ML23129A162
| ML23129A162 | |
| Person / Time | |
|---|---|
| Site: | Nine Mile Point  |
| Issue date: | 05/09/2023 |
| From: | Brian Fuller NRC/RGN-I/DORS/OB |
| To: | Alexander M Constellation Energy Generation |
| References | |
| EPID L-2023-OLL-0006 | |
| Download: ML23129A162 (1) | |
Text
ILT221 NRCWrittenExam ApplicantReferencePacket
AC Sources - Operating 3.8.1 NMP2 3.8.1-1 Amendment 91, 109 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:
a.
Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electric Power Distribution System; and b.
Three diesel generators (DGs).
APPLICABILITY:
MODES 1, 2, and 3.
- - - - - - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - - - - - - - -
Division 3 AC electrical power sources are not required to be OPERABLE when High Pressure Core Spray (HPCS) System is inoperable.
ACTIONS
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NOTE - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
LCO 3.0.4.b is not applicable to DGs.
CONDITION REQUIRED ACTION COMPLETION TIME A.
One required offsite circuit inoperable.
A.1 Perform SR 3.8.1.1 for OPERABLE required offsite circuit.
AND 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-2 Amendment 91, 138, 159, 186 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
(continued)
A.2 Declare required feature(s) with no offsite power available inoperable when the redundant required feature(s) are inoperable.
AND A.3 Restore required offsite circuit to OPERABLE status.
24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from discovery of no offsite power to one division concurrent with inoperability of redundant required feature(s) 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR In accordance with the Risk Informed Completion Time Program AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from discovery of both HPCS and Low Pressure Core Spray (LPCS) Systems with no offsite power OR In accordance with the Risk Informed Completion Time Program B.
One required DG inoperable.
B.1 Perform SR 3.8.1.1 for OPERABLE required offsite circuit(s).
AND 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-3 Amendment 91, 138, 159, 186 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B.
(continued)
B.2 Declare required feature(s), supported by the inoperable DG, inoperable when the redundant required feature(s) are inoperable.
AND B.3.1 Determine OPERABLE DG(s) are not inoperable due to common cause failure.
OR B.3.2 Perform SR 3.8.1.2 for OPERABLE DG(s).
AND B.4 Restore required DG to OPERABLE status.
4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> from discovery of an inoperable Division 3 DG OR In accordance with the Risk Informed Completion Time Program AND 14 days OR In accordance with the Risk Informed Completion Time Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-4 Amendment 91, 186 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.
Two required offsite circuits inoperable.
C.1 Declare required feature(s) inoperable when the redundant required feature(s) are inoperable.
AND C.2 Restore one required offsite circuit to OPERABLE status.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from discovery of Condition C concurrent with inoperability of redundant required feature(s) 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR In accordance with the Risk Informed Completion Time Program D.
One required offsite circuit inoperable.
AND One required DG inoperable.
NOTE-------------------
Enter applicable Conditions and Required Actions of LCO 3.8.8, "Distribution Systems - Operating," when Condition D is entered with no AC power source to any division.
D.1 Restore required offsite circuit to OPERABLE status.
OR D.2 Restore required DG to OPERABLE status.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Risk Informed Completion Time Program 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR In accordance with the Risk Informed Completion Time Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-6 Amendment 91, 152, 174 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.2
NOTE ----------------------------
All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.
Verify each required DG starts from standby conditions and achieves:
- a.
In d 10 seconds, voltage t 3950 V for Division 1 and 2 DGs and t 3820 V for Division 3 DG, and frequency t 58.8 Hz for Division 1 and 2 DGs and t 58.0 Hz for Division 3 DG; and
- b.
Steady state voltage t 3950 V and d 4370 V and frequency t 58.8 Hz and d 61.2 Hz.
In accordance with the Surveillance Frequency Control Program*
(continued)
- Following return to OPERABILITY of the HPCS System, the past due Surveillances will be completed by January 18, 2019.
AC Sources - Operating 3.8.1 NMP2 3.8.1-7 Amendment 91, 152, 174, 187 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.3
NOTES-----------------------------
1.
DG loadings may include gradual loading as recommended by the manufacturer.
2.
Momentary transients outside the load range do not invalidate this test.
3.
This Surveillance shall be conducted on only one DG at a time.
4.
This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2.
Verify each required DG is synchronized and loaded and operates for t 60 minutes at a load t 3960 kW and d 4400 kW for Division 1 and 2 DGs, and t 2340 kW and d 2600 kW for Division 3 DG.
In accordance with the Surveillance Frequency Control Program*
SR 3.8.1.4 Verify each required day tank contains t onHhour supply of fuel oil.
In accordance with the Surveillance Frequency Control Program*
SR 3.8.1.5 Check for and remove accumulated water from each required day tank.
In accordance with the Surveillance Frequency Control Program*
SR 3.8.1.6 Verify each required fuel oil transfer subsystem operates to automatically transfer fuel oil from the storage tank to the day tank.
In accordance with the Surveillance Frequency Control Program*
(continued)
- Following return to OPERABILITY of the HPCS System, the past due Surveillances will be completed by January 18, 2019.
AC Sources - Operating 3.8.1 NMP2 3.8.1-8 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.7
NOTES-----------------------------
- 1.
This Surveillance shall not normally be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
- 2.
If performed with DG synchronized with offsite power, it shall be performed within the power factor limit. However if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each required DG rejects a load greater than or equal to its associated single largest post-accident load, and following load rejection, the frequency is d 64.5 Hz for Division 1 and 2 DGs and d 66.75 Hz for Division 3 DG.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-9 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.8
NOTES ---------------------------
- 1.
This Surveillance shall not normally be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
- 2.
If grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each required DG operating within the power factor limit does not trip and voltage is maintained:
- a.
d 4576 V during and following a load rejection of a load t 4400 kW for Division 1 and 2 DGs; and
- b.
d 5824 V during and following a load rejection of a load t 2600 kW for Division 3 DG.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-10 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.9
NOTES ---------------------------
- 1.
All DG starts may be preceded by an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG).
However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated loss of offsite power signal:
- a.
De-energization of emergency buses;
- b.
Load shedding from emergency buses for Divisions 1 and 2 only; and
- c.
DG auto-starts from standby condition and:
- 1.
energizes permanently connected loads in d 13.20 seconds,
- 2.
energizes auto-connected shutdown loads for Division 1 and 2 DGs only, through the associated automatic load sequence time delay
- relays,
- 3.
maintains steady state voltage t 3950 V and d 4370 V,
- 4.
maintains steady state frequency t 58.8 Hz and d 61.2 Hz, and
- 5.
supplies permanently connected and auto-connected shutdown loads for t 5 minutes for Division 1 and 2 DGs and supplies permanently connected shutdown loads for t 5 minutes for Division 3 DG.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-11 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.10
NOTES ---------------------------
- 1.
All DG starts may be preceded by an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1 or 2 (not applicable to Division 3 DG). However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each required DG auto-starts from standby condition and:
- a.
In d 10 seconds after auto-start, achieves voltage t 3950 V for Division 1 and 2 DGs and t 3820 V for Division 3 DG, and frequency t 58.8 Hz for Division 1 and 2 DGs and t 58.0 Hz for Division 3 DG;
- b.
Achieves steady state voltage t 3950 V and d 4370 V and frequency t 58.8 Hz and d 61.2 Hz;
- c.
Operates for t 5 minutes;
- d.
Permanently connected loads remain energized from the offsite power system for Divisions 1 and 2 only; and
- e.
Emergency loads are auto-connected through the associated automatic load sequence time delay relays to the offsite power system for Divisions 1 and 2 only.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-12 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.11
NOTE ----------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify each required DG's automatic trips are bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ECCS initiation signal except:
- a.
Engine overspeed; and
- b.
Generator differential current.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-13 Amendment 91, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.12
NOTES ---------------------------
- 1.
Momentary transients outside the load and power factor ranges do not invalidate this test.
- 2.
This Surveillance shall not normally be performed in MODE 1 or 2 unless the other two DGs are OPERABLE. If either of the other two DGs become inoperable, this Surveillance shall be suspended. However, this surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
- 3.
If grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each required DG operating within the power factor limit operates for t 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />s:
- a.
For t 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded t 4620 kW and d 4840 kW for Division 1 and 2 DGs, and t 2730 kW and d 2860 kW for Division 3 DG; and
- b.
For the remaining hours of the test loaded t 3960 kW and d 4400 kW for Division 1 and 2 DGs, and t 2340 kW and d 2600 kW for Division 3 DG.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-14 Amendment 91, 152, 174 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.13
NOTES ---------------------------
- 1.
This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated t 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> loaded t 3960 kW for Division 1 and 2 DGs, and t 2340 kW for Division 3 DG.
Momentary transients below the load limit do not invalidate this test.
- 2.
All DG starts may be preceded by an engine prelube period.
Verify each required DG starts and achieves:
- a.
In d 10 seconds, voltage t 3950 V for Division 1 and 2 DGs and t 3820 V for Division 3 DG, and frequency t 58.8 Hz for Division 1 and 2 DGs and t 58.0 Hz for Division 3 DG; and
- b.
Steady state voltage t 3950 V and d 4370 V and frequency t 58.8 Hz and d 61.2 Hz.
In accordance with the Surveillance Frequency Control Program*
(continued)
- Following return to OPERABILITY of the HPCS System, the past due Surveillances will be completed by January 18, 2019.
AC Sources - Operating 3.8.1 NMP2 3.8.1-15 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.14
NOTE ----------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG). However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify each required DG:
- a.
Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;
- b.
Transfers loads to offsite power source; and
- c.
Returns to ready-to-load operation.
In accordance with the Surveillance Frequency Control Program SR 3.8.1.15
NOTE ----------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG).
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:
- a.
Returning DG to ready-to-load operation; and
- b.
Automatically energizing the emergency load from offsite power.
In accordance with the Surveillance Frequency Control Program (continued)
AC Sources - Operating 3.8.1 NMP2 3.8.1-16 Amendment 91, 152, 165, 174 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.16
NOTE ----------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify interval between each sequenced load block, for the Division 1 and 2 DGs only, is t 90% of the design interval for each automatic load sequence time delay relay.
In accordance with the Surveillance Frequency Control Program*
(continued)
- Following return to OPERABILITY of the HPCS System, the past due Surveillances will be completed by January 11, 2019.
AC Sources - Operating 3.8.1 NMP2 3.8.1-17 Amendment 91, 133, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.1.17
NOTES ---------------------------
- 1.
All DG starts may be preceded by an engine prelube period.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3 DG).
However, portions of the surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR.
Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal:
- a.
De-energization of emergency buses;
- b.
Load shedding from emergency buses for Divisions 1 and 2 only; and
- c.
DG auto-starts from standby condition and:
- 1.
energizes permanently connected loads in d 10 seconds,
- 2.
for Divisions 1 and 2, energizes auto-connected emergency loads through the associated automatic load sequence time delay relays and for Division 3, energizes auto-connected emergency loads,
- 3.
maintains steady state voltage t 3950 V and d 4370 V,
- 4.
maintains steady state frequency t 58.8 Hz and d 61.2 Hz, and
- 5.
supplies permanently connected and auto-connected emergency loads for t 5 minutes.
In accordance with the Surveillance Frequency Control Program (continued)
DC Sources - Operating 3.8.4 NMP2 3.8.4-1 Amendment 91, 186 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Division 1, Division 2, and Division 3 DC electrical power subsystems shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.
Division 1 or 2 DC electrical power subsystem inoperable.
A.1 Restore Division 1 and 2 DC electrical power subsystems to OPERABLE status.
2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OR In accordance with the Risk Informed Completion Time Program B.
Division 3 DC electrical power subsystem inoperable.
B.1 Declare High Pressure Core Spray System inoperable.
Immediately C.
Required Action and associated Completion Time not met.
C.1 Be in MODE 3.
AND C.2 Be in MODE 4.
12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours
DC Sources - Operating 3.8.4 NMP2 3.8.4-3 Amendment 91, 136, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.6 Verify each required Division 1 and 2 battery charger supplies t 300 amps and the required Division 3 battery charger supplies t 40 amps at t 130 V for t 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
In accordance with the Surveillance Frequency Control Program SR 3.8.4.7
NOTES ---------------------------
- 1.
The modified performance discharge test in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7 provided the modified performance discharge test completely envelops the service test.
- 2.
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3). However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.
In accordance with the Surveillance Frequency Control Program (continued)
DC Sources - Operating 3.8.4 NMP2 3.8.4-4 Amendment 91, 136, 152, 165 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.8.4.8
NOTE ----------------------------
This Surveillance shall not normally be performed in MODE 1, 2, or 3 (not applicable to Division 3).
However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
Verify battery capacity is 80% of the manufacturers rating when subjected to a performance discharge test or a modified performance discharge test.
In accordance with the Surveillance Frequency Control Program AND 12 months when battery shows degradation or has reached 85%
of expected life with capacity
< 100% of manufacturers rating AND 24 months when battery has reached 85% of the expected life with capacity 100% of manufacturers rating
Loss of AC Power RPS Failure Control Room Ind.
Hazard Affecting Safety System M
3 4
5 6
1 Loss of DC Power 2
GENERAL EMERGENCY SITE AREA EMERGENCY ALERT UNUSUAL EVENT RCS Leakage 7
Comm.
MODE 1, 2 or 3 F
Fission Product Barrier Degradation
- Turbine runback > 25% thermal reactor power
- Electric load rejection > 25% full electric load
- Reactor Scram
- ECCS Activation
- Thermal Power oscillations > 10%
Table M2 Significant Transients
- Reactor Power
- RPV Water Level
- RPV Pressure
- Primary Containment Pressure
- Suppression Pool Level
- Suppression Pool Temperature Table M1 Control Room Parameters Table M3 Communication Capabilities System Offsite Onsite NRC X
Gaitronics Hand Held Portable Radio (Station Radio)
X PBX (Conventional Telephone Lines)
Control Room installed satellite phone (non portable)
X X
X X
X X
X CT - Containment FC - Fuel Clad RC - Reactor Coolant System Loss Potential Loss 1
RCS Activity 2
RPV Water Level Coolant activity > 300 µCi/gm Dose Equivalent I-131.
Loss Potential Loss Loss Potential Loss
- 1. It cannot be determined that core debris will be retained in the RPV.
None 2.
RPV water level cannot be restored and maintained > -14 inches (TAF).
OR 3.
RPV water level cannot be determined.
1.
RPV water level cannot be restored and maintained > -14 inches (TAF).
OR 2.
RPV water level cannot be determined.
It cannot be determined that core debris will be retained in the RPV.
3 Primary Containment Pressure /
Conditions 1.
a.
Primary Containment pressure > 1.68 psig.
AND b.
Primary Containment pressure rise is due to RCS leakage.
1.
UNPLANNED rapid drop in Primary Containment pressure following Primary Containment pressure rise.
OR 2.
Primary Containment pressure response not consistent with LOCA conditions.
3.
Primary Containment pressure
> 45 psig.
OR 4.
a.
Primary Containment hydrogen concentration > 6%.
AND b.
Primary Containment oxygen concentration > 5%.
OR 5.
Heat Capacity Temperature Limit (HCTL) (N2-EOP-PC (1-3) Figure M) exceeded.
4 RCS Leak Rate 5
Primary Containment Radiation 6
Primary Containment Isolation Failure 7
Emergency Director Judgement 1.
UNISOLABLE Main Steam line (MSL),
RCIC, Feedwater, or WCS line break.
OR 2.
RPV Blowdown is required.
3.
UNISOLABLE primary system leakage that results in EITHER of the following:
a.
RB area temperature above an isolation setpoint.
OR b.
RB area radiation monitor above an alarm setpoint.
Drywell area radiation monitor reading
> 1.4 E+03 R/hr (1.4 E+06 mR/hr).
Drywell radiation reading
> 100 R/hr (1.0 E+05 mR/hr).
Drywell radiation reading
> 1.4 E+04 R/hr (1.4 E+07 mR/hr).
1.
UNISOLABLE direct downstream pathway to the environment exists after Primary Containment Isolation signal.
OR 2.
Intentional Primary Containment venting/purging per EOPs or SAPs due to accident conditions.
OR 3.
UNISOLABLE primary system leakage that results in EITHER of the following:
- a. Exceeding RB area temperature Maximum Safe Value (N2-EOP-SC/RR (1-3) Detail S).
- b. RB area radiation
> 8.00 E+03 mR/hr.
1.
ANY condition in the opinion of the Emergency Director that indicates Loss of the Fuel Clad barrier.
2.
ANY condition in the opinion of the Emergency Director that indicates Potential Loss of the Fuel Clad barrier.
1.
ANY condition in the opinion of the Emergency Director that indicates Loss of the RCS barrier.
2.
ANY condition in the opinion of the Emergency Director that indicates Potential Loss of the RCS barrier.
1.
ANY condition in the opinion of the Emergency Director that indicates Loss of the Containment barrier.
2.
ANY condition in the opinion of the Emergency Director that indicates Potential Loss of the Containment barrier.
Bases: 2-51 Bases: 2-51 Bases: 2-50 Bases: 2-55 Bases: 2-64 Bases: 2-57 Bases: 2-64 Bases: 2-58 Bases: 2-58 Bases: 2-66 Bases: 2-61 Bases: 2-53 Bases: 2-67 Bases: 2-70 Bases: 2-70 Bases: 2-62 Bases: 2-62 Bases: 2-54 Bases: 2-54 Bases: 2-63 None None None None None None None None None None None None None None None None None None None None None Fission Product Barrier Matrix
`
Loss of ANY two barriers AND Loss or Potential Loss of third barrier.
Loss or Potential Loss of ANY two barriers.
ANY Loss or ANY Potential Loss of either Fuel Clad or RCS.
None FG1 Bases: 2-47 FA1 Bases: 2-49 FS1 Bases: 2-48 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D 1.
Loss of ALL offsite and onsite AC power to 4.16 kV emergency buses 2ENS*SWG101 and 2ENS*SWG103.
AND 2.
EITHER of the following:
a.
Restoration of at least one 4.16 kV emergency bus 2ENS*SWG101 or 2ENS*SWG103 in < 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is not likely.
OR b.
RPV water level cannot be restored and maintained > -39 inches.
MU1 Bases: 2-77 1.
Loss of ALL offsite and onsite AC power to 4.16 kV emergency buses 2ENS*SWG101 and 2ENS*SWG103.
AND 2.
Failure to restore power to at least one 4.16 kV emergency bus 2ENS*SWG101 or 2ENS*SWG103 in < 15 minutes from the time of loss of both offsite and onsite AC power.
1.
AC power capability to 4.16 kV emergency buses 2ENS*SWG101 and 2ENS*SWG103 reduced to only one of the following power sources for > 15 minutes:
Reserve Transformer A Reserve Transformer B Aux Boiler Transformer 2EGS*EG1 2EGS*EG3 2EGS*EG2 AND 2.
ANY additional single power source failure will result in a loss of ALL AC power to SAFETY SYSTEMS.
Loss of ALL offsite AC power capability to 4.16 kV emergency buses 2ENS*SWG101 and 2ENS*SWG103 for > 15 minutes:
Reserve Transformer A Reserve Transformer B Aux Boiler Transformer MA1 Bases: 2-75 MS1 Bases: 2-73 MG1 Bases: 2-71 Prolonged loss of all offsite and all onsite AC power to emergency buses.
Loss of all offsite and onsite AC power to emergency buses for 15 minutes or longer.
Loss of all but one AC power source to emergency buses for 15 minutes or longer.
Loss of all offsite AC power capability to emergency buses for 15 minutes or longer.
See Note: A See Note: A See Note: A See Note: A 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D Voltage is < 105 VDC on 2BYS*SWG002A and 2BYS*SWG002B for > 15 minutes.
1.
Loss of ALL offsite and onsite AC power to 4.16 kV emergency buses 2ENS*SWG101 and 2ENS*SWG103.
AND 2.
Voltage is < 105 VDC on Vital DC buses 2BYS*SWG002A and 2BYS*SWG002B.
AND 3.
ALL AC and Vital DC power sources in EALs #1 and #2 (excluding Division 3) have been lost for > 15 minutes.
MS2 Bases: 2-80 MG2 Bases: 2-78 None None Loss of all AC and Vital DC power sources for 15 minutes or longer.
Loss of all Vital DC power for 15 minutes or longer.
See Note: A See Note: A 1
2 3
4 5
D 1
2 3
4 5
D 1.
Automatic scram did not shutdown the reactor as indicated by Reactor Power > 4%.
AND 2.
ALL manual / ARI actions to shutdown the reactor have been unsuccessful as indicated by Reactor Power > 4%.
AND 3.
EITHER of the following conditions exist:
RPV water level cannot be restored and maintained > -39 inches.
OR Heat Capacity Temperature Limit (HCTL)
(N2-EOP-PC (1-3) Figure M) exceeded.
1.
Automatic or manual scram did not shutdown the reactor as indicated by Reactor Power > 4%.
AND 2.
Manual / ARI actions taken at the Reactor Control Console are not successful in shutting down the reactor as indicated by Reactor Power > 4%.
1.
a.
Automatic scram did not shutdown the reactor as indicated by Reactor Power > 4%.
AND b.
Subsequent manual / ARI action taken at the Reactor Control Console is successful in shutting down the reactor as indicated by Reactor Power < 4%.
OR 2.
a.
Manual scram did not shutdown the reactor as indicated by Reactor Power > 4%.
AND b.
EITHER of the following:
- 1. Subsequent manual / ARI action taken at the Reactor Control Console is successful in shutting down the reactor as indicated by Reactor Power < 4%.
- 2. Subsequent automatic scram / ARI is successful in shutting down the reactor as indicated by Reactor Power < 4%.
MS3 Bases: 2-81 MA3 Bases: 2-83 MU3 Bases: 2-85 None Inability to shutdown the reactor causing a challenge to RPV water level or RCS heat removal.
Automatic or manual scram fails to shutdown the reactor, and subsequent manual actions taken at the Reactor Control Console are not successful in shutting down the reactor.
Automatic or manual scram fails to shutdown the reactor.
See Note: G See Note: G 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D 1.
ANY Table M1 parameter cannot be determined from within the Control Room for > 15 minutes due to an UNPLANNED event.
AND 2.
ANY Table M2 transient in progress.
ANY Table M1 parameter cannot be determined from within the Control Room for > 15 minutes due to an UNPLANNED event.
MA4 Bases: 2-88 MU4 Bases: 2-90 UNPLANNED loss of Control Room indications for 15 minutes or longer with a significant transient in progress.
UNPLANNED loss of Control Room indications for 15 minutes or longer.
See Note: A See Note: A 1
2 3
4 5
D 1
2 3
4 5
D MA5 Bases: 2-92 Hazardous event affecting a SAFETY SYSTEM required for the current operating mode.
See Notes: H, J, K 1
2 3
4 5
D 1.
RCS unidentified or pressure boundary leakage in the Drywell
> 10 gpm for > 15 minutes.
OR 2.
RCS identified leakage in the Drywell > 25 gpm for > 15 minutes.
OR 3.
Leakage from the RCS to a location outside the Drywell
> 25 gpm for > 15 minutes.
MU6 Bases: 2-95 RCS leakage for 15 minutes or longer.
See Note: A 1
2 3
4 5
D 1.
Loss of ALL Table M3 onsite communication capabilities affecting the ability to perform routine operations.
OR 2.
Loss of ALL Table M3 offsite communication capabilities affecting the ability to perform offsite notifications.
OR 3.
Loss of ALL Table M3 NRC communication capabilities affecting the ability to perform NRC notifications.
MU7 Bases: 2-97 Loss of all onsite or offsite communication capabilities.
1 2
3 4
5 D
System Malfunctions Onsite Rad Conditions Spent Fuel Events Abnormal Radiation Levels \ Radiological Effluents R
2 Offsite Rad Conditions 1
3 GENERAL EMERGENCY SITE AREA EMERGENCY ALERT UNUSUAL EVENT SFP /
Refueling Pathway Level RU1 Bases: 2-33 RA1 Bases: 2-30 RS1 Bases: 2-28 RG1 Bases: 2-26 1
2 3
4 5
D Release of gaseous radioactivity resulting in offsite dose greater than 1,000 mRem TEDE or 5,000 mRem CDE thyroid.
Release of gaseous radioactivity resulting in offsite dose greater than 100 mRem TEDE or 500 mRem CDE thyroid.
Release of gaseous or liquid radioactivity resulting in offsite dose greater than 10 mRem TEDE or 50 mRem CDE thyroid.
Release of gaseous or liquid radioactivity greater than 2 times the ODCM limits for 60 minutes or longer.
See Notes: A, B, C, D See Notes: A, B, C, D See Notes: A, B, C, D See Notes: A, C, E Table R1 Effluent Monitor Thresholds Monitor General Emergency Site Area Emergency Alert Unusual Event Radwaste/RB Vent Effluent (2RMS-PNL180C) 4.80 E+06 µCi/sec 1.69 E+05 µCi/sec Main Stack Effluent (2RMS-PNL170C) 7.12 E+05 µCi/sec 4.80 E+07 µCi/sec 4.80 E+05 µCi/sec 1.02 E+09 µCi/sec 1.02 E+10 µCi/sec 1.02 E+11 µCi/sec 1.
Readings on ANY Table R1 Effluent Monitor > Table R1 value for > 15 minutes.
OR 2.
Dose assessment using actual meteorology indicates doses at or beyond the site boundary of EITHER:
Field survey results at or beyond the site boundary indicate EITHER:
- a. Gamma (closed window) dose rates > 1000 mR/hr are expected to continue for > 60 minutes.
- b. Analyses of field survey samples indicate
> 5000 mRem CDE Thyroid for 60 minutes of inhalation.
1.
Reading on the Liquid Radwaste Effluent Monitor (LWS-RE206)
> 2 times DRMS High (red) established by a current radioactive release discharge permit for > 60 minutes.
OR 2.
Readings on ANY Table R1 Effluent Monitor > Table R1 value for > 60 minutes.
OR 3.
Confirmed sample analyses for gaseous or liquid releases indicate concentrations or release rates > 2 times ODCM Limit with a release duration of > 60 minutes.
1.
Readings on ANY Table R1 Effluent Monitor > Table R1 value for > 15 minutes.
OR 2.
Dose assessment using actual meteorology indicates doses at or beyond the site boundary of EITHER:
Analysis of a liquid effluent sample indicates a concentration or release rate that would result in doses greater than EITHER of the following at or beyond the site boundary:
Field survey results at or beyond the site boundary indicate EITHER:
- a. Gamma (closed window) dose rates > 10 mR/hr are expected to continue for > 60 minutes.
- b. Analyses of field survey samples indicate > 50 mRem CDE Thyroid for 60 minutes of inhalation.
1.
Readings on ANY Table R1 Effluent Monitor > Table R1 value for > 15 minutes.
OR 2.
Dose assessment using actual meteorology indicates doses at or beyond the site boundary of EITHER:
Field survey results at or beyond the site boundary indicate EITHER:
- a. Gamma (closed window) dose rates > 100 mR/hr are expected to continue for > 60 minutes.
- b. Analyses of field survey samples indicate
> 500 mRem CDE Thyroid for 60 minutes of inhalation.
1 2
3 4
5 D
1 2
3 4
5 D
1 2
3 4
5 D
1.
a.
UNPLANNED water level drop in the REFUELING PATHWAY as indicated by ANY of the following:
Inability to restore and maintain Spent Fuel Pool water level > low water level alarm.
OR Indication or report of a drop in water level in the REFUELING PATHWAY.
AND b.
UNPLANNED Area Radiation Monitor reading rise on ANY Table R2 radiation monitor.
1.
Uncovery of irradiated fuel in the REFUELING PATHWAY.
OR 2.
Damage to irradiated fuel resulting in a release of radioactivity from the fuel as indicated by ANY Table R2 Radiation Monitor Alarm.
OR 3.
Lowering of spent fuel pool level to 340 feet as indicated on 2SFC-LI413A or B.
Lowering of spent fuel pool level to 330 feet as indicated on 2SFC-LI413A or B.
Spent fuel pool level cannot be restored to at least 330 feet as indicated on 2SFC-LI413A or B for > 60 minutes.
RG2 Bases: 2-36 RS2 Bases: 2-37 RA2 Bases: 2-38 RU2 Bases: 2-41 Spent fuel pool level cannot be restored to at least 330 feet for 60 minutes or longer.
Spent fuel pool level at 330 feet.
Significant lowering of water level above, or damage to, irradiated fuel.
UNPLANNED loss of water level above irradiated fuel.
See Note: A 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D 1.
Dose rate > 15 mR/hr in ANY of the areas in Table R3.
OR 2.
UNPLANNED event results in radiation levels that prohibit or significantly impede access to ANY of the areas in Table R4.
RA3 Bases: 2-43 RU3 Bases: 2-46 1.
Offgas radiation DRMS high (red) alarm for > 15 minutes.
OR 2.
Specific coolant activity > 4.0 µCi/gm Dose Equivalent I-131.
Table R4 Areas with Entry Related Mode Applicability Area Entry Related Mode Applicability Reactor Building 175 RHS A Pump Room (RHR A) 196 Az 56 Deg (RHR A) 175 RHS B Pump Room (RHR A & B)
Control Building Mode 3, 4, and 5 261 Div 1 Switchgear Room (RHR A & B) 261 Div 2 Switchgear Room (RHR A & B)
Table R2 Refuel Floor Radiation Monitors
- 2HVR*RE14A
- 2HVR*RE14B Table R3 Areas Requiring Continuous Occupancy
- Main Control Room
- Central Alarm Station - (by survey)
Radiation levels that impede access to equipment necessary for normal plant operations, cooldown or shutdown.
Reactor coolant activity greater than Technical Specification allowable limits.
See Note: F 1
2 3
4 5
D 1
2 3
4 5
D Hazards & Other Conditions Affecting Plant Safety H
Hostile Action Fire Toxic Gas Earthquake Judgment 1
2 3
4 5
6 Transfer of Plant Control 7
Hazardous Event ISFSI E
A notification from the Security Supervisor that a HOSTILE ACTION is occurring or has occurred within the PROTECTED AREA.
1.
A validated notification from NRC of an aircraft attack threat
< 30 minutes from the site.
OR 2.
Notification by the Security Supervisor that a HOSTILE ACTION is occurring or has occurred within the OWNER CONTROLLED AREA.
1.
Notification of a credible security threat directed at the site as determined per SY-AA-101-132, Security Assessment and Response to Unusual Activities.
OR 2.
A validated notification from the NRC providing information of an aircraft threat.
OR 3.
Notification by the Security Supervisor of a SECURITY CONDITION that does not involve a HOSTILE ACTION.
1.
A FIRE in ANY Table H2 area is not extinguished in < 15 minutes of ANY of the following FIRE detection indications:
Report from the field (i.e., visual observation)
Receipt of multiple (more than 1) fire alarms or indications Field verification of a single fire alarm OR 2.
a.
Receipt of a single fire alarm in ANY Table H2 area (i.e., no other indications of a FIRE).
AND b.
The existence of a FIRE is not verified in < 30 minutes of alarm receipt.
OR 3.
A FIRE within the plant PROTECTED AREA not extinguished in
< 60 minutes of the initial report, alarm or indication.
OR 4.
A FIRE within the plant PROTECTED AREA that requires firefighting support by an offsite fire response agency to extinguish.
1.
Release of a toxic, corrosive, asphyxiant or flammable gas in ANY Table H3 area.
AND 2.
Entry into the room or area is prohibited or impeded.
Other conditions exist which in the judgment of the Emergency Director indicate that events are in progress or have occurred which involve actual or IMMINENT substantial core degradation or melting with potential for loss of containment integrity or HOSTILE ACTION that results in an actual loss of physical control of the facility. Releases can be reasonably expected to exceed EPA Protective Action Guideline exposure levels offsite for more than the immediate site area.
Other conditions exist which in the judgment of the Emergency Director indicate that events are in progress or have occurred which involve actual or likely major failures of plant functions needed for protection of the public or HOSTILE ACTION that results in intentional damage or malicious acts, (1) toward site personnel or equipment that could lead to the likely failure of or, (2) that prevent effective access to equipment needed for the protection of the public. Any releases are not expected to result in exposure levels which exceed EPA Protective Action Guideline exposure levels beyond the site boundary.
Other conditions exist which, in the judgment of the Emergency Director, indicate that events are in progress or have occurred which involve an actual or potential substantial degradation of the level of safety of the plant or a security event that involves probable life threatening risk to site personnel or damage to site equipment because of HOSTILE ACTION. Any releases are expected to be limited to small fractions of the EPA Protective Action Guideline exposure levels.
Other conditions exist which in the judgment of the Emergency Director indicate that events are in progress or have occurred which indicate a potential degradation of the level of safety of the plant or indicate a security threat to facility protection has been initiated. No releases of radioactive material requiring offsite response or monitoring are expected unless further degradation of safety systems occurs.
HS1 Bases: 2-127 HA1 Bases: 2-129 HU1 Bases: 2-132 HU3 Bases: 2-137 HU4 Bases: 2-141 HA5 Bases: 2-144 HU6 Bases: 2-147 HG7 Bases: 2-150 HS7 Bases: 2-151 HA7 Bases: 2-152 HU7 Bases: 2-153 E-HU1 Bases: 2-154
`
Notes A.
The Emergency Director should declare the event promptly upon determining that the applicable time has been exceeded, or will likely be exceeded.
B.
If an ongoing release is detected and the release start time is unknown, assume that the release duration has exceeded 15 minutes.
C.
Classification based on effluent monitor readings assumes that a release path to the environment is established. If the effluent flow past an effluent monitor is known to have stopped due to actions to isolate the release path, then the effluent monitor reading is no longer valid for classification purposes.
D.
The pre-calculated effluent monitor values presented in EAL #1 (Table R1) should be used for emergency classification assessments until the results from a dose assessment using actual meteorology are available.
E.
If an ongoing release is detected and the release start time is unknown, assume that the release duration has exceeded 60 minutes.
F.
If the equipment in the room or area listed in Table R4 was already inoperable, or out of service, before the event occurred, then no emergency classification is warranted.
G.
A manual action is any operator action, or set of actions, which causes the control rods to be rapidly inserted into the core. This action does not include manually driving in control rods or implementation of boron injection strategies.
H.
If the affected SAFETY SYSTEM train was already inoperable before the hazardous event occurred, then this emergency classification is not warranted.
J.
If the hazardous event only resulted in VISIBLE DAMAGE, with no indications of degraded performance to at least one train of a SAFETY SYSTEM, then this emergency classification is not warranted.
K.
If a hazardous event occurs and it is determined that the conditions of MA5 are not met then assess the event via HU3, HU4, or HU6.
L.
Escalation of the emergency classification level would be via IC CA2 or MA5.
M. For emergency classification if EAL #2.b is not able to be confirmed, then the occurrence of a seismic event is confirmed in a manner deemed appropriate by the Shift Manager or Emergency Director in < 15 minutes of the event.
N.
If the equipment in the listed room or area was already inoperable, or out of service, before the event occurred, then no emergency classification is warranted.
P.
EAL #4 does not apply to routine traffic impediments such as fog, snow, ice, or vehicle breakdowns or accidents.
HOSTILE ACTION within the PROTECTED AREA.
HOSTILE ACTION within the OWNER CONTROLLED AREA or airborne attack threat within 30 minutes.
Confirmed SECURITY CONDITION or threat.
Other conditions exist which in the judgment of the Emergency Director warrant declaration of a GENERAL EMERGENCY.
Other conditions exist which in the judgment of the Emergency Director warrant declaration of a SITE AREA EMERGENCY.
Other conditions exist which in the judgment of the Emergency Director warrant declaration of an ALERT.
Other conditions exist which in the judgment of the Emergency Director warrant declaration of an UNUSUAL EVENT.
Gaseous release impeding access to equipment necessary for normal plant operations, cooldown or shutdown.
Hazardous Event Seismic event greater than OBE levels.
FIRE potentially degrading the level of safety of the plant.
Damage to a loaded cask CONFINEMENT BOUNDARY.
See Notes: A, L See Notes: L, M See Note: N See Notes: L, P None None None None
- Reactivity Control (ability to shutdown the reactor and keep it shutdown)
- RPV Water Level (ability to cool the core)
- RCS Heat Removal (ability to maintain a heat sink)
Table H1 Safety Functions None 1
2 3
4 5
D 1
2 3
4 5
D 1
2 3
4 5
D A Control Room evacuation has resulted in plant control being transferred from the Control Room to alternate locations per N2-SOP-78, Control Room Evacuation.
1.
A Control Room evacuation has resulted in plant control being transferred from the Control Room to alternate locations per N2-SOP-78, Control Room Evacuation.
AND 2.
Control of ANY Table H1 key safety function is not reestablished in < 15 minutes.
HA2 Bases: 2-136 HS2 Bases: 2-134 Inability to control a key safety function from outside the Control Room.
Control Room evacuation resulting in transfer of plant control to alternate locations.
See Note: A 1
2 3
4 5
D 1
2 3
4 5
D Reactor Building (when inerted the Drywell is exempt)
Control Room Relay Room Diesel Generator Engine and Board Rooms Standby Switchgear and Battery Rooms HPCS Switchgear and Battery Rooms Remote Shutdown Rooms Control Building HVAC Rooms Electrical Protection Assembly Room Service Water Pump Rooms Table H2 Areas
`
1 2
3 4
5 D
Table H3 Areas with Entry Related Mode Applicability Area Entry Related Mode Applicability Reactor Building 175 RHS A Pump Room (RHR A) 196 Az 56 Deg (RHR A) 175 RHS B Pump Room (RHR A & B)
Control Building Modes 3, 4 and 5 261 Div 1 Switchgear Room (RHR A & B) 261 Div 2 Switchgear Room (RHR A & B) 1 2
3 4
5 D
Seismic event as indicated by:
1.
Seismic event > Operating Basis Earthquake (OBE) as indicated by:
Computer Point ERSNC02, OBE Detected OR ANY amber LED light lit at the Seismic Monitor Panel, Response Spectrum Annunciator.
OR 2.
When Seismic Monitoring Equipment is not available:
a.
Control Room personnel feel an actual or potential seismic event.
AND b.
ANY one of the following confirmed in < 15 minutes of the event:
The earthquake resulted in Modified Mercalli Intensity (MMI)
> VI and occurred < 3.5 miles of the plant.
The earthquake was magnitude > 6.0 The earthquake was magnitude > 5.0 and occurred
< 125 miles from the plant.
If the above bullets are not able to be confirmed, then the occurrence of a seismic event is confirmed in manner deemed appropriate by the Shift Manager or Emergency Director.
1 2
3 4
5 D
1.
Tornado strike within the PROTECTED AREA.
OR 2.
Internal room or area flooding of a magnitude sufficient to require manual or automatic electrical isolation of a SAFETY SYSTEM component required by Technical Specifications for the current operating mode.
OR 3.
Movement of personnel within the PROTECTED AREA is impeded due to an offsite event involving hazardous materials (e.g., an offsite chemical spill or toxic gas release).
OR 4.
A hazardous event that results in on-site conditions sufficient to prohibit the plant staff from accessing the site via personal vehicles.
OR 5.
Intake water level < 237 feet.
1 2
3 4
5 D
1 2
3 4
5 D
1 2
3 4
5 D
1 2
3 4
5 D
1 2
3 4
5 D
Modes:
1 Power Operation 2
Startup Defueled D
4 Cold Shutdown Hot Shutdown 3
Refueling 5
Nine Mile Point Nuclear Station Unit 2 EP-AA-1013 Addendum 4, Appendix 1 Revision 02 - April 2021 NMP Unit 2 EAL Wallboard Page 1 of 2 HOT MATRIX This EAL is only applicable to SAFETY SYSTEMs having two (2) or more trains.
1.
a.
The occurrence of ANY of the following hazardous events:
Seismic event (earthquake)
Internal or external flooding event High winds or tornado strike FIRE EXPLOSION Other events with similar hazard characteristics as determined by the Shift Manager AND b.
Event damage has caused indications of degraded performance to one train of a SAFETY SYSTEM required by Technical Specifications for the current operating mode.
AND c.
EITHER of the following:
Event damage has caused indications of degraded performance to a second train of the SAFETY SYSTEM required by Technical Specifications for the current operating mode.
OR Event damage has resulted in VISIBLE DAMAGE to a second train of the SAFETY SYSTEM required by Technical Specifications for the current operating mode.
None None None None None None None None None None None None CR / CAS Radiation OR Fuel Clad Degradation Damage to a loaded cask CONFINEMENT BOUNDARY as indicated by exceeding ANY Table E1 radiation reading.
Table E1 Radiation Readings Hi-Storm Multipurpose Canister Storage System Hi-Storm Overpack Hi-Storm Transfer Cask 60 mrem/hr (gamma + neutron) on the top of the Overpack 600 mrem/hr (gamma + neutron) on the side of the Overpack, excluding inlet and outlet ducts 7000 mrem/hr (gamma + neutron) on the side of the Transfer Cask None Cask Type Amendment 10 Amendment 14 - HSM Amendment 14 - HSM-H Labeled 61BT Labeled 61BTH - Type 1
> 800 mrem/hr 3 feet from the HSM surface OR
> 200 mrem/hr outside the HSM door on centerline of DSC OR
> 40 mrem/hr end of shield wall exterior
> 1400 mrem/hr on the HSM or HSM-H front surface OR
> 200 mrem/hr on the HSM or HSM-H door centerline OR
> 40 mrem/hr on the end shield wall exterior
> 400 mrem/hr on the HSM front surface OR
> 200 mrem/hr on the HSM door OR
> 30 mrem/hr on the end shield wall exterior
> 1350 mrem/hr on the HSM-H front surface OR
> 4 mrem/hr on the HSM-H door OR
> 40 mrem/hr on the end shield wall exterior None None 1
2 3
4 5
D