 Page 5 of 5

1.

Licensed operators are responsible to initiate a reactor trip or safety feature actuation if, in their judgment, such actions are warranted. This authorization and responsibility is, and shall remain, the overriding philosophy.

2.

IF a plant parameter associated with an automatic protective feature actuation is trending toward its.actuation setpoint, and it has been.determined in the best judgment of the operator that the tre.nd is valid and will NOT be reversed by actions in progress,.the oper(itor is expected to manually initiate the protective feature without waiting for the automatic actuation to occur.

3.

Operators shall attempt to validate abnormal indications with at least two other instruments or parameters. IF validation is NOT possible OR can NOT be performed in a timely manner, the operators shall act based on the most conservative indication.

4.

WHEN valid plant conditions indicate the need for reactor protection system or safety system actuation, and the actuation fails to automatically occur, the operator is required to manually initiate the protective action.

5.

IF it has been determined that the reactor protection system is incapable of performing its automatic reactor trip function, and valid plant conditions indicate no need for reactor protection system actuation, operators shall immediately commence a controlled reactor shutdown to a condition with the reactor trip breakers open. It is expected that the Unplanned Power Reduction procedure will be used to complete a controlled shutdown as expeditiously as possible. During the period of automatic reactor protection system inoperability wi_th the reactor trip breakers closed, control room personnel must continuously monitor reactor trip parameters and initiate a manual reactor trip if trip setpoints are approached.

6.

IF it has been determined that the solid state protection system is incapable of initiating automatic safety system actuation, and valid plant conditions indicate no need for safety system actuation, operators shall immediately take action to place the plant in a mode or condition where automatic safety system actuation is NOT required. It is expected that the Unplanned Power Reduction procedure will be used, if necessary, to complete a controlled shutdown as expeditiously as possible. Until the plant is placed in a mode or condition where automatic safety system actuation is not required, control room personnel must continuously monitor SSPS initiating parameters and initiate manual actuations if setpoints are approached.

Title:

NUCLEAR OPERATING PROCEDURE Procedure Number: NOP-OP-1002 Use Category: Conduct of Operations General Skill Reference Revision: I Pag3o of 101 11 Know the bases of plant design, licensing requirements, and technical specifications. Regularly review system drawings and bases documents with the intention of refreshing fundamental knowledge. Have a solid understanding of engineering principles and sciences. Know system and component purposes, design and limitations of equipment, operating limits, and how operator actions affect margins to limits. Understand how core reactivity coefficients vary with core life and the actions you can implement to properly control the reactor, giving special attention to coefficients that add positive reactivity. Establish a learning environment (culture of intellectual curiosity) among crewmembers that encourages questioning, challenging, and knowledge reviews. Include plant design, engineering principles, and sciences in operator continuing training. Ask for simulator scenarios that challenge fundamental knowledge of plant design, engineering principles, and sciences. Regularly evaluate crewmember knowledge of plant design, engineering principles, and sciences.

5.

Conservatism - Operators have a conservative bias. Follow procedures and processes, with a thorough understanding and focus on the tasks. Control operating bands and rates to create and maintain sufficient operating margins. Take action based on sound operational principles, not solely on compliance with rules. Understand plant conditions, effectively control the plant and know the appropriate action to take when control of the plant or a component cannot be maintained, including stopping the evolution, involving supervision, tripping the component, and scramming the reactor.

BVPS-AOP 1 OM-53C.4.1.28.1 Number Title 1.28.1 Loss of Secondary Component Cooling Water Revision 3 STEP 11 ACTION/EXPECTED RESPONSE 11 RESPONSE NOT OBTAINED ~ Plant - MODE I GO TO Step 6.

a. Check the following parameters:
1) Turbine Bearing Oil Discharge Temperature - LESS THAN 180F

[T2054A], TURB LUBE OIL CLR OIL OUT T/C-lTB-213

2) Turbine Journal & Thrust Bearing Metal Temperature -

LESS THAN 225F [T2061A through T2069A], TURB BRG METAL TEMP [T2071A through T2074A], LP TURB THR BRG METAL TEMP

3) Main Generator Cold Gas Temperatures - LESS THAN 56C

[T2811A through T2814A], GEN COLD H2 GAS TEMP, less than 56C.

4) Turbine Vibration - LESS THAN 14 MILS 1AOP1281 7/1612013

[VR-TR-001), Vibration Brg. No. l, 2, 3 [VR-TR-002], Vibration Brg. No. 4, 5, 6 [VR-TR-003], Vibration Brg. No. 7, 8, 9 3of24

a. Perform the following:

IF power ~P9, perform the foll owing: a) Trip the reactor. b) GO TO E-0, "Reactor Trip or Safety Injectionu. c) WHEN immediate actions of E-0 are complete, perform this procedure in parallel with EOPs. lE power <P9, perform the following: a) Trip the turbine. b) GO TO AOP 1.26.l, "Turbine And Generator Tripu. c) WHEN immediate actions of AOP 1.26.1 are complete, perform this procedure in parallel with AOPs.

BVPS - AOP 1 OM-53C.4.1.28.1 Number Title 1.28.1 Loss of Secondary Component Cooling Water Revision 3 STEP 11 ACTION/EXPECTED RESPONSE 11 RESPONSE NOT OBTAINED ~ Check The Following Parameters

a. Check the following:
1) Main Bearing Lube Oil Temperatures - LESS THAN 195F

[T2041A through T2046A]. TURB BRG OIL TEMP [T2047A, T2048A], MAIN GEN BRG OIL TEMP [T2049A]

  • EXCITER BRG #9 OIL T /C-1TB-211A

[T2051A, T2052A]

  • LP TURB THR BRG OIL TEMP
2) [lCN-P-lA, 18], Condensate Pumps - AT LEAST ONE RUNNING 1AOP1281 7116/2013 4 of24
a. Perfonn the following:

a) Verify turbine tripped. b) WHEN turbine speed drops to ~600 rpm, Open [MOV-lAS-100], Main Cnds Vac Break MOV c) Secure gland steam: Verify Closed [MOV-lMS-201] Main Turb Gland Steam Control Vlv. IF supplied by Auxiliary Steam, Close [lMS-42], Aux Stm to Gland Stm Isol. {Turb Bldg, Mezz, Overhead SW, El 713) Place [1CN-SC-2A AND 28], control switches in PULL-TO-LOCK. Refer to Attachment A for additional actions. d) Open tarps at condenser bay AND start turbine building fans. e) Start [lLO-M-7], Turning Gear Oil Pump f) WHEN turbine speed drops to zero Verify turbine engaged on turning gear. g) IF possible, Maintain turbine on turning gear for 6 - 8 hours.

ATTACHMENT A Proposed Answer Key Changes Question 42

Question 42 Recommendation: The facility recommends accepting two correct answers for question #42 Reason: Technical information available that supports an additional answer.

42.

Which of the following conditions does NOT meet the applicable Limiting Condition for Operation (LCO)? A. TV-1MS-101C, Main Steam Trip Valve lost DC control power in MODE 4. B. HYV-lFW-lOOB, lB Main Feedwater CNMT Isolation Valve has a broken stem in MODE 4. C. SV-lMS-lOSA, 'A' Steam Generator Safety Valve lift setpoint is out of tolerance in MODE 3. D. HCV-lMS-104, Residual Heat Release Control Valve broken air line on actuator in MODE 1. Question 42 tested knowledge of Technical Specification section 3.7 Plant Systems, specifically LCO 3.7.1 "Main Steam Safety Valves (MSSVs)". TS 3.7.1 and Bases (attached) support the original correct answer of "C". For answer "B", the Explanation/Justification references only LCO 3.7.3 "Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs) and MFRV Bypass Valves (attached), which is only applicable in MODES 1, 2 and 3 and was the justification for why this answer is not correct. The Explanation/Justification does not consider the fact that HYV-lFW-lOOB is also a containment isolation valve and is required to be operable by LCO 3.6.3 "Containment Isolation Valves", with an applicability of MODES 1, 2, 3 AND 4 (attached). HYV-lFW-lOOB, 1B Main Feedwater CNMT Isolation Valve, is specifically listed as containment isolation valve in LRM Table 3.6.1-1 "Containment Penetrations" (attached). The condition of HYV-lFW-lOOB described in answer "B" does not meet LCO 3.6.3 (Containment Isolation Valves). Therefore, answer "B" should also be considered to be a correct answer to question 42. The facility recommends accepting two correct answers for question 42, the original correct Answer "C" and Answer "B", based on LCO 3.6.3 not being met by the condition described.

3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs) MSSVs 3.7.1 LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE. APPLICABILITY: MODES 1, 2, and 3. ACTIONS -NOTE* Separate Condition entry is allowed for each MSSV. CONDITION REQUIRED ACTION A. One or more steam A.1 Reduce THERMAL generators with one POWER to~ 57% RTP. MSSV inoperable and the Moderator Temperature Coefficient (MTC) zero or negative at all power levels. B. One or more steam B.1 Reduce THERMAL generators with two or POWER to less than or more MSSVs inoperable. equal to the Maximum Allowable % RTP specified OR in Table 3.7.1-1 for the number of OPERABLE One or more steam MSSVs. generators with one MSSV inoperable and the MTC AND positive at any power level. Beaver Valley Units 1 and 2 3.7.1 -1 COMPLETION TIME 4 hours 4 hours Amendments 278 I 161

ACTIONS (continued) CONDITION REQUIRED ACTION B.2 -NOTE - Only required in MODE 1. Reduce the Power Range Neutron Flux - High reactor trip setpoint to less than or equal to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs. C. Required Action and C. 1 Be in MODE 3. associated Completion Time not met. AND OR C.2 Be in MODE 4. One or more steam generators with ~ 4 MSSVs inoperable. SURVEILLANCE REQUIREMENTS SR 3.7.1.1 SURVEILLANCE - NOTE - Only required to be performed in MODES 1 and 2. Verify each required MSSV lift setpoint per Table 3.7.1-2a (Unit 1), Table 3.7.1-2b (Unit 2) in accordance with the lnservice Testing Program. Following testing, lift setting shall be within+/- 1%. Beaver Valley Units 1 and 2 3.7.1-2 MSSVs 3.7.1 COMPLETION TIME 36 hours 6 hours 12 hours FREQUENCY In accordance with the lnservice Testing Program Amendments 278 / 161

Table 3.7.1-1(page1of1) OPERABLE Main Steam Safety Valves versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs PER STEAM GENERATOR 4 3 2 MAXIMUM ALLOWABLE POWER (% RTP)

S; 50 MSSVs 3.7.1 Beaver Valley Units 1 and 2 3.7.1-3 Amendments 278 I 161

3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves Containment Isolation Valves 3.6.3 LCO 3.6.3 Each containment isolation valve shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS - NOTES -

1.

Penetration flow path(s) except for 42-inch purge and exhaust valve flow paths may be unisolated intermittently under administrative controls.

2.

Separate Condition entry is allowed for each penetration flow path.

3.

Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves. CONDITION A. A. 1 -NOTE - Not applicable to penetration flow paths addressed by Condition C. One or more penetration flow paths with one containment isolation valve AND inoperable. Beaver Valley Units 1 and 2 REQUIRED ACTION COMPLETION TIME Isolate the affected 4 hours penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured. 3.6.3 - 1 Amendments 278 / 161

Licensing Requirements Manual Containment Isolation Valves 3.6.1 3.6 CONTAINMENT 3.6.1 Containment Isolation Valves LR 3.6.1 APPLICABILITY: Beaver Valley Unit 1 Each containment isolation valve listed in....__shall be maintained in the manner specified in Tec~cation (TS) 3.6.3. As specified in TS 3.6.3. 3.6.1 - 1 LRM Revision 56

Licensing Requirements Manual PENT. No. IDENTIFICATION DESCRIPTION Auxiliary Feedwater Loop 1 B 78 FW Loop 1C Auxiliary Feedwater Loop 1 C 79 RW to 1A RSP Hx 80 RW to 1C RSP Hx 81 RW to 18 RSP Hx 82 RW to 1D RSP Hx 83 RW from 1 A RSP Hx 84 RW from 1 C RSP Hx 85 RW from 1 B RSP Hx 86 RW from 1 D RSP Hx Beaver Valley Unit 1 (Page9of15) ~PENETRATIONS MAXIMUM STROKE TIME INSIDE VALVE (SEC} Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A Closed System N/A 3.6.1 - 10 Containment Isolation Valves 3.6.1 MAXIMUM STROKE TIME OUTSIDE VALVE (SEC} ~ 10(15) N/A (2)HYV-1FW-100C 10(15) (2)FW-44 NIA (2)MOV-1RW-104A N/A (2)MOV-1RW-104C N/A (2)MOV-1RW-104B N/A (2)MOV-1RW-104D N/A (2)MOV-1RW-105A N/A (2)1RW-615 N/A (2)RV-1 RW-101A N/A (2)MOV-1 RW-105C N/A (2)1RW-627 N/A (2)RV-1RW-101C N/A (2)MOV-1RW-105B N/A (2)1RW-621 N/A (2)RV-1RW-101 B N/A (2)MOV-1RW-105D N/A (2)1RW-633 N/A (2)RV-1RW-101 D N/A LRM Revision 56

ATTACHMENT A Proposed Answer Key Changes Question 71

Question 71 Recommendation: The facility recommends changing the correct answer from "A" to "C" for #71. Reason: Technical information available that supports C as the correct answer.

71.

You are going into a contaminated area, which has the following radiological characteristics to perform a valve lineup: Your current exposure for the year is 93 8 mrem The RWP states: General area dose rate = 30 mrem/hr Airborne contamination concentration = 10.0 DAC The valve lineup will take you 2 hours if you wear a full-face respirator. The valve lineup will only take you 1 hour if you do NOT wear the respirator

1)

Which of the following choices for completing this job would maintain your exposure within the station administrative requirements and the principles of ALARA?

2) Why is this action appropriate?

A.

1) You should NOT wear the respirator
2) Your calculated TEDE dose received will be less than if you do wear a respirator B.

l) You should NOT wear the respirator

2) Your dose received wearing a respirator will exceed the site annual personnel dose limits.

C. l) You must wear the respirator.

2) You will exceed the DAC limits if you do NOT wear a respirator D.

I) You must wear the respirator

2) Your calculated TEDE dose received will be less than if you do NOT wear a respirator Answer "C" is correct based on Yz-ADM-1601, Radiation Protection Standards, section 7.4, "Airborne Radiation Control", subsection 7.4.1.5, "Protective Actions" (attached).

Subsection 7.4.1.5, states: . Protective actions (e.g., stopping work, evacuation, donning respirators) shall be taken in occupied areas in which particulate and I or iodine airborne activity exceeds 1.0 DAC, if internal dose control measures have not already been implemented. The stem of question 71 states that the Airborne Contamination= 10 DAC which exceeds the airborne activity of 1.0 DAC identified in Subsection 7.4.1.5. Based on the information given in the stem of the question, internal dose control measures have not been implemented, and stopping work or evacuation is not provided as an alternative answer. Since the given Airborne contamination concentration of 10 DAC exceeds the limit in Subsection 7.4.1.5 of Yz-ADM-1601, Radiation Protection Standards, respiratory protection must be worn. If respiratory protection is not worn, the worker will exceed the 1.0 DAC limit identified in Yz-ADM-1601. Based on the above information the facility recommends changing the correct answer of question 71 to "C" 1) You must wear the respirator. 2) You will exceed the DAC limits if you do NOT wear a respirator.

ALARA Plan ALARA Plan #: Rev.#: Work Order#: RWP#: NOP-OP-4107-04 Rev. 04 Page 2 of 8 RWP TASK ANALYSIS Eff. 80% Stop Task/Work Order Risk P-Hrs Dose Dose Dose Alarm D/R Alarm Rate Work Dose 1 2 3 4 5 6 7 8 9 10 Estimated Duration in Estimated Dose person hours (mrem) SPECIFIC HIGH RISK TASKS I ACTIVITIES ASSUMPTIONS USED DURING TASK PLANNING (e.g., Exposure Challenge Goals) DOSE REDUCTION TOOLS AND TECHNIQUES TO BE USED (highlight or circle controls) DOSE Install Fill With System Move Item to OTHER Isotopic Remote Robotics Specify in Dose CONTROL Shielding Water Flush Decay Low Dose Tooling Reduction Section CONT AM Pre-Job Job Step Strip OTHER Glovebag I DPZ Controls Knee Double Step-Specify in CONTROL Decon De con Coat Containment Walls Off-Pads Contam Control Section AIRBORNE OTHER Planned HEPA HEPA Dampen Use Fixatives GenArea Breathing Specify in CONTROL Intake Ventilation Vacuum Surfaces Air Sampler Zone A/S Airborne Control Section WORK Mockup Dry-Run Experienced Reduce Crew Use Special A LARA External MG OTHER Specify in Dose CONTROL Training Practice Workers Size Tooling Briefing Alarms Reduction Section

RTL #A5.800B Beaver Valley Power Station Revision Number Unit 1/2 1/2-ADM-1601 Radiation Protection Standards Document Owner Manager, Radiation Protection 23 Level Of Use General Skill Reference Safety Related Procedure No Effective Date 07/31/15

Beaver Valley Power Station Procedure Number: 1/2-ADM-1601

Title:

Unit: Level Of Use: Radiation Protection Standards 112 General Skill Reference Revision: Page Number: 23 16of36 7.4.1.2 Applicability 7.4.1.2.1 Excluded Sources: - Airborne radioactivity criteria do not apply to naturally occurring sources of radon gas (Rn-222) or its particulate decay products (radon daughters) because these radionuclides are not occupational sources of exposure. 7.4.1.2.2 Noble Gases: - Airborne radioactivity criteria for noble gases (Ar, Kr, Xe) apply to external dose control only. The internal dose associated with exposure to noble gases is insignificant compared to the external dose.(3.1.1s) 7.4.1.2.3 Transuranics: - Airborne transuranic (TRU) fission products are controlled by monitoring and controlling particulate alpha airborne activity. Monitoring for alpha airborne activity is necessary only when transuranics are present or suspected (e.g., removable alpha contamination detected, beta-gamma or gamma air concentration in excess of the level at which transuranic airborne activity is predicted to be significant based on scaling factors).

7. 4.1.3 Airborne Activity Measurements or estimates of airborne activity shall be based on applicable Derived Air Concentrations (DACs) 7.4.1.3.1 Mixtures: The airborne activity for a mixture of radionuclides is:

7.4.1.3.1.1 If the identity of each radionuclide in the mixture is known, but the concentration of one or more of the radionuclides is not known, the ratio of the total (gross) air concentration to the DAC for the limiting radionuclide, (3* 1*1) or 7.4.1.3.1.2 If the identity and concentration of each radionuclide in the mixture is

known, 7.4.1.4 7.4.1.3.1.2.1 7.4.1.3.1.2.2 The sum of the ratios of the air concentration to the DAC for each radionuclide in the mixture,<3*1.1) or The ratio of the total of the air concentrations for the nuclides in the mixture to the most restrictive DAC for any radionuclide in the mixture. (3. I. I)

Radiological Controls Appropriate radiological controls shall be implemented in occupied Airborne Radioactivity Areas (see Section 7.2.4), including: 7.4.1.4.1 Air sampling per NOP-OP-4702. <3.u9)

Beaver Valley Power Station Procedure Number: 1/2-ADM-1601

Title:

Unit: Level Of Use: Radiation Protection Standards 112 General Skill Reference Revision: Page Number: ?1 17of36 7.4.1.4.2 Process and engineering controls per NOP-OP-4107. <3.1.15> 7.4.1.4.3 Internal dose monitoring and control per Section 7.4.3 for exposure to airborne activity other than noble gases 7.4.1.5 Protective Actions Protective actions (e.g., stopping work, evacuation, donning respirators) shall be taken in occupied areas in which particulate and/or iodine airborne activity exceeds 1.0 DAC, if internal dose control measures have not already been implemented. 7.4.2 Processing and Engineering Controls 7.4.2.1 7.4.2.2 Process or other engineering controls shall be used to the extent practical to control airborne radioactivity in occupied areas.<3.u) NOP-OP-4107<3.us) provides for use of processing and engineering controls. 7.4.3 Internal Dose Control 7.4.3.1 7.4.3.2 When process or engineering controls are not practical or effective, internal dose controls shall be used as necessary to limit intakes, consistent with maintaining Total Effective Dose Equivalent (TEDE) as low as is reasonably achievable (ALARA). If performing an ALARA evaluation to determine whether or not respirators should be used, safety factors other than radiological factors (e.g., heat stress, impaired vision) may be considered. The impact of respirator use on the worker(s) industrial health and safety should be considered.c3*l.l) NOP-OP-4301 <3.1.20> and NOP-OP-4107<3.1.15> provide for internal dose control. 7.4.4 Determination of External Dose From Airborne Radioactive Material 7.4.4.1 7.4.4.2 When determining worker dose from airborne radioactive material, the contribution to DDE, LDE and SDE from the radioactive cloud shall be included when monitoring for the dose quantity is required.<3.1.1) NOP-OP-4204<3.1.21> provides the methodology and means to determine dose from exposure to Xe-133. This may be applied to other external airborne radionuclide exposures. 7.5 Monitoring and Surveys 7.5.1 External Dose Monitoring 7.5.1.1 Exposures to external sources of radiation shall be monitored to assess occupational doses and to provide information to assist in maintaining doses as low as is reasonably achievable (ALARA). NOP-OP-4201<3.l.II) and NOP-OP-4204<3.1.21> provide for external dose monitoring.}}

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