ML17081A537

1-COLUMBIA-2017-02 Draft Outlines

ML17081A537
Person / Time
Site:	Columbia
Issue date:	03/09/2017
From:	Vincent Gaddy Operations Branch IV
To:	Energy Northwest
References
Download: ML17081A537 (64)

Text

ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 Facility: Columbia Generating Station Date of Exam: 2/27/17 RO K/A Category Points SRO-Only Points Tier Group K K K K K K A A A A G* Total A2 G* Total 1 2 3 4 5 6 1 2 3 4

1. 1 2 3 4 4 3 4 20 Emergency &

2 2 1 1 N/A 1 1 N/A 1 7 Abnormal Plant Evolutions Tier Totals 4 4 5 5 4 5 27 1 2 2 2 2 3 3 2 4 2 2 2 26 2.

Plant 2 1 1 1 2 1 1 1 1 1 1 1 12 Systems Tier Totals 3 3 3 4 4 4 3 5 3 3 3 38 1 2 3 4 1 2 3 4

3. Generic Knowledge and Abilities 10 Categories 3 3 2 2 Note: 1. Ensure that at least two topics from every applicable K/A category are sampled within each tier of the RO and SRO-only outlines (i.e., except for one category in Tier 3 of the SRO-only outline, the Tier Totals in each K/A category shall not be less than two). (One Tier 3 Radiation Control K/A is allowed if the K/A is replaced by a K/A from another Tier 3 Category.)

2. The point total for each group and tier in the proposed outline must match that specified in the table. The final point total for each group and tier may deviate by +/-1 from that specified in the table based on NRC revisions.

The final RO exam must total 75 points and the SRO-only exam must total 25 points.

3. Systems/evolutions within each group are identified on the associated outline; systems or evolutions that do not apply at the facility should be deleted with justification; operationally important, site-specific systems/evolutions that are not included on the outline should be added. Refer to Section D.1.b of ES-401 for guidance regarding the elimination of inappropriate K/A statements.

4. Select topics from as many systems and evolutions as possible; sample every system or evolution in the group before selecting a second topic for any system or evolution.

5. Absent a plant-specific priority, only those K/As having an importance rating (IR) of 2.5 or higher shall be selected. Use the RO and SRO ratings for the RO and SRO-only portions, respectively.

6. Select SRO topics for Tiers 1 and 2 from the shaded systems and K/A categories.

7. The generic (G) K/As in Tiers 1 and 2 shall be selected from Section 2 of the K/A Catalog, but the topics must be relevant to the applicable evolution or system. Refer to Section D.1.b of ES-401 for the applicable K/As.

8. On the following pages, enter the K/A numbers, a brief description of each topic, the topics importance ratings (IRs) for the applicable license level, and the point totals (#) for each system and category. Enter the group and tier totals for each category in the table above; if fuel handling equipment is sampled in a category other than Category A2 or G* on the SRO-only exam, enter it on the left side of Column A2 for Tier 2, Group 2 (Note #1 does not apply). Use duplicate pages for RO and SRO-only exams.

9. For Tier 3, select topics from Section 2 of the K/A catalog, and enter the K/A numbers, descriptions, IRs, and point totals (#) on Form ES-401-3. Limit SRO selections to K/As that are linked to 10 CFR 55.43.

G* Generic K/As Attachment 7 (RO)

Page 1 of 12

ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Emergency and Abnormal Plant Evolutions - Tier 1/Group 1 (RO / SRO)

E/APE # / Name / Safety Function K K K A A G* K/A Topic(s) IR #

1 2 3 1 2 AA1.01 Ability to operate and/or monitor the following as they apply to PARTIAL OR COMPLETE 295001 Partial or Complete Loss of Forced LOSS OF FORCED CORE FLOW CIRCULATION:

X Recirculation system 3.5 1 Core Flow Circulation / 1 & 4 (CFR: 41.7 / 45.6)

AA2.01 Ability to determine and/or interpret the following as they apply to PARTIAL OR COMPLETE LOSS OF A.C. POWER:

295003 Partial or Complete Loss of AC / 6 X Cause of partial or complete loss of A.C. power 3.4 2 (CFR: 41.10 / 43.5 / 45.13) 2.4.46 Ability to verify that the alarms are consistent with the plant conditions.

295004 Partial or Total Loss of DC Pwr / 6 X 4.2 3 (CFR: 41.10 / 43.5 / 45.3 / 45.12)

AK3.02 Knowledge of the reasons for the following responses as they apply to MAIN TURBINE GENERATOR TRIP:

295005 Main Turbine Generator Trip / 3 X Recirculation pump downshift/trip 3.4 4 (CFR: 41.5 / 45.6)

AK2.04 Knowledge of the interrelations between SCRAM and the following:

295006 SCRAM / 1 X Turbine trip logic 3.6 5 (CFR: 41.7 / 45.8)

AA1.06 Ability to operate and/or monitor the following as they apply to CONTROL ROOM ABANDONMENT:

295016 Control Room Abandonment / 7 X Reactor water level 4.0 6 (CFR: 41.7 / 45.6)

AK3.01 Knowledge of the reasons for the following responses as they apply to PARTIAL OR COMPLETE LOSS OF COMPONENT 295018 Partial or Total Loss of CCW / 8 X COOLING WATER : 2.9 7 Isolation of non-essential heat loads (CFR: 41.5 / 45.6)

AA2.01 Ability to determine and/or interpret the following as they apply to PARTIAL OR COMPLETE LOSS OF INSTRUMENT AIR:

295019 Partial or Total Loss of Inst. Air / 8 X Instrument air system pressure 3.5 8 (CFR: 41.10 / 43.5 / 45.13) 2.4.11 Knowledge of abnormal condition procedures: Loss of Shutdown Cooling 295021 Loss of Shutdown Cooling / 4 X 4.0 9 (CFR: 41.10 / 43.5 / 45.13)

AK1.03 Knowledge of the operational implications of the following concepts as they apply to REFUELING ACCIDENTS:

295023 Refueling Acc / 8 X Inadvertent criticality 3.7 10 (CFR: 41.8 to 41.10)

Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 EK2.08 Knowledge of the interrelations between HIGH DRYWELL PRESSURE and the following:

295024 High Drywell Pressure / 5 X ADS 4.0 11 (CFR: 41.7 / 45.8)

EK3.02 Knowledge of the reasons for the following responses as they apply to HIGH REACTOR PRESSURE :

295025 High Reactor Pressure / 3 X Recirculation pump trip 3.9 12 (CFR: 41.5 / 45.6)

EA1.01 Ability to operate and/or monitor the following as they apply to SUPPRESSION POOL HIGH WATER 295026 Suppression Pool High Water Temp. / TEMPERATURE:

X Suppression pool cooling 4.1 13 5

(CFR: 41.7 / 45.6) 295027 High Containment Temperature / 5 2.4.6 Knowledge of EOP mitigation strategies.

295028 High Drywell Temperature / 5 X 3.7 14 (CFR: 41.10 / 43.5 / 45.13)

EK1.01 Knowledge of the operational implications of the following concepts as they apply to LOW SUPPRESSION POOL WATER LEVEL:

295030 Low Suppression Pool Wtr Lvl / 5 X Steam condensation 3.8 15 (CFR: 41.8 to 41.10)

EA1.05 Ability to operate and/or monitor the following as they apply to REACTOR LOW WATER LEVEL:

295031 Reactor Low Water Level / 2 X Reactor core isolation system 4.3 16 (CFR: 41.7 / 45.6)

EK3.05 Knowledge of the reasons for the following responses as they apply to SCRAM CONDITION 295037 SCRAM Condition Present and PRESENT AND REACTOR POWER ABOVE APRM Reactor Power Above APRM Downscale or X DOWNSCALE OR UNKNOWN: 3.2 17 Unknown / 1 Cold shutdown boron weight (CFR: 41.5 / 45.6)

EK2.07 Knowledge of the interrelations between HIGH OFF-SITE RELEASE RATE and the following:

295038 High Off-site Release Rate / 9 X Control room ventilation 3.5 18 (CFR: 41.7 / 45.8)

AA2.14 Ability to determine and interpret the following as they apply to PLANT FIRE ON SITE:

600000 Plant Fire On Site / 8 X Equipment that will be affected by fire suppression 3.0 19 activities in each zone 2.4.4 Ability to recognize abnormal indications for system operating parameters that are entry-level 700000 Generator Voltage and Electric Grid conditions for emergency and abnormal operating X procedures. 4.5 20 Disturbances / 6 (CFR: 41.10 / 43.2 / 45.6)

K/A Category Totals: 2 3 4 4 3 4 Group Point Total: 20 Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Emergency and Abnormal Plant Evolutions - Tier 1/Group 2 (RO / SRO)

K K K A A G* K/A Topic(s) IR #

E/APE # / Name / Safety Function 1 2 3 1 2 AA2.04 Ability to determine and/or interpret the following as they apply to LOSS OF MAIN CONDENSER VACUUM:

295002 Loss of Main Condenser Vac / 3 X Offgas system flow 2.8 21 (CFR: 41.10 / 43.5 / 45.13) 295007 High Reactor Pressure / 3 295008 High Reactor Water Level / 2 AK2.01 Knowledge of the interrelations between LOW REACTOR WATER LEVEL and the following:

295009 Low Reactor Water Level / 2 X Reactor water level indication 3.9 22 (CFR: 41.7 / 45.8) 295010 High Drywell Pressure / 5 295011 High Containment Temp / 5 AK3.01 Knowledge of the reasons for the following responses as they apply to HIGH DRYWELL TEMPERATURE:

295012 High Drywell Temperature / 5 X Increased drywell cooling 3.5 23 (CFR: 41.5 / 45.6) 295013 High Suppression Pool Temp. / 5 295014 Inadvertent Reactivity Addition / 1 AA1.02 Ability to operate and/or monitor the following as they apply to INCOMPLETE SCRAM:

295015 Incomplete SCRAM / 1 X RPS 4.0 24 (CFR: 41.7 / 45.6) 295017 High Off-site Release Rate / 9 295020 Inadvertent Cont. Isolation / 5 & 7 295022 Loss of CRD Pumps / 1 EK1.01 Knowledge of the operational implications of the following concepts as they apply to HIGH SUPPRESSION POOL WATER LEVEL :

295029 High Suppression Pool Wtr Lvl / 5 X Containment integrity 3.4 25 (CFR: 41.8 to 41.10) 295032 High Secondary Containment Area Temperature / 5 295033 High Secondary Containment Area Radiation Levels / 9 2.2.40 Ability to apply Technical Specifications for a 295034 Secondary Containment system.

X 3.4 26 Ventilation High Radiation / 9 (CFR: 41.10 / 43.2 / 43.5 / 45.3) 295035 Secondary Containment High Differential Pressure / 5 Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 EK1.01 Knowledge of the operational implications of the following concepts as they apply to SECONDARY 295036 Secondary Containment High CONTAINMENT HIGH SUMP/AREA WATER LEVEL:

X Radiation releases 2.9 27 Sump/Area Water Level / 5 (CFR: 41.8 to 41.10) 500000 High CTMT Hydrogen Conc. / 5 K/A Category Point Totals: 2 1 1 1 1 1 Group Point Total: 7 Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Plant Systems - Tier 2/Group 1 (RO / SRO)

K K K K K K A A A A G* K/A Topic(s) IR #

System # / Name 1 2 3 4 5 6 1 2 3 4 K5.02 Knowledge of the operational implications of the following concepts as they apply to RHR/LPCI: INJECTION 203000 RHR/LPCI: Injection MODE (PLANT SPECIFIC):

X 3.5 28 Mode Core cooling methods (CFR: 41.5 / 45.3)

A2.14 Ability to (a) predict the impacts of the following on the RHR/LPCI: INJECTION MODE (PLANT SPECIFIC) ; and (b) based on those predictions, use procedures to 203000 RHR/LPCI: Injection correct, control, or mitigate the X 3.8 29 Mode consequences of those abnormal conditions or operations: Initiating logic failure (CFR: 41.5 / 45.6)

K6.01 Knowledge of the effect that a loss or malfunction of the following will have on the SHUTDOWN COOLING SYSTEM (RHR 205000 Shutdown Cooling X SHUTDOWN COOLING MODE): 3.3 30 A.C. electrical power (CFR: 41.7 / 45.7) 206000 HPCI 207000 Isolation (Emergency)

Condenser A1.01 Ability to predict and/or monitor changes in parameters associated with operating the LOW PRESSURE CORE 209001 LPCS X SPRAY SYSTEM controls including: 3.4 31 Core spray flow (CFR: 41.5 / 45.5)

K4.07 Knowledge of HIGH PRESSURE CORE SPRAY SYSTEM (HPCS) design feature(s) and/or interlocks which provide for 209002 HPCS X the following: 3.5 32 Override of reactor water level interlock (CFR: 41.7)

A4.08 Ability to manually operate and/or monitor in the control room:

211000 SLC X System initiation 4.2 33 (CFR: 41.7 / 45.5 to 45.8)

A3.01 Ability to monitor automatic operations of the REACTOR PROTECTION 212000 RPS X SYSTEM including: Reactor power 4.4 34 (CFR: 41.7 / 45.7) 2.1.31 Ability to locate control room switches, controls, and indications, and to determine that they correctly reflect the 215003 IRM X desired plant lineup. 4.6 35 (CFR: 41.10 / 45.12)

Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 A2.06 Ability to (a) predict the impacts of the following on the INTERMEDIATE RANGE MONITOR (IRM) SYSTEM ; and (b) based on those predictions, use procedures to correct, control, or mitigate the 215003 IRM X consequences of those abnormal conditions 3.0 36 or operations:

Faulty range switch (CFR: 41.5 / 45.6)

K1.01 Knowledge of the physical connections and/or cause-effect relationships between SOURCE RANGE MONITOR (SRM) SYSTEM and the 215004 Source Range Monitor X following: 3.6 37 Reactor protection system (CFR: 41.2 to 41.9 / 45.7 to 45.8)

K2.02 Knowledge of electrical power supplies to the following:

215005 APRM / LPRM X APRM channels 2.6 38 (CFR: 41.7)

K3.04 Knowledge of the effect that a loss or malfunction of the REACTOR CORE ISOLATION COOLING SYSTEM (RCIC) will 217000 RCIC X have on following: 3.6 39 Adequate core cooling (CFR: 41.7 / 45.4)

A2.14 Ability to (a) predict the impacts of the following on the REACTOR CORE ISOLATION COOLING SYSTEM (RCIC) ;

and (b) based on those predictions, use procedures to correct, control, or mitigate the 217000 RCIC X consequences of those abnormal conditions 3.3 40 or operations:

Rupture disc failure: Exhaust-Diaphragm (CFR: 41.5 / 45.6)

K4.03 Knowledge of AUTOMATIC DEPRESSURIZATION SYSTEM design feature(s) and/or interlocks which provide for 218000 ADS X the following: 3.8 41 ADS logic control (CFR: 41.7)

K6.04 Knowledge of the effect that a loss or malfunction of the following will have on the PRIMARY CONTAINMENT ISOLATION 223002 PCIS/Nuclear Steam SYSTEM/NUCLEAR STEAM SUPPLY X SHUT-OFF: 3.3 42 Supply Shutoff Nuclear boiler instrumentation (CFR: 41.7 / 45.7)

K5.05 Knowledge of the operational implications of the following concepts as they apply to RELIEF/SAFETY VALVES:

239002 SRVs X Discharge line quencher operation 2.6 43 (CFR: 41.5 / 45.3)

Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 A1.04 Ability to predict and/or monitor changes in parameters associated with operating the REACTOR WATER LEVEL 259002 Reactor Water Level CONTROL SYSTEM controls including:

X Reactor water level control controller 3.6 44 Control indications (CFR: 41.5 / 45.5)

A2.03 Ability to (a) predict the impacts of the following on the STANDBY GAS TREATMENT SYSTEM ; and (b) based on those predictions, use procedures to correct, 261000 SGTS X control, or mitigate the consequences of 2.9 45 those abnormal conditions or operations:

High train temperature (CFR: 41.5 / 45.6)

A3.01 Ability to monitor automatic operations of the A.C. ELECTRICAL 262001 AC Electrical DISTRIBUTION including:

X Breaker tripping 3.1 46 Distribution (CFR: 41.7 / 45.7)

A4.01 Ability to manually operate and/or monitor in the control room:

Transfer from alternative source to preferred 262002 UPS (AC/DC) X source 2.8 47 (CFR: 41.7 / 45.5 to 45.8) 2.2.22 Knowledge of limiting conditions for 263000 DC Electrical operations and safety limits.

X 4.0 48 Distribution (CFR: 41.5 / 43.2 / 45.2)

K5.01 Knowledge of the operational implications of the following concepts as they apply to D.C. ELECTRICAL 263000 DC Electrical DISTRIBUTION:

X 2.6 49 Distribution Hydrogen generation during battery charging (CFR: 41.5 / 45.3)

K1.05 Knowledge of the physical connections and/or cause-effect relationships between EMERGENCY GENERATORS (DIESEL/JET) and the 264000 EDGs X following: 3.2 50 Emergency generator fuel oil supply system (CFR: 41.2 to 41.9 / 45.7 to 45.8)

K2.01 Knowledge of electrical power supplies to the following:

300000 Instrument Air X Instrument air compressor 2.8 51 (CFR: 41.7)

K6.13 Knowledge of the effect that a loss or malfunction of the following will have on the INSTRUMENT AIR SYSTEM:

300000 Instrument Air X Filters 2.8 52 (CFR: 41.7 / 45.7)

Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 K3.01 Knowledge of the effect that a loss or malfunction of the CCWS will have on the 400000 Component Cooling following:

X Loads cooled by CCWS 2.9 53 Water (CFR: 41.7 / 45.6)

K/A Category Point Totals: 2 2 2 2 3 3 2 4 2 2 2 Group Point Total: 26 Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Plant Systems - Tier 2/Group 2 (RO / SRO)

System # / Name K K K K K K A A A A G* K/A Topic(s) IR #

1 2 3 4 5 6 1 2 3 4 201001 CRD Hydraulic A1.03 Ability to predict and/or monitor changes in parameters associated with operating the REACTOR MANUAL 201002 RMCS X CONTROL SYSTEM controls including: 3.0 54 Rod movement sequence lights (CFR: 41.5 / 45.5)

K5.08 Knowledge of the operational implications of the following concepts as they apply to CONTROL ROD AND 201003 Control Rod and Drive DRIVE MECHANISM:

X How control rods affect shutdown 3.1 55 Mechanism margin (CFR: 41.5 / 45.3) 201004 RSCS 201005 RCIS 201006 RWM 202001 Recirculation K6.05 Knowledge of the effect that a loss or malfunction of the following will have on the RECIRCULATION FLOW 202002 Recirculation Flow Control X CONTROL SYSTEM: 3.1 56 Reactor water level (CFR: 41.7 / 45.7)

K4.02 Knowledge of REACTOR WATER CLEANUP SYSTEM design feature(s) and/or interlocks which 204000 RWCU X provide for the following: 2.7 57 Piping over-pressurization protection (CFR: 41.7) 214000 RPIS A2.01 Ability to (a) predict the impacts of the following on the TRAVERSING IN-CORE PROBE ; and (b) based on those predictions, use procedures to correct, control, or mitigate the 215001 Traversing In-Core Probe X consequences of those abnormal 2.7 58 conditions or operations:

Low reactor water level: Mark-I&II(Not-BWR1)

(CFR: 41.5 / 45.6)

A3.04 Ability to monitor automatic operations of the ROD BLOCK MONITOR SYSTEM including:

215002 RBM X Verification or proper functioning/ 3.6 59 operability: BWR-3,4,5 (CFR: 41.7 / 45.7) 216000 Nuclear Boiler Inst.

Attachment 7 (RO)

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ES-401 BWR Examination Outline - RO (Rev 2 - 10/24/16) Form ES-401-1 219000 RHR/LPCI: Torus/Pool Cooling Mode 223001 Primary CTMT and Aux.

A4.19 Ability to manually operate and/or monitor in the control room:

226001 RHR/LPCI: CTMT Spray Drywell temperature X 3.4 60 Mode (CFR: 41.7 / 45.5 to 45.8) 230000 RHR/LPCI: Torus/Pool Spray Mode 233000 Fuel Pool Cooling/Cleanup 234000 Fuel Handling Equipment 2.2.42 Ability to recognize system parameters that are entry-level 239001 Main and Reheat Steam X conditions for Technical Specifications. 3.9 61 (CFR: 41.7 / 41.10 / 43.2 / 43.3 / 45.3) 239003 MSIV Leakage Control 241000 Reactor/Turbine Pressure Regulator 245000 Main Turbine Gen. / Aux.

256000 Reactor Condensate K1.11 Knowledge of the physical connections and/or cause-effect relationships between REACTOR 259001 Reactor Feedwater X FEEDWATER SYSTEM and the 2.7 62 following: RFP lube oil system (CFR: 41.2 to 41.9 / 45.7 to 45.8)

K3.04 Knowledge of the effect that a loss or malfunction of the RADWASTE will have on following:

268000 Radwaste X Drain sumps 2.7 63 (CFR: 41.5 / 45.3) 271000 Offgas K4.02 Knowledge of RADIATION MONITORING System design feature(s) and/or interlocks which provide for the following:

Automatic actions to contain the 272000 Radiation Monitoring X radioactive release in the event that the 3.7 64 predetermined release rates are exceeded (CFR: 41.7)

K2.02 Knowledge of electrical power supplies to the following: Pumps 286000 Fire Protection X 2.9 65 (CFR: 41.7) 288000 Plant Ventilation 290001 Secondary CTMT 290003 Control Room HVAC 290002 Reactor Vessel Internals K/A Category Point Totals: 1 1 1 2 1 1 1 1 1 1 1 Group Point Total: 12 Attachment 7 (RO)

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ES-401 Generic Knowledge and Abilities Outline (Tier 3) (Rev 2 - 10/24/16) Form ES-401-3 Facility: Columbia Generating Station Date of Exam: 2/27/17 Category K/A # Topic RO SRO-Only IR # IR #

Knowledge of operator responsibilities during all modes of plant operation.

2.1.2 4.1 66 (CFR: 41.10 / 45.13)

Ability to interpret and execute procedure steps.

1.

2.1.20 4.6 67 Conduct of (CFR: 41.10 / 43.5 / 45.12)

Operations Ability to perform specific system and integrated plant procedures during all modes of plant operation.

2.1.23 4.3 68 (CFR: 41.10 / 43.5 / 45.2 / 45.6)

Subtotal 3 Knowledge of the process for making changes to procedures.

2.2.6 3.0 69 (CFR: 41.10 / 43.3 / 45.13)

Ability to determine Technical Specification Mode of 2.

Operation.

Equipment 2.2.35 3.6 70 Control (CFR: 41.7 / 41.10 / 43.2 / 45.13)

Knowledge of surveillance procedures.

2.2.12 3.7 71 (CFR: 41.10 / 45.13)

Subtotal 3 Knowledge of radiological safety principles pertaining to licensed operator duties, such as containment entry requirements, fuel handling responsibilities, access to 2.3.12 3.2 72 locked high-radiation areas, aligning filters, etc.

3. (CFR: 41.12 / 45.9 / 45.10)

Radiation Knowledge of radiation or contamination hazards that Control may arise during normal, abnormal, or emergency 2.3.14 conditions or activities. 3.4 73 (CFR: 41.12 / 43.4 / 45.10)

Subtotal 2 Ability to recognize abnormal indications for system operating parameters that are entry-level conditions for 2.4.4 emergency and abnormal operating procedures. 4.5 74

4. (CFR: 41.10 / 43.2 / 45.6)

Emergency Knowledge of the organization of the operating Procedures /

procedures network for normal, abnormal, and Plan 2.4.5 emergency evolutions. 3.7 75 (CFR: 41.10 / 43.5 / 45.13)

Subtotal 2 Tier 3 Point Total 10 Attachment 7 (RO)

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ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 Facility: Columbia Generating Station Date of Exam: 2/27/17 RO K/A Category Points SRO-Only Points Tier Group K K K K K K A A A A G* Total A2 G* Total 1 2 3 4 5 6 1 2 3 4

1. 1 4 3 7 Emergency & 2 1 2 3 N/A N/A Abnormal Plant Evolutions Tier Totals 5 5 10

2. 1 3 2 5 Plant 2 1 1 1 3 Systems Tier Totals 5 3 8 1 2 3 4 1 2 3 4

3. Generic Knowledge and Abilities 7

Categories 2 2 1 2 Note: 1. Ensure that at least two topics from every applicable K/A category are sampled within each tier of the RO and SRO-only outlines (i.e., except for one category in Tier 3 of the SRO-only outline, the Tier Totals in each K/A category shall not be less than two). (One Tier 3 Radiation Control K/A is allowed if the K/A is replaced by a K/A from another Tier 3 Category.)

2. The point total for each group and tier in the proposed outline must match that specified in the table. The final point total for each group and tier may deviate by +/-1 from that specified in the table based on NRC revisions.

The final RO exam must total 75 points and the SRO-only exam must total 25 points.

3. Systems/evolutions within each group are identified on the associated outline; systems or evolutions that do not apply at the facility should be deleted with justification; operationally important, site-specific systems/evolutions that are not included on the outline should be added. Refer to Secti on D.1.b of ES-401 for guidance regarding the elimination of inappropriate K/A statements.

4. Select topics from as many systems and evolutions as possible; sample every system or evolution in the group before selecting a second topic for any system or evolution.

5. Absent a plant-specific priority, only those K/As having an importance rating (IR) of 2.5 or higher shall be selected. Use the RO and SRO ratings for the RO and SRO-only portions, respectively.

6. Select SRO topics for Tiers 1 and 2 from the shaded systems and K/A categories.

7. The generic (G) K/As in Tiers 1 and 2 shall be selected from Section 2 of the K/A Catalog, but the topics must be relevant to the applicable evolution or system. Refer to Section D.1.b of ES-401 for the applicable K/As.

8. On the following pages, enter the K/A numbers, a brief description of each topic, the topics importance ratings (IRs) for the applicable license level, and the point totals (#) for each system and category. Enter the group and tier totals for each category in the table above; if fuel handling equipment is sampled in a category other than Category A2 or G* on the SRO-only exam, enter it on the left side of Column A2 for Tier 2, Group 2 (Note #1 does not apply). Use duplicate pages for RO and SRO-only exams.

9. For Tier 3, select topics from Section 2 of the K/A catalog, and enter the K/A numbers, descriptions, IRs, and point totals (#) on Form ES-401-3. Limit SRO selections to K/As that are linked to 10 CFR 55.43.

G* Generic K/As Attachment 7 (SRO)

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ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Emergency and Abnormal Plant Evolutions - Tier 1/Group 1 (RO / SRO)

E/APE # / Name / Safety Function K1 K2 K3 A1 A2 G* K/A Topic(s) IR #

AA2.03 Ability to determine and/or interpret the following as they apply to PARTIAL OR COMPLETE 295001 Partial or Complete Loss of Forced LOSS OF FORCED CORE FLOW CIRCULATION:

X Actual core flow 3.3 76 Core Flow Circulation / 1 & 4 (CFR: 41.10/43.5/45.13) 2.2.36 Ability to analyze the effect of maintenance activities, such as degraded power sources, on the 295003 Partial or Complete Loss of AC / 6 X status of limiting conditions for operations. 4.2 77 (CFR: 41.10 / 43.2 / 45.13)

AA2.01 Ability to determine and/or interpret the following as they apply to PARTIAL OR COMPLETE LOSS OF D.C. POWER:

295004 Partial or Total Loss of DC Pwr / 6 X 3.6 78 Cause of partial or complete loss of D.C. power (CFR: 41.10 / 43.5 / 45.13) 295005 Main Turbine Generator Trip / 3 295006 SCRAM / 1 2.4.50 Ability to verify system alarm setpoints and operate controls identified in the alarm response 295016 Control Room Abandonment / 7 X manual. 4.0 79 (CFR: 41.10 / 43.5 / 45.3) 295018 Partial or Total Loss of CCW / 8 AA2.02 Ability to determine and/or interpret the following as they apply to PARTIAL OR COMPLETE LOSS OF INSTRUMENT AIR :

295019 Partial or Total Loss of Inst. Air / 8 X 3.7 80 Status of safety-related instrument air system loads (CFR: 41.10 / 43.5 / 45.13) 2.1.19 Ability to use plant computers to evaluate system or component status.

295021 Loss of Shutdown Cooling / 4 X 3.8 81 (CFR: 41.10 / 45.12) 295023 Refueling Acc / 8 295024 High Drywell Pressure / 5 295025 High Reactor Pressure / 3 295026 Suppression Pool High Water Temp. / 5 295027 High Containment Temperature / 5 295028 High Drywell Temperature / 5 295030 Low Suppression Pool Wtr Lvl / 5 295031 Reactor Low Water Level / 2 295037 SCRAM Condition Present and Reactor Power Above APRM Downscale or Unknown / 1 295038 High Off-site Release Rate / 9 600000 Plant Fire On Site / 8 Attachment 7 (SRO)

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ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 AA2.08 Ability to determine and/or interpret the following as they apply to GENERATOR VOLTAGE 700000 Generator Voltage and Electric Grid AND ELECTRIC GRID DISTURBANCES:

X 4.4 82 Disturbances / 6 Criteria to trip the turbine or reactor (CFR: 41.5 and 43.5 / 45.5, 45.7, and 45.8)

K/A Category Totals: 4 3 Group Point Total: 7 Attachment 7 (SRO)

Page 3 of 9

ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Emergency and Abnormal Plant Evolutions - Tier 1/Group 2 (RO / SRO)

E/APE # / Name / Safety Function K K K A A G* K/A Topic(s) IR #

1 2 3 1 2 295002 Loss of Main Condenser Vac / 3 2.4.21 Knowledge of the parameters and logic used to assess the status of safety functions, such as reactivity control, core cooling and heat removal, 295007 High Reactor Pressure / 3 X reactor coolant system integrity, containment 4.6 83 conditions, radioactivity release control, etc.

(CFR: 41.7 / 43.5 / 45.12) 295008 High Reactor Water Level / 2 295009 Low Reactor Water Level / 2 AA2.03 Ability to determine and/or interpret the following as they apply to HIGH DRYWELL PRESSURE:

295010 High Drywell Pressure / 5 X 3.6 84 Drywell radiation levels (CFR: 41.10 / 43.5 / 45.13) 295011 High Containment Temp / 5 295012 High Drywell Temperature / 5 295013 High Suppression Pool Temp. / 5 295014 Inadvertent Reactivity Addition / 1 295015 Incomplete SCRAM / 1 295017 High Off-site Release Rate / 9 295020 Inadvertent Cont. Isolation / 5 & 7 295022 Loss of CRD Pumps / 1 295029 High Suppression Pool Wtr Lvl / 5 295032 High Secondary Containment Area Temperature / 5 2.2.37 Ability to determine operability and/or 295033 High Secondary Containment Area availability of safety related equipment.

X 4.6 85 Radiation Levels / 9 (CFR: 41.7 / 43.5 / 45.12) 295034 Secondary Containment Ventilation High Radiation / 9 295035 Secondary Containment High Differential Pressure / 5 295036 Secondary Containment High Sump/Area Water Level / 5 500000 High CTMT Hydrogen Conc. / 5 K/A Category Point Totals: 1 2 Group Point Total: 3 Attachment 7 (SRO)

Page 4 of 9

ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Plant Systems - Tier 2/Group 1 (RO / SRO)

System # / Name K K K K K K A A A A G* K/A Topic(s) IR #

1 2 3 4 5 6 1 2 3 4 203000 RHR/LPCI: Injection Mode A2.10 Ability to (a) predict the impacts of the following on the SHUTDOWN COOLING SYSTEM (RHR SHUTDOWN COOLING MODE) ; and (b) based on those predictions, use procedures to correct, control, or 205000 Shutdown Cooling X 2.9 86 mitigate the consequences of those abnormal conditions or operations:

Valve operation (CFR: 41.5 / 45.6) 206000 HPCI 207000 Isolation (Emergency)

Condenser 2.4.9 Knowledge of low power/shutdown implications in accident (e.g., loss of coolant accident or loss of residual heat removal) 209001 LPCS X 4.2 87 mitigation strategies.

(CFR: 41.10 / 43.5 / 45.13) 209002 HPCS 211000 SLC 212000 RPS A2.03 Ability to (a) predict the impacts of the following on the INTERMEDIATE RANGE MONITOR (IRM) SYSTEM ; and (b) based on those predictions, use procedures 215003 IRM X to correct, control, or mitigate the 3.1 88 consequences of those abnormal conditions or operations: Stuck detector (CFR: 41.5 / 45.6) 215004 Source Range Monitor 215005 APRM / LPRM 217000 RCIC 2.4.6 Knowledge of EOP mitigation strategies.

218000 ADS X 4.7 89 (CFR: 41.10 / 43.5 / 45.13) 223002 PCIS/Nuclear Steam Supply Shutoff 239002 SRVs 259002 Reactor Water Level Control 261000 SGTS 262001 AC Electrical Distribution 262002 UPS (AC/DC)

Attachment 7 (SRO)

Page 5 of 9

ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 263000 DC Electrical Distribution 264000 EDGs 300000 Instrument Air A2.01 Ability to (a) predict the impacts of the following on the CCWS and (b) based on those predictions, use procedures to correct, 400000 Component Cooling control, or mitigate the consequences of X 3.4 90 Water those abnormal operation:

Loss of CCW pump (CFR: 41.5 / 45.6)

Group Point Total:

K/A Category Point Totals: 3 2 5 Attachment 7 (SRO)

Page 6 of 9

ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 ES-401 BWR Examination Outline Form ES-401-1 Plant Systems - Tier 2/Group 2 (RO / SRO)

System # / Name K K K K K K A A A A G* K/A Topic(s) IR #

1 2 3 4 5 6 1 2 3 4 201001 CRD Hydraulic 201002 RMCS 201003 Control Rod and Drive Mechanism 201004 RSCS 201005 RCIS 201006 RWM 202001 Recirculation 202002 Recirculation Flow Control 204000 RWCU 214000 RPIS 215001 Traversing In-Core Probe 215002 RBM 216000 Nuclear Boiler Inst.

A2.10 Ability to (a) predict the impacts of the following on the RHR/LPCI:

TORUS/SUPPRESSION POOL COOLING MODE; and (b) based on those predictions, use procedures to 219000 RHR/LPCI: Torus/Pool X correct, control, or mitigate the 3.2 91 Cooling Mode consequences of those abnormal conditions or operations:

Nuclear boiler instrument failures (CFR: 41.5 / 45.6) 223001 Primary CTMT and Aux.

226001 RHR/LPCI: CTMT Spray Mode 230000 RHR/LPCI: Torus/Pool Spray Mode 233000 Fuel Pool Cooling/Cleanup A3.02 Ability to monitor automatic operations of the FUEL HANDLING EQUIPMENT including:

234000 Fuel Handling Equipment X 3.7 92 Interlock operation (CFR: 41.7 / 45.7) 239001 Main and Reheat Steam 239003 MSIV Leakage Control 241000 Reactor/Turbine Pressure Regulator 245000 Main Turbine Gen. / Aux.

Attachment 7 (SRO)

Page 7 of 9

ES-401 BWR Examination Outline - SRO (Rev 2 - 10/24/16) Form ES-401-1 2.4.47 Ability to diagnose and recognize trends in an accurate and timely manner utilizing the appropriate 256000 Reactor Condensate X 4.2 93 control room reference material.

(CFR: 41.10 / 43.5 / 45.12) 259001 Reactor Feedwater 268000 Radwaste 271000 Offgas 272000 Radiation Monitoring 286000 Fire Protection 288000 Plant Ventilation 290001 Secondary CTMT 290003 Control Room HVAC 290002 Reactor Vessel Internals K/A Category Point Totals: 1 1 1 Group Point Total: 3 Attachment 7 (SRO)

Page 8 of 9

ES-401 Generic Knowledge and Abilities Outline (Tier 3) (Rev 2 - 10/24/16) Form ES-401-3 Facility: Columbia Generating Station Date of Exam: 2/27/17 RO SRO-Only Category K/A # Topic IR # IR #

Knowledge of individual licensed operator responsibilities related to shift staffing, such as medical requirements, no-solo operation, maintenance of active license status, 2.1.4 3.8 94 10CFR55, etc.

1.

Conduct of (CFR: 41.10 / 43.2)

Operations Ability to perform specific system and integrated plant procedures during all modes of plant operation.

2.1.23 4.4 95 (CFR: 41.10 / 43.5 / 45.2 / 45.6)

Subtotal 2 Knowledge of the process for controlling temporary design changes.

2.2.11 3.3 96

2. (CFR: 41.10 / 43.3 / 45.13)

Equipment Knowledge of the process for managing troubleshooting Control activities.

2.2.20 3.8 97 (CFR: 41.10 / 43.5 / 45.13)

Subtotal 2 Ability to control radiation releases.

3.

2.3.11 4.3 98 Radiation (CFR: 41.11 / 43.4 / 45.10)

Control Subtotal 1 2.4.29 Knowledge of the emergency plan.

2.4.29 4.4 99

4. (CFR: 41.10 / 43.5 / 45.11)

Emergency Knowledge of the operational implications of EOP Procedures / warnings, cautions, and notes.

2.4.20 4.3 100 Plan (CFR: 41.10 / 43.5 / 45.13)

Subtotal 2 Tier 3 Point Total 7 Attachment 7 (SRO)

Page 9 of 9

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Knowledge of the operational implications of the following concepts as they apply to MAIN TURBINE GENERATOR TRIP: Pressure effects on reactor level. (RO-3.5)

Reason for rejection: System does not operate like the K/A statement implies. From COLUMBIA GENERATING STATION SYSTEM DESCRIPTION, Volume 4, Chapter 2, NUCLEAR BOILER INSTRUMENTATION (NBI): Changes in reactor pressure influence the reference line and variable line hydrostatic pressures in the same direction and magnitude; this effectively eliminates 295005.AK1.03 changes in level indication due to changes in reactor pressure 1/1 (Question 4 on RO outline)

Suggested K/A: 295005.AK3.02 - Knowledge of the reasons for the following responses as they apply to MAIN TURBINE GENERATOR TRIP: Recirculation pump downshift/trip (CFR: 41.5 /

45.6) Importance: RO - 3.4 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Knowledge of RO responsibilities in emergency plan implementation: Loss of Shutdown Cooling. (RO-3.9).

Reason for rejection: Supports testing at the SRO-only level, but NOT the RO level due to CGS RO job responsibilities. There are no ERO responsibilities assigned to RO personnel.

295021.2.4.39 Suggested K/A: 295021.2.4.11 - Knowledge of abnormal condition 1/1 (Question 9 on RO procedures: Loss of Shutdown Cooling (CFR: 41.10 / 43.5 / 45.13) outline)

Importance RO-4.0.

K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 1 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Ability to prioritize and interpret the significance of each annunciator or alarm. (RO-4.1)

Reason for rejection: Unable to write a suitable RO level question with three plausible distractors.

295028 2.4.45 Suggested K/A: 295028 2.4.6 - Knowledge of EOP mitigation 1/1 (Question 14 in RO strategies. (CFR: 41.10 / 43.5 / 45.13) outline) Importance: RO-3.7 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Generator Voltage and Electric Grid Disturbances: Knowledge of the specific bases for EOPs (RO: 3.3)

Reason for rejection: Unable to write a suitable question. There are no EOP bases concerning generator voltage and electric grid disturbances.

700000 2.4.18 Suggested K/A: 700000 2.4.4 - Generator Voltage and Electric Grid 1/1 (Question 20 on RO Disturbances: Ability to recognize abnormal indications for system outline) operating parameters that are entry-level conditions for emergency and abnormal operating procedures. (CFR: 41.10 / 43.2 / 45.6)

Importance: RO-4.5 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 2 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Ability to predict and/or monitor changes in parameters associated with operating the RHR/LPCI: INJECTION MODE (PLANT SPECIFIC) controls including: Suppression pool level (RO-3.8)

Reason for rejection: Unable to develop a question with three plausible distractors.

Suggested K/A: 203000.A2.14 - Ability to (a) predict the impacts of 203000.A1.05 the following on the RHR/LPCI: INJECTION MODE (PLANT 2/1 (Question 29 on RO SPECIFIC) ; and (b) based on those predictions, use procedures to outline) correct, control, or mitigate the consequences of those abnormal conditions or operations: Initiating logic failure (CFR: 41.5 / 45.6)

Importance: RO- 3.8 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Ability to predict and/or monitor changes in parameters associated with operating the LOW PRESSURE CORE SPRAY SYSTEM controls including: Torus/suppression pool water level (RO-3.5)

Reason for rejection: Unable develop a question with three plausible distractors.

209001.A1.05 Suggested K/A: 209001.A1.01 - Ability to predict and/or monitor 2/1 (Question 31 on RO changes in parameters associated with operating the LOW outline) PRESSURE CORE SPRAY SYSTEM controls including: Core spray flow (CFR: 41.5 / 45.5) Importance: RO- 3.4 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 3 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Ability to manually operate and/or monitor in the control room: Flow indication (RO-4.1)

Reason for rejection: Overlap with Operating Test dynamic scenario event in which a degraded SLC flow condition exists. Simulator dynamic event better suited to evaluate K/A.

211000.A4.05 Suggested K/A: 211000.A4.08 - Ability to manually operate and/or 2/1 (Question 33 on RO monitor in the control room: System initiation (CFR: 41.7 / 45.5 to outline) 45.8) Importance: RO- 4.2 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Ability to monitor automatic operations of the REACTOR PROTECTION SYSTEM including: SCRAM air header pressure (RO-3.6)

Reason for rejection: Overlap with Operating Test dynamic scenario event involving hydraulic ATWS where RPS trip signals have to be bypassed to reset the scram for a re-scram attempt. Simulator dynamic event better suited to evaluate K/A.

212000.A3.07 2/1 (Question 34 on RO Suggested K/A: 212000.A3.01 - Ability to monitor automatic outline) operations of the REACTOR PROTECTION SYSTEM including:

Reactor power (CFR: 41.7 / 45.7) Importance: RO- 4.4 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 4 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A 2.2.44 Ability to interpret control room indications to verify the status and operation of a system, and understand how operator actions and directives affect plant and system conditions. (RO-4.2)

Reason for rejection: Limited indications in the control room for DC distribution (annunciators and voltages only) make writing a question different from a previous question in the outline (RO Question #3 - K/A 295004 2.4.46) not possible.

263000 2.2.44 2/1 (Question 48 in RO Suggested K/A: 263000 2.2.22 - DC Electrical Distribution:

outline) Knowledge of limiting conditions for operations and safety limits.

(CFR: 41.5 / 43.2 / 45.2)

Importance: RO 4.0 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Ability to manually operate and/or monitor in the control room: Containment spray system flow (RO-3.2)

Reason for rejection: Overlap with Operating Test dynamic scenario event involving placing containment sprays in service and monitoring effectiveness. Simulator dynamic event better suited to evaluate K/A.

226001.A4.08 2/2 (Question 60 on RO Suggested K/A: 226001.A4.19 - Ability to manually operate and/or outline) monitor in the control room: Drywell temperature (CFR: 41.7 / 45.5 to 45.8) Importance: RO- 3.4 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 5 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Knowledge of the process for managing troubleshooting activities.

(RO-2.6)

Reason for rejection: Overlap with NRC exam item SRO-97. This K/A has a SRO importance factor of 3.8 vice 2.6 for RO and therefore supports questioning at the SRO level.

2.2.20 Suggested K/A: 2.2.35 - Ability to determine Technical Specification 3/2 (Question 70 on RO Mode of Operation. (CFR: 41.7 / 41.10 / 43.2 / 45.13) outline)

Importance: RO-3.6 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Knowledge of pre- and post-maintenance operability requirements.

(RO-2.9)

Reason for rejection: Unable to write RO level question that can evaluate BOTH pre and post maintenance operability. Also, operability determination is generally SRO function.

2.2.21 3/2 (Question 71 on RO Suggested K/A 2.2.12 - Knowledge of surveillance procedures outline) (CFR 41.10 / 45.13). Importance: RO - 3.7 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

RO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 6 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Ability to (a) predict the impacts of the following on the INTERMEDIATE RANGE MONITOR (IRM) SYSTEM ; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those abnormal conditions or operations: (SRO-3.8)

Reason for rejection: Overlap with Operating Test dynamic scenario event in which an IRM fails upscale during startup. Simulator dynamic event better suited to evaluate K/A.

215003.A2.04 Suggested K/A: 215003.A2.03 - Ability to (a) predict the impacts of 2/1 (Question 88 on the following on the INTERMEDIATE RANGE MONITOR (IRM)

SRO outline)

SYSTEM ; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those abnormal conditions or operations: Stuck detector (CFR: 41.5 / 45.6)

Importance: SRO- 3.1 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

SRO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Tier / Randomly Reason for Rejection Group Selected K/A Ability to direct personnel activities inside the control room. (SRO-4.5)

Reason for rejection: K/A is not linked to 10CFR 55.43 topics as required by NUREG 1021, ES-401, section D.1.c.

Suggested K/A: 2.1.4 - Knowledge of individual licensed operator 2.1.9 responsibilities related to shift staffing, such as medical 3/1 (Question 94 in SRO requirements, no-solo operation, maintenance of active license outline) status, 10CFR55, etc. (CFR: 41.10 / 43.2)

Importance: SRO-3.8 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

SRO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 7 of 8

ES-401 Record of Rejected K/As (Rev 0 - 10/24/16) Form ES-401-4 Tier / Randomly Reason for Rejection Group Selected K/A Knowledge of annunciator alarms indications, or response procedures. (SRO-4.1)

Reason for rejection: K/A is not linked to 10CFR 55.43 topics as required by NUREG 1021, ES-401, section D.1.c.

2.4.31 Suggested K/A: 2.4.20 - Knowledge of the operational implications 3/4 (Question 100 in of EOP warnings, cautions, and notes. (CFR: 41.10 / 43.5 / 45.13)

SRO outline) Importance: SRO-4.3 K/A was randomly selected using methodology contained in ES-401, Attachment 1.

SRO outline meets requirements of NUREG 1021 (Rev 10) with this change.

Attachment 8 Page 8 of 8

ES-301 Administrative Topics Outline (Rev 0 - 10/24/16) Form ES-301-1 Facility: Columbia Generating Station Date of Examination: 2/27/17 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic (see Note) Type Describe activity to be performed Code*

DETERMINE ACTIONS FOR CRITICALITY OUTSIDE OF ECP (EARLY)

A-1 Conduct of Operations

Description:

Determine that criticality has been (D)(R) achieved prior to reaching the minimum K/A: 2.1.37 (4.3 / 4.6) Estimated Critical Position (ECP) and correctly identify the next action to be taken due to being critical outside the ECP.

MAIN TURBINE (MT) LOAD RATE CHANGE A-2 DETERMINATION Conduct of Operations (D)(P)(R)

Description:

Determine the Main Turbine Load K/A: 2.1.25 (3.9 / 4.2) Change Recommendation when raising Main Turbine load from 5% to 90%.

A-3 VALIDATE FUSE INSTALLATION PER PPM 1.3.47 (FUSE REPLACEMENT CONTROL)

Equipment Control (N)(R)

K/A: 2.2.41 (3.5 / 3.9)

Description:

For the RO Candidate, given circumstance requiring fuse replacement and OPEX AR 00314141 an electrical print, determine correct replacement fuse and provide justification.

DETERMINE IF TAGOUT CAN BE HUNG A-4 Radiation Control (D)(R)

Description:

Determination will have to be K/A: 2.3.7 (3.5 / 3.6) made (with justification) whether or not a tag can be hung based on provided Clearance Order, RWP and Survey Map.

NOTE: All items (five total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items).

• Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes)

(N)ew or (M)odified from bank ( 1)

(P)revious 2 exams ( 1; randomly selected)

Attachment 3 Page 1 of 3

ES-301 Administrative Topics Outline (Rev 0 - 10/24/16) Form ES-301-1 Facility: Columbia Generating Station Date of Examination: 2/27/17 Examination Level: RO SRO Operating Test Number: 1 Administrative Topic (see Note) Type Describe activity to be performed Code*

DETERMINE ACTION BASED ON PLANT CONDITIONS AND PROCEDURAL A-1 GUIDANCE Conduct of Operations (D)(R)

Description:

Given equipment status and an K/A: 2.1.7 (4.4 / 4.7) electrical bus lockout, determine required operator action based on existing plant conditions.

DETERMINE THE OPERABILITY OF THE SLC SYSTEM A-2 Conduct of Operations (D)(R)

Description:

Given the SLC portion of OSP-INST-H101 (Shift and Daily Instrument Checks K/A: 2.1.25 (3.9 / 4.2) for Modes 1, 2 & 3), determine the operability status of the Standby Liquid Control (SLC)

System.

A-3 VALIDATE FUSE INSTALLATION PER PPM 1.3.47 (FUSE REPLACEMENT CONTROL)

Equipment Control (N)(R)

Description:

For the SRO Candidate, given K/A: 2.2.41 (3.5 / 3.9) circumstance requiring fuse replacement and an electrical print, either authorize or do not OPEX AR 00314141 authorize fuse replacement with proposed fuse type. Provide justification.

ESTIMATE MAIN CONDENSER AIR EJECTOR GROSS GAMMA ACTIVITY RATE A-4 AND DETERMINE ACTIONS Radiation Control (D)(P)(R)

Description:

Estimate Main Condenser air ejector Gross gamma activity rate and K/A: 2.3.11 (3.8 / 4.3) determine that a reactor power reduction is required to maintain Main Condenser Gross activity LT the LCO 3.7.5 limit.

A-5 COMPLETE CLASSIFICATION NOTIFICATION FORM (CNF) FOR SAE Emergency Plan (D)(R)

Description:

Given a dose projection printout, K/A: 2.4.41 (2.9 / 4.6) classify the event and complete Classification Notification Form. (Time Critical)

Attachment 3 Page 2 of 3

ES-301 Administrative Topics Outline (Rev 0 - 10/24/16) Form ES-301-1 NOTE: All items (five total) are required for SROs. RO applicants require only four items unless they are retaking only the administrative topics (which would require all five items).

• Type Codes & Criteria: (C)ontrol room, (S)imulator, or Class(R)oom (D)irect from bank ( 3 for ROs; 4 for SROs & RO retakes)

(N)ew or (M)odified from bank ( 1)

(P)revious 2 exams ( 1; randomly selected)

Attachment 3 Page 3 of 3

ES-301 Control Room/In-Plant Systems Outline (Rev 0 - 10/24/16) Form ES-301-2 Facility: Columbia Generating Station Date of Examination: 2/27/17 Exam Level: RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems:* 8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Code* Safety Function S-1: (RRC) RRC-P-1A START IN MODE 1

Description:

Start Reactor Recirculation Pump 1A at power (pump fails to (A)(D)(S) 1 come up to speed on start and must be manually secured).

K/A: 202001.A4.01 (3.7/3.7)

S-2: (RHR) RESPOND TO LOSS OF SHUTDOWN COOLING

Description:

Restore Residual Heat Removal (RHR) Loop B shutdown cooling per SOP-RHR-SDC (RHR Loop B Shutdown Cooling Quick Restart). (A)(L)(N)(S) 4 Following pump start, insufficient pump head (and consequently flow) will necessitate securing pump per CAUTION in procedure.

K/A: 205000.A2.06 (3.4/3.5)

S-3: (HPCS) HPCS SYSTEM INITIATION (D)(EN)

Description:

Initiate High Pressure Core Spray (HPCS) system per SOP- 2 HPCS-INJECTION and restore RPV level back to directed band. (L)(S)

K/A: 209002.A4.08 (3.6/3.7)

S-4: (CR HVAC) INITIATE CR HVAC MANUAL PRESSURIZATION MODE

Description:

Place both trains of Control Room Ventilation in the Manual Pressurization Mode of operation per SOP-HVAC/CR-OPS (inlet damper for (A)(D)(EN) 9 one of the Control Room Emergency Filter Units fail to auto open and must be (S) opened manually).

K/A: 290003.A4.01 (3.2/3.2)

S-5: (RB HVAC) RE-ESTABLISH SECONDARY CONTAINMENT/START RB HVAC

Description:

Restart Reactor Building (RB) HVAC using RB Outside Air Fan (D)(P)(S) 5 1A and RB Exhaust Air Fan 1A per SOP-HVAC RB-RESTART-QC to re-establish Secondary Containment integrity.

K/A: 290001.A4.01 (3.3/3.4)

S-6: (DEH) LOWER RPV PRESSURE USING DEH

Description:

Recognize that auto control of bypass valves to lower RPV pressure to a target of 550 psig does not work and that the manual lowering of (A)(D)(L)(P) 3 RPV pressure at a rate LE 50 psig per minute through manual control of (S)

Bypass Valves would be required.

K/A: 241000.A4.02 (4.1/4.1)

S-7: (RPS) RESTORE RPS A FROM ALTERNATE POWER SOURCE

Description:

Transfer RPS A to its Alternate power supply by performing (D)(P)(S) 7 subsequent steps in ABN-RPS.

K/A: 212000.A2.01 (3.7/3.9)

Attachment 4 Page 1 of 6

ES-301 Control Room/In-Plant Systems Outline (Rev 0 - 10/24/16) Form ES-301-2 S-8: (Fire Protection) ABN-FIRE Immediate Actions

Description:

Given the report of heavy smoke in the field and the observance (N)(S) 8 of several fire alarms, perform the Immediate Actions of ABN-FIRE.

K/A: 286000.A4.01 (3.3/3.2)

In-Plant Systems* (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P-1: (DG) PARALLEL DG1 LOCALLY - VARS DOWNSCALE

Description:

With DG-1 already (simulated) running, will (simulate) paralleling DG-1 to Div 1 Class-1E safety bus (SM-7) from the Diesel Room and then (A)(D)(R) 6 load to 1100 KW. Upon loading, should recognize that Diesel Generator us under excited thereby requiring trip of the DG output breaker.

K/A: 264000.A2.04 (2.9/3.0)

P-2: CHOOSE METHOD - INSERT CONTROL RODS BY VENTING SCRAM AIR HEADER

Description:

Based on initial conditions provided, recognize that manually (D)(E)(R) 1 venting the scram air header is the next action to take in an attempt to insert control rods.

K/A: 295037.EA1.05 (3.9/4.0)

P-3: (RSD) REMOTE SHUTDOWN PANEL ACTIVATION DURING A CONTROL ROOM EVACUATION (Time Critical)**

Description:

Based on a Main Control Room evacuation due to fire, and from (D)(E)(R) 7 a designated starting point, transit to the Remote Shutdown Panel and activate panel within required time using ABN-CR-EVAC Attachment 7.2.

K/A: 295016 AA1.07 (4.2/4.3) ** Ref: OI-69, TCOA-3/TCOA-4

• All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

• Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature 1 / 1 / 1 (control room system)

(L)ow-Power / Shutdown 1/1/1 (N)ew or (M)odified from bank including 1(A) 2/2/1 (P)revious 2 exams 3 / 3 / 2 (randomly selected)

(R)CA 1/1/1 (S)imulator Attachment 4 Page 2 of 6

ES-301 Control Room/In-Plant Systems Outline (Rev 0 - 10/24/16) Form ES-301-2 Facility: Columbia Generating Station Date of Examination: 2/27/17 Exam Level: RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems:* 8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Code* Safety Function S-1: (RRC) RRC-P-1A START IN MODE 1

Description:

Start Reactor Recirculation Pump 1A at power (pump fails to (A)(D)(S) 1 come up to speed on start and must be manually secured).

K/A: 202001.A4.01 (3.7/3.7)

S-2: (RHR) RESPOND TO LOSS OF SHUTDOWN COOLING

Description:

Restore Residual Heat Removal (RHR) Loop B shutdown cooling per SOP-RHR-SDC (RHR Loop B Shutdown Cooling Quick Restart). (A)(L)(N)(S) 4 Following pump start, insufficient pump head (and consequently flow) will necessitate securing pump per CAUTION in procedure.

K/A: 205000.A2.06 (3.4/3.5)

S-3: (HPCS) HPCS SYSTEM INITIATION (D)(EN)

Description:

Initiate High Pressure Core Spray (HPCS) system per SOP- 2 HPCS-INJECTION and restore RPV level back to directed band. (L)(S)

K/A: 209002.A4.08 (3.6/3.7)

S-4: (CR HVAC) INITIATE CR HVAC MANUAL PRESSURIZATION MODE

Description:

Place both trains of Control Room Ventilation in the Manual Pressurization Mode of operation per SOP-HVAC/CR-OPS (inlet damper for (A)(D)(EN) 9 one of the Control Room Emergency Filter Units fail to auto open and must be (S) opened manually).

K/A: 290003.A4.01 (3.2/3.2)

S-5: (RB HVAC) RE-ESTABLISH SECONDARY CONTAINMENT/START RB HVAC

Description:

Restart Reactor Building (RB) HVAC using RB Outside Air Fan (D)(P)(S) 5 1A and RB Exhaust Air Fan 1A per SOP-HVAC RB-RESTART-QC to re-establish Secondary Containment integrity.

K/A: 290001.A4.01 (3.3/3.4)

S-6: (DEH) LOWER RPV PRESSURE USING DEH

Description:

Recognize that auto control of bypass valves to lower RPV pressure to a target of 550 psig does not work and that the manual lowering of (A)(D)(L)(P) 3 RPV pressure at a rate LE 50 psig per minute through manual control of (S)

Bypass Valves would be required.

K/A: 241000.A4.02 (4.1/4.1)

S-8: (Fire Protection) ABN-FIRE Immediate Actions

Description:

Given the report of heavy smoke in the field and the observance (N)(S) 8 of several fire alarms, perform the Immediate Actions of ABN-FIRE.

K/A: 286000.A4.01 (3.3/3.2)

Attachment 4 Page 3 of 6

ES-301 Control Room/In-Plant Systems Outline (Rev 0 - 10/24/16) Form ES-301-2 In-Plant Systems* (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P-1: (DG) PARALLEL DG1 LOCALLY - VARS DOWNSCALE

Description:

With DG-1 already (simulated) running, will (simulate) paralleling DG-1 to Div 1 Class-1E safety bus (SM-7) from the Diesel Room and then (A)(D)(R) 6 load to 1100 KW. Upon loading, should recognize that Diesel Generator us under excited thereby requiring trip of the DG output breaker.

K/A: 264000.A2.04 (2.9/3.0)

P-2: CHOOSE METHOD - INSERT CONTROL RODS BY VENTING SCRAM AIR HEADER

Description:

Based on initial conditions provided, recognize that manually (D)(E)(R) 1 venting the scram air header is the next action to take in an attempt to insert control rods.

K/A: 295037.EA1.05 (3.9/4.0)

P-3: (RSD) REMOTE SHUTDOWN PANEL ACTIVATION DURING A CONTROL ROOM EVACUATION (Time Critical)**

Description:

Based on a Main Control Room evacuation due to fire, and from (D)(E)(R) 7 a designated starting point, transit to the Remote Shutdown Panel and activate panel within required time using ABN-CR-EVAC Attachment 7.2.

K/A: 295016 AA1.07 (4.2/4.3) ** Ref: OI-69 (TCOA-3 / TCOA-4)

• All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

• Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature 1 / 1 / 1 (control room system)

(L)ow-Power / Shutdown 1/1/1 (N)ew or (M)odified from bank including 1(A) 2/2/1 (P)revious 2 exams 3 / 3 / 2 (randomly selected)

(R)CA 1/1/1 (S)imulator Attachment 4 Page 4 of 6

ES-301 Control Room/In-Plant Systems Outline (Rev 0 - 10/24/16) Form ES-301-2 Facility: Columbia Generating Station Date of Examination: 2/27/17 Exam Level: RO SRO-I SRO-U Operating Test No.: 1 Control Room Systems:* 8 for RO; 7 for SRO-I; 2 or 3 for SRO-U System / JPM Title Type Code* Safety Function S-1: (RRC) RRC-P-1A START IN MODE 1

Description:

Start Reactor Recirculation Pump 1A at power (pump fails to (A)(D)(S) 1 come up to speed on start and must be manually secured).

K/A: 202001.A4.01 (3.7/3.7)

S-2: (RHR) RESPOND TO LOSS OF SHUTDOWN COOLING

Description:

Restore Residual Heat Removal (RHR) Loop B shutdown cooling per SOP-RHR-SDC (RHR Loop B Shutdown Cooling Quick Restart). (A)(L)(N)(S) 4 Following pump start, insufficient pump head (and consequently flow) will necessitate securing pump per CAUTION in procedure.

K/A: 205000.A2.06 (3.4/3.5)

S-3: (HPCS) HPCS SYSTEM INITIATION (D)(EN)

Description:

Initiate High Pressure Core Spray (HPCS) system per SOP- 2 HPCS-INJECTION and restore RPV level back to directed band. (L)(S)

K/A: 209002.A4.08 (3.6/3.7)

In-Plant Systems* (3 for RO); (3 for SRO-I); (3 or 2 for SRO-U)

P-1: (DG) PARALLEL DG1 LOCALLY - VARS DOWNSCALE

Description:

With DG-1 already (simulated) running, will (simulate) paralleling DG-1 to Div 1 Class-1E safety bus (SM-7) from the Diesel Room and then (A)(D)(R) 6 load to 1100 KW. Upon loading, should recognize that Diesel Generator us under excited thereby requiring trip of the DG output breaker.

K/A: 264000.A2.04 (2.9/3.0)

P-3: (RSD) REMOTE SHUTDOWN PANEL ACTIVATION DURING A CONTROL ROOM EVACUATION (Time Critical)**

Description:

Based on a Main Control Room evacuation due to fire, and from (D)(E)(R) 7 a designated starting point, transit to the Remote Shutdown Panel and activate panel within required time using ABN-CR-EVAC Attachment 7.2.

K/A: 295016 AA1.07 (4.2/4.3) ** Ref: OI-69, TCOA-3/TCOA-4

• All RO and SRO-I control room (and in-plant) systems must be different and serve different safety functions; all five SRO-U systems must serve different safety functions; in-plant systems and functions may overlap those tested in the control room.

Attachment 4 Page 5 of 6

ES-301 Control Room/In-Plant Systems Outline (Rev 0 - 10/24/16) Form ES-301-2 Type Codes Criteria for RO / SRO-I / SRO-U (A)lternate path 4-6 / 4-6 / 2-3 (C)ontrol room (D)irect from bank 9/8/4 (E)mergency or abnormal in-plant 1/1/1 (EN)gineered safety feature 1 / 1 / 1 (control room system)

(L)ow-Power / Shutdown 1/1/1 (N)ew or (M)odified from bank including 1(A) 2/2/1 (P)revious 2 exams 3 / 3 / 2 (randomly selected)

(R)CA 1/1/1 (S)imulator Attachment 4 Page 6 of 6

CREW 1 (Rev 0 - 10/24/2016)

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Columbia Generating Station Date of Exam: 2/27/2017 Operating Test No.: 1 A E Scenarios P V P E 1 2 3 4 T M L N O I CREW CREW POSITION CREW POSITION CREW POSITION N I T POSITION T C I A

A T S A B S A B S A B S A B M L U N Y R T O R T O R T O R T O T P O C P O C P O C P O C P M(*)

E R I U RO RX 0 1 1 0 SRO-I NOR 0 1 1 1 U1 I/C 4,5,6 3,4 5 4 4 2 SRO-U MAJ 7,8 6 3 2 2 1 TS 3,4 3,4 4 0 2 2 RX 1 1 1 1 0 RO R4 NOR 1 1 1 1 1 SRO-I I/C 5,8 3,5,8 5 4 4 2 SRO-U MAJ 7,8 6 3 2 2 1 TS 0 0 2 2 RO RX 1 1 1 1 0 SRO-I NOR 2 1 1 1 1 R5 I/C 4,6, 2,4, 7 4 4 2 SRO-U 7,9 7 MAJ 7,8 6 3 2 2 1 TS 0 0 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions. Instant SROs (SRO-I) must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an SRO-I additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a one-for-one basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

4. For licensees that use the ATC operator primarily for monitoring plant parameters, the chief examiner may place SRO-I applicants in either the ATC or BOP position to best evaluate the SRO-I in manipulating plant controls.

CREW 2 (Rev 0 - 10/24/2016)

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Columbia Generating Station Date of Exam: 2/27/2017 Operating Test No.: 1 A E Scenarios P V P E 1 2 3 4 T M L N O I CREW CREW POSITION CREW POSITION CREW POSITION N I T POSITION T C I A

A T S A B S A B S A B S A B M L U N Y R T O R T O R T O R T O T P O C P O C P O C P O C P M(*)

E R I U RO RX 1 3 2 1 1 0 SRO-I NOR 0 1 1 1 I1 SRO-U I/C 4,5,6 2,4, 7

2,3 8 4 4 2 MAJ 7,8 6 4,5 5 2 2 1 TS 3,4 1,2 4 0 2 2 RX 3 1 1 1 0 RO I2 NOR 2 1 1 1 1 SRO-I I/C 4,6, 7,9 3,4 2,3 8 4 4 2 SRO-U MAJ 7,8 6 4,5 5 2 2 1 TS 3,4 2 0 2 2 RO RX 1 1 1 1 0 SRO-I NOR 1 1 2 1 1 1 R1 I/C 5,8 3,5,8 6 6 4 4 2 SRO-U MAJ 7,8 6 4,5 5 2 2 1 TS 0 0 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions. Instant SROs (SRO-I) must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an SRO-I additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a one-for-one basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

4. For licensees that use the ATC operator primarily for monitoring plant parameters, the chief examiner may place SRO-I applicants in either the ATC or BOP position to best evaluate the SRO-I in manipulating plant controls.

CREW 3 (Rev 0 - 10/24/2016)

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Columbia Generating Station Date of Exam: 2/27/2017 Operating Test No.: 1 A E Scenarios P V P E 1 2 3 4 T M L N O I CREW CREW POSITION CREW POSITION CREW POSITION N I T POSITION T C I A

A T S A B S A B S A B S A B M L U N Y R T O R T O R T O R T O T P O C P O C P O C P O C P M(*)

E R I U RO RX 1 3 2 1 1 0 SRO-I NOR 0 1 1 1 I3 SRO-U I/C 4,5,6 2,4, 7

2,3 8 4 4 2 MAJ 7,8 6 4,5 5 2 2 1 TS 3,4 1,2 4 0 2 2 RX 3 1 1 1 0 RO I4 NOR 2 1 1 1 1 SRO-I I/C 4,6, 7,9 3,4 2,3 8 4 4 2 SRO-U MAJ 7,8 6 4,5 5 2 2 1 TS 3,4 2 0 2 2 RO RX 1 1 1 1 0 SRO-I NOR 1 1 2 1 1 1 R2 I/C 5,8 3,5,8 6 6 4 4 2 SRO-U MAJ 7,8 6 4,5 5 2 2 1 TS 0 0 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions. Instant SROs (SRO-I) must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an SRO-I additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a one-for-one basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

4. For licensees that use the ATC operator primarily for monitoring plant parameters, the chief examiner may place SRO-I applicants in either the ATC or BOP position to best evaluate the SRO-I in manipulating plant controls.

CREW 4 (Rev 0 - 10/24/2016)

ES-301 Transient and Event Checklist Form ES-301-5 Facility: Columbia Generating Station Date of Exam: 2/27/2017 Operating Test No.: 1 A E Scenarios P V P E 1 2 3 4 T M L N O I CREW CREW POSITION CREW POSITION CREW POSITION N I T POSITION T C I A

A T S A B S A B S A B S A B M L U N Y R T O R T O R T O R T O T P O C P O C P O C P O C P M(*)

E R I U RO RX 1 3 2 1 1 0 SRO-I NOR 0 1 1 1 I5 SRO-U I/C 4,5,6 2,4, 7

2,3 8 4 4 2 MAJ 7,8 6 4,5 5 2 2 1 TS 3,4 1,2 4 0 2 2 RX 3 1 1 1 0 RO I6 NOR 2 1 1 1 1 SRO-I I/C 4,6, 7,9 3,4 2,3 8 4 4 2 SRO-U MAJ 7,8 6 4,5 5 2 2 1 TS 3,4 2 0 2 2 RO RX 1 1 1 1 0 SRO-I NOR 1 1 2 1 1 1 R3 I/C 5,8 3,5,8 6 6 4 4 2 SRO-U MAJ 7,8 6 4,5 5 2 2 1 TS 0 0 2 2 Instructions:

1. Check the applicant level and enter the operating test number and Form ES-D-1 event numbers for each event type; TS are not applicable for RO applicants. ROs must serve in both the at-the-controls (ATC) and balance-of-plant (BOP) positions. Instant SROs (SRO-I) must serve in both the SRO and the ATC positions, including at least two instrument or component (I/C) malfunctions and one major transient, in the ATC position. If an SRO-I additionally serves in the BOP position, one I/C malfunction can be credited toward the two I/C malfunctions required for the ATC position.

2. Reactivity manipulations may be conducted under normal or controlled abnormal conditions (refer to Section D.5.d) but must be significant per Section C.2.a of Appendix D. (*) Reactivity and normal evolutions may be replaced with additional instrument or component malfunctions on a one-for-one basis.

3. Whenever practical, both instrument and component malfunctions should be included; only those that require verifiable actions that provide insight to the applicants competence count toward the minimum requirements specified for the applicants license level in the right-hand columns.

4. For licensees that use the ATC operator primarily for monitoring plant parameters, the chief examiner may place SRO-I applicants in either the ATC or BOP position to best evaluate the SRO-I in manipulating plant controls.

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Facility: Columbia Generating Scenario No.: 1 Op Test No.: 1 Station Examiners: Operators:

The reactor is in Mode 2 during reactor startup. RPV pressure is approximately 300 psig. Reactor Feedwater Pump 1A (RFW-P-1A) has been at 800 rpm for the last 30 minutes and is ready to be Initial Conditions:

placed in service. Reactor Building Exhaust Fan 1A (REA-FN-1A) is out of service for extended maintenance.

Withdraw control rods as required to establish and maintain Bypass Valves approximately 20% open.

Turnover:

Continuous rod withdrawal permitted. Once complete, continue startup of RFW-P-1A.

Critical Tasks:

CT-1 Manually scram the reactor before wetwell level drops below 19 feet 2 inches.

When wetwell level cannot be maintained above 19 feet 2 inches, initiate emergency depressurization by CT-2 opening seven (7) Safety Relief Valves (ADS preferred).

Event Malf.

Event Type* Event Description No. No.

Withdraw control rods as required to establish and maintain the bypass 1 N/A R (ATC) valves approximately 20% open 2 N/A N (BOP) Complete startup of RFW-P-1A 3 TRG-1 TS (SRO) Rod Accumulator Trouble alarm occurs for Rod 22-11 (Tech Spec)

C (BOP,SRO) Trip of REA-FN-1B results in a high reactor building pressure and entry 4 TRG-3 TS (SRO) into PPM 5.3.1 (EOP - Secondary Containment Control) (Tech Spec) 5 TRG-4 I (ATC,SRO) IRM A fails upscale resulting in a half scram A minimum seismic earthquake results in a loss of SL-11 which requires 6 TRG-5 C (BOP,SRO) bus to be re-energized from alternate source OBE causes failure of the RHR-P-2A suction line and failure of primary M (ALL) containment (resulting in lowering wetwell level)

SW-V-29 fails to auto open when HPCS-P-2 is started for wetwell 7 TRG-6 C (BOP) makeup FDR-V-607 fails to auto close due to a failed level switch (which allows flooding to continue into RCIC Pump Room). Cannot be closed manually Manual scram inserted prior to wetwell level lowering to 19 feet 2 inches M (ALL)

(CT #1) 8 N/A Reactor mode switch fails to scram reactor but use of manual scram C (ATC) pushbuttons does scram reactor (CT #1)

Prior to wetwell level going below 19 feet 2 inches, the crew determines

--- that wetwell level cannot be maintained 19 feet 2 inches and initiates 9 N/A RPV Emergency Depressurization (ED) with 7 SRVs opened (CT #2)

One ADS SRV (MS-RV-4D) fails to open requiring manually opening one C (BOP) non-ADS SRV (CT #2)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Technical Specifications CGS 2017 NRC Exam Scenario 1 Outline Page 1 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Target Quantitative Attributes Actual Description SW-V-29 fails to auto open; FDR-V-607 fails to close; Malfunctions after EOP entry (1-2) 4 Mode switch failure; ADS SRV fails to open Fan REA-FN-1B trip; IRM A trip with half scram; Loss Abnormal events (2-4) 3 of SL-11 Major transients (1-2) 2 Primary containment failure; Manual scram PPM 5.3.1 (Secondary Containment Control); PPM 5.2.1 EOPs entered/requiring substantive actions (1-2) 3 (Primary Containment Control); PPM 5.1.1 (RPV Control)

EOP contingencies requiring substantive actions (0-2) 1 PPM 5.1.3 (Emergency RPV Depressurization)

Critical tasks (2-3) 2 See Critical Task Determination table Trigger Evaluator How Purpose Malfunction Numbers (TRG-x) Directed Triggered TRG-1 YES Manually Event Initiator MAL-CRD001-2211 TRG-2 Manually Field Action MAL-CRD001-2211 TRG-3 YES Manually Event Initiator PMP-SCN010S TRG-4 YES Manually Event Initiator MAL-NIS002A TRG-5 YES Manually Event Initiator MAL-RWB001; BKR-EPS001; BKR-EPS004; ANN-800C3A02 MAL-RWB001; MAL-RHR001; XMT-PCN006A; XMT-PCN007A; TRG-6 YES Manually Event Initiator XMT-PCN003A; XMT-PCN004A TRG-7 Manually Field Action BKR-RHR001 CGS 2017 NRC Exam Scenario 1 Outline Page 2 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station SCENARIO 1

SUMMARY

Event 1 With reactor power at ~3% and reactor pressure at ~300 psig, the ATC operator withdraws control rods to restore and maintain Main Turbine Bypass Valves (BPVs) approximately 20% open as directed by PPM 3.1.2 (Startup Flowchart), Attachment 7.3, step Q32. Bypass Valves should be open at approximately 20% prior to completing startup of Reactor Feedwater Pump 1A (RFW-P-1A).

Event 2 RFW-P-1A has been rotating at 800 rpm for 30 minutes and is ready for the next speed increase. The BOP operator completes startup of RFW-P-1A per SOP-RFT-START.

Event 3 (TRG-1) The crew receives a ROD ACCUMULATOR TROUBLE alarm. The full core display will indicate trouble with the accumulator for control rod 22-11. A field report indicates that the accumulator pressure is approximately 930 psig (below TS limit). The crew takes actions per Annunciator Response Procedure (ARP) 4.603.A7.6-7 (ROD ACCUMULATOR TROUBLE). The CRS directs the Field Operator to recharge the accumulator per SOP-CRD-HCU. When recharged (TRG-2), the accumulator indication for rod 22-11 will clear on the full core display. The CRS refers to Technical Specifications and determines that TS 3.1.5 (Control Rod Scram Accumulators) Action C.2 applies which requires declaring control rod 22-1 inoperable unless accumulator is restored to operable status within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

Event 4 (TRG-3) Trip of Reactor Building Exhaust Fan 1B (REA-FN-1B) results in a high Reactor Building pressure and entry into PPM 5.3.1 (EOP - Secondary Containment Control). Secondary containment becomes inoperable. ARP 4.812.R2 9-1 (REACTOR BUILDING EXHAUST FAN B TRIP) directs starting REA-FN-1A which cannot be started (out-of-service). Subsequent ARP direction requires the BOP operator to isolate Reactor Building HVAC and starting the Standby Gas Treatment system to return Reactor Building pressure to within the TS limit ( 0.25 inch of vacuum water gauge). The CRS refers to Technical Specifications and determines that TS 3.6.4.1 (Secondary Containment), Action A.1 applies which requires restoring secondary containment to operable status within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

Event 5 (TRG-4) IRM A fails upscale resulting in an IRM upscale trip and Neutron Monitor System trip annunciators and a half scram. Per the ARP and when directed by the CRS, the ATC operator bypasses IRM A and resets the half-scram. The CRS refers to Technical Specifications 3.3.1.1 (RPS Instrumentation) and determines that the minimum number of IRM instruments required remains operable and that no TS actions are required.

Event 6 (TRG-5) A Minimum Seismic Earthquake occurs causing a differential current lockout of transformer (TR-1/11) supplying 480V Bus SL-11 which de-energizes the bus. After accessing what caused the lockout, and when directed, the BOP operator repowers SL-11 from SL-21 using the Quick Card (SOP-ELEC-480V-OPS-QC). The crew also takes actions per ABN-EARTHQUAKE to include checking seismic status indications, making a plant announcement, and assessing the need for a controlled reactor shutdown.

CGS 2017 NRC Exam Scenario 1 Outline Page 3 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Event 7 (TRG-6) An Operating Bases Earthquake (OBE) occurs. The crew uses ABN-EARTHQUAKE (entered previously) to validate that an OBE event has occurred and discusses need to perform a controlled reactor shutdown. Subsequent to the earthquake, a break on the Residual Heat Removal Pump 2A (RHR-P-2A) suction line causes wetwell level to lower. ABN-FLOODING is entered. When attempting to close the RHR-P-2A Motor-Operated suction valve (RHR-V-4A), the valve fails open. The CRS enters PPM 5.2.1 (EOP - Primary Containment Control) on Suppression Pool low level. Crew should direct removal of control power fuses (TRG-7) for RHR-P-2A as time permits.

The crew takes actions to restore wetwell level using the High Pressure Core Spray (HPCS) pump (HPCS-P-1) per PPM 5.5.23 (Emergency Suppression Pool Makeup). During this lineup, the HPCS Standby Service Water Pump (HPCS-P-2) discharge valve (SW-V-29) fails to auto open when HPCS-P-2 is started, requiring the BOP operator to manually open the valve. HPCS is ineffective is restoring Suppression Pool level.

FDR-V-607, the cross-connect valve between the RHR-SYS-A and Reactor Core Isolation Cooling (RCIC) rooms fails to auto close due to a failed level switch (which allows flooding to continue into RCIC Pump Room). The valve cannot be manually closed. The CRS re-enters PPM 5.3.1 (EOP - Secondary Containment Control) due high RHR-SYS-A and RCIC room levels. The leak from the Suppression Pool is not considered a Primary System discharging into Secondary Containment and therefore a controlled reactor shutdown (previously required for the OBE) is also required for high RCIC room water level (6 inches above floor).

Event 8 The CRS enters PPM 5.1.1 (EOP - RPV Control) and directs manually scramming the reactor prior to wetwell level reaching 19 feet 2 inches. (CT #1) The reactor will not scram when the mode switch is taken to SHUTDOWN. The ATC operator identifies the failure to scram and takes actions per PPM 3.3.1 (Reactor Scram) to scram the reactor. The Manual Scram Pushbuttons are effective in inserting all control rods.

Event 9 Prior to wetwell level going below 19 feet 2 inches, the CRS determines that wetwell level cannot be maintained 19 feet 2 inches and directs RPV Emergency Depressurization (ED) per PPM 5.1.3 (EOP - Emergency RPV Depressurization) to include opening seven (7) Safety Relief Valves (ADS SRVs preferred). (CT #2)

One Automatic Depressurization System (ADS) Safety Relief Valve (SRV) fails to open (MS-RV-4D) during the ED requiring the BOP operator to manually open a non-ADS SRV. (CT #2).

TERMINATION CRITERIA: The scenario will be terminated when emergency depressurization has commenced (7 SRVs open) and RPV level is being controlled in the prescribed band OR as directed by the Examination Team.

CGS 2017 NRC Exam Scenario 1 Outline Page 4 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Critical Task Determination Measurable Safety Performance Critical Task Cueing Performance Significance Feedback Indicators CT #1 - Manually Ensures reactor is Procedural direction by The operator will All control rods fully scram the reactor scrammed and PPM 5.2.1 (EOP for manually scram insert.

before wetwell level shutdown before Primary Containment reactor by placing drops below 19 feet requirement to Control) Step L-5 Reactor Mode 2 inches. Emergency directs entering PPM Switch in Depressurize (ED) is 5.1.1 (which requires Shutdown (and reached. placing Reactor Mode follow up with all Switch in Shutdown) Manual Scram If ED is anticipated once it is determined pushbuttons when (see PPM 5.1.1 P-1 that wetwell level RMS fails to scram override), dumping cannot be maintained the reactor).

steam to main above 19 feet 2 inches.

condenser via Main Turbine bypass valves may be used to reduce reactor pressure before the requirement to ED occurs. ED would still be performed if required by EOPs.

(Ref: PPM 5.0.10 Rev 21, 8.8.2 f))

CT #2 - When Suppression of Procedural direction by The operator will The valve light pressure from PPM 5.2.1 (EOP for manually open 7 indications for each wetwell level cannot be maintained blowdown Primary Containment Safety Relief of the 7 Safety above 19 feet 2 (Emergency Control) Step L-6 Valves (ADS Relief Valves will Depressurization) directs Emergency preferred) to change from Green inches, initiate through the Depressurizing reactor emergency lit to Red lit when emergency depressurization by downcomers when Wetwell water depressurize the control switch is opening seven (7) cannot be assured for level cannot be RPV. taken to Open.

water levels below 19 maintained above 19 Safety Relief Valves (ADS preferred). feet 2 inches. feet 2 inches. Reactor pressure will lower in (Ref: PPM 5.0.10 response.

. Rev 21, 7.12.3)

CGS 2017 NRC Exam Scenario 1 Outline Page 5 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Facility: Columbia Generating Scenario No.: 2 Op Test No.: 1 Station Examiners: Operators:

Columbia is operating at 100% power. Control Rod Drive (CRD) Pump 1B (CRD-P-1B) is out of Initial Conditions:

service for extended Maintenance. CRD-P-1A is Protected.

Lower reactor power to 90% using Reactor Recirculation flow per PPM 3.2.6 (Power Maneuvering)

Turnover: after assuming the shift. Steps 5.1.1 thru 5.1.6 of PPM 3.2.6 are complete. Proper margin to Pre-Conditioned Status (PCS) exists per PPM 9.3.18. The Reactivity brief has been performed.

Critical Tasks:

During ATWS with power > 5%, terminate and prevent injection with exception of SLC, RCIC, and CRD, into CT-1 the RPV until RPV level is -65 inches to establish a Lowered Level (LL).

Maintain plant parameters to prevent an unnecessary emergency depressurization that would unnecessarily CT-2 threaten containment or the RPV.

Event Malf. Event Type* Event Description No.

Lower reactor power with Reactor Recirculation (RRC) flow to 90% for R (ATC) 1 N/A load following per PPM 3.2.6 (which includes placing Main Turbine into N (BOP)

Governor Valve Sequential Valve Mode)

CRD Drive Header Flow Control Valve controller (CRD-FC-600) output 2 TRG-1 I (ATC) fails high while in automatic C (BOP,SRO) 3 TRG-2 RHR-SYS-A/LPCS Keep Fill Pump (LPCS-P-2) trips (Tech Spec)

TS (SRO)

Failure of MS-PS-23D which causes a half scram on RPS B side. Two C (ATC,SRO) 4 TRG-3 control rods scram but one does not go full in (must be manually inserted)

TS (SRO)

(Tech Spec) 5 TRG-4 C (BOP) Ground causes FPC-P-1B to spuriously trip (FPC-P-1A fails to auto start)

Trip of E-CB-1/7 with transfer of SM-7 to Backup Transformer resulting in reactor trip signal 6 TRG-5 M (ALL)**

Hydraulic ATWS - Lower RPV Level -80 inches to -140 inches (CT #1)

(CT #2)

SLC-P-1A shaft shears when pump starts and SLC-P-1B develops a 7 N/A C (ATC) discharge flow blockage which limits SLC injection flow. RWCU-V-4 does not auto close but can be closed manually Scram/Reset/Scram not effective in inserting control rods - Control rods 8 N/A C (BOP) can be manually driven in

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS) Technical Specifications

• • Event forms a portion of significant CGS PSA Accident Sequence (TTC044) (Ref: PSA-1-SM-0001 (Rev 7))

CGS 2017 NRC Exam Scenario 2 Outline Page 1 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Target Quantitative Attributes Actual Description SLC-P-1A shaft shear; SLC-P-1B flow blockage; Malfunctions after EOP entry (1-2) 4 RWCU-V-4 fails to auto close; Scram-reset-scram ineffective CRD-FC-600 failure; LPCS-P-2 shaft seizure; RPS B Abnormal events (2-4) 4 half scram (2 control rods inadvertently scram); FPC-P-1B trip Major transients (1-2) 1 E-CB-1/7 breaker trip leading to hydraulic ATWS EOPs entered/requiring substantive actions (1-2) 1 PPM 5.1.1 (RPV Control)

EOP contingencies requiring substantive actions (0-2) 1 PPM 5.1.2 (RPV Control - ATWS)

EOP based Critical tasks (2-3) 2 See Critical Task Determination table Trigger Evaluator How Purpose Malfunction Numbers (TRG-x) Directed Triggered TRG-1 YES Manually Event Initiator CNH-CRD001E; BST-CRD001F TRG-2 YES Manually Event Initiator PMP-CSS004S BST-RRS067F; MAL-RMC007-3835; MAL-RMC007-1815; TRG-3 YES Manually Event Initiator MAL-RMC005-1815 TRG-4 YES Manually Event Initiator MOT-FPC002G BKR-EPS003; MAL-CRD007A1; MAL-CRD007A2; MAL-CRD007B1; TRG-5 YES Manually Event Initiator MAL-CRD007B2 TRG-6 Manually Field Action BKR-RHR001 TRG-7 Manually Field Action BKR-CSS002 CGS 2017 NRC Exam Scenario 2 Outline Page 2 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station SCENARIO 2

SUMMARY

Event 1 The Scenario starts from 100% power with Control Rod Drive (CRD) Pump 1B (CRD-P-1B) out of service for extended maintenance. Once the crew has the shift, the ATC operator lowers reactor power (for load following) using Reactor Recirculation (RRC) flow to 90% per PPM 3.2.6 (Power Maneuvering). The BOP operator takes the Main Turbine out of Governor Valve Optimization mode per SOP-MT-GV/OPTIMIZATION (Section 5.2) prior to the RRC flow reduction.

Event 2 (TRG-1) CRD Drive Header Flow Control Valve controller (CRD-FC-600) output fails high while in automatic which causes 603.A7 5-8 (CRD PUMP SUCTION FLTR D HIGH) annunciator to come in caused by abnormally high system flow. Upon finding the CRD-FC-600 controller output failed high, the ATC operator informs the CRS and shifts the controller to manual and restores CRD system parameters to normal. Annunciator will clear once system parameters restored to normal.

Event 3 (TRG-2) The shaft on RHR-SYS-A/LPCS Keep Fill Pump (LPCS-P-2) seizes causing a trip of the pump.

The RHR A PUMP DISCH PRESS HIGH/LOW annunciator alarms shortly after LPCS-P-2 trips. The LPCS PUMP DISCH PRESS HIGH/LOW annunciator will alarm ~13 minutes after LPCS-P-2 trips (unless LPCS pump started before then). Based on system status and ARP direction, the CRS will direct the BOP operator to start the Low Pressure Core Spray (LPCS) Pump (and place into Suppression Pool Mixing per SOP-LPCS-SP) to maintain system availability provided the LPCS PUMP DISCH PRESS HIGH/LOW annunciator is not in alarm. To prevent an inadvertent start of Residual Heat Removal (RHR)

Pump 2A (RHR-P-2A) and therefore a potential for water hammer, the CRS will direct control power fuses removed (TRG-6) from the RHR-P-2A starting circuit. If LPCS pump is not started and the LPCS PUMP DISCH PRESS HIGH/LOW annunciator is received, LPCS Pump control power fuses will also be removed (TRG-7). The CRS will refer to ABN-RHR-DEPRESS as time permits to determine system recovery actions.

With RHR-P-2A and LPCS inoperable, the CRS refers to Technical Specifications and Licensee Controlled Specifications and determines the following actions are applicable:

• LCO 3.5.1 A.1 (RHR-SYS-A & LPCS are both tracked as inoperable) - Restore respective subsystem to operable status within 7 days

• LCO 3.5.1 C.1 - Restore either RHR-SYS-A or LPCS subsystem to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />

• LCO 3.6.1.5 A.1 - Restore RHR-SYS-A Drywell Spray subsystem to operable status within 7 days

• LCO 3.6.2.3 A.1 - Restore RHR-SYS-A Suppression Pool Cooling subsystem to operable status within 7 days

• LCO 3.3.3.2 A.1 - Restore required Function (9.d - RHR-SYS-A Loop Pump) to operable status within 30 days

• RFO 1.6.1.5 A.1 - Restore RHR-SYS-A Suppression Pool Spray subsystem to operable status within 7 days Note that LCOs 3.4.6, 3.4.9, and 3.6.1.3 are considered but not applicable with the plant in Mode 1.

Event 4 (TRG-3) Main Steam pressure switch 23D (MS-PS-23D) fails high causing Reactor Protection System (RPS) relay K5D (RPS-RLY-K5D) to actuate a RPV Pressure High Trip Scram relay (as evidenced by annunciator 603.A8 2-2 (RPV PRESS HIGH TRIP)). This actuation causes a half scram on the RPS B side with all RPS B white RPS scram lights de-energized. The ATC operator will determine that two control rods (38-35 and 18-15) inadvertently scrammed during the half scram and that control rod 18-15 only partially inserted. The CRS enters ABN-ROD, section 4.2, for inadvertently scrammed rods. The ATC operator reduces RRC flow to 74 Mlbm/hr at 5% per minute. Following flow reduction, an attempt is made to fully insert control rod 18-15 using the CONTINUOUS INSERT pushbutton (which will be successful). The crew diagnoses the instrument failure and determines the half scram cannot be reset.

The CRS refers to Technical Specifications and determines that TS 3.3.1.1 (RPS Instrumentation) Action A.1 or A.2 requires affected channel or affected trip system, respectively, to be placed in TRIP within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. In addition, control rod 18-15 is considered inoperable for not fully inserting when inadvertently CGS 2017 NRC Exam Scenario 2 Outline Page 3 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station scrammed. LCO 3.1.3 (Control Rod Operability) Action C.1 requires rod 18-15 to be fully inserted within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> and its associated CRD (HCU) disarmed within four hours.

Event 5 (TRG-4) Bus 81 ground as sensed on MC-8BB which powers Fuel Pool Cooling Pump 1B (FPC-P-1B) causes FPC-P-1B to trip when power fuses blow. With this power loss, the standby Fuel Pooling Cooling pump (FPC-P-1A) will not auto start. ARP 4.627.FPC2.3-1 (CIRCULATION PUMP B DISCHARGE PRESSURE LOW) directs entry into ABN-FPC-LOSS. The BOP operator will manually start FPC-P-1A to re-establish fuel pool cooling. Resetting the Bus 81 ground annunciator (TRG-10) will be successful, if attempted, since ground cleared upon the FPC-P-1B power fuses blowing. Since the status of the FPC-P-1B thermal overloads are unknown at this point the BOP operator may place the FPC-P-1B control switch in the IR-69 position to allow reset of associated overloads.

Event 6 (TRG-5) Trip of CB-1/7 (4160V feed from SM-1 to SM-7) results in an automatic transfer of Division 1 AC safety bus (SM-7) to the Backup Transformer (TR-B). The transient results in a trip of the LPCS Pump (previously started) and a loss of RPS Motor Generator A power to RPS A. With a RPS B half scram signal already present, a full scram signal now exists. The ATC operator recognizes a scram should have occurred and that an ATWS condition exists. The ATC operator takes scram actions including pressing all Manual scram pushbuttons and initiating ARI logic. Both trains of SLC are started due to reactor power being > 5%.

The CRS enters PPM 5.1.1 (RPV Control) and transitions into PPM 5.1.2 (RPV Control - ATWS) and directs the BOP operator to inhibit ADS and to take manual control of HPCS. The CRS addresses the level leg first and directs the BOP operator to perform PPM 5.5.6 (Bypassing MSIV Low RPV Level and High Steam Tunnel Temperature interlocks) to allow MSIVs to stay open on subsequent RPV level reduction. PPM 5.5.1 (Overriding ECCS Valve Logic To Allow Throttling ECCS Injection) is also performed. The CRS then directs stopping and preventing all injection into the RPV except for SLC, CRD and RCIC. When level reaches -65 inches, the ATC operator will restart injection into the RPV through the RFW Startup flow control valve to maintain a RPV Level band of -80 to -140 inches. (CT #1) (CT #2)

The CRS directs an RPV pressure band of 800 to 1050 psig with the Digital Electro-Hydraulic (DEH) system in automatic. If reactor power is above 25%, the capacity of the RFW Start-up flow line will be exceeded and the ATC operator will have to augment flow by opening RFW-V-109 (Bypass valve for Feedwater Heaters 6A and 6B). The BOP operator performs PPM 5.5.11 (Alternate Control Rod Insertions) in an attempt to insert control rods.

This event forms a portion of significant CGS PSA Accident Sequence (TTC044) (Ref: PSA-1-SM-0001 (Rev 7))

Event 7 Standby Liquid Control (SLC) Pump 1A fails due to a sheared shaft and SLC Pump 1B discharge is partially blocked resulting in a reduced SLC injection flow in the RPV at approximately 24 gpm. This injection rate will cause reactor power to drop slowly but not prior to the crew lowering RPV level to -80 to

-140 inches. Reactor Water Cleanup Valve 4 (RWCU-V-4) does not auto close on the SLC initiation but will be closed manually.

Event 8 Control rods insertion will be attempted per PPM 5.5.11 (Alternate Control Rod Insertions). Since hydraulic ATWS occurred (no white RPS scram lights lit), the BOP operator will remove two (2) ARI fuses and bypass (via switch) the Scram Discharge Volume (SDV) High Level trip. CRD-P-1A will be found tripped and will have to be restarted before a re-scram is attempted. The Scram - Reset - Scram method of control rod insertion is not effective requiring the BOP operator to bypass the Rod Worth Minimizer (RWM) and manually insert control rods individually using CRD drive pressure.

CGS 2017 NRC Exam Scenario 2 Outline Page 4 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station TERMINATION CRITERIA: The scenario will be terminated when RPV level is being maintained between -80 inches to -140 inches, one attempt at scram-reset-scram has been completed, and manual insertion of control rods has commenced OR as directed by the Examination Team.

CGS 2017 NRC Exam Scenario 2 Outline Page 5 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Critical Task Determination Measurable Performance Critical Task Safety Significance Cueing Performance Feedback Indicators CT #1 - During This is a procedural Procedural direction Crew stops and RPV level and ATWS with power requirement of PPM by PPM 5.1.2 Step L- prevents injection reactor power start

> 5%, terminate and 5.1.2 (RPV Control - 6 directs lowering with the exception lowering.

prevent injection with ATWS). Allowing RPV level to < -65 of SLC, RCIC, and exception of SLC, SLC, RCIC and CRD inches by stopping CRD.

RCIC, and CRD, into injection avoids and preventing all the RPV until RPV conflicts with other injection into RPV level is -65 inches to instructions in the except from boron establish a Lowered EOPs such as injections systems, Level (LL). injecting SLC and RCIC and CRD, inserting control rods. defeating interlocks if Stopping other necessary.

injection sources prevents potential fuel damage due to cold water injection.

(Ref: PPM 5.0.10 Rev 21, section 8.3.4.)

CT #2 - Maintain Prevent unnecessary Procedural direction Crew uses Reactor RPV level plant parameters to significant challenge to by PPM 5.1.2 Step L- Feedwater system indication.

prevent an containment or the 12 directs to maintain RPV unnecessary RPV. maintaining RPV level above -186 emergency level from -140 inches.

depressurization that inches to -80 inches would unnecessarily (best practice band) (ED required if threaten containment with outside shroud level cannot be or the RPV. injection systems restored and (Table 5). maintained above

-186 inches)

OI-15 (EOP and EAL Clarifications),

Section 4.3.2.b.)

CGS 2017 NRC Exam Scenario 2 Outline Page 6 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Facility: Columbia Generating Scenario No.: 3 Op Test No.: 1 Station Examiners: Operators:

Columbia is operating at 85% power due to economic dispatch. Safety Relief Valve 2C (MS-RV-2C) is known to be leaking. Suppression Pool high temperature alarms (601.A11.1-3 and 601.A12.1-3)

Initial Conditions:

have just annunciated. Reactor Closed Cooling (RCC) Pump 1B is tagged out for planned maintenance. RCC-P-1A and RCC-P-1C are protected.

After shift turnover place Residual Heat Removal Pump 2A (RHR-P-2A) in Suppression Pool Cooling Turnover: and allow Standby Service Water Pump 1A (SW-P-1A) to auto start. The pre-evolution brief has been completed and operators are stationed near both pumps.

Critical Tasks:

With reactor at power and with primary system discharging into secondary containment, manually scram CT-1 reactor before any area exceeds its maximum safe operating temperature.

With a primary system discharging into secondary containment and area temperature exceeding maximum CT-2 safe operating level in more than one area, initiate emergency depressurization by opening seven (7) Safety Relief Valves (ADS preferred).

Event Malf. Event Type* Event Description No.

N (BOP) Place RHR-SYS-A in Suppression Pool Cooling (LPCS/RHR A ADS 1 N/A TS (SRO) Permissive fails to annunciate during pump start) (Tech Spec) **

C (ATC,SRO) Control rod (26-19) drifts out. Once inserted, releasing the continuous 2 TRG-1 insert pushbutton allows the control rod to drift out again, requiring the TS (SRO) control rod to be isolated (Tech Spec)

C (ATC,SRO) Reactor Feed Pump (RFP) B vibrations rise requiring RRC Flow 3 TRG-3 R (ATC,SRO) reduction and manual trip of the B RFP Operating Bases Earthquake causes a steam leak in the RCIC Pump 4 TRG-4 M (ALL) Room with Failure of RCIC-V-8 and RCIC-V-63 to fully close (preventing RCIC leak isolation)

Manual scram inserted before first secondary containment max safe 5 N/A M (ALL) operating temperature is reached (CT #1)

Steam leak develops in the Main Steam Tunnel (MS-V-22A and MS-V-6 N/A C (BOP) 28A through D fail to automatically close - MS-V-28A through D can be closed manually but does not isolate leak).

Emergency Depressurization (PPM 5.1.3) is performed when two areas 7 N/A ---

exceed their max safe operating temperature (CT #2)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS) Technical Specifications

• • Ref: Columbia OE (AR-00049685 - Root Cause Analysis of RHR-PS-19A Isolation Mispositioning Event)

CGS 2017 NRC Exam Scenario 3 Outline Page 1 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Target Quantitative Attributes Actual Description Steam leak in Main Steam Tunnel; MS-V-28A through Malfunctions after EOP entry (1-2) 3 D fail to auto close (relay fault); MS-V-22A will not close (mechanical)

ADS Permissive fails on RHR pump A start; Rod 26-Abnormal events (2-4) 3 19 drifts out; RFB B high vibrations Major transients (1-2) 2 RCIC steam leak; Manual scram PPM 5.1.1 (RPV Control); PPM 5.3.1 (Secondary EOPs entered/requiring substantive actions (1-2) 2 Containment Control)

EOP contingencies requiring substantive actions (0-2) 1 PPM 5.1.3 (Emergency RPV Depressurization)

EOP based Critical tasks (2-3) 2 See Critical Task Determination table Trigger Evaluator How Purpose Malfunction Numbers (TRG-x) Directed Triggered TRG-1 YES Manually Event Initiator MAL-RMC004-2619 TRG-2 Manually Field Action MAL-RMC004-2619 TRG-3 YES Manually Event Initiator ANN-840A1G05; MAL-FPT005B TRG-4 YES Manually Event Initiator MAL-RWB001; MAL-RCI004 TRG-5 Automatically Malf Trigger MAL-RRS006A; MAL-RCI004 TRG-6 Automatically Malf Trigger MAL-RRS006A TRG-7 Manually Field Action ANN-840A1G05 CGS 2017 NRC Exam Scenario 3 Outline Page 2 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station SCENARIO 3

SUMMARY

Event 1 As part of the turnover, and with annunciators for Suppression Pool high temperature in alarm (601.A11 1-3 and 601.A12 1-3)), the BOP operator will place Residual Heat Removal Loop A (RHR-SYS-A) into Suppression Pool Cooling mode per SOP-RHR-SPC (Suppression Pool Cooling/Spray/Discharge

/Mixing). Standby Service Water Pump (SW-P-1A) will be allowed to auto start as permitted by procedure.

The CRS declares RHR-SYS-A as inoperable but available and refers to Technical Specifications and the Licensee Controlled Specifications and determines that the following applies:

• LCO 3.5.1 Action A.1 which requires restoring RHR-SYS-A to operable status within 7 days

• LCO 3.6.1.5 Action A.1 which requires restoring RHR-SYS-A drywell spray subsystem to operable status within 7 days

• LCO 3.6.2.3 Action A.1 which requires restoring RHR-SYS-A suppression pool cooling subsystem to operable status within 7 days

• RFO 1.6.1.5 Action A.1 which requires restoring RHR-SYS-A suppression pool spray subsystem to operable status within 7 days During RHR-P-2A pump start for entering Suppression Pool cooling mode, an isolated pressure switch (RHR-PS-19A) prevents the LPCS/RHR A ADS Permissive alarm from annunciating on P601. The CRS refers to Technical Specifications and determines that LCO 3.3.5.1 (Emergency Core Cooling System (ECCS) Instrumentation) Action A.1 applies which directs entry into the Condition referenced in Table 3.3.5.1-1 for the channel (Function 4.e) immediately (Condition G). ACTION G.2 directs restoring channel to operable status within 8 days.

Previous Columbia OE (Ref: AR-00049685 - Root Cause Analysis of RHR-PS-19A Isolation Mispositioning Event dated 4/1/2007) involved isolation of same pressure switch which was not discovered until RHR-P-2A was started and the ADS Permissive annunciator did not come in as expected.

Event 2 (TRG-1) Control rod 26-19 drifts out of the core. The ATC operator recognizes the rod drift and takes Immediate Actions to fully insert the control rod using the Continuous Insert pushbutton. The CRS enters ABN-ROD. When the Insert pushbutton is released, the control rod begins again to drift out of the core.

The ATC operator re-inserts the control rod full-in (and keeps the Continuous Inset pushbutton pressed) while the crew takes action to isolate the HCU for control rod 26-19 (TRG-2). The CRS declares control rod 26-19 inoperable. The CRS refers to Technical Specifications and determines that LCO 3.1.3 (Control Rod Operability) Action C.1 applies which requires rod 26-19 to be fully inserted within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> and Action C.2 which requires associated CRD (HCU) disarmed within four hours.

Event 3 (TRG-3) Vibrations start to rise above the ALERT setpoint on Reactor Feed Pump (RFP) B as indicated by annunciator P840.A1.7-5 (Turbine B Vibration Trouble) and validated on (local) vibration instrument RFW-VBI-1B/XS/T1BXY (Turbine Radial Inboard Bearing Vibration). Feed pump bias is adjusted to minimize load on RFP B in an attempt to reduce vibration (which is unsuccessful). Vibration level will exceed the DANGER setpoint requiring Reactor Recirculation flow to be incrementally reduced in 1% to 5% step changes while monitoring vibration level. Vibration level remains above the DANGER setpoint even after Reactor Recirculation (RRC) flow has been reduced to 74 Mlbm/hr. RFP B is manually tripped per ARP direction. The CRS may direct tripping of RFP B before the flow reduction is complete if equipment damage is a concern. Following the trip, the high vibration annunciator will clear if crew attempts a local reset (TRG-7). As RPV level lowers due to the feed pump trip, both Reactor Recirculation (RRC) Pumps will runback to 30 Hz causing reactor power to stabilize at a lower level of

~68% power.

CGS 2017 NRC Exam Scenario 3 Outline Page 3 of 5

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Event 4 (TRG-4) An earthquake (OBE) causes annunciator 851.S-1 5-1 (Operating Basis Earthquake Exceeded) to alarm. ABN-EARTHQUAKE is entered. Concurrently, a steam leak in the RCIC Pump Room develops resulting in RCIC Equipment Area high temperature alarms. PPM 5.3.1 (Secondary Containment Control) and ABN-HELB (Line Break) are entered on Reactor Building (RB) area high temperature. Crew attempts to isolate steam leak as directed by PPM 5.3.1 (Secondary Containment Control). Control Room notifies plant personnel of safety hazard and directs evacuation of affected areas. Neither RCIC-V-63 (RCIC Steam Supply Inboard Isolation) nor RCIC-V-8 (RCIC Turbine Steam Supply Isolation) will automatically close. Manual attempts to shut RCIC-V-63 and RCIC-V-8 are unsuccessful.

Event 5 CRS enters PPM 5.1.1 (RPV Control) and directs a manual reactor scram before reaching the max safe operating temperature for the RCIC Pump room (CT #1). All control rods fully insert. The CRS may direct a reactor pressure reduction to 500 to 600 psig to reduce leak rate.

Event 6 Three (3) minutes after the scram, Main Steam Line A piping ruptures causing a steam leak in the Main Steam Tunnel along with the failure of MSIV 22A (MS-V-22A) to close. The outboard MSIVs fail to AUTO close due to failure of a logic relay but can be manually closed. The CRS re-enters PPM 5.3.1 (Secondary Containment Control) based on a second un-isolable steam leak in Secondary Containment resulting in high Main Steam Tunnel temperature.

Event 7 The CRS directs entry into PPM 5.1.3 (Emergency RPV Depressurization) once Main Steam Tunnel Temperature exceeds its max safe operating value of 330°F based on two secondary containment areas greater than max safe operating value (CT #2). Seven Safety Relief Valves (ADS preferred) are opened as directed by PPM 5.1.3 (Emergency RPV Depressurization). RPV level will be restored using Condensate Booster Pumps following Emergency Depressurization.

TERMINATION CRITERIA: The scenario will be terminated when an Emergency Depressurization has been performed and RPV level is being controlled in the prescribed band OR as directed by the Examination Team.

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Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Critical Task Determination Measurable Performance Critical Task Safety Significance Cueing Performance Feedback Indicators CT #1 - With reactor If secondary Procedural direction The operator will All control rods will at power and with containment by PPM 5.3.1 (EOP manually scram fully insert.

primary system temperature for Secondary reactor by placing discharging into approaches its Containment Control) Reactor Mode secondary maximum safe Step SC-14 directs Switch in containment, operating value, entering PPM 5.1.1 Shutdown.

manually scram adequate core (which requires reactor before any cooling, containment placing Reactor area exceeds its integrity, safety of Mode Switch in maximum safe personnel, or Shutdown) before operating continued operability any area exceeds its temperature. of equipment required maximum safe to perform EOP operating flowchart actions can temperature.

no longer be assured.

(Ref: PPM 5.0.10 Rev 21, section 8.9.3 k.1))

CT #2 - With a The criteria of "2 or Procedural direction The operator will The valve light primary system more areas" identifies by PPM 5.3.1 (EOP manually open 7 indications for each discharging into the increase in for Secondary Safety Relief of the 7 Safety secondary parameter trend Containment Control) Valves (ADS Relief Valves will containment and as a wide spread Step SC-15 directs preferred) to change from Green area temperature problem which may Emergency emergency lit to Red lit when exceeding maximum pose a direct and Depressurizing depressurize the control switch is safe operating level immediate threat to reactor when a RPV. taken to Open.

in more than one secondary primary system area, initiate containment integrity, (RCIC) is discharging Reactor pressure emergency equipment located in into secondary will lower in depressurization by the secondary containment and two response.

opening seven (7) containment, or more area Safety Relief Valves continued safe temperatures are (ADS preferred). operation of the plant, exceeding their and personnel both on maximum safe and off site. operating level.

(Ref: PPM 5.0.10 Rev 21, section 8.9.3 k.3))

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Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Facility: Columbia Generating Scenario No.: S Op Test No.: 1 Station Examiners: Operators:

The reactor is in Mode 1 at 100% power. RCIC Operability Test surveillance was just completed to satisfy Post Maintenance Testing (PMT) requirements and has been returned to a Standby status and declared operable. RHR-SYS-B was placed in Suppression Pool Cooling three (3) hours ago to Initial Conditions:

restore Suppression Pool temperature following the testing and to satisfy RHR-P-2B PMT requirements. LCO 3.5.1 A.1, LCO 3.6.1.5 A.1, LCO 3.6.2.3 A.1, and RFO 1.6.1.5 A.1 have been entered for RHR-SYS-B being inoperable.

Turnover: Maintain RHR-P-2B in operation for the next three (3) hours to satisfy pump PMT requirements.

Critical Tasks:

Initiate Drywell sprays when Wetwell pressure exceeds 12 psig but prior to exceeding PSP, after verifying CT-1 Drywell parameters are within DSIL and RHR is NOT required for adequate core cooling.

CT-2 Initiate Emergency Depressurization (ED) by opening seven (7) Safety Relief Valves (ADS preferred) after RPV water level reaches TAF (-161 inches) and within 5 minutes of level dropping below TAF.

CT-3 After ED restore and maintain RPV water level above TAF (-161 inches) when low pressure ECCS becomes available for injection.

Event Malf Event Type* Event Description No. No.

I (ATC,SRO) 1 TRG-1 RFW-DPT-4A fails downscale (Tech Spec)

TS (SRO) 2 TRG-2 C (BOP,SRO) RWCU NRHX fouling causes high temperature isolation on RWCU-V-4 3 TRG-3 C (ATC,SRO) CRD-P-1A trips requiring CRD-P-1B to be started 4 TRG-4 TS (SRO) HPCS-P-1 control power failure (Tech Spec) 5 TRG-5 I (ATC,SRO) RRC-FT-14A fails low causing APRM-CHS-1 to trip C (BOP,SRO) 6 TRG-6 SRV MS-RV-2B inadvertently opens (will close upon fuse removal)

R (ATC,SRO)

LOCA from RRC-P-1B suction line requiring manual scram 7 TRG-7 M (ALL)

Spray Wetwell and Drywell (CT #1)

RFW-FIC-620 controller failure with RFW-V-109 failing to open and RFW-8 N/A C (ATC,SRO)

V-112A & B failing to open once closed 9 N/A C (BOP) RCIC-FIC-600 fails low on startup requiring manual trip of RCIC turbine Initiate Emergency Depressurization (ED) on low RPV level and restore 10 N/A ---

RPV level to above TAF (CT #2) (CT #3)

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor, (TS)Technical Specifications CGS 2017 NRC Exam SPARE Scenario Outline Page 1 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Target Quantitative Attributes Actual Description Malfunctions after EOP entry (1-2)

RFW-FIC-620(1) failure; RFW-V-109(1), 112A(1) & 112B(1) fail (1) Note: 4 of the 5 malfunctions collectively 5 to open; RCIC-FIC-600 output fails low used to prevent RPV feeding via feedwater.

RWCU NRHX fouling; CRD-P-1A trip; SRV MS-RV-2B Abnormal events (2-4) 3 opens Major transients (1-2) 1 LOCA from RRC-P-1B suction line PPM 5.1.1 (RPV Control); PPM 5.2.1 (Primary Containment EOPs entered/requiring substantive actions (1-2) 2 Control)

EOP contingencies requiring substantive actions 1 PPM 5.1.3 (Emergency RPV Depressurization)

(0-2)

Critical tasks (2-3) 3 See Critical Task Determination table Trigger Evaluator How Purpose Malfunction Numbers (TRG-x) Directed Triggered TRG-1 YES Manually Event Initiator XMT-RRS106A TRG-2 YES Manually Event Initiator HTX-RCC010F TRG-3 YES Manually Event Initiator BKR-CRD001 TRG-4 YES Manually Event Initiator BKR-CSS001 TRG-5 YES Manually Event Initiator XMT-RRS036A TRG-6 YES Manually Event Initiator OVR-RRS022D TRG-7 YES Manually Event Initiator MAL-RRS004B TRG-8 Automatically Malf Trigger MAL-RRS004D TRG-9 Automatically Malf Trigger MOV-CFW044F TRG-10 Automatically Malf Trigger MOV-CFW045F TRG-11 YES(2) Manually Malf Trigger BKR-CFW004; BKR-CFW005; BKR-CFW006 (2) Contingency action (see Event 8 description).

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Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station SPARE SCENARIO

SUMMARY

Event 1 (TRG-1) The first event is a failure of RFW-DPT-4A/RFW-LI-606 downscale. The crew performs actions per Alarm Response Procedure (ARP) 603.A8.3-7 and enters ABN-INSTRUMENTATION and ABN-LEVEL. The CRS directs the BOP to verify FWLC system has automatically shifted to Channel B and directs the ATC to place the Reactor Vessel Level Control Channel selector switch to Channel B. The SRO refers to Technical Specifications and determines that LCO 3.3.2.2, action A.1 applies which requires tripping the affected channel within 7 days.

Event 2 (TRG-2) Reactor Water Cleanup Non-Regenerative Heat Exchanger (RWCU-HX-2A/2B NRHX) fouling causes a rising temperature at the outlet of the NRHX leading to the RWCU filter demineralizers. The crew takes actions per ARP 4.602.A5 6-8 (CLEANUP FLTR INLET TEMP HI) to include monitoring temperature, verifying system lineup, and ensuring proper Reactor Closed Cooling (RCC) flow to the RWCU NRHX exist. When the crew recognizes that the RWCU NRHX outlet temperature is approaching 140°F, and isolation appears imminent, the BOP operator will stop the running RWCU pump (RWCU-P-1A) and close the RWCU Suction Outboard Isolation Motor-Operated Valve (MOV) (RWCU-V-4). The crew may also elect to close the Inboard isolation MOV (RWCU-V-1).

Note that if the crew does not take action to prevent automatic closure of RWCU-V-4 (which occurs at 140°F), RWCU-V-4 will automatically close but the running RWCU pump (RWCU-P-1A) will fail to trip.

The BOP operator will have to manually trip the pump.

Event 3 (TRG-3) Control Rod Drive Pump 1A (CRD-P-1A) inadvertently trips requiring the ATC operator to start CRD-P-1B per ARP H13-P603 A-7 3-8 (CRD CHARGE WATER PRESS LOW). Actions include placing the CRD Flow Controller in Manual, zeroing the output and then starting CRD-P-1B. The controller is then nulled and placed back in Auto and CRD system parameters restored.

Depending on the time required to restore CRD flow, one or more control rod HCU accumulator alarms may come in. If asked, local accumulator pressures will be reported to be 980 psig which is below the alarm setpoint but above the LCO 3.1.5 minimum limit of 940 psig required for operability. No Technical Specification actions will be required.

Event 4 (TRG-4) High Pressure Core Spray (HPCS-P-1) control power fails (fuses blow) due to electrical fault.

The BOP operator refers to ARP 601.A1 6-8 (HIGH PRESSURE CORE SPRAY SYSTEM OUT OF SERVICE). If directed to investigate, the HPCS pump control power fuses are reported as blown. Any attempt to replace fuses will result in fuses again blowing.

With both RHR-SYS-B and HPCS inoperable, the CRS refers to Technical Specifications and determines the following additional actions apply:

• LCO 3.5.1 B.1 - Immediately verify by administrative means that RCIC is operable

• LCO 3.5.1 B.2 - Restore HPCS system to operable status within 14 days

• LCO 3.5.1 C.1 - Restore RHR-SYS-B or HPCS system to operable status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> CGS 2017 NRC Exam SPARE Scenario Outline Page 3 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Event 5 (TRG-5) A downscale failure of Reactor Recirculation Flow Transmitter 14A (RRC-FT-14A) occurs causing Channel 1 of the Average Power Range Monitor (APRM-CHS-1) to trip. With only one (1) vote sent to the 2-out-of-4 voter logic no half-scram or reactor trip signals are generated. The crew takes actions per annunciator 603.A8 3-6 (FLOW REFERENCE OFF NORMAL). The CRS directs the ATC operator to bypass APRM-CHS-1.

With APRM-CHS-1 inoperable (and bypassed), the CRS refers to Technical Specifications and determines that only three (3) APRM channels are required to be operable and that no Technical Specification actions are required.

Event 6 (TRG-6) Non-ADS Safety Relief Valve (SRV) MS-RV-2B inadvertently opens. The crew confirms this by observing at least one of the following: 1) Rise on MS-RV-2B tailpipe temperature on MS-TR-614; 2)

Rising Suppression Pool temperature or level; or 3) Reduction in Main Generator output of ~70 MWe.

The CRS enters ABN-SRV and directs the ATC operator to reduce reactor power to < 90% using Reactor Recirculation (RRC) flow. The BOP attempts to close the SRV using the control switch. The valve will not close requiring the BOP to remove solenoid fuses per Attachment 7.1. Once fuses are removed the SRV closes. Entry into PPM 5.2.1 (Primary Containment Control) will be required if Suppression Pool temperature rises to > 90°F.

Event 7 (TRG-7) A primary leak from the RRC-P-1B suction line occurs. The crew takes actions to identify and isolate the leak per ABN-LEAK which will not be successful. The leak continues to increase until degrading plant parameters require a manual reactor scram. The crew takes actions per PPM 3.3.1 (Reactor Scram), PPM 5.1.1 (RPV Control), and PPM 5.2.1 (Primary Containment Control). The crew initiates Wetwell sprays when Wetwell pressure reaches 2 psig and initiates Drywell sprays when Wetwell pressure exceeds 12 psig but prior to exceeding the Pressure Suppression Pressure (PSP) limit (PPM 5.2.1 Figure F) and after verifying Drywell parameters are within the Drywell Spray Initiation Limit (DSIL)

(PPM 5.2.1 Figure E) and RHR is NOT required for adequate core cooling (CT #1). RHR will be re-aligned from Drywell spray to LPCI injection after emergency depressurization is initiated. Due to a loss of sufficient RPV injection, RPV level continues to lower requiring the crew to emergency depressurize the RPV because sufficient high pressure injections system are not available.

Event 8 Total loss of feedwater injection occurs: Reactor Feedwater Flow Indicating Controller (RFW-FIC-620) output fails low and FWH 6A/6B Bypass Valve (RFW-V-109) fails to open preventing RFW injection into the RPV. RFW-HX-6A & B Discharge to Rx Discharge MOVs (RFW-V-112A & B) fail to open (if attempted) after being initially closed to support feeding with the RFW Flow Control Valves (RFW-FCV-10A/B).

Examiner Note: If the ATC operator fails to close either RFW-V-112A or RFW-V-112B then with specific Examiner direction, Trigger 11 will be entered to cause a trip of all running Condensate Booster pumps to ensure a total loss of feedwater injection occurs which is needed to support Critical Tasks.

Event 9 Reactor Core Isolation Cooling Flow Indicating Controller (RCIC-FIC-600) fails low on RCIC system startup requiring a manual trip of the RCIC turbine.

CGS 2017 NRC Exam SPARE Scenario Outline Page 4 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Event 10 With insufficient high pressure injection sources available, and with RPV level continuing to lower, the CRS enters PPM 5.1.3 (Emergency RPV Depressurization) and initiates emergency depressurization by opening seven (7) Safety Relief Valves (ADS preferred) after RPV water level reaches TAF (-161 inches) and within 5 minutes of level dropping below TAF. (CT #2) RPV level is restored above TAF with low pressure injection sources after emergency depressurization. (CT #3) Wetwell and Drywell sprays can be reinitiated per PPM 5.2.1 when not needed for adequate core cooling.

TERMINATION CRITERIA: The scenario will be terminated when Drywell sprays have been initiated, an Emergency Depressurization has been performed and RPV level is being controlled in the prescribed band OR as directed by the Examination Team.

CGS 2017 NRC Exam SPARE Scenario Outline Page 5 of 6

Appendix D NRC SCENARIO OUTLINE (Rev 0 - 10/24/2016) FORM ES-D-1 Columbia Generating Station Critical Task Determination Measurable Performance Critical Task Safety Significance Cueing Performance Feedback Indicators CT #1 - Initiate Drywell Primary containment Procedural direction The operator Valve position will sprays when Wetwell pressures at or above in PPM 5.2.1 (Primary will manually change and Drywell pressure exceeds 12 specified limits pose a Containment Control - open Drywell spray flow will psig but prior to direct threat to primary step P-7) when spray isolation increase.

exceeding PSP, after containment integrity Wetwell pressure valves.

verifying Drywell and the pressure exceeds 12 psig.

parameters are within suppression function.

DSIL and RHR is NOT required for adequate (Ref: PPM 13.1.1A core cooling. (Classifying the Emergency - Technical Bases) Attachment 4.1 section 3)

CT #2 - Initiate Preclude core damage Procedural direction The operator The valve light Emergency by establishing in PPM 5.1.1 (RPV will manually indications for each Depressurization (ED) conditions that allow Control - step L-15) open 7 Safety of the 7 Safety by opening seven (7) low pressure ECCS when RPV Level Relief Valves Relief Valves will Safety Relief Valves systems to restore cannot be restored (ADS preferred) change from Green (ADS preferred) after water level above TAF and maintained above to emergency lit to Red lit when RPV water level (Safety Limit) -186 inches. depressurize control switch is reaches TAF (-161 the RPV. taken to Open.

inches) and within 5 (Ref: CGS Technical minutes of level Specifications - 2.1.1.3) Reactor pressure dropping below TAF. will lower in response.

CT #3 - After ED Preclude core damage Procedural direction All available low Indication of restore and maintain by establishing in PPM 5.1.1 (RPV pressure ECCS applicable ECCS RPV water level above conditions that allow Control - step L-16) systems are system flow.

TAF (-161 inches) low pressure ECCS which directs aligned to when low pressure systems to restore restoring and restore RPV RPV level rises to ECCS becomes water level above TAF maintaining RPV level level. greater than TAF.

available for injection. (Safety Limit) above -186 inches and ultimately above (Ref: CGS Technical TAF.

Specifications - 2.1.1.3)

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