ML15174A244
| ML15174A244 | |
| Person / Time | |
|---|---|
| Site: | Oconee  |
| Issue date: | 06/23/2015 |
| From: | NRC/RGN-II |
| To: | Duke Energy Corp |
| References | |
| 50-269/15-301, 50-270/15-301, 50-287/15-301 50-269/15-301, 50-270/15-301, 50-287/15-301 | |
| Download: ML15174A244 (325) | |
Text
Oconee Nuclear Station Question: 1 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor trip has just occurred from 100% power CR GP 5 Rod 5 remained fully withdrawn Reactor power is less than 1 percent and decreasing
- 1) As the remainder of the control rods fully inserted, the startup rate would have been
____(1)____ before stabilizing at - 1/3 DPM while power decreases towards the source range.
- 2) EOP subsequent actions ____(2)____ direct boration from the BWST.
Which ONE of the following completes the statements above?
A. 1. greater than -1/3 DPM (more negative)
- 2. does B. 1. greater than -1/3 DPM (more negative)
- 2. does NOT C. 1. less than -1/3 DPM (less negative)
- 2. does D. 1. less than -1/3 DPM (less negative)
- 2. does NOT Page 1 of 100
Oconee Nuclear Station Question: 2 ILT 47 ONS SRO NRC Examination (1 point)
Unit 1 plant conditions:
Reactor Power =100%
1SA-18, A/1 PRESSURIZER RELIEF VALVE FLOW alarms RCS pressure = 2200 psig decreasing 1RC-66 indicates partially open 1RC-4 will not close from the control room
____(1)____ will be entered which will dispatch an operator to open 1DIB Breaker # 24 to fail ____(2)____ closed.
Which ONE of the following completes the statement above?
A. 1. AP/2, (Excessive RCS Leakage)
- 2. 1RC-4 C. 1. AP/44, (Abnormal Pressurizer Pressure Control)
- 2. 1RC-66 D. 1. AP/44, (Abnormal Pressurizer Pressure Control)
- 2. 1RC-4 Page 2 of 100
Oconee Nuclear Station Question: 3 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0400 Reactor Trip from 100%
SBLOCA has occurred Rule 2 (Loss of SCM) in progress 1A and 1B MD EFDWPs are operating Time = 0410 Rule 7 (SG Feed Control) in progress RCS temperature = 470°F slowly decreasing EFW flow = 100 gpm to each SG 1A and 1B SG levels = 85 XSUR stable
- 1) At 0400, in accordance with Rule 2, __ (1) __ gpm EFDW flow will initially be established to each SG.
- 2) At 0410, in accordance with Rule 7 (SG Feed Control), EFDW flow should be
__ (2) __.
Which ONE of the following completes the statements above?
A. 1. 300
- 2. decreased B. 1. 300
- 2. increased C. 1. 450
- 2. decreased D. 1. 450
- 2. increased Page 3 of 100
Oconee Nuclear Station Question: 4 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800:
Reactor power = 100%
LBLOCA occurs Time = 0810:
RCS Pressure = 200 psig decreasing HPI Flow in 1A Header = 750 gpm HPI Flow in 1B Header = 490 gpm Which ONE of the following describes the required operator actions per Rule 6 HPI PUMP THROTTLING LIMITS, to protect the HPI pumps?
A. Throttle each HPI pump flow to <475 gpm B. Throttle HPI flow in ONLY 1A header to <750 gpm C. Throttle HPI flows in BOTH 1A & 1B headers to <950 gpm combined D. Throttle HPI flow in ONLY 1B header to <475 gpm Page 4 of 100
Oconee Nuclear Station Question: 5 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial Conditions Core Thermal Power = 100%.
Current conditions:
A Station Blackout occurs at 0600.
AP/0/A/1700/025 (Standby Shutdown Facility Emergency Operating Procedure) has been initiated.
1XSF is being powered from 0XSF.
- 1) In accordance with station Time Critical Actions, SSF RCMU flow must be established to Unit 1 RCP seals no later than ___(1)___.
Which ONE of the following completes the statements above?
A. 1. 0614
- 2. can B. 1. 0620
- 2. can C. 1. 0614
- 2. cannot D. 1. 0620
- 2. cannot Page 5 of 100
Oconee Nuclear Station Question: 6 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200 Reactor power = 80%
1HP-120 (RC VOLUME CONTROL) FAILED CLOSED Makeup flow has been re-established in accordance with AP/14 (Loss of Normal HPI Makeup and/or RCP Seal Injection)
Time = 1215 Pressurizer level is 220 stable
- 1) In accordance with AP/14, ____(1)____ was throttled first to maintain Pzr level.
- 2) If 1RC-1 subsequently fails open at Time = 1220, prior to any Operator actions RCS makeup flow will ____(2)____.
Which ONE of the following completes the statements above?
A. 1. 1HP-26 (1A HP INJECTION)
- 2. decrease C. 1. 1HP-122 (RC VOLUME CONTROL BYPASS)
- 2. increase D. 1. 1HP-122 (RC VOLUME CONTROL BYPASS)
- 2. decrease Page 6 of 100
Oconee Nuclear Station Question: 7 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions Reactor power = 100%
The running CC pump trips AP/20 LOSS OF COMPONENT COOLING has been entered 2 minutes have elapsed CC Surge Tank level = 10 NO automatic actions occur
- 1) Assuming that no operator actions are taken during the first 2 minutes of the event,
____(1)____.
- 2) Based on the above plant conditions, AP/20 ____(2)____ direct the operator to start the standby CC pump.
Which ONE of the following completes the statements above?
A. 1. CRDM temperatures will have increased to the point at which damage has occurred to the stator windings
- 2. will B. 1. CRDM temperatures will have increased to the point at which damage has occurred to the stator windings
- 2. will NOT C. 1. Demineralizer temperatures will have increased to the point at which damage has occurred to the demineralizer resin
- 2. will D. 1. Demineralizer temperatures will have increased to the point at which damage has occurred to the demineralizer resin
- 2. will NOT Page 7 of 100
Oconee Nuclear Station Question: 8 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
RCS pressure = 2360 psig increasing Current conditions:
Reactor power = 7% decreasing
- 1) With Reactor power decreasing, the MINIMUM power level at which Rule 1 (ATWS/UNPP) is required to be performed to address Emergency Boration is
__(1)__.
- 2) The reason this power level is chosen is so the Boron will reduce reactor power to
__ (2) __.
Which ONE of the following completes the statements above?
A. 1. 1%
- 2. below the point of adding heat B. 1. 1%
- 2. within the capacity of the EFDW system C. 1. 5%
- 2. below the point of adding heat D. 1. 5%
- 2. to within the capacity of the EFDW system Page 8 of 100
Oconee Nuclear Station Question: 9 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
SGTR tab in progress 1B SG isolated 1B1 RCP secured 1A loop Tcold = 440°F decreasing 1B S/G TUBE/SHELL DT = (-)72°F
- 1) The reason the SGTR tab directs minimizing core SCM during cooldown is to minimize__(1)__.
- 2) The initial method that will be used to reduce the SCM is __(2)__.
Which ONE of the following completes the statements above?
A. 1. primary to secondary leak rate
- 2. de-energizing Pzr heaters and cycling Pzr spray B. 1. primary to secondary leak rate
- 2. de-energizing Pzr heaters and cycling Pzr spray D. 1. compressive stresses in the 1B SG
- 2. cycling the PORV Page 9 of 100
Oconee Nuclear Station Question: 10 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800:00 Reactor power = 90%
Control Rod Gp 7 position = 90%
The PI panel is selected to Relative Steam line break on the 1A SG occurs inside containment Time = 0801:00 Reactor trip occurs
- 1) At Time = 0800:30 ____(1)____ SG pressure(s) will be decreasing.
- 2) The MINIMUM requirement for Relative Position Indication (RPI) to AUTOMATICALLY reset to 0% is to have ____(2)____.
Which ONE of the following completes the statements above?
A. 1. ONLY 1A
- 2. a Trip Confirmed signal generated B. 1. ONLY 1A
- 2. ALL Regulating Rod Group IN LIMITs satisfied C. 1. BOTH 1A and 1B
- 2. a Trip Confirmed signal generated D. 1. BOTH 1A and 1B
- 2. ALL Regulating Rod Group IN LIMITs satisfied Page 10 of 100
Oconee Nuclear Station Question: 11 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
Both Main FDW pumps trip 1A and 1B MDEFDW pumps did NOT start TDEFWP did NOT start Current conditions:
Tave = 566ºF stable Recovery from CBP feed with the TDEFDW pump is in progress TDEFWP is running and flow has been verified Which ONE of the following describes how Tave and SG levels will be controlled INITIALLY during the recovery from CBP feed?
Tave will INITIALLY be controlled by throttling ____(1)____ and INITIALLY a SG level
____(2)____ be established.
A. 1. EFDW flow
- 2. will NOT B. 1. the TBVs
- 2. will NOT C. 1. EFDW flow
- 2. will D. 1. the TBVs
- 2. will Page 11 of 100
Oconee Nuclear Station Question: 12 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial Conditions:
Reactor power = 100%
1A HPI pump switch in ON 1B HPI pump switch in AUTO SBLOCA occurs The reactor trips on variable low RCS pressure Current conditions 1A HPI pump switch in ON 1B HPI pump switch in AUTO A Switchyard Isolation occurs CT-1 locks out RCS pressure has decreased to 1500 psig Following the CT-1 lockout, when the 4160 VAC busses re-energize:
- 1) there will be ____(1)____ HPIP(s) operating.
- 2) If 1HP-26 fails to open the operator will ____(2)____.
Which ONE of the following completes the statements above?
A. 1. 2
- 2. open 1HP-410 B. 1. 3
- 2. open 1HP-410 C. 1. 2
- 2. dispatch an operator to manually open 1HP-26 D. 1. 3
- 2. dispatch an operator to manually open 1HP-26 Page 12 of 100
Oconee Nuclear Station Question: 13 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
A loss of both MFW pumps occurs from 100% power Rule 3 (Loss of Main or Emergency FDW) is in progress 1FDW-315 and 1FDW-316 are maintaining SG levels at 30 XSUR Current conditions:
1KVIB is de-energized Assuming no additional operator actions, which ONE of the following will be directed by the EOP and why?
A. Take manual control of 1FDW-315 since its Moore controller will automatically swap to its alternate power supply B. Take manual control of 1FDW-316 since its Moore controller will automatically swap to its alternate power supply C. Feed the 1A SG through 1FDW-35 (1A STARTUP FDW CONTROL) since 1FDW-315 will fail open D. Feed the 1A SG through 1FDW-35 (1A STARTUP FDW CONTROL) since 1FDW-316 will fail open Page 13 of 100
Oconee Nuclear Station Question: 14 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Plant conditions:
1CA Battery Charger fails - output voltage = 0 VDC 1CA Battery voltage = 126 VDC 1DCB Bus voltage = 123 VDC Unit 2 DCA/DCB Bus voltage = 124 VDC Unit 3 DCA/DCB Bus voltage = 127 VDC Which ONE of the following will be supplying power to 1DIA panelboard?
A. 1DCB Bus B. 1CA Battery C. Unit 2 DC Bus D. Unit 3 DC Bus Page 14 of 100
Oconee Nuclear Station Question: 15 ILT 47 ONS SRO NRC Examination (1 point)
Given the following plant conditions:
Time = 0800:
Unit 1 = 100% power Unit 2 = Mode 5 Unit 3 = 100% power A, B and C LPSW pumps are operating Time = 0805:
C LPSW pump trips AP/24, Loss of LPSW is initiated LPSW header pressure = 65 psig stable
- 1) The LCO for TS 3.7.7 Low Pressure Service Water (LPSW) System ____(1)____
met for Unit 1.
be directed.
Which ONE of the following completes the statements above?
A. 1. is
- 2. will B. 1. is
- 2. will NOT C. 1. is NOT
- 2. will D. 1. is NOT
- 2. will NOT Page 15 of 100
Oconee Nuclear Station Question: 16 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
A complete loss of Instrument Air (IA) and Auxiliary Instrument Air (AIA) occurs.
Which ONE of the following describes RCP seal cooling and Pressurizer level response?
RCP Seal cooling will be maintained by ____(1)____ and pressurizer level will
____(2)____
ASSUME NO OPERATOR ACTIONS A. 1. Component Cooling
- 2. decrease B. 1. Component Cooling
- 2. increase C. 1. HPI Seal Injection
- 2. decrease D. 1. HPI Seal Injection
- 2. increase Page 16 of 100
Oconee Nuclear Station Question: 17 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
Current conditions:
Both Main Feedwater pumps tripped EFDW NOT available 1TD de-energized RCS pressure = 2217 psig slowly increasing
- 1) The pumps that will be aligned first to provide decay heat removal in accordance with the EOP are the __(1)__?
- 2) AP/11 (Recovery from Loss of Power) entry conditions __(2)__ met?
A. 1. HPI Pumps
- 2. are B. 1. HPI Pumps
- 2. are NOT C. 1. Condensate Booster Pumps
- 2. are D. 1. Condensate Booster Pumps
- 2. are NOT Page 17 of 100
Oconee Nuclear Station Question: 18 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800:
Reactor power = 100%
Grid voltage oscillating Generator Parameters:
o MWe = 950 o Vars = -350 MVAR o H2 Pressure = 45 psig AP/34 (Degraded Grid) has been initiated Time = 0805:
Reactor power = 60%
Generator Parameters o MWe = 550 o Vars = -450 MVAR o H2 Pressure = 45 psig
- 1) At 0805, AP/34 directs the operator to ____(1)____.
- 2) The reason this action is taken is to protect the generator from excessive
____(2)____.
Which ONE of the following competes the statements above?
REFERENCE PROVIDED A. 1. OPEN PCB 20 and PCB 21
- 2. armature core end heating B. 1. OPEN PCB 20 and PCB 21
- 2. field heating C. 1. Trip the reactor
- 2. armature core end heating D. 1. Trip the reactor
- 2. field heating Page 18 of 100
Oconee Nuclear Station Question: 19 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 90%
Controlling Tave fails low Plant Transient Response is performed Appropriate ICS stations are placed in MANUAL
- 1) Feedwater flow will ____(1)____ due to the failure.
- 2) Control rods are moved to ____(1)____.
Which ONE of the following completes the statements above?
A. 1. increase
- 2. the pre-transient rod height B. 1. increase
- 2. match current feedwater demand C. 1. decrease
- 2. the pre-transient rod height D. 1. decrease
- 2. match current feedwater demand Page 19 of 100
Oconee Nuclear Station Question: 20 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Reactor in MODE 6 Core offload in progress MP/0/A/1500/029, Reactor Bridge Operation is in progress Main Fuel Bridge is withdrawing a fuel assembly that appears to be binding The __(1)__ interlock will stop the withdrawal of the fuel assembly to prevent fuel Damage. The load setpoint for this interlock is __(2)__.
Which ONE of the following completes the statement above?
A. 1. TS-1 (Overload Bypass)
- 2. 2500 lb B. 1. TS-1 (Overload Bypass)
- 2. 3000 lb C. 1. TS-2 (Hoist Interlock Bypass)
- 2. 2500 lb D. 1. TS-2 (Hoist Interlock Bypass)
- 2. 3000 lb Page 20 of 100
Oconee Nuclear Station Question: 21 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Plant conditions:
All Units Reactor power = 100%
1SA3/B-6 (Fire Alarm) actuated AO reports flames and heavy smoke spreading to equipment and cable trays Fire location = Near the LPSW pumps, Column G30 Which ONE of the following locations is the affected SSF Risk Area(s) and the required action in accordance with AP/25 (Standby Shutdown Facility Emergency Operating Procedure)?
REFERENCE PROVIDED A. ALL Three Units are affected therefore trip ALL Three Units B. ONLY Unit 2 is affected therefore trip Unit 2 ONLY C. ALL Three Units are affected therefore perform a rapid shutdown on all three units D. ONLY Unit 2 is affected therefore perform a rapid shutdown on Unit 2 ONLY Page 21 of 100
Oconee Nuclear Station Question: 22 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
The reactor was tripped Unit 1 & 2 Control Room was evacuated prior to any additional actions being taken The crew has proceeded to the Auxiliary Shutdown Panel (ASP)
AP/8 (Loss Of Control Room) is in progress LDST level at the ASP = 47 inches decreasing In accordance with AP/8:
- 1) LDST level will be maintained by aligning HPIP suction to the BWST____(1)____
- 2) If no action is taken, 1HP-24 and 1HP-25 will automatically open when LDST level decreases to a setpoint value of ____(2)____ inches.
Which ONE of the following completes the statement above?
A. 1. at the ASP
- 2. 40 B. 1. at the ASP
- 2. 45 C. 1. locally at the valve(s)
- 2. 40 D. 1. locally at the valve(s)
- 2. 45 Page 22 of 100
Oconee Nuclear Station Question: 23 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800:
Reactor power = 100%
Auxiliary Steam header being supplied by Unit 2 Large Break LOCA occurs Time = 0804:
Transition to the ICC tab is made The step to reduce SG pressure is initiated Which ONE of the following describes the guidance provided by the ICC tab?
A. SGs depressurization will be limited to 100 OF / hr cooldown rate and will stop at 250 psig.
B. SGs depressurization will be limited to 100 OF / hr cooldown rate and will continue until SGs are completely depressurized.
C. SGs depressurization will occur as rapidly as possible and will stop at 250 psig.
D. SGs depressurization will occur as rapidly as possible and will continue until SGs are completely depressurized.
Page 23 of 100
Oconee Nuclear Station Question: 24 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 80% stable Tc Controller is in HAND 1B1 RCP trips Crew performs Plant Transient Response Crew enters AP/1 (Unit Runback)
Tc = +1.2 and becoming more positive The operator will have to manually re-ratio feedwater such that feed to the __(1)__ SG will increase because the ___(2)___.
Which ONE of the following completes the above statement?
A. 1. 1A
- 2. RC Flow Ratio circuit has failed B. 1. 1A
- 2. RC Flow Ratio circuit is blocked when the Delta Tc controller is in HAND C. 1. 1B
- 2. RC Flow Ratio circuit has failed D. 1. 1B
- 2. RC Flow Ratio circuit is blocked when the Delta Tc controller is in HAND Page 24 of 100
Oconee Nuclear Station Question: 25 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200 Reactor power = 40%
PCB 20 and PCB 21, Generator Output Breakers open A plant runback initiates Time = 1202 Reactor power = 30% decreasing Main Turbine trips At Time = 1204, the SGs will be fed from ____(1)____ feedwater and heat removal from the reactor will be by ____(2)____circulation.
Which ONE of the following completest the statements above?
A. 1. Main
- 2. Natural B. 1. Main
- 2. Forced C. 1. Emergency
- 2. Natural D. 1. Emergency
- 2. Forced Page 25 of 100
Oconee Nuclear Station Question: 26 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
A SB LOCA has occurred LOCA CD tab in progress 1A LPI Pump operating in the Piggyback alignment Which ONE of the following describes the:
- 2) pump(s) being protected by the above limitation?
A. 1. Maximized to < 3100 gpm
- 2. LPI B. 1. Maximized to < 3100 gpm
- 2. HPI C. 1. Maximized to < 2900 gpm
- 2. LPI D. 1. Maximized to < 2900 gpm
- 2. HPI Page 26 of 100
Oconee Nuclear Station Question: 27 ILT 47 ONS SRO NRC Examination (1 point) 1SA-1 1 2 3 4 5 6 7 8 9 10 11 12 ICS A 1 A RPS TRIP 1A LO PRESS TRIP 1A FLUX/ IMB/ FLOW TRIP 1A HI TEMP TRIP 1A VAR LO PRESS TRIP 1A HI PRESS 1A RCP / FLUX 1A HI FLUX 1A R.B. HI PRESS ES 1 TRIP ES 5 TRIP LOSS OF ACS POWER FUSE TRIP TRIP TRIP TRIP BLOWN 1B 1B 1B ICS B 1 B RPS TRIP 1B LO PRESS TRIP FLUX/IMB/ FLOW TRIP HI TEMP TRIP 1B VAR LO PRESS TRIP HI PRESS TRIP 1B RCP / FLUX TRIP 1B HI FLUX TRIP 1B R.B. HI PRESS TRIP ES 2 TRIP ES 6 TRIP AUTO/ HAND POWER FUSE BLOWN 1C C 1 C RPS TRIP 1C LO PRESS TRIP 1C FLUX/IMB/ FLOW TRIP HI TEMP TRIP 1C VAR LO PRESS 1C HI PRESS 1C RCP / FLUX 1C HI FLUX 1C R.B. HI PRESS ES 3 TRIP ES 7 TRIP LP INJECTION PUMP A DIFF. PRESS TRIP TRIP TRIP TRIP TRIP LOW 1D 1D 1D D 1 DRPS TRIP LO PRESS TRIP FLUX/ IMB/ FLOW TRIP HI TEMP TRIP 1A VAR LO PRESS 1D HI PRESS 1D RCP / FLUX 1D HI FLUX 1D R.B. HI PRESS ES 4 TRIP ES 8 TRIP LP INJECTION PUMP B DIFF. PRESS TRIP TRIP TRIP TRIP TRIP LOW CRD CRD CRD E SEQUENCE FAULT TRIP BKR A TRIP TRIP BKR B TRIP CRD TRIP BKR C TRIP CRD TRIP BKR D TRIP CRD ELECTRONIC CRD ELECTRONIC TRIP E TRIP F DIVERSE HPI BYP DIVERSE HPI TRIP DIVERSE LPI BYP DIVERSE LPI TRIP LP INJECTION PUMP C DIFF. PRESS LOW Given the following Unit 1 conditions Initial conditions:
Reactor power = 45% stable Current conditions:
Reactor power = <1% WR decreasing Core SCM = 0°F stable RCS pressure = 140 psig decreasing Reactor Building pressure = 16.4 psig increasing 1SA-1 alarms as indicated above Which ONE of the following describes actions required by the EOP?
A. Secure running LPI pumps B. Manually actuate ES Digital Channels 7 & 8 C. Dispatch AO to open CRD breakers C & D D. Feed to LOSCM setpoint with Emergency Feedwater Page 27 of 100
Oconee Nuclear Station Question: 28 ILT 47 ONS SRO NRC Examination (1 point)
Plant conditions:
It is desired to perform a manual start of KHU-1 from the Unit 1/2 Control Room The MASTER TRANSFER switch for KHU-1 is positioned to REMOTE UNIT 1 MASTER SELECTOR is placed in MAN UNIT 1 SYNC 230 KV selector is placed in MAN UNIT 1 LOCAL MASTER switch is placed in START and held in position for
> 10 seconds until KHU-1 starts In the above starting sequence, which ONE of the following is correct regarding generator cooling water flow?
A. When the MASTER SELECTOR switch is placed in MAN, the generator cooling water pump will start to provide water to the cooler.
B. When the MASTER SELECTOR switch is placed in MAN, the generator cooling water valve will open to provide water to the cooler.
C. When the LOCAL MASTER switch is placed in START, the generator cooling water pump will start to provide water to the cooler.
D. When the LOCAL MASTER switch is placed in START, the generator cooling water valve will open to provide water to the cooler.
Page 28 of 100
Oconee Nuclear Station Question: 29 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200 Reactor power = 65% stable 1LPSW-6 (UNIT 1 RCP COOLERS SUPPLY) fails closed Time = 1205 AP/16 (Abnormal RCP Operation) in progress RCP Temperatures:
1A1 1A2 1B1 1B2 Upper Guide 182ºF 197ºF 188ºF 185ºF Bearing Temp Seal Return 169ºF 174ºF 227ºF 187ºF Temp Which ONE of the following is required per AP/16 at Time = 1205?
A. Trend affected RCP temperatures since no RCP immediate trip criteria has been reached B. Manually trip the Reactor and stop RCPs 1A2 & 1B1 ONLY C. Stop RCP 1A2 ONLY and verify FDW re-ratios properly D. Stop RCP 1B1 ONLY and verify FDW re-ratios properly Page 29 of 100
Oconee Nuclear Station Question: 30 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
LDST level = 90 Stable Current conditions:
1HP-14 fails to the Bleed position
- 1) Over the next 5 minutes, 1HP-120 will __ (1) __ to maintain Pzr level constant.
- 2) __ (2) __ will be entered to mitigate this event.
Which ONE of the following completes the statements above?
A. 1. open
- 2. AP/02 (Excessive Leakage)
B. 1. open
- 2. AP/32 (Loss of Letdown)
C. 1. remain in its current position
- 2. AP/02 (Excessive Leakage)
D. 1. remain in its current position
- 2. AP/32 (Loss of Letdown)
Page 30 of 100
Oconee Nuclear Station Question: 31 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
A LOCA occurs Rule 2 (Loss of SCM) is initiated RCS pressure = 1500 psig slowly decreasing 1HP-24 and 1HP-25 fail to open When the Piggyback lineup is complete, there will be ____(1)____ LPI pump(s) and
____(2)____ HPI pumps operating.
Which ONE of the following completes the statement above?
A. 1. one
- 2. two B. 1. one
- 2. three C. 1. two
- 2. two D. 1. two
- 2. three Page 31 of 100
Oconee Nuclear Station Question: 32 ILT 47 ONS SRO NRC Examination (1 point)
Which ONE of the following states the power supply for 3LP-18?
A. 3XS-1 B. 3XS-2 C. 3XS-3 D. 3XS-4 Page 32 of 100
Oconee Nuclear Station Question: 33 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Loss of all Feedwater HPI forced cooling initiated Quench Tank pressure = 50 psig increasing RCS activity indicates no fuel failures present Current conditions:
Quench Tank pressure = 3 psig stable Which ONE of the following describes the containment response?
A. RB Normal sump level rises and 1RIA-47 radiation level increases B. RB Normal sump level rises and 1RIA-47 radiation level remains constant C. RB Normal sump level remains constant and 1RIA-47 radiation level increases D. RB Normal sump level remains constant and 1RIA-47 radiation level remains constant Page 33 of 100
Oconee Nuclear Station Question: 34 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
OP/1/A/1103/002, (Filling and Venting RCS) Enclosure 4.14 (Establishing Pzr Steam Bubble And RCS Final Vent) in progress The Pressurizer is vented to the Quench Tank for 30 minutes
- 1) In accordance with OP/1/A/1103/002, Quench Tank level should increase a minimum of ____(1)____ to indicate that Pzr Steam Bubble Formation is complete?
- 2) A consequence of incomplete Pzr bubble formation is that ____(2)____.
Which ONE of the following completes the statements above?
A. 1. 0.2 inches
- 2. Pzr spray will NOT effectively control RCS pressure on an insurge B. 1. 0.2 inches
- 2. Pzr heaters will NOT effectively control RCS pressure on an outsurge C. 1. 2.0 inches
- 2. Pzr spray will NOT effectively control RCS pressure on an insurge D. 1. 2.0 inches
- 2. Pzr heaters will NOT effectively control RCS pressure on an outsurge Page 34 of 100
Oconee Nuclear Station Question: 35 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 Conditions:
Reactor power = 100%
- 1) ___(1)___ would result in an increase in CC Cooler outlet temperature ºF.
- 2) The Component Cooling water temperature exiting the Letdown Cooler is monitored by ___(2)___.
Which ONE of the following completes the statements above?
A. 1. Throttling open 1HP-7
- 2. OAC indication ONLY B. 1. Throttling open 1HP-7
- 2. OAC indication AND Control Room temperature gage C. 1. Placing 1HP-14 in BLEED
- 2. OAC indication ONLY D. 1. Placing 1HP-14 in BLEED
- 2. OAC indication AND Control Room temperature gage Page 35 of 100
Oconee Nuclear Station Question: 36 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Initial conditions:
Reactor power = 100%
Switchyard Isolation occurs Current Conditions:
Natural Circulation established RCS pressure = 2155 psig Tcold = 550°F stable Pressurizer level = 220 stable Pressurizer temperature = 628°F
- 1) The Pressurizer is __(1)__.
- 2) Pressurizer Heater Bank #2 (Groups B & D) heaters are __(2)__.
Which ONE of the following completes the statements above?
A. 1. saturated
- 2. energized B. 1. subcooled
- 2. energized C. 1. saturated
- 2. NOT energized D. 1. subcooled
- 2. NOT energized Page 36 of 100
Oconee Nuclear Station Question: 37 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Mode 5 Pzr bubble has just been established PT/1/A/0201/004 (RC-66 Stroke Test) is being performed Pzr pressure = 40 psig Quench Tank pressure = 0 psig When RC-66 is opened QT pressure will ____(1)____ and the temperature downstream of the PORV will increase to ____(2)____.
Which ONE of the following completes the statement above?
A. 1. remain approximately the same
- 2. 252 OF B. 1. remain approximately the same
- 2. 265 OF C. 1. increase
- 2. 252 OF D. 1. increase
- 2. 265 OF Page 37 of 100
Oconee Nuclear Station Question: 38 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
1A RPS Thot RTD power supply is lost Which ONE of the following describes:
- 1) ALL RPS trips affected by the failure?
- 2) the actions preferred in accordance with OP/1/A/1105/014 (Control Room Instrumentation Operation And Information)?
A. 1. RCS High Outlet Temperature ONLY
- 2. Place MANUAL TRIP Keyswitch in "TRIP".
B. 1. RCS High Outlet Temperature ONLY
C. 1. RCS High Outlet Temperature and RCS Variable Low Pressure
- 2. Place MANUAL TRIP Keyswitch in "TRIP".
D. 1. RCS High Outlet Temperature and RCS Variable Low Pressure
Page 38 of 100
Oconee Nuclear Station Question: 39 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 50% stable Power to ES Channel 1 VOTERS is lost
- 1) The loss of power above ___(1)___ actuate ES Channel 1.
- 2) In accordance with TS 3.3.7 (ESPS Automatic Actuation Output Logic Channels) the Completion Time for placing the associated ES Ch 1 components in their ES configuration is ___(2)___.
Which ONE of the following completes the statements above?
A. 1. will
- 2. immediately B. 1. will
- 2. one hour C. 1. will NOT
- 2. immediately D. 1. will NOT
- 2. one hour Page 39 of 100
Oconee Nuclear Station Question: 40 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Time = 1200 Reactor Power = 100%
1A MSLB inside the Reactor Building Current conditions:
Time = 1201 Reactor Building Pressure = 3 psig increasing Which ONE of the following describes the operation of 1A RBCU OUTLET, 1LPSW-18?
A. It is NORMALLY fully open however it will receive a signal to open from ES-5 at 1201 B. It is NORMALLY throttled and will go fully open when it receives a signal to open from ES-5 at 1201 C. It is NORMALLY fully open however it will receive a signal to open from ES-5 at 1204 D. It is NORMALLY throttled and will go fully open when it receives a signal to open from ES-5 at 1204 Page 40 of 100
Oconee Nuclear Station Question: 41 ILT 47 ONS SRO NRC Examination (1 point)
Which ONE of the following is the power supply for Reactor Building Cooling Unit (RBCU) 1A?
A. 1XS2 B. 1XS3 C. 1X8 D. 1X9 Page 41 of 100
Oconee Nuclear Station Question: 42 ILT 47 ONS SRO NRC Examination (1 point)
Which ONE of the following is the power supply to Building Spray Pump 1A discharge valve, 1BS-1?
A. 1XS-2 B. 1XS-3 C. 1XS-4 D. 1XS-5 Page 42 of 100
Oconee Nuclear Station Question: 43 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
1RIA-40 (CSAE Off-Gas Monitor) reading is rising slowly 1RIA-54 (Turbine Building (TB) Sump Monitor) is inoperable The operating crew has just entered AP/31 (Primary To Secondary Leakage) due to a 6 gpm leak in the 1A SG
- 1) In accordance with AP/31 an AO is required to __ (1) __.
- 2) Emergency Dose Limits __ (2) __ in affect.
A. 1. open and white tag the TB Sump Pump breakers
- 2. are NOT Page 43 of 100
Oconee Nuclear Station Question: 44 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Unit startup in progress Turbine heatup has been initiated Turbine Bypass Lines Pumping Trap has malfunctioned and is not removing moisture
- 1) Plant damage, as a result of the malfunctioning pumping trap is a concern due to the potential of__ (1) __.
- 2) The Turbine Bypass Lines Pumping Trap is aligned to the __ (2) __.
Which ONE of the following completes the statements above?
A. 1. a water hammer
- 2. Condenser B. 1. a water hammer
- 2. Condensate Storage Tank C. 1. moisture impingement on the turbine blades
- 2. Condenser D. 1. moisture impingement on the turbine blades
- 2. Condensate Storage Tank Page 44 of 100
Oconee Nuclear Station Question: 45 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 40%
Loop B FDW valve P selected to 1B2 Current conditions:
1B2 Loop B FDW valve P fails LOW
- 1) Feedwater Flow will initially __ (1) __.
- 2) AP/28 (ICS Instrument Failures) will ensure BOTH __ (2) __ are in HAND to stabilize the plant.
Which ONE of the following completes the statements above?
A. 1. decrease
- 2. FDW Masters B. 1. decrease
- 2. Main FDW Pumps C. 1. increase
- 2. FDW Masters D. 1. increase
- 2. Main FDW Pumps Page 45 of 100
Oconee Nuclear Station Question: 46 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
Current conditions:
Condenser vacuum = 18.5 inches Hg stable 1TA and 1TB de-energized SG levels will be automatically controlled at ________.
Which ONE of the following completes the statement above?
A. 25 inches SUR B. 30 inches XSUR C. 50% OR D. 240 inches XSUR Page 46 of 100
Oconee Nuclear Station Question: 47 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200 Reactor power = 100%
Unit 1 TDEFWP unavailable Time = 1230 Both Main FDW pumps trip 1B MDEFWP fails to start Which ONE of the following:
- 1) describes actions directed by the EOP to remove core decay heat?
- 2) states the maximum flow rate (gpm) that can be supplied by the 1A MDEFWP at Time = 1230 in accordance with Rule 7 (SG Feed Control).
A. 1. cross connect with an alternate unit to supply the 1B Steam Generator
- 2. 440 B. 1. cross connect with an alternate unit to supply the 1B Steam Generator
- 2. 600 C. 1. feed both SGs with 1A MDEFWP
- 2. 440 D. 1. feed both SGs with 1A MDEFWP
- 2. 600 Page 47 of 100
Oconee Nuclear Station Question: 48 ILT 47 ONS SRO NRC Examination (1 point)
Given the following plant conditions:
ACB-2 (Keowee 2 Generator BKR) CLOSED ACB-3 (Keowee 1 Emergency Feeder BKR) CLOSED A LOOP (Switchyard Isolation) causes ALL 4160 V switchgear (1TC, 1TD, and 1TE) to de-energize.
Which ONE of the following describes the response of Keowee switchgear power supplies?
A. 1X switchgear de-energizes and then is restored 15 seconds later B. 1X switchgear de-energizes and then is restored 36 seconds later C. 2X switchgear de-energizes and then is restored 15 seconds later D. 2X switchgear de-energizes and then is restored 36 seconds later Page 48 of 100
Oconee Nuclear Station Question: 49 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
1SA-04/E-6 (125 Volt Ground Trouble) actuates
- 1) 1SA-04/E-6 ARG directs the Operator to __ (1) __ to determine if the ground is on the battery or the Bus.
- 2) 1SA-04/E-6 actuating indicates that the ground is located on __ (2) __.
Which ONE of the following completes the statements above?
A. 1. rotate the Ground Relay Selector Switch
- 2. Unit 1 ONLY B. 1. rotate the Ground Relay Selector Switch
- 2. any Unit C. 1. isolate the battery from the Bus
- 2. Unit 1 ONLY D. 1. isolate the battery from the Bus
- 2. any Unit Page 49 of 100
Oconee Nuclear Station Question: 50 ILT 47 ONS SRO NRC Examination (1 point)
Given the following plant conditions:
Operators are preparing to synchronize KHU-2 to the grid OP/0/A/1106/019, (Keowee Hydro At Oconee) in progress Grid Frequency = 60.3 cycles Keowee Frequency = 59.9cycles Keowee 2 Line Volts = 13.8 kV Keowee 2 Output Volts = 13.8 kV
- 1) KHU Unit 2 __ (1) __ must be adjusted prior to closing ACB-2 .
- 2) Procedural requirements for Keowee Output Volts are provided to ensure acceptable
__(2)__ when ACB-2 is closed.
Which ONE of the following completes the statements above?
A. 1. Auto Voltage Adjuster
- 2. MVARs B. 1. Speed Changer Motor
- 2. MVARs C. 1. Auto Voltage Adjuster
- 2. MWs D. 1. Speed Changer Motor
- 2. MWs Page 50 of 100
Oconee Nuclear Station Question: 51 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor in MODE 5 RB Purge is in progress Reactor Building Airborne activity is increasing .
RM Reactor BLDG Purge Disch RAD Inhibit will occur ____(1)____ and will close
____(2)____.
Which ONE of the following completes the statement above?
A. 1. prior to the switchover from 1RIA-45 to 1RIA-46 occurring
Oconee Nuclear Station Question: 52 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Time = 1200 Reactor power = 100%
3B MDEFWP switch in AUTO 2 3A MDEFWP switch in AUTO 1 for testing Time = 1201 BOTH Main Feedwater pumps trip 3MS-87 (MS to TDEFDWP Control) fails closed
- 1) The 3A MD EFDW pump ____(1)____ be operating.
- 2) The TD EFDW pump ____(2)____ be operating.
Which ONE of the following completes the statements above at time = 1202 assuming NO operator actions?
A. 1. will
- 2. will B. 1. will
- 2. will NOT C. 1. will NOT
- 2. will D. 1. will NOT
- 2. will NOT Page 52 of 100
Oconee Nuclear Station Question: 53 ILT 47 ONS SRO NRC Examination (1 point)
During normal operation of the CC system
- 1) CC flow through each letdown cooler is maintained at ____(1)____ gpm.
- 2) If letdown flow were increased, CC outlet temperature on the in-service CC cooler would be maintained by ____(2)____ operation of the associated LPSW valve.
Which ONE of the following completes the statements above?
A. 1. 200 gpm
- 2. manual B. 1. 200 gpm
- 2. automatic C. 1. 400 gpm
- 2. manual D. 1. 400 gpm
- 2. automatic Page 53 of 100
Oconee Nuclear Station Question: 54 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
Instrument Air Pressure decreasing AP/22 (Loss of Instrument Air) initiated Current conditions:
Instrument Air pressure = 63 psig decreasing
- 1) A reactor trip ____(1)____required at this time per AP/22.
- 2) When air is lost to the Main Feedwater Control valves, they fail ____(2)____.
Which ONE of the following completes the statements above?
A. 1. is
- 2. open B. 1. is
- 2. as is C. 1. is NOT
- 2. open D. 1. is NOT
- 2. as is Page 54 of 100
Oconee Nuclear Station Question: 55 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0805 Reactor in MODE 6 Fuel offload is in progress Reactor Building Normal Sump (RBNS) is being pumped A fuel assembly is dropped Time = 0809 A High Radiation Annunciator in the Control Room alarms The Reactor Building Normal Sump has failed to isolate AP/9 SPENT FUEL DAMAGE is initiated
- 1) 1RIA __(1)__ in HIGH alarm should have caused the RBNS isolation.
- 2) If the RB Normal sump isolation valves are the last open penetrations to be closed and are closed at 0830, the criteria for isolating open penetrations per AP/9 __(2)__
been met.
Which ONE of the following completes the statements above?
A. 1. 4 (Reactor Building Entrance)
- 2. has B. 1. 4 (Reactor Building Entrance)
- 2. has NOT C. 1. 49 (RB Gas)
- 2. has D. 1. 49 (RB Gas)
- 2. has NOT Page 55 of 100
Oconee Nuclear Station Question: 56 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 80%
1B1 RCP trips
- 1) The ICS will initiate a unit runback at __ (1) __%/minute.
- 2) When the runback is complete, reactor power will be approximately __ (2) _%.
Which ONE of the following completes the statements above?
A. 1. 20
- 2. 65 B. 1. 20
- 2. 74 C. 1. 25
- 2. 65 D. 1. 25
- 2. 74 Page 56 of 100
Oconee Nuclear Station Question: 57 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800 Reactor power = 100%
NR RCS pressure Channel B has failed high Time = 0801 NR RCS pressure Channel E fails high
- 2) The reactor ____(2)____ receive a High RCS Pressure trip signal.
Based on the plant conditions at 0801, complete the above statements.
(Assume NO operator actions)
A. 1. will
- 2. will B. 1. will
- 2. will NOT C. 1. will NOT
- 2. will D. 1. will NOT
- 2. will NOT Page 57 of 100
Oconee Nuclear Station Question: 58 ILT 47 ONS SRO NRC Examination (1 point)
The C LPSW Pump is normally powered from __(1)__ and it __(2)__ have an alternate supply from another unit.
A. 1. 1TC
- 2. does B. 1. 1TC
- 2. does NOT C. 1. 2TC
- 2. does D. 1. 2TC
- 2. does NOT Page 58 of 100
Oconee Nuclear Station Question: 59 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 80%
1A TBVs (1MS-22 and 1MS-19) fail open When the plant stabilizes from the event, the 1A SG level will be __(1)__ the pre-transient level and the plant MWe output will be __(2)__ the initial output .
Which ONE of the following completes the statement above?
A. 1. the same as
- 2. the same as B. 1. the same as
- 2. lower than C. 1. higher than
- 2. the same as D. 1. higher than
- 2. lower than Page 59 of 100
Oconee Nuclear Station Question: 60 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
The operating CSAE malfunctions Condenser vacuum = 24.5 slowly decreasing AP/27 (Loss Of Condenser Vacuum) has been initiated Vacuum Pumps have been started In accordance with AP/27, which ONE of the following states:
- 1) the MINIMUM vacuum that the Main Vacuum Pump must be pulling prior to opening its inlet valves?
- 2) the consequences if the above criteria is violated?
A. 1. 20 Hg Vacuum
- 2. The loss of vacuum may worsen B. 1. 20 Hg Vacuum
- 2. The vacuum pump seal may be lost resulting in damage to the pump C. 1. 24 Hg Vacuum
- 2. The loss of vacuum may worsen D. 1. 24 Hg Vacuum
- 2. The vacuum pump seal may be lost resulting in damage to the pump Page 60 of 100
Oconee Nuclear Station Question: 61 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200:00 Reactor power = 80% stable 1A and 1B CBP operating Time = 1201:00 1A CBP trips Feedwater Pump suction pressure = 225 psig slowly decreasing Time = 1203:00 Feedwater Pump suction pressure = 220 slowly increasing Which ONE of the following describes the:
- 1) runback rate (%/min) inserted at Time = 1201:00 to ICS?
- 2) procedure that will be directed by the CRS at Time = 1203:00?
A. 1. 15
- 2. AP/1/A/1700/001 (Unit Runback)
B. 1. 15
- 2. EOP C. 1. 20
- 2. AP/1/A/1700/001 (Unit Runback)
D. 1. 20
- 2. EOP Page 61 of 100
Oconee Nuclear Station Question: 62 ILT 47 ONS SRO NRC Examination (1 point)
Unit 1 plant conditions:
A gaseous waste release at 1/3 station limit is being performed
- 1) The Alert and High setpoints for ____(1)____ are based on this limit.
- 2) If the High alarm setpoint is reached on ____(2)____, the gaseous waste release will be automatically terminated.
Which ONE of the following completes the statements above?
A. 1. 1RIA-38
- 2. 1RIA-45 Page 62 of 100
Oconee Nuclear Station Question: 63 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
An area radiation monitor is being checked per PT/0/A/0230/001 When performing the source check, the RIA reading ____(1)____ increase and the Process Monitor Fault Alarm ____(2)____be received.
Which ONE of the following completes the statements above?
A. 1. should
- 2. should B. 1. should
- 2. should NOT C. 1. should NOT
- 2. should D. 1. should NOT
- 2. should NOT Page 63 of 100
Oconee Nuclear Station Question: 64 ILT 47 ONS SRO NRC Examination (1 point)
Given the following conditions:
Time = 0400 IA header develops a leak The maximum IA header pressure where SA-141, SA to IA Controller will be open is
____psig .
Which ONE of the following completes the statement above?
A. 95 B. 93 C. 90 D. 85 Page 64 of 100
Oconee Nuclear Station Question: 65 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial Conditions:
Time = 1200 Power escalation in progress Core Thermal Power = 50% slowly increasing NI Power = 52% slowly increasing Current Conditions:
Time = 1400 Core Thermal Power = 60% slowly increasing
- 1) At Time = 1200 NIs are considered __(1)__.
- 2) As a result of changes in RCS temperature, at Time = 1400 NIs will be __(2)__
than 2% different than Core Thermal Power.
Which ONE of the following completes the statements above?
A. 1. conservative
- 2. less B. 1. conservative
- 2. greater C. 1. non-conservative
- 2. less D. 1. non-conservative
- 2. greater Page 65 of 100
Oconee Nuclear Station Question: 66 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 plant conditions:
0800:
Reactor Power = 100%
1SA2/A12, ICS TRACKING is received Plant transient response is performed ICS is taken to HAND 0804:
The plant is declared stable Exiting Transient Annunciator Response is announced by the CRS In accordance with AD-OP-ALL-1000 (Conduct of Operations)
- 1) At 0800, the CRS __(1)__ required to announce Implementing Transient Annunciator Response in order to suspend normal annunciator response protocol.
- 2) At 0804, ARGs for ____(2)____ are required to be reviewed.
Which ONE of the following completes the statements above?
A. 1. is
- 2. ONLY statalarms that remain lit B. 1. is
- 2. ALL statalarms that were received during the transient C. 1. is NOT
- 2. ONLY statalarms that remain lit D. 1. is NOT
- 2. ALL statalarms that were received during the transient Page 66 of 100
Oconee Nuclear Station Question: 67 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Time = 1200 LDST level = 75 inches decreasing LDST pressure = 35 psig slowly decreasing Which ONE of the following describes the:
- 1) status of the HPI system at Time = 1200?
- 2) required action in accordance with OP/1108/001 (Curves and General Information)?
REFERENCE PROVIDED A. 1. Operable
- 2. Initiate makeup to LDST B. 1. Operable
- 2. Depressurize LDST C. 1. Inoperable
- 2. Initiate makeup to LDST D. 1. Inoperable
- 2. Depressurize LDST Page 67 of 100
Oconee Nuclear Station Question: 68 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
RCS pressure = 525 psig stable An attempt is made to open 1LP-1 (LPI RETURN BLOCK FROM RCS)
- 1) 1LP-1 __ (1) __ open.
- 2) The reason 1LP-1 has an interlock is to __ (2) __.
Which ONE of the following completes the statements above?
A. 1. will
- 2. prevent over pressurizing LPI suction piping B. 1. will
- 2. ensure delta p across 1LP-1 will allow it to open C. 1. will NOT
- 2. prevent over pressurizing LPI suction piping D. 1. will NOT
- 2. ensure delta p across 1LP-1 will allow it to open Page 68 of 100
Oconee Nuclear Station Question: 69 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Reactor power = 100%
3RC-1 has failed OPEN 3RC-3 will NOT close RCS pressure continues to decrease Which ONE of the following describes the Reactor Coolant Pump(s) that will be INITIALLY secured after the Reactor has been Manually tripped in accordance with AP/3/A/1700/044 (Abnormal Pressurizer Pressure Control)?
A. 3B1 ONLY B. 3B1 AND 3B2 C. 3A1 ONLY D. 3A1 AND 3A2 Page 69 of 100
Oconee Nuclear Station Question: 70 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power is being reduced from 100% to 88% in order to perform surveillance testing OP/1/A/1102/004 (Operation at Power), Enclosure 4.2 (Power Reduction) is in progress
- 1) The SOC ____(1)____ required to be notified.
- 2) The E Heater Drain Pumps ____(2)____ required to be secured.
Which ONE of the following completes the above statements for the power reduction?
A. 1. is
- 2. are B. 1. is
- 2. are NOT C. 1. is NOT
- 2. are D. 1. is NOT
- 2. are NOT Page 70 of 100
Oconee Nuclear Station Question: 71 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
An AO is to valve out the 1A Seal Supply filter Anticipated dose rate alarms were briefed by RP
- 1) Based on the RWP and the Plan View, the maximum time below that can be taken to perform this task per PD-RP-ALL-0001, Radiation Worker Responsibilities before the AO is expected to exit the area is __ (1) __ minutes.
- 2) Upon receipt of a second dose rate alarm that was anticipated and previously briefed, the AO __ (2) __.
Which ONE of the following completes the statement above?
REFERENCE PROVIDED A. 1. 21
- 2. may continue to work B. 1. 21
- 2. must immediately exit the area C. 1. 27
- 2. may continue to work D. 1. 27
- 2. must immediately exit the area Page 71 of 100
Oconee Nuclear Station Question: 72 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Plant conditions:
Spent Fuel Storage Cask has been dropped in Unit 1&2 SFP Spent Fuel damage is visible RIA-6 and RIA-41 HIGH alarm actuates Spent Fuel Pool level = -3.5 feet decreasing Which ONE of the following describes the
- 1) RB Purge filters that will be used to reduce off site releases
- 2) status of any SF Pumps that were in operation at the time of the event?
A. 1. Unit 1
- 2. ON B. 1. Unit 1
- 2. OFF C. 1. Unit 2
- 2. ON D. 1. Unit 2
- 2. OFF Page 72 of 100
Oconee Nuclear Station Question: 73 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
Both Main Feedwater pumps trip Current conditions:
REACTOR TRIP pushbutton has been depressed Reactor power = 4% slowly decreasing Which ONE of the following describes the NEXT action required in accordance with EOP Immediate Manual Actions?
A. Perform Rule 1 (ATWS)
B. Manually insert control rods C. Verify RCP seal injection available D. Depress the Turbine TRIP pushbutton Page 73 of 100
Oconee Nuclear Station Question: 74 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor power = 100%
1SA3/B6 (FIRE ALARM) actuated Fire Alarm panel indication o point 0202071 (Unit 1 pipe trench room 348 North End) actuated o point 0202072 (Unit 1 pipe trench room 348 East Side) actuated RP/0/A/1000/029 Fire Brigade Response is in progress
- 1) MERT will be dispatched to the area ____(1)____.
- 2) Per RP/0/A/1000/029, if water is to be used for extinguishing the fire, a transformer mulsifyre is activated or a fire hydrant is opened to ____(2)____.
Which ONE of the following completes the statements above?
A. 1. at the same time as the fire brigade
- 2. ensure HPSW pump minimum flow requirements are met B. 1. at the same time as the fire brigade
- 2. mitigate the pressure surge from any water hammer event that occurs upon HPSW pump start C. 1. ONLY after the fire is confirmed
- 2. ensure HPSW pump minimum flow requirements are met D. 1. ONLY after the fire is confirmed
- 2. mitigate the pressure surge from any water hammer event that occurs upon HPSW pump start Page 74 of 100
Oconee Nuclear Station Question: 75 ILT 47 ONS SRO NRC Examination (1 point)
- 1) The on-site emergency facility that assumes responsibility for communications with offsite agencies including the NRC once it is activated is the __ (1) __.
- 2) The minimum level of emergency classification that always requires activation of the TSC and OSC is a(n) __ (2) __
Which ONE of the following completes the statements above?
A. 1. Technical Support Center (TSC)
- 2. Alert B. 1. Technical Support Center (TSC)
- 2. Unusual Event C. 1. Operations Support Center (OSC)
- 2. Alert D. 1. Operations Support Center (OSC)
- 2. Unusual Event Page 75 of 100
Oconee Nuclear Station Question: 76 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0400 Reactor power = 70% decreasing Unit shut down in progress due to a 140 gpm RCS leak Time = 0420 Core SCM = 0 ºF RCS temperature = 550 ºF decreasing Reactor building pressure = 6 psig increasing 1RIA-58 = 15 R/hr increasing Time = 0445 Reactor building pressure = 18 psig increasing Tremor felt in the control room Seismic trigger actuates Time = 0455 Reactor building pressure = 4 psig decreasing 1RIA-58 = 55 R/hr decreasing Little River Dam has failed
- 1) The Emergency Classification at 0420 is __ (1) __.
- 2) The Emergency Classification at 0455 is __ (2) __.
Which ONE of the following completes the statements above?
REFERENCE PROVIDED A. 1. Alert
- 2. Site Area Emergency B. 1. Alert
- 2. General Emergency C. 1. Site Area Emergency
- 2. Site Area Emergency D. 1. Site Area Emergency
- 2. General Emergency Page 76 of 100
Oconee Nuclear Station Question: 77 ILT 47 ONS SRO NRC Examination (1 point)
Unit 1 initial conditions:
Reactor in MODE 6 Fuel Transfer Canal full SF-1 and SF-2 are open Current conditions:
Operator reports Fuel Transfer Canal level slowly decreasing RBNS level increasing Control Room indicates Spent Fuel Pool level decreasing Based on the above conditions, which ONE of the following:
- 1) actions would be performed first in accordance with AP/26 (Loss of Decay Heat Removal)?
- 2) states the reason for the action?
A. 1. Secure ALL LPI Pumps
- 2. Preparation for closing 1SF-1 and 1SF-2 C. 1. Secure SF Cooling pump used for Refueling Cooling Mode
- 2. Determine if leak is on discharge of SF Cooling Pump D. 1. Secure SF Cooling pump used for Refueling Cooling Mode
Oconee Nuclear Station Question: 78 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Reactor in MODE 5 ALL LTOP requirements established in accordance with Tech Spec 3.4.12 (LTOP) 1HP-120 demand signal fails to 100%
Which ONE of the following describes the reason the failure will NOT result in exceeding RCS brittle fracture pressure limits?
A. LTOP requires the HPI system to be deactivated therefore no HPI pumps will be injecting B. Mechanical Travel Stop on 1HP-120 limits flow such that the operator has 10 minutes to identify and mitigate the event C. The PORV will act as a backup to the failed Administrative Control and prevent exceeding the brittle fracture limits D. The dedicated LTOP operator is credited with identifying the failure and responding within 10 minute of the event initiation Page 78 of 100
Oconee Nuclear Station Question: 79 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor power = 100%
ACB-4 closed Switchyard Isolation occurs Current conditions:
Keowee Unit 2 emergency lockout 230 KV Yellow Bus Differential lockout Blackout Tab is in progress
- 1) The Blackout tab will direct the performance of ___(1)___ to energize 1TC, 1TD and 1TE.
- 2) The MFB will be re-energized from ___(2)___ in accordance with the procedure directed in part 1.
Which ONE of the following completes the statements above?
A. 1. Enclosure 5.38 (Restoration of Power)
- 2. CT-4 B. 1. Enclosure 5.38 (Restoration of Power)
- 2. CT-5 C. 1. AP/11 (Recovery from Loss of Power)
- 2. CT-4 D. 1. AP/11 (Recovery from Loss of Power)
- 2. CT-5 Page 79 of 100
Oconee Nuclear Station Question: 80 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200:
Reactor power = 100%
1SA6/B2 INVERTER 1DID SYSTEM TROUBLE actuated Time = 1205 AO reports:
o 1SA13/A8 INVERTER 1DID INPUT VOLTAGE LOW actuated o Inverter 1DID output voltage low
- 1) The status of 1KVID at Time = 1205 is __(1)__.
- 2) The MINIMUM action(s) required to restore the 1DID inverter to OPERABLE in accordance with Tech Spec 3.8.6 (Vital Inverters-Operating) is/are to restore DC input voltage __(2)__.
Which ONE of the following completes the statements above?
A. 1. NOT energized
- 2. ONLY B. 1. NOT energized
- 2. AND re-connect to 1KVID C. 1. Energized
- 2. ONLY D. 1. Energized
- 2. AND re-connect to 1KVID Page 80 of 100
Oconee Nuclear Station Question: 81 ILT 47 ONS SRO NRC Examination (1 point)
Given the following plant conditions:
Initial plant conditions:
Unit 1 AND Unit 2 Reactor power = 100%
A and C LPSW pumps are operating O1D2226 (LPSW-2 Pump A Suction) alarms and indicates NOT OPEN Current plant conditions:
1SA-09 / A-9, LPSW HEADER A PRESS LOW alarms and clears LPSW header pressure is fluctuating between 75 psig and 85 psig A LPSW pump amps are erratic AP/24, LOSS OF LPSW is initiated In accordance with AP/24:
- 1) the Standby LPSW Pump auto start circuitry ____(1)____ disabled prior to securing the A LPSW pump.
- 2) the A LPSW pump can be restarted____(2)____.
Which ONE of the following completes the statements above?
A. 1. is
- 2. as soon as 1LPSW-2 has been re-opened B. 1. is
- 2. ONLY after the A LPSW pump has been filled and vented C. 1. is NOT
- 2. as soon as 1LPSW-2 has been re-opened D. 1. is NOT
- 2. ONLY after the A LPSW pump has been filled and vented Page 81 of 100
Oconee Nuclear Station Question: 82 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800:
Reactor power = 80% stable 1RIA-40 Alert and High Alarm actuated AP/31, PRIMARY TO SECONDARY LEAKAGE is initiated 1RIA-59 = 20 gpm increasing 1RIA-60 = 0.4 gpm increasing Time = 0805:
1RIA-59 = 30 gpm increasing 1RIA-60 = 0.6 gpm increasing SGTR tab is entered Maximum Runback is initiated Time = 0809 Reactor power = 15%
Auxiliaries have been transferred
- 1) The increased indication on 1RIA-60 is only due to radiation____(1)____.
Which ONE of the following completes the statements above?
A. 1. from the B steam header due to cross contamination
- 2. trip the Main Turbine ONLY B. 1. from the B steam header due to cross contamination
- 2. trip the Main Turbine AND the Reactor C. 1. from the A SG header reaching 1RIA-60 due to the close proximity of the steam lines
- 2. trip the Main Turbine ONLY D. 1. from the A SG header reaching 1RIA-60 due to the close proximity of the steam lines
- 2. trip the Main Turbine AND the Reactor Page 82 of 100
Oconee Nuclear Station Question: 83 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Reactor power = 100%
Condenser vacuum = 26Hg decreasing Steam pressure to the CSAEs = 240 psig stable
- 1) Per 3AP/27, steam pressure to the CSAEs ____(1)____ required to be increased.
- 2) Guidance to address aligning the Main Vacuum Pumps to Unit 3 is contained in
____(2)____.
Based on the given plant conditions, complete the above statements.
A. 1. is
- 2. 1AP/27 B. 1. is
- 2. 3AP/27 C. 1. Is NOT
- 2. 1AP/27 D. 1. Is NOT
- 2. 3AP/27 Page 83 of 100
Oconee Nuclear Station Question: 84 ILT 47 ONS SRO NRC Examination (1 point)
Unit 1 plant conditions:
A liquid rad waste release is being performed The skid for RIA-54 loses power
- 1) Liquid Waste Release Isolation Valve (LW-131) ____(1)____ isolate AUTOMATICALLY to terminate the release.
- 2) In accordance with SLC 16.11.3 (Radioactive Effluent Monitoring Instrumentation),
the minimum requirements to restart the release with RIA-54 inoperable are to collect and analyze ____(2)____ prior to the release.
Which ONE of the following completes the statements above?
REFERENCE PROVIDED A. 1. will
- 2. a single grab sample B. 1. will
- 2. two independent grab samples C. 1. will NOT
- 2. a single grab sample D. 1. will NOT
- 2. two independent grab samples Page 84 of 100
Oconee Nuclear Station Question: 85 ILT 47 ONS SRO NRC Examination (1 point)
Unit 3 plant conditions:
Time = 0800 A main steam line break occurred inside containment The EHT tab was performed The crew transferred to the Forced Cooldown (FCD) Tab Time = 0830 The decision has been made to perform a natural circulation cooldown Time = 1500 RCS temperature = 240 OF RCS pressure = 250 psig
- 1) At this point in the cooldown, the FCD tab directs using the ____(1)____ to complete the RCS cooldown.
- 2) Transition to OP/3/A/1102/010 (Controlling Procedure for Unit Shutdown) is done
____(2)____.
A. 1. Normal Decay Heat Removal Mode
- 2. ONLY after the LPI alignment in (1) above is made B. 1. Normal Decay Heat Removal Mode
- 2. to perform the alignment directed in (1) above C. 1. LPI Series Mode
- 2. to perform the alignment directed in (1) above Page 85 of 100
Oconee Nuclear Station Question: 86 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 2 conditions:
Reactor is shutdown OP/2/A/1103/011, Draining and Nitrogen Purging RCS is in progress LPI is aligned to normal DHR Reactor Vessel level is to be decreased to below 50 on LT5
- 1) The reason that reducing Reactor Vessel level to below 50 on LT5 using an LPI pump is prohibited is to prevent __(1)__.
- 2) Prior to reducing level to below 50 on LT-5 __(2)__ is required.
Which ONE of the following completes the statements above.
A. 1. LPI pump damage from vortexing
- 2. energizing both Standby busses from a Lee Combustion Turbine C. 1. high flow rates from LPI pumps causing erroneous level indication
- 2. an available alternate makeup path through 2HP-363 D. 1. high flow rates from LPI pumps causing erroneous level indication
- 2. energizing both Standby busses from a Lee Combustion Turbine Page 86 of 100
Oconee Nuclear Station Question: 87 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200:00 Reactor startup in progress Reactor power = 3% stable The operating Main Feedwater Pump trips Time = 1200:15 The SRO directs the OATC to perform IMAs Time = 1202 Reactor power = 3% stable
- 1) The reactor ____(1)____ have automatically tripped at Time = 1200 when the operating FDW pump tripped.
- 2) The SRO should ____2____.
Which ONE of the following completes the statements above?
A. 1. should
- 2. perform actions in the Subsequent Actions tab to shut down the reactor B. 1. should
- 2. GO TO the UNPP tab to perform actions to shut down the reactor C. 1. should NOT
- 2. perform actions in the Subsequent Actions tab to shut down the reactor D. 1. should NOT
- 2. GO TO the UNPP tab to perform actions to shut down the reactor Page 87 of 100
Oconee Nuclear Station Question: 88 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Reactor tripped at 0600 AFIS header B initiated 1A S/G pressure = 800 psig and slowly decreasing ES 1 & 2 actuated RB pressure = 2 psig and increasing Core SCM = 0º F Rule 2 (Loss of SCM) is in progress Current conditions:
Time = 0608 Core SCM = 15º F Rule 5 is complete EHT Tab has been initiated Tcold = 460º F Pressurizer level = 136 slowly increasing RCS makeup flow = 130 gpm
- 1) Rule 8 (PTS) ____(1)____ required to be initiated.
- 2) In accordance with the EHT Tab, the ____ (2) ____ Tab will be initiated.
At 0608, which ONE of the following completes the statements above?
A. 1. is
- 2. FCD B. 1. is
- 2. LOCA CD C. 1. is NOT
- 2. FCD D. 1. is NOT
- 2. LOCA CD Page 88 of 100
Oconee Nuclear Station Question: 89 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0800 Reactor power = 100%
LOCA occurs Time = 0815 RB pressure peaks at 12 psig Building Spray pump 1B fails to start Time = 0830 LOCA CD tab is in progress RB pressure = 8 psig decreasing
- 1) The operating BS train ____(1)____ meet the minimum requirement for Iodine removal assumed in the safety analysis for this accident.
- 2) At 0830, RB pressure ____(2)____ meet the criteria to secure Reactor Building Spray pumps.
Which ONE of the following completes the above statements?
A. 1. does
- 2. does B. 1. does
- 2. does NOT C. 1. does NOT
- 2. does D. 1. does NOT
- 2. does NOT Page 89 of 100
Oconee Nuclear Station Question: 90 ILT 47 ONS SRO NRC Examination (1 point)
Unit 1 plant conditions:
Reactor startup is in progress Reactor in MODE 3 1LPSW-1061 (RB AUX COOLERS RETURN BLOCK) is declared INOPERABLE and is deactivated to satisfy TS 3.6.3 (Containment Isolation Valves) Condition A
- 1) The Unit 1 startup ____(1)____ continue into MODE 2.
- 2) If administrative controls are established to open 1LPSW-1061, the time that it is allowed to be open ____(2)____ limited to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
Which ONE of the following completes the statements above?
REFERENCE PROVIDED A. 1. may
- 2. is B. 1. may
- 2. is NOT C. 1. may NOT
- 2. is D. 1. may NOT
- 2. is NOT Page 90 of 100
Oconee Nuclear Station Question: 91 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
Time 0600 Reactor power = 100%
Pressurizer (PZR) Level 3 selected SASS in MANUAL ICCM Train "1B" experiences a total loss of power
- 1) Due to the loss of power, 1HP-120 will __ (1) __.
- 2) If power cannot be restored, TS 3.3.8 (Post Accident Monitoring Instrumentation)
__ (2) __require a shutdown within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
Which ONE of the following completes the statements above?
REFERENCE PROVIDED A. 1. close
- 2. does B. 1. close
- 2. does NOT C. 1. open
- 2. does D. 1. open
- 2. does NOT Page 91 of 100
Oconee Nuclear Station Question: 92 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 1200 Reactor power = 100%
Relative Position Indication (RPI) inoperable for ALL Control Rods Time = 1230 Absolute Position Indication (API) inoperable for Group 1 Rod 7 Control Rod Current Conditions:
Tech Spec 3.1.4 Required Action A.2.1.1 (SDM Verification) has just been completed and shutdown margin requirements of the COLR have been determined to be NOT met Which ONE of the following:
- 1) is the LATEST time that Group 1 Rod 7 Control Rod must be declared inoperable in accordance with Tech Specs?
- 2) should be used to restore shutdown margin requirements in accordance with Tech Spec bases?
A. 1. 1230
- 2. CBAST and BWST ONLY B. 1. 1230
- 2. CBAST, BWST and A BHUT C. 1. 1330
- 2. CBAST and BWST ONLY D. 1. 1330
- 2. CBAST, BWST and A BHUT Page 92 of 100
Oconee Nuclear Station Question: 93 ILT 47 ONS SRO NRC Examination (1 point)
Unit 1 plant conditions:
Reactor power = 100%
A SGTL occurs on the 1A SG AP/31 (Primary to Secondary Leakage) is initiated
- 1) While in AP/31, EOP Enclosure 5.5 __(1)__ allowed to be utilized to maintain Pressurizer at desired level.
- 2) The Tech Spec limit on primary to secondary leakage is that amount assumed in the safety analysis for a ____(2)____ which will ensure that dose consequences are less than the limits defined in 10 CFR 100.
Which ONE of the following completes the statements above?
A. 1. is
- 2. lifted MSRV following a reactor trip from 100 percent power B. 1. is
- 2. Steam Line Break C. 1. is NOT
- 2. lifted MSRV following a reactor trip from 100 percent power D. 1. is NOT
- 2. Steam Line Break Page 93 of 100
Oconee Nuclear Station Question: 94 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 2 conditions:
Refueling in progress FTC level = 22 feet stable No water additions are being made to the system 2A LPI train is operable and in service Current conditions:
Refueling SRO desires stopping the 2A LPI Pump to aid in inserting a fuel assembly 2A LPI pump has been in continuous operation for the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Which ONE of the following describes whether the 2A LPI pump may be stopped in accordance with OP/2/A/1502/007 (Operations Defueling /Refueling Responsibilities) and the bases for this action?
A. 2A LPI Pump may be stopped FTC provides adequate backup decay heat removal B. 2A LPI Pump may be stopped Spent Fuel Cooling system provides adequate backup decay heat removal C. 2A LPI Pump may NOT be stopped FTC does NOT provide adequate backup decay heat removal.
D. 2A LPI Pump may NOT be stopped Spent Fuel Cooling does NOT provide adequate backup decay heat removal Page 94 of 100
Oconee Nuclear Station Question: 95 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
All 3 Units reactor power = 100%
1SA-3/B6 (FIRE ALARM) actuated AO's dispatched to the Turbine Building 3rd Floor (1TA and 1TB area)
Current conditions:
AO reports the fire on 1TB with heavy smoke and rolling flames Fire Brigade has been dispatched Class C extinguishing agent has been ineffective in extinguishing the fire
- 1) In accordance with the Fire Plan a water fog __ (1) __ be used on the switchgear to fight the fire.
__ (2) __ required to serve as the fire brigade leader.
Which ONE of the following completes the statements above?
A. 1. should
- 2. is B. 1. should
- 2. is NOT C. 1. should NOT
- 2. is D. 1. should NOT
- 2. is NOT Page 95 of 100
Oconee Nuclear Station Question: 96 ILT 47 ONS SRO NRC Examination (1 point)
In accordance with NSD 301 (Engineering Change Program):
- 1) An on-line temporary design change is required to have a plan that specifies removal of the change within __ (1) __ year(s) from installation.
- 2) The Operational Control Group (Operations) __ (2) __ responsible for maintaining a log of installed changes.
Which ONE of the following completes the statements above?
A. 1. 3
- 2. is B. 1. 3
- 2. is NOT C. 1. 1
- 2. is D. 1. 1
- 2. is NOT Page 96 of 100
Oconee Nuclear Station Question: 97 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 3 conditions:
Time = 1100 3KVIA panelboard de-energized Current conditions:
Time = 1200 DC panelboard 3DIB is de-energized
- 1) Tech Spec 3.8.8 requires that you __(1)__.
- 2) KVIA AND KVIB have shorter completion times than KVIC and KVID because they
__(2)__.
Which ONE of the following completes the statements above?
REFERENCE PROVIDED A. 1. restore 3KVIA by 1500 and 3KVIB by 1600
- 2. are the source of power for the ES Digital Channels B. 1. restore 3KVIA by 1500 and 3KVIB by 1600
- 2. provide power for SK and SL breakers protective relaying Page 97 of 100
Oconee Nuclear Station Question: 98 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Initial conditions:
EOP Enclosure 5.12 (ECCS Suction Swap to RBES) in progress Current conditions:
The step to open 1HP-939 and 1HP-940 has just been completed
- 1) These valves direct HPI flow to the __ (1) __.
- 2) In accordance with the bases of SLC 16.6.12 (Additional HPI Requirements) this flow path is established to prevent __ (2) __.
Which ONE of the following completes the statements above?
A. 1. RBES
- 2. elevated dose rates in the Auxiliary Building B. 1. RBES
- 2. Boron precipitation in the core C. 1. LDST
- 2. elevated dose rates in the Auxiliary Building D. 1. LDST
- 2. HPI pump damage due to flow below minimum Page 98 of 100
Oconee Nuclear Station Question: 99 ILT 47 ONS SRO NRC Examination (1 point)
Given the following Unit 1 conditions:
Time = 0400 Reactor has tripped Subsequent Actions tab in progress RCS pressure = 2150 psig stable RCS temperature = 547°F stable Time = 0405 While at step 4.13 of the SA tab (checking for indications of a SGTR) the following occurs:
o 1SA-18/D-6 (RC System Approaching Saturation Conditions) actuates o 1SA-8/B-9 (Process Monitor Radiation High) actuates o Pzr level = 0 inches o RBNS level increases off scale high o RCS pressure 1330 psig slowly decreasing o A loop SCM = 0°F o B loop SCM = 18°F slowly decreasing o Core SCM = 18°F slowly decreasing
- 1) At 0405, the Procedure Director will GO TO the LOSCM tab based on a Parallel Actions page transfer ___(1)___
- 2) After the transfer to the LOSCM tab is made, a subsequent ___(2)___ will require a transfer to a different EOP tab.
Which ONE of the following completes the statement above?
A. 1. immediately
- 2. Turbine Building Flood B. 1. immediately
- 2. Blackout C. 1. ONLY when Core SCM reaches 0°F
- 2. Turbine Building Flood D. 1. ONLY when Core SCM reaches 0°F
- 2. Blackout Page 99 of 100
Oconee Nuclear Station Question: 100 ILT 47 ONS SRO NRC Examination (1 point)
Given the following plant conditions:
Time = 1200 Security Supervisor reports intruders have forced their way through the Vehicle Access Point (Security Point 1) near the complex using various weapons and have been seen heading towards the 525kv Switchyard Time = 1205 Security Supervisor reports intruders and their weapons are in the 525kvSwitchyard AND the 230kv Switchyard Without using the Emergency Coordinator Judgment option, which ONE of the following:
- 1) states the EAL classification required by the conditions at Time = 1205?
- 2) is the correct notification code to activate the Emergency Response Organization (ERO) per RP/0/A/1000/002 (Control Room Emergency Coordinator Procedure)?
REFERENCE PROVIDED A. 1. Alert
- 2. E2a B. 1. Alert
- 2. E2f C. 1. Site Area Emergency
- 2. E3a D. 1. Site Area Emergency
- 2. E3f Page 100 of 100
Examination KEY for: ILT 47 ONS SRO NRC Exami Question Answer Number 1 A 2 C 3 B 4 D 5 D 6 A 7 D 8 D 9 A 10 C 11 A 12 B 13 A 14 B 15 D 16 D 17 D 18 C 19 D 20 A 21 B 22 C 23 D 24 A 25 D Printed 5/14/2015 9:51:39 AM Page 1 of 4
Examination KEY for: ILT 47 ONS SRO NRC Exami Question Answer Number 26 A 27 B 28 B 29 C 30 C 31 B 32 B 33 A 34 C 35 A 36 B 37 B 38 D 39 D 40 B 41 C 42 C 43 B 44 A 45 D 46 D 47 D 48 A or C 49 D 50 B Printed 5/14/2015 9:51:41 AM Page 2 of 4
Examination KEY for: ILT 47 ONS SRO NRC Exami Question Answer Number 51 A 52 C 53 B 54 B 55 C 56 D 57 B 58 D 59 B 60 C 61 D 62 A or C 63 D 64 D 65 A 66 C 67 D 68 C 69 B 70 B 71 A 72 D 73 D 74 A 75 A Printed 5/14/2015 9:51:41 AM Page 3 of 4
Examination KEY for: ILT 47 ONS SRO NRC Exami Question Answer Number 76 B 77 A 78 B 79 A 80 B 81 B 82 C 83 A 84 C 85 A 86 A 87 B 88 A 89 B 90 B 91 D 92 A 93 B 94 A 95 B 96 C 97 C 98 A 99 B 100 B Printed 5/14/2015 9:51:41 AM Page 4 of 4
Reference List for: ILT 47 ONS SRO NRC Examination AP 43 Encl 5.1 Generator Capability Curve OP/0/A/1108/001 .39 (page 1 only with action notes removed)
Plan View RWP 23 RP 1000 001 RP 1000 001 RP 1000 002 SLC 16.11.3 TS 3.3.8 TS 3.6.3 TS 3.8.8 Printed 5/14/2015 10:15:45 AM
Page 1 of 1 Enclosure 5.1 AP/0/A/1700/043 SSF Risk Areas Page 1 of 5 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. __ Determine from dispatched operator if fire is in SSF RISK AREA by using table below:
SSF Risk Area Affected Units Cross-Hatched Areas in TB Refer to Page 3 of this 3rd Floor enclosure.
Cross-Hatched Areas in TB Refer to Page 5 of this Basement enclosure.
Enclosure 5.1 AP/0/A/1700/043 SSF Risk Areas Page 2 of 5 THIS PAGE INTENTIONALLY BLANK
Enclosure 5.1 AP/0/A/1700/043 SSF Risk Areas Page 3 of 5 Turbine Building 3rd Floor NORTH 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 B B C C D D E E F F G G H H J J K K L L M M 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 LEGEND SSF RISK AREA SSF RISK AREA ALL 3 UNITS UNIT 3 Fire plan 796.des Rev. 0 11/18/06 RTR 7312
Enclosure 5.1 AP/0/A/1700/043 SSF Risk Areas Page 4 of 5 THIS PAGE INTENTIONALLY BLANK
Enclosure 5.1 AP/0/A/1700/043 SSF Risk Areas Page 5 of 5 Turbine Building Basement NORTH B HPSW PUMP ROOM (NOT PART OF U2 SSF RISK AREA)
LDST Pressure (psig) 0 W Cfl 0) 0 (0 0 C) 0 0 0 0 0 o 0 0 .
0 I) .
-1 -- -
I
-t.--- ---- ----..
-t- .
.1
-r-- - -
- CD r_._ .J I . :3 (Do ..-,---- -.-
4-
- (.1 a.
- o__
I - //
(DO) / /*// - --
%4/( !
E2 d lCD C
- ,J< (I)
CD c.
i 0 0
o Cl)
C 0
l) Q ci CD Cl)
Enclosure 5.1 AP/1/A/1700/034 Generator Capability Page 1 of 3 Curve
Duke Energy Procedure No.
Oconee Nuclear Station 0 RP/ /A/1000/001 Emergency Classification Revision No.
002 Electronic Reference No.
OP009A63 Reference Use PERFORMANCE
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format
OP/0/A/1108/001 Page 2 of 4
- 1. Purpose 1.1 To provide various tank, system, and concentration curves along with general information necessary for the efficient operation of the plant.
- 2. Limits and Precautions 2.1 None
- 3. Procedure 3.1 Refer to various listed enclosures as required.
- 4. Enclosures 4.1 BHUT Volume Vs. Level Curve {31}
4.2 CBAST Volume Vs. Level Curve (All Units) 4.3 GWD Tank Volume Vs. Pressure Curve (A, B, 3A, 3B) 4.4 GWD Tank Volume Vs. Pressure Curve (C, D, 3C) 4.5 HAWT Volume Vs. Level Curve (Unit 1&2 And Unit 3) 4.6 LAWT Volume Vs. Level Curve (Unit 1&2 And Unit 3) 4.7 Unit 1&2 MWHUT Volume Vs. Level Curve 4.8 Unit 3 MWHUT Volume Vs. Level Curve 4.9 Hotwell Volume Vs. Level Curve (All Units) 4.10 UST Volume Vs. Level Curve (All Units) 4.11 Unit 1&2 RCW Storage Tank Volume Vs. Level Curve 4.12 Unit 3 RCW Storage Tank Volume Vs. Level Curve 4.13 Turbine Oil Storage Tank Volume Vs. Level Curve (All Units) 4.14 Boric Acid Solubility In Water Curve 4.15 CBAST Concentration Vs. Level Curve (All Units) 4.16 Laundry And Hot Shower Tank Volume Vs. Level Curve (All Units) 4.17 Evaluation For Removal Of Statalarms/Control Room Indications {28}
4.18 CSAE Blower Head Curve
OP/0/A/1108/001 Page 3 of 4 4.19 Deborating IX Capacity For Saturation Of Demineralizer 4.20 Compartment Identification Of 600/208 VAC Motor Control Centers 4.21 ICS Schematic 4.22 SG Level Ranges 4.23 Unit 1 Mechanical RB Penetrations (East And West) 4.24 Unit 2&3 Mechanical RB Penetrations (East And West) 4.25 Expected Feedwater Flow Per Header Vs. Reactor Power 4.26 Miscellaneous Data 4.27 Instructions For Adjusting Alarm Setpoints On The NI Recorder 4.28 Unit 1 Core Map 4.29 Unit 2 Core Map 4.30 Unit 3 Core Map 4.31 Unit 1 RCS Heatup/Cooldown Curves 4.32 Unit 2 RCS Heatup/Cooldown Curves 4.33 Unit 3 RCS Heatup/Cooldown Curves 4.34 Unit 1&2 Spent Fuel Pool Level Vs. Temperature Curve (DELETED- moved to OP/0/A/1108/001 B (Spent Fuel Pool Level Vs. Temperature Curves) 4.35 Combined Inventory For Emergency Feedwater Curve 4.36 Site Assembly Alarm Test 4.37 Emergency Power Switching Logic (EPSL) 4.38 Condenser Flow And Temperature Data 4.39 LDST Pressure Vs. Level (All Units) 4.40 ESV System Vacuum Requirements 4.41 CCW Discharge Local Temperature Data 4.42 Not Used 4.43 Not Used 4.44 RCS Boron Changes Due To Letdown Temperature Changes
OP/0/A/1108/001 Page 4 of 4 4.45 RCS Instrumentation 4.46 Total Loss Of DHR Time To Boil (DELETED- moved to OP/0/A/1108/001 A (Reactor Core And SFP Loss Of Cooling Heatup Tables) 4.47 Maximum SFP Temperature Vs. Total SFC System Flow 4.48 Appendix
Enclosure 4.1 OP/0/A/1108/001 BHUT Volume Vs. Level Curve Page 1 of 1 90,000 80,000 70,000 Volume of Liquid in Tank (VBHUT) [gal]
60,000 50,000 NOTE: Bleed Transfer Pump trips at 15" 40,000 indicated level (29" actual level). {10}
30,000 20,000 10,000 0
0 20 40 60 80 100 120 140 160 180 200 Indicated Level of Liquid in Tank (LBHUT) [in]
BHUT Rev 4 (Final).xlsx (OSC-7129 Rev. 4)
Enclosure 4.2 OP/0/A/1108/001 CBAST Volume Vs. Level Curve (All Units) {30} Page 1 of 1 CBAST Volume Vs. Level 23 22 21 20 19 18 17 16 15 14 13 GALLONS 12 (THOUSANDS) 11 10 9
8 7
6 5
4 3
2 1
0 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 LEVEL (INCHES)
CBAST lvl vs vol curve rev 0.xlsx
Enclosure 4.3 OP/0/A/1108/001 GWD Tank Volume Vs. Pressure Curve (A, B, 3A, 3B) Page 1 of 1 Gwd tank 1.des
Enclosure 4.4 OP/0/A/1108/001 GWD Tank Volume Vs. Pressure Curve (C, D, 3C) Page 1 of 1 Gwd tank 2.des
Enclosure 4.5 OP/0/A/1108/001 HAWT Volume Vs. Level Curve (Unit 1&2 And Unit 3) Page 1 of 1 HAWT rev 1.des rtr7312 4 23 13
Enclosure 4.6 OP/0/A/1108/001 LAWT Volume Vs. Level Curve (Unit 1&2 And Unit 3) Page 1 of 1 LAWT rev 1.des rtr7312 4 23 13
Enclosure 4.7 OP/0/A/1108/001 Unit 1&2 MWHUT Volume Vs. Level Curve Page 1 of 1 1_2 mwhut.des
Enclosure 4.8 OP/0/A/1108/001 Unit 3 MWHUT Volume Vs. Level Curve Page 1 of 1 3 mwhut.des
Enclosure 4.9 OP/0/A/1108/001 Hotwell Volume Vs. Level Curve (All Units) Page 1 of 1 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 70 70 60 60 50 50 LEVEL, INCHES (COMPUTER READOUT) 40 40 30 30 20 20 10 10 HOTWELL MAY CONTAIN AS MUCH AS 14,000 GALLONS WHEN COMPUTER READOUT INDICATES "0" INCHES 0 0
-6 -6 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 VOLUME, GALLONS X 1000 Hotwell Lvl vs Volume rev 2.des 05/21/08 rtr7312
Enclosure 4.10 OP/0/A/1108/001 UST Volume Vs. Level Curve (All Units) Page 1 of 1 0 1 2 3 4 5 6 7 8 9 10 11 12 80,000 80,000 70,000 70,000 60,000 60,000 COMBINED VOLUME OF BOTH USTs, ONE UNIT 50,000 50,000 VOLUME, GALLONS 40,000 40,000 30,000 30,000 20,000 20,000 10,000 10,000 0 0 0 1 2 3 4 5 6 7 8 9 10 11 12 LEVEL, FEET USTCRV.TCW
Enclosure 4.11 OP/0/A/1108/001 Unit 1&2 RCW Storage Tank Volume Vs. Level Curve Page 1 of 1 1_ 2 rcw tnk.des
Enclosure 4.12 OP/0/A/1108/001 Unit 3 RCW Storage Tank Volume Vs. Level Curve Page 1 of 1 3 rcw tnk.des
Enclosure 4.13 OP/0/A/1108/001 Turbine Oil Storage Tank Volume Vs. Level Curve (All Units) Page 1 of 1 to stg tnk.des
Enclosure 4.14 OP/0/A/1108/001 Boric Acid Solubility In Water Curve Page 1 of 1 ba sol.bmp
Enclosure 4.15 OP/0/A/1108/001 CBAST Concentration Vs. Level Curve (All Units) Page 1 of 1 CBAST Concentration vs Level Curve - All Units 16000 15500 15000 14500 14000 13500 CBAST Concentration, ppm boron Operable Range 13000 Operating Guidelines:
10,000 - 14,500 ppm boron, normally 12500 >13,000 ppm boron prior to RFO {6}
Inoperable Range 12000 11500 11000 10500 10000 9500 9000 8500 8000 0 10 20 30 40 50 60 70 80 90 100 110 120 130 CBAST Level, inches Source: ONTC-0-106A-001-001 rev.0
Enclosure 4.16 OP/0/A/1108/001 Laundry And Hot Shower Tank Volume Vs. Level Curve (All Units) Page 1 of 1 LAUNDRY & HOT SHOWER TANKS A & B LEVEL VS. VOLUME UNITS 1,2,3 6000 FULL CAPACITY = 5,513 GAL OR 101.75 INCHES OF TANK HEIGHT 5000 VOLUME OF TANK (GALLONS) [GAL]
4000 3000 2000 1000 0
0 10 20 30 40 50 60 70 80 90 100 110 LEVEL OF TANK (INCHES) [IN]
Enclosure 4.17 OP/0/A/1108/001 Evaluation For Removal Of Page 1 of 4 Statalarms/Control Room Indications {28}
- 1. Initial Conditions 1.1 Plant component failure or plant conditions have occurred such that it is necessary to remove a Statalarm window from service, or identify a Control Room indication as out of service.
- 2. Limits And Precautions 2.1 The implications of loss of alarm and Control Room indication functions must be fully evaluated and understood by Control Room personnel.
2.2 EACH alarm card in BETALARM panel (3SA-19 and all alarm panels in the SSF Control Room) powers two (2) alarm windows. An alarm test must be performed to verify which two alarms will be silenced by pulling the card. Both alarms should be evaluated for safety impact before leaving the card pulled. {27}
- 3. Procedure (Removal) 3.1 Complete the following steps for the Statalarm/Control Room indication to be removed from service:
_____ 3.1.1 Name of Statalarm/Control Room Indicator:
_____ 3.1.2 Identify the reason for removal (equipment malfunction, nuisance alarm, multiple inputs with no reflash, etc.):
_____ 3.1.3 List any safety-related equipment affected by the removal of this statalarm/indicator:
_____ 3.1.4 List any applicable TS and/or SLCs:
_____ 3.1.5 List alternate monitoring (if required):
_____ 3.1.6 IF applicable generate a WR for equipment being removed from service:
WR # : ________________ (For Control Room statalarms, designate as CRIP)
_____ 3.1.7 Perform a review of the statalarm/Control Room indicator to determine the CRS acceptability of removal from service. Resources may include, but are not limited to, the following: TS, SLC, ARG, OP, AP, EOP, and Ops Guides.
Enclosure 4.17 OP/0/A/1108/001 Evaluation For Removal Of Page 2 of 4 Statalarms/Control Room Indications {28}
_____ 3.1.8 Determine if evaluation is needed by Engineering and/or Operations CRS Procedures Group for the affected component; generate PIP as required.
Engineering Contact (if applicable): ________________________________
OPS Procedure Group Contact_____________________________________
3.1.9 Removal prepared by:
________________________ _____/_____
(CRS/RO) Date Time 3.1.10 Removal approved by:
________________________ _____/_____
(CRS) Date Time NOTE: EACH alarm card in BETALARM panel (3SA-19 and all alarm panels in the SSF Control Room) powers two (2) alarm windows. An alarm test must be performed to verify which two alarms will be silenced by pulling the card. Both alarms should be evaluated for safety impact before leaving the card pulled. {27}
CAUTION: While Statalarm panel is open, energized electrical conductors that supply alarm lights are exposed.
3.2 Complete the following removal steps for the affected Statalarm/Control Room Indicator:
_____ 3.2.1 IF removal of a Statalarm requires pulling a statalarm card, perform the following:
_____ A. Identify statalarm card number and record: _______________
_____ B. Remove all jewelry and watches and wear safety glasses before removing statalarm card.
_____ C. Make determination as to which alarm card is to be pulled, and pull selected card.
_____ D. Perform statalarm panel test on affected panel to verify correct card has been pulled.
Enclosure 4.17 OP/0/A/1108/001 Evaluation For Removal Of Page 3 of 4 Statalarms/Control Room Indications {28}
3.2.2 IF a statalarm card is pulled, OR a multiple input statalarm with no reflash capability is "Locked In" perform the following:
_____ Add removed statalarm to the "Out of Normal Alarms" section of the Unit Turnover Sheet or AO Turnover Sheet.
_____ Place a "T/O Sheet" or "CBWO" status label on the statalarm window.
3.2.3 IF removing a Control Room indication from service perform the following for _______________________________ (identify Control Room indication):
_____ A. Add the Out Of Service indicator to the "Equipment Deficiencies" section of Unit Turnover Sheet.
_____ B. Place an "OOS/I&E" plant status label on the indicator.
_____ 3.3 IF alternate monitoring is required:
_____ Add affected statalarm/indication to "Additional Monitoring" section of Unit Turnover Sheet or AO Turnover Sheet.
_____ IF not performed in Step 3.2.2, place a "T/O Sheet" plant status label on the statalarm window.
_____ 3.4 Place this enclosure in the "Alarm Status" section of respective unit "PT/600/001 Working Copy" notebook.
Enclosure 4.17 OP/0/A/1108/001 Evaluation For Removal Of Page 4 of 4 Statalarms/Control Room Indications {28}
- 4. Restoration CAUTION: While Statalarm panel is open, energized electrical conductors that supply alarm lights are exposed.
4.1 WHEN notified that the statalarm/Control Room indicator is ready to be returned to service, perform the following:
_____ 4.1.1 IF restoring a statalarm to service requires reinserting a statalarm card, perform the following:
_____ A. Identify statalarm card number and record: _______________
_____ B. Remove all jewelry and watches and wear safety glasses before installing cards.
_____ C. Make determination as to which alarm card is to be inserted, and insert selected card.
_____ D. Perform statalarm panel test on affected panel to verify the statalarm has been returned to service.
_____ 4.1.2 IF Step 3.2.2 was performed, perform the following as required:
_____ A. Delete restored statalarm from the "Out of Normal Alarms" section of the Unit Turnover Sheet or AO Turnover Sheet.
_____ B. Remove the "T/O Sheet" or "CBWO" status label from the statalarm window.
_____ 4.1.3 IF restoring a Control Room indication to service perform the following for
_____________________________ (identify Control Room indication):
_____ A. Delete the Out Of Service indicator from the "Equipment Deficiencies" section of Unit Turnover Sheet
_____ B. Remove the "OOS/I&E" plant status label from the indicator.
_____ 4.2 IF alternate monitoring was required:
_____ Delete the affected statalarm/indication from the "Additional Monitoring" section of Unit Turnover Sheet or AO Turnover Sheet.
_____ Remove the "T/O Sheet" plant status label from the statalarm window.
_____ 4.3 Complete the enclosure coversheet and forward to Shift Clerk for processing.
Enclosure 4.18 OP/0/A/1108/001 CSAE Blower Head Curve Page 1 of 1 60 59 58 57 56 55 54 Inches of H 2O 53 52 51 50 49 48 47 46 45 100 150 200 250 300 350 SCFM
Enclosure 4.19 OP/0/A/1108/001 Deborating IX Capacity For Saturation Of Demineralizer {29} Page 1 of 1 Curve file located at \\onsfs00\dwgs\Boron curves for op 0 a 1108 001 rev. 107.doc
Enclosure 4.20 OP/0/A/1108/001 Compartment Identification Of 600/208 VAC Page 1 of 1 Motor Control Centers Notes:
- 1. Front of MCC is 600 VAC side; determined by location of incoming feeder breaker. Compartments are numbered from left to right, lettered vertically, one letter for each breaker.
- 2. Rear of MCC is 208 VAC side; compartments are numbered from right to left, lettered vertically, one letter for each breaker.
FRONT, 600 VAC (TYPICAL)
REAR, 208 VAC (TYPICAL)
ELECPNL.TCW Rev. 1 11/15/99 rtr
Enclosure 4.21 OP/0/A/1108/001 ICS Schematic Page 1 of 3 Unit 1 TRACKING INPUTS TAVE CTP ERROR LOAD LIMITS FDW FLOW GEN MWe THP ERROR T10 RC FLOW (variable) NI FLUX 1.2 RC PUMPS (74%) CTP TAVE ERROR CTP BEST BEST < >
FDW PUMPS (65%)
ASY ROD (55%)
BOTH GEN BKRS OPEN (20%) T3 SP CTP CTP MAXIMUM RUNBACK (15%) DEMAND 2250#
RX TRIP (0%) SETPOINT DEMAND RCS OPERATOR S/G PRESS T1 T2 d/dt f(g) MASTER DEMAND H/A
>101%
MANEUVERING RATES THP ERROR FDW RX LOW LEVEL LIMITS 1%/MIN* X f(g) TEMP TAVE ASY ROD 1%/MIN* SP MASTER MAXIMUM RB 20%/MIN H/A SP TRACKING 20%/MIN 2250#
RX CROSS LIMITS RC FLOW 20%/MIN RCS T11 NEUTRON LOW CBP/MFP SUCT PRESS 20%/MIN ERROR +/- 5% NI PRESS BOTH GEN BKRS OPEN 20%/MIN LOSS OF ONE RCP 25%/MIN LOSS OF ONE FWP 25%/MIN X DIAMONDPANEL REACTOR TRIP 600%/MIN IN OUT RC RC CRDMS THP ERROR 1A FDW FLOW FLOW 1B FDW THP SETPOINT A B MASTER RATIO MASTER S/G S/G H/A H/A THP PRESS PRESS TOTAL FDW FLOW TO SP A B T2 Tc 2250# FDW TC FDW H/A SP FLOW FLOW THPERROR RCS SP SP PRESS T7 T7 OPER OPER LEVEL LEVEL TURBINE 125psig Tc FDW VALVE LOAD/UNLOAD SP P SP CONTROLLER 50 psig T8 25" 25" 0 psig SP SU 35 # SU LEVEL T4 T5 LEVEL TURBINE COMPOSITE COMPOSITE THP VALVE DEMAND VALVE DEMAND MASTER CONTROLLER CONTROLLER SP H/A SEQ SEQ SP SP BIAS BIAS EHC 1035# 1035#
SP SP TRANSFERFUNCTIONS T1 LOAD LIMITS OPER OPER LEVEL T6 T6 LEVEL T2 TRACKING T3 FDW CONTROL CORRECTION SELECTOR T4 LO LEVEL LIMIT SELECTOR S/G 'A' 1ATBV 7" Hg 1B TBV 1A MFDW 1A S/U 1A MFWP BIAS 1B S/U FDW 1B MFDW T5 LO LEVEL LIMIT SELECTOR S/G 'B' H/A Vac H/A CONTROL FDW 1B MFWP CONTROL CONTROL CONTROL H/A T6 SU FDW VALVES CONTROL 50% OP LVL H/A H/A H/A H/A H/A T7 TBV CONTROL ERROR SELECTOR T9 T9 T8 TBV OPERATING BIAS MFWP 1A MGU MFWP 1B MGU T9 7" Hg VAC SHUTS TBVs 1A TBV 1B TBV AUX S/DPANEL 1A S/U FDW 1B S/U FDW T10 REACTOR CONTROL CORRECTION SELECTOR H/A H/A CONTROL CONTROL T11 MANEUVERING RATE SELECTION (ASP) (ASP) H/A(ASP) H/A (ASP) U1 ICS.des Rev. 1 rtr 2/15/05
Enclosure 4.21 OP/0/A/1108/001 ICS Schematic Page 2 of 3 Unit 2 TAVE TRACKING INPUTS CTP ERROR LOAD LIMITS FDW FLOW GEN MWe THP ERROR T10 RC FLOW (variable) NI FLUX 1.2 RC PUMPS (74%) CTP TAVE ERROR CTP BEST BEST < >
FDW PUMPS (65%)
ASY ROD (55%)
BOTH GEN BKRS OPEN (20%) T3 SP CTP CTP MAXIMUM RUNBACK (15%) DEMAND 2250#
RX TRIP (0%) SETPOINT DEMAND RCS OPERATOR S/G PRESS T1 T2 d/dt f(g) MASTER DEMAND H/A
>101%
MANEUVERING RATES THP ERROR FDW RX LOW LEVEL LIMITS 1%/MIN* X f(g) TEMP TAVE SP MASTER ASY ROD 1%/MIN* H/A SP MAXIMUM RB 20%/MIN 2250#
TRACKING 20%/MIN RX CROSS LIMITS RC FLOW 20%/MIN T11 RCS NEUTRON LOW CBP/MFP SUCT. PRESS. 20%/MIN PRESS ERROR +/- 5% NI BOTH GEN BKRS OPEN 20%/MIN LOSS OF ONE RCP 25%/MIN X DIAMONDPANEL LOSS OF ONE FWP 25%/MIN REACTOR TRIP 600%/MIN IN OUT RC RC CRDMS THP ERROR A FDW FLOW FLOW B FDW THP SETPOINT A B MASTER RATIO MASTER S/G S/G H/A H/A THP PRESS PRESS TOTAL FDW FLOW TO SP A B T2 Tc 2250# FDW TC FDW H/A SP FLOW FLOW THPERROR RCS SP SP PRESS T7 T7 OPER OPER LEVEL LEVEL TURBINE 125psig Tc FDW VALVE LOAD/UNLOAD SP P SP CONTROLLER 50 psig T8 25" 25" 0 psig SP SU 35 # SU LEVEL T4 T5 LEVEL TURBINE COMPOSITE COMPOSITE THP VALVE DEMAND VALVE DEMAND MASTER CONTROLLER CONTROLLER SP H/A SEQ SEQ SP SP BIAS BIAS EHC 1035# 1035#
SP SP TRANSFERFUNCTIONS T1 LOAD LIMITS OPER OPER LEVEL T6 T6 LEVEL T2 TRACKING T3 FDW CONTROL CORRECTION SELECTOR T4 LO LEVEL LIMIT SELECTOR S/G 'A' A TBV 7" Hg B TBV A MFDW A S/U A MFWP BIAS B S/U FDW B MFDW T5 LO LEVEL LIMIT SELECTOR S/G 'B' H/A Vac H/A CONTROL FDW B MFWP CONTROL CONTROL CONTROL H/A T6 SU FDW VALVES CONTROL 50% OP LVL H/A H/A H/A H/A H/A T7 TBV CONTROL ERROR SELECTOR T9 T9 T8 TBV OPERATING BIAS MFWP A MGU MFWP B MGU T9 7" Hg VAC SHUTS TBVs A TBV B TBV AUX S/DPANEL A S/U FDW B S/U FDW T10 REACTOR CONTROL CORRECTION SELECTOR H/A CONTROL Unit 2 ICS Schematic H/A CONTROL O2ICS0001.des T11 MANEUVERING RATE SELECTION (ASP) (ASP) H/A(ASP) H/A (ASP) rtr 10/26/05 Rev. 1
Enclosure 4.21 OP/0/A/1108/001 ICS Schematic Page 3 of 3 Unit 3 TAVE TRACKING INPUTS CTP ERROR LOAD LIMITS FDW FLOW GEN MWe THP ERROR T10 RC FLOW (variable) NI FLUX 1.2 RC PUMPS (74%) CTP TAVE ERROR CTP BEST BEST < >
FDW PUMPS (65%)
ASY ROD (55%)
BOTH GEN BKRS OPEN (20%) T3 SP CTP CTP MAXIMUM RUNBACK (15%) DEMAND 2250#
RX TRIP (0%) SETPOINT DEMAND RCS OPERATOR S/G PRESS T1 T2 d/dt f(g) MASTER DEMAND H/A
>101%
MANEUVERING RATES THP ERROR FDW RX LOW LEVEL LIMITS 1%/MIN* X f(g) TEMP TAVE SP MASTER ASY ROD 1%/MIN* H/A SP MAXIMUM RB 20%/MIN 2250#
TRACKING 20%/MIN RX CROSS LIMITS RC FLOW 20%/MIN T11 RCS NEUTRON LOW CBP/MFP SUCT. PRESS. 20%/MIN PRESS ERROR +/- 5% NI BOTH GEN BKRS OPEN 20%/MIN LOSS OF ONE RCP 25%/MIN X DIAMONDPANEL LOSS OF ONE FWP 25%/MIN REACTOR TRIP 600%/MIN IN OUT RC RC CRDMS THP ERROR A FDW FLOW FLOW B FDW THP SETPOINT A B MASTER RATIO MASTER S/G S/G H/A H/A THP PRESS PRESS TOTAL FDW FLOW TO SP A B T2 Tc 2250# FDW TC FDW H/A SP FLOW FLOW THP ERROR RCS SP SP PRESS T7 T7 OPER OPER LEVEL LEVEL TURBINE 125psig Tc FDW VALVE LOAD/UNLOAD SP P SP CONTROLLER 50 psig T8 25" 25" 0 psig SP SU 35 # SU LEVEL T4 T5 LEVEL TURBINE COMPOSITE COMPOSITE THP VALVE DEMAND VALVE DEMAND MASTER CONTROLLER CONTROLLER SP H/A SEQ SEQ SP SP BIAS BIAS EHC 1035# 1035#
SP SP TRANSFERFUNCTIONS T1 LOAD LIMITS OPER OPER LEVEL T6 T6 LEVEL T2 TRACKING T3 FDW CONTROL CORRECTION SELECTOR T4 LO LEVEL LIMIT SELECTOR S/G 'A' A TBV 7" Hg B TBV A MFDW A S/U A MFWP BIAS B S/U FDW B MFDW T5 LO LEVEL LIMIT SELECTOR S/G 'B' H/A Vac H/A CONTROL FDW B MFWP CONTROL CONTROL CONTROL H/A T6 SU FDW VALVES CONTROL 50% OP LVL H/A H/A H/A H/A H/A T7 TBV CONTROL ERROR SELECTOR T9 T9 T8 TBV OPERATING BIAS MFWP A MGU MFWP B MGU T9 7" Hg VAC SHUTS TBVs A TBV B TBV AUX S/DPANEL A S/U FDW B S/U FDW T10 REACTOR CONTROL CORRECTION SELECTOR H/A CONTROL Unit 3 ICS Schematic H/A CONTROL O3ICS0001.des T11 MANEUVERING RATE SELECTION (ASP) (ASP) H/A(ASP) H/A (ASP) rtr 4/30/06 Rev. 2
Enclosure 4.22 OP/0/A/1108/001 SG Level Ranges Page 1 of 1 NOTE: SG secondary side contains approximately 41.46 Gal./Inch FORMULAS Full Range (Inches)=Full Range (%) X 6.50 Full Range (%)=Full Range (Inches) 6.50 100% 650" 621" (Upper Tube Sheet) 600" 90%
540" 80%
480" 70%
420" 60% 100% 388" 388" FULL RANGE (%)
360" 90%
80%
50%
EXTENDED STARTUP RANGE OPERATING RANGE 300" 70% 300" 60%
40%
50% 250" 240" 40%
30% 200" 200" 30%
180" STARTUP RANGE 20%
20% 10%
120" 0% 96" 100" 100" 10% 60" 0% 0" 0" 0" NOTE: Lower tap for Full Range, Startup Range, and Extended Startup Range (0" reference level) is 8" above lower tube sheet.
SGLVL RV2.des rtr 1/26/05
Enclosure 4.23 OP/0/A/1108/001 Unit 1 Mechanical RB Penetrations (East And West) {13} Page 1 of 4 (INSIDE RB LOOKING TOWARD E. PENT. RM.)
EMV-1 EMV-2 20 42 41 27 25 45 44 43 El. 828' - 0" (2F)
El. 827' - 0" (2F) 30 60 El. 824' - 0" (2G) 61 46 34 33 32 49 48 3 47 El. 820' - 0" (2G) 31 35 24 23 22 21 15 50 38 El. 816' - 0" (1G) 13 18 9 8 7 6 2 1 El. 812' - 0" (1G) u1 rb east pen.tcw Rev. 1 rtr 2/23/01
Enclosure 4.23 OP/0/A/1108/001 Unit 1 Mechanical RB Penetrations (East And West) {13} Page 2 of 4 (INSIDE E. PENT. RM. LOOKING TOWARD RB)
EMV-2 EMV-1 20 41 42 27 25 43 44 45 El. 828'-0" El. 827'-0" 60 30 61 El. 824'-0" 46 47 3 48 49 32 33 34 El. 820'-0" 31 38 50 21 22 23 24 35 15 El. 816'-0" 1 2 6 7 8 9 18 13 El. 812'-0" Note: 1. Pent. #63 & 64 are not shown on this drawing, u1 east pent Rev 2.tcw but are located near Col. Qa-65 in E. Pent. Rm. rtr 2/6/06
- 2. Changes to this graphic may require changes to AP/1/A/1700/026.
Enclosure 4.23 OP/0/A/1108/001 Unit 1 Mechanical RB Penetrations (East And West) {13} Page 3 of 4 (INSIDE RB LOOKING TOWARD W. PENT. RM.)
19 51 17 16 WMV1 WMV2 El. 816' - 6" El. 816' - 0" El. 816' - 0" (1G)
(1G) 57 39 56 55 4 54 10 14 53 52 El. 812' - 0" 59 58 El. 811' - 6" u1 rb west pen.tcw Rev. 1 rtr 2/23/01
Enclosure 4.23 OP/0/A/1108/001 Unit 1 Mechanical RB Penetrations (East And West) {13} Page 4 of 4 (INSIDE W. PENT. RM. LOOKING TOWARD RB) 16 17 51 19 WMV2 WMV1 El. 816' - 6" El. 816' - 0" El. 816' - 0" 52 53 14 10 54 4 55 56 39 57 El. 812' - 0" 58 59 El. 811' - 6" u1 west pen.tcw Rev. 1 rtr 2/23/01
Enclosure 4.24 OP/0/A/1108/001 Unit 2&3 Mechanical RB Penetrations (East And West) {13} Page 1 of 4 EMV-2 EMV-1 (INSIDE RB LOOKING TOWARD E. PENT. RM.)
20 41 42 25 27 43 44 45 El. 828' - 0" (2F)
El. 827' - 0" (2F) 60 30 61 El. 824' - 0" (2G) 46 47 3 48 49 32 33 34 31 El. 820' - 0" (2G) 38 50 15 21 22 23 24 35 El. 816' - 0" (1G) 1 2 6 7 8 9 18 13 El. 812' - 0" (1G) u2&3 rb east pen.tcw Rev. 1 rtr 2/23/01
Enclosure 4.24 OP/0/A/1108/001 Unit 2&3 Mechanical RB Penetrations (East And West) {13} Page 2 of 4 EMV-1 EMV-2 (INSIDE E. PENT. RM. LOOKING TOWARD RB) 20 42 41 27 25 45 44 43 EL. 828'-0" EL. 827'-0" 30 60 EL. 824'-0" 61 46 34 33 32 49 48 3 47 EL. 820'-0" 31 35 24 23 22 21 15 50 38 EL. 816'-0" 13 18 9 8 7 6 2 1 EL. 812'-0" Note: 1. Pent. #63 & 64 are not shown on this drawing, U2&3 east pen Rev 2.tcw but are located near Col. Qa-81 in U2 E. Pent. Rm. rtr 2/6/06 and near Col. Qa-96 in U3 E. Pent. Rm.
- 2. Changes to this graphic may require changes to AP/2,3/A/1700/026.
Enclosure 4.24 OP/0/A/1108/001 Unit 2&3 Mechanical RB Penetrations (East And West) {13} Page 3 of 4 (INSIDE RB LOOKING TOWARD W. PENT. RM.)
16 17 51 19 WMV2 WMV1 El. 816' - 6" El. 816' - 0" El. 816' - 0" (1G) 52 53 14 10 54 4 55 56 39 57 (1G)
El. 812' - 0" 58 59 El. 811' - 6" u2&3 rb west pen.tcw Rev. 1 rtr 2/23/01
Enclosure 4.24 OP/0/A/1108/001 Unit 2&3 Mechanical RB Penetrations (East And West) {13} Page 4 of 4 (INSIDE W. PENT. RM. LOOKING TOWARD RB) 19 51 17 16 WMV1 WMV2 El. 816' - 6" El. 816' - 0" El. 816' - 0" 57 39 56 55 4 54 10 14 53 52 El. 812' - 0" 59 58 El. 811' - 6" u2&3 west pen.tcw Rev. 0 rtr 2/23/01
Enclosure 4.25 OP/0/A/1108/001 Expected Feedwater Flow Per Header Vs. Reactor Power Page 1 of 1 Fdw flow.des
Enclosure 4.26 OP/0/A/1108/001 Miscellaneous Data Page 1 of 3 NOTE: The values in this enclosure are approximations only. Do not use these numbers to perform calculations other than estimates.
- 1. Lake Keowee Elevation Calculation From Keowee Forebay Elevation Indication (2AB3) {14}
FOREBAY ELEV + 700' = Lake Keowee Level (level above sea level in feet)
- 2. Volume Vs. Level For Various Tanks And SFP Pressurizer 23.94 gal/inch Quench Tank 34.94 gal/inch BWST 7608 gal/foot SFP (Unit 1&2) 1512 gal/ 0.1 foot; 544,000 gal. total at 0 feet (1)
(Unit 3) 1041 gal/ 0.1 foot; 376,000 gal. total at 0 feet (2)
SFP/FTC (Unit 1&2) 2300 gal/inch (3)
(Unit 3) 1907 gal/inch (3)
FTC Deep End 261.8 gal/inch Core Flood Tank 5 gal/ 0.01 foot RB Normal Sump 15 gal/inch BAMT (All Units) 400 gallons + 40 gal/inch; tank contains 400 gallons when level indication is at 0 inches. {5}
LDST (All Units) 677 gallons + 31.3 gal/inch; tank contains 677 gallons when level indication is at 0 inches. (4)
CC Surge Tank Level (All Units) 7.8 gal/inch
References:
- 1. OSC-4998 and drawing 0-155G
- 2. OSC-4776 and drawing 0-2155G
- 3. Drawing 0-58A
- 4. OSC-7129
Enclosure 4.26 OP/0/A/1108/001 Miscellaneous Data Page 2 of 3
- 3. Volume For Various Plant Components {8}
Component Volume (gal)* Reference Letdown Coolers 60 Letdown Filters 60 1,2,3 'A' Seal Return Coolers 36 OM-1201-3217, O-436D, O-436G, O-1436A, O-1436C, 1,2,3 'B' Seal Return Coolers 43 O-2436D, O-2436J Seal Return Filter Bypass 1 Seal Supply Filters 5 Seal Supply Filter Bypass 1 Pzr at 0" 718 OSC 7129 {11}
Pzr Surge Line 163 Total volume with Pzr at 0" 881 U1 and U3 HPI Pump A 75 U1 and U3 HPI Pump B 75 U1 HPI Pump C 136 U3 HPI Pump C 128 2A HPI Pump 113 PIP 10-7606 {25}
2B HPI Pump 105 PIP 10-7606 {25}
2C HPI Pump 132 PIP 10-7606 {25}
U1 Purification IX Bypass Line 12 O-435E & O-435L {9}
U2 Purification IX Bypass Line 4 O-435D & O-435L {9}
Piping between 1CS-89 and 57 3CS-89
- If original volume information provided had fractional value, Volume is rounded up to next whole gallon.
Enclosure 4.26 OP/0/A/1108/001 Miscellaneous Data Page 3 of 3
- 4. Volume For Various Plant Demineralizers Component Volume- Resin Volume- Water Reference (ft3) (gallons)
Unit 1 Purification and Spare 35 650 OP/1/A/1103/004 B Purification IXs Unit 1 Deborating and Spare 60 1200 OP/1/A/1103/004 C Deborating IXs Unit 2 Purification and Spare 35 650 OP/2/A/1103/004 B Purification IXs Unit 2 Deborating and Spare 60 1200 OP/2/A/1103/004 C Deborating IXs Unit 3A and 3B Purification 50 650 OP/3/A/1103/004 B IXs Unit 3A and 3B Deborating 60 1200 OP/3/A/1103/004 C IXs
Enclosure 4.27 OP/0/A/1108/001 Instructions For Adjusting Alarm Setpoints Page 1 of 4 On The NI Recorder
- 1. Procedure 1.1 Setting Chart Alarm Setpoints (Unit 1 & Unit 3; see next page for Unit 2)
- 1. Depress the "Root" key.
- 2. Select "Operator".
- 3. Select "Config".
- 4. Select "Channels" to adjust PR alarms, or "Maths" to adjust SR or WR alarms.
- 5. Select appropriate channel number using combo box.
- 6. Select appropriate alarm number (typically alarm 1 is the high alarm, alarm 2 is the low alarm).
- 7. Select the white threshold box.
- 8. Enter the specified threshold.
- 9. Select "OK".
- 10. Repeat Steps 5 through 9 for all alarm functions as necessary.
- 11. Select "Apply".
- 12. Select "Root" key.
- 13. Using "Goto Group" and "Goto Display", navigate to appropriate group as necessary.
Enclosure 4.27 OP/0/A/1108/001 Instructions For Adjusting Alarm Setpoints Page 2 of 4 On The NI Recorder NOTE: Selection of Source Range and Wide Range NI signals to be viewed on Unit 2 NI recorder will be via switches mounted to left of recorder.
1.2 Setting Chart Alarm Setpoints (Unit 2) {26}
- 1. IF Unit 2 NI Recorder Current Access Level is "Logged Out" as indicated in the top left corner of the display, perform the following:
> Select "Current Access Level Key" (top left corner of chart).
> Select "Operator" from the resulting pick list.
- 2. Depress the "Root" key.
- 3. Select "Operator".
- 4. Select "Config".
- 5. Select "Channels" to adjust PR alarms, or "Maths" to adjust SR or WR alarms.
- 6. Select appropriate channel number using combo box.
- 7. Select appropriate alarm number (typically alarm 1 is the high alarm, alarm 2 is the low alarm).
- 8. Select the white threshold box.
- 9. Enter the specified threshold.
- 10. Select "OK".
- 11. Repeat Steps 5 through 9 for all alarm functions as necessary.
- 12. Select "Apply".
- 13. Select "Root" key.
- 14. Using "Goto Group" and "Goto Display", navigate to appropriate group as necessary.
Enclosure 4.27 OP/0/A/1108/001 Instructions For Adjusting Alarm Setpoints Page 3 of 4 On The NI Recorder 1.3 Changing Chart Scale/Speed
- 1. Select "Root Menu" key.
- 2. Select "Go To View".
- 3. Select "Unit _ NI Flux".
- 4. The top chart is SR and WR on a logarithmic scale.
- 5. The bottom chart is WR and PR on a linear scale.
- 6. The remaining displays show the current value of each channel.
NOTE: Grid decades/divisions are set for the Hi Set. Toggling the Hi/Lo Set may mean the decades/divisions do not match the scale (i.e. the zoomed in span may be three decades, where normal scale is ten decades).
- 7. Select the Hi/Lo Set key at bottom left of chart as desired to toggle between chart scale/speeds for the entire recorder.
Enclosure 4.27 OP/0/A/1108/001 Instructions For Adjusting Alarm Setpoints Page 4 of 4 On The NI Recorder 1.4 History Trend
- 1. Select "Options" key.
- 2. Select "Enter History"-
- Use Slider and Page buttons to scroll in time.
- Note- BLACK background indicates that screen is showing history.
- 3. Select "Options" key.
- 4. Select "Exit History" or select "Root" key to return NI chart.
Enclosure 4.28 OP/0/A/1108/001 Unit 1 Core Map Page 1 of 1 North X
1NI-3 1NI-5 1NI-6 1A HOT 1NI-1 1A 2 CO 1 1A D LD L CO W Y 1 1B 1B D CO 2 L LD CO 1B HOT 1NI-8 1NI-2 1NI-4 1NI-7 Z Unit 1 Core Map Rev 1.des rtr 3/21/11
Enclosure 4.29 OP/0/A/1108/001 Unit 2 Core Map Page 1 of 1 North X
2NI-4 2NI-7 2B HOT 2NI-8 2NI-2 2B 2 CO 1 2B D LD L CO W Y 1 2A 2A D CO 2 L LD CO 2NI-1 2A HOT 2NI-5 2NI-6 2NI-3 Z Unit 2 Core Map Rev 1.des
.rtr 7312 08/20/13
Enclosure 4.30 OP/0/A/1108/001 Unit 3 Core Map Page 1 of 1 North X
3NI-4 3NI-7 3B HOT 3NI-8 3NI-2 3B 2 CO 1 3B D L
LD CO W Y 1 3A 3A D CO 2 L LD CO 3NI-1 3A HOT 3NI-5 3NI-6 3NI-3 Z Unit 3 Core Map Rev 1.des rtr 2/13/12
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 1 of 9 NOTE: If changes are required to curves in this enclosure, the OAC curves must be updated at the same time or the OAC curves must be considered not valid. {1}
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 2 of 9 Notes For Unit 1 Wide Range Cooldown Curve
- 1. Maintain RCS P/T below and to the right of the 300°F, 250°F, and 200°F Subcooled curves.
- 2. Maintain RCS P/T above and to the left of the 20°F Subcooled curve.
- 3. When any number of RCPs are running, maintain RCS P/T above and to the left of the 4 RCP NPSH curve. (See EOP curves for abnormal containment conditions).
- 4. When a single RCP in a loop is operating, minimize operating time below the < 4 RC Pump NPSH curve. This limits cumulative damage to the single operating pump caused by cavitation due to required NPSH at high flows.
- 5. RCS is considered depressurized when all of the following conditions exist:
RCS temperature < 200°F RCS pressure < 50 psig All RCPs off
- 6. Use Low Range Curves when either of the following exist:
RCS pressure is < 550 psig RCS temperature is <350°F Heatup/Cooldown Limits RCS Temp Max Cooldown Rate RCS Temp Max Heatup Rate {22}
T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 3 of 9 Unit 1 Wide Range Cooldown Curve Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 4 of 9 Notes For Unit 1 Wide Range Heatup Curve
- 1. Maintain RCS P/T below and to the right of the 300°F, 250°F, and 200°F Subcooled curves.
- 2. Maintain RCS P/T above and to the left of the 20°F Subcooled curve.
- 3. When any number of RCPs are running, maintain RCS P/T above and to the left of the 4 RCP NPSH curve. (See EOP curves for abnormal containment conditions).
- 4. When a single RCP in a loop is operating, minimize operating time below the < 4 RC Pump NPSH curve. This limits cumulative damage to operating pump caused by cavitation due to required NPSH needed at high flows.
- 5. Use Low Range Curves when either of the following exist:
RCS pressure is < 550 psig RCS temperature is <350°F Heatup/Cooldown Limits RCS Temp Max Cooldown Rate {22} RCS Temp Max Heatup Rate T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 5 of 9 Unit 1 Wide Range Heatup Curve Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 6 of 9 Notes For Unit 1 Low Range Cooldown Curve
- 1. Curve #1- RCS cooldown limitations.
- 3. Curve #3- Minimum RCS pressure for continuous operation of single RCP in a loop. Minimize operating time below this line with single RCP in a loop operating to limit cumulative damage to operating pump caused by cavitation.
- 5. RCS is considered depressurized when all of the following conditions exist:
RCS temperature < 200°F RCS pressure < 50 psig All RCPs off
< 40 psig is acceptable while swapping RCPs.
Heatup/Cooldown Limits RCS Temp Max Cooldown Rate RCS Temp Max Heatup Rate {22}
T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 7 of 9 Unit 1 Low Range Cooldown Curve
Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 8 of 9 Notes For Unit 1 Low Range Heatup Curve
- 1. Curve #1- RCS heatup limitations.
- 3. Curve #3- Minimum RCS pressure for continuous operation of single RCP in a loop. Minimize operating time below this line with single RCP in a loop operating to limit cumulative damage to operating pump caused by cavitation.
< 40 psig is acceptable while swapping RCPs.
Heatup/Cooldown Limits RCS Temp Max Cooldown Rate {22} RCS Temp Max Heatup Rate T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.31 OP/0/A/1108/001 Unit 1 RCS Heatup/Cooldown Curves Page 9 of 9 Unit 1 Low Range Heatup Curve
Note: PT/1/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 1 of 9 NOTE: If changes are required to curves in this enclosure, the OAC curves must be updated at the same time or the OAC curves must be considered not valid. {1}
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 2 of 9 Notes For Unit 2 Wide Range Cooldown Curve
- 1. Maintain RCS P/T below and to the right of the 300°F, 250°F, and 200°F Subcooled curves.
- 2. Maintain RCS P/T above and to the left of the 20°F Subcooled curve.
- 3. When RCPs are running, maintain RCS P/T above and to the left of the RCP NPSH curve. (See EOP curves for abnormal containment conditions).
- 4. RCS is considered depressurized when all of the following conditions exist:
RCS temperature < 200°F RCS pressure < 50 psig All RCPs off
- 5. Use Low Range Curves when either of the following exist:
RCS pressure is < 550 psig RCS temperature is <350°F Heatup/Cooldown Limits RCS Temp Max Cooldown Rate RCS Temp Max Heatup Rate {22}
T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 3 of 9 Unit 2 Wide Range Cooldown Curve Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 4 of 9 Notes For Unit 2 Wide Range Heatup Curve
- 1. Maintain RCS P/T below and to the right of the 300°F, 250°F, and 200°F Subcooled curves.
- 2. Maintain RCS P/T above and to the left of the 20°F Subcooled curve.
- 3. When RCPs are running, maintain RCS P/T above and to the left of the RCP NPSH curve. (See EOP curves for abnormal containment conditions).
- 4. Use Low Range Curves when either of the following exist:
RCS pressure is < 550 psig RCS temperature is <350°F Heatup/Cooldown Limits RCS Temp Max Cooldown Rate {22} RCS Temp Max Heatup Rate T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 5 of 9 Unit 2 Wide Range Heatup Curve Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 6 of 9 Notes For Unit 2 Low Range Cooldown Curve
- 1. Curve #1- RCS cooldown limitations.
- 3. Curve #3- Minimum RCS pressure for continuous operation of single RCP in a loop. Minimize operating time below this line with single RCP in a loop operating to limit cumulative damage to operating pump caused by cavitation.
- 5. RCS is considered depressurized when all of the following conditions exist:
RCS temperature < 200°F RCS pressure < 50 psig All RCPs off
- 6. Briefly operating above the LPI pressure curve (#4) or below the RCP NPSH curve (#2) by < 40 psig is acceptable while swapping RCPs.
Heatup/Cooldown Limits RCS Temp Max Cooldown Rate RCS Temp Max Heatup Rate {22}
T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 7 of 9 Unit 2 Low Range Cooldown Curve
Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 8 of 9 Notes For Unit 2 Low Range Heatup Curve
- 1. Curve #1- RCS heatup limitations.
- 3. Curve #3- Minimum RCS pressure for continuous operation of single RCP in a loop. Minimize operating time below this line with single RCP in a loop operating to limit cumulative damage to operating pump caused by cavitation.
- 5. Briefly operating above the LPI pressure curve (#4) or below the RCP NPSH curve (#2) by < 40 psig is acceptable while swapping RCPs.
Heatup/Cooldown Limits RCS Temp Max Cooldown Rate {22} RCS Temp Max Heatup Rate T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.32 OP/0/A/1108/001 Unit 2 RCS Heatup/Cooldown Curves Page 9 of 9 Unit 2 Low Range Heatup Curve
- PZR level restricted to < 380 inches when RCS temperature is < 160°F, < 100 psig AND NO HPIPs operating.
Note: PT/2/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 1 of 9 NOTE: If changes are required to curves in this enclosure, the OAC curves must be updated at the same time or the OAC curves must be considered not valid. {1}
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 2 of 9 Notes For Unit 3 Wide Range Cooldown Curve
- 1. Maintain RCS P/T below and to the right of the 300°F, 250°F, and 200°F Subcooled curves.
- 2. Maintain RCS P/T above and to the left of the 20°F Subcooled curve.
- 3. When RCPs are running, maintain RCS P/T above and to the left of the RCP NPSH curve. (See EOP curves for abnormal containment conditions).
- 4. RCS is considered depressurized when all of the following conditions exist:
RCS temperature < 200°F RCS pressure < 50 psig All RCPs off
- 5. Use Low Range Curves when either of the following exist:
RCS pressure is < 550 psig RCS temperature is <350°F Heatup/Cooldown Limits RCS Temp Max Cooldown Rate RCS Temp Max Heatup Rate {22}
T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 3 of 9 Unit 3 Wide Range Cooldown Curve Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 4 of 9 Notes For Unit 3 Wide Range Heatup Curve
- 1. Maintain RCS P/T below and to the right of the 300°F, 250°F, and 200°F Subcooled curves.
- 2. Maintain RCS P/T above and to the left of the 20°F Subcooled curve.
- 3. When RCPs are running, maintain RCS P/T above and to the left of the RCP NPSH curve. (See EOP curves for abnormal containment conditions).
- 4. Use Low Range Curves when either of the following exist:
RCS pressure is < 550 psig RCS temperature is <350°F Heatup/Cooldown Limits RCS Temp Max Cooldown Rate {22} RCS Temp Max Heatup Rate T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 5 of 9 Unit 3 Wide Range Heatup Curve Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 6 of 9 Notes For Unit 3 Low Range Cooldown Curve
- 1. Curve #1- RCS cooldown limitations.
- 3. Curve #3- Minimum RCS pressure for continuous operation of single RCP in a loop. Minimize operating time below this line with single RCP in a loop operating to limit cumulative damage to operating pump caused by cavitation.
- 5. RCS is considered depressurized when all of the following conditions exist:
RCS temperature < 200°F RCS pressure < 50 psig All RCPs off
- 6. Briefly operating above the LPI pressure curve (#4) or below the RCP NPSH curve (#2) by < 40 psig is acceptable while swapping RCPs.
Heatup/Cooldown Limits RCS Temp Max Cooldown Rate RCS Temp Max Heatup Rate {22}
T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 7 of 9 Unit 3 Low Range Cooldown Curve
Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 8 of 9 Notes For Unit 3 Low Range Heatup Curve
- 1. Curve #1- RCS heatup limitations.
- 3. Curve #3- Minimum RCS pressure for continuous operation of single RCP in a loop. Minimize operating time below this line with single RCP in a loop operating to limit cumulative damage to operating pump caused by cavitation.
- 5. Briefly operating above the LPI pressure curve (#4) or below the RCP NPSH curve (#2) by < 40 psig is acceptable while swapping RCPs.
Heatup/Cooldown Limits RCS Temp Max Cooldown Rate {22} RCS Temp Max Heatup Rate T > 270°F < 45°F in any 1/2 hour period T < 270°F < 25°F in any 1/2 hour period 140°F < T < 270°F < 20°F in any 1/2 hour period T > 270°F < 45°F in any 1/2 hour period T < 140°F < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period RCS depressurized < 45°F in any 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.33 OP/0/A/1108/001 Unit 3 RCS Heatup/Cooldown Curves Page 9 of 9 Unit 3 Low Range Heatup Curve
- PZR level restricted to < 380 inches when RCS temperature is < 160°F, < 100 psig AND NO HPIPs operating.
Note: PT/3/A/0600/001 (Periodic Instrument Surveillance) contains Enclosure (RCS Pressure, Temperature, Heatup and Cooldown Surveillance Sheet) for conditions when RCS pressure/temperature are changing.
Enclosure 4.34 OP/0/A/1108/001 Unit 1&2 Spent Fuel Pool Level Vs. Temperature Curve (DELETED- moved to Page 1 of 1 OP/0/A/1108/001 B (Spent Fuel Pool Level Vs. Temperature Curves))
Enclosure 4.35 OP/0/A/1108/001 Combined Inventory For Emergency Feedwater Curve Page 1 of 1 COMBINED INVENTORY FOR EFW 12 11 10 Acceptable Operation
(>155,000 gal.)
UST LEVEL (FEET) 9 8
Unacceptable Operation 7 (<155,000 gal.)
6 40 45 50 55 60 HOTWELL (INCHES)
Enclosure 4.36 OP/0/A/1108/001 Site Assembly Alarm Test Page 1 of 1
- 1. Initial Conditions 1.1 None.
- 2. Procedure NOTE: IF the CR phone cannot access the PA system, the CR "gray" phone may be tried as an alternate.
2.1 Ensure "PAGE OVERRIDE" switch in "up" position.
2.2 Dial 70 on CR phone.
2.3 Announce
- "THIS IS A TEST OF THE SITE ASSEMBLY ALARM."
- "THIS IS A TEST OF THE SITE ASSEMBLY ALARM."
2.4 Hang-up CR phone.
2.5 Activate alarm as follows:
2.5.1 Place "SITE ASSEMBLY ALARM" to "ON".
2.5.2 After 5 seconds, place "SITE ASSEMBLY ALARM" to "OFF".
2.6 Repeat Step 2.5 one time (for a total of two alarm activations).
2.7 Dial 70 on CR phone.
2.8 Announce
- "THIS CONCLUDES TEST OF THE SITE ASSEMBLY ALARM."
- "THIS CONCLUDES TEST OF THE SITE ASSEMBLY ALARM."
2.9 Hang-up CR phone.
2.10 Ensure "PAGE OVERRIDE" switch in "down" position.
Enclosure 4.37 OP/0/A/1108/001 Emergency Power Switching Logic (EPSL) Page 1 of 2 Manual:
Keowee Emergency Emergency Start switches in each Control Room Emergency Start switches in each Cable Room Automatic:
ES 1 or 2 Start MFBMP actuation Grid Protection (SY Isolate) 1 Load Shed AND Startup Source UV (10 Sec TD)
Standby Breaker Close Initiation (SBCI) 2 Load Shed AND STAR Relay (no Time Delay) 3 Load Shed and E1 and E2 Bkr Tripped OR NOT in Operate Position AND MFB1 AND MFB2 UV AND Retransfer to SU CH1 and CH2 NOT actuated (10 Sec TD) 4 Load Shed and S1 Closed and Standby Bus 1 not Locked out (no Time Delay) 5 Load Shed and S2 Closed and Standby Bus 2 not Locked out (no Time Delay) 6 Seal-in: Load Shed and SBCI signal already satisfied AND No Retransfer to Startup Ch. 1 or 2 signal SBCI Retransfer to AND ES-1(2) OR MFBMP (either one satisfies RX relay)
AND Standby Bus 1 and 2 UV Startup Source AND Startup Source NOT UV (5 Sec TD)
UNDERVOLTAGE UV (62% - 164KV) on same 2 of 3 phases of BOTH Switchyard Isolate the Red and Yellow Bus.
UNDERFREQUENCY UF (57 Hz for 15 cycles - .25 seconds) on same 2 of 3 phases of BOTH the Red and Yellow Bus.
(any one of three)
DEGRADED GRID VOLTAGE UV (227.468KV) on 2 of 3 phases of the YELLOW Bus for >9 Seconds AND ES-1 or 2 on ANY Unit.
Enclosure 4.37 OP/0/A/1108/001 Emergency Power Switching Logic (EPSL) Page 2 of 2 Initiation Main Feeder Bus Monitor UV for 20 seconds on 2 of 3 phases of BOTH MFB's After Initiation:
Provides input to SK Breaker logic AND Retransfer to Startup logic Keowee Emergency Start Panel Initiates a Load Shed signal.
Load Shed signal provides seal-in to prevent loss
- of MFBMP signal.
Starts 'A' & 'B' HPIP's and CC Pumps STAR Relay energizes when:
2 of 3 phases of Startup Source UV detected AND a second UV detected on startup bus within 1 minute of voltage returning STAR to normal from initial UV.
STAR will:
Trip 'E' breakers and block their closure Input to 'Transfer to Standby' logic Input to 'Load Shed' logic Load Shed Logic Path # 1 (1 sec TD after logic satisfied)
- UV on 2 of 3 phases of Startup Source AND
- UV on 2 of 3 phases of Normal Source AND
- ES or STAR Load Shed Logic Path # 2 (1 sec TD after logic satisfied)
- Breaker N1 open AND
- Breaker E1 open AND
- UV on MFB # 1 Z phase AND Load Shed
- ES-1 or STAR-'A' Load Shed Logic Path # 3 (1 sec TD after logic satisfied)
MFBMP (Ch. 1 OR 2): Channel initiates when BOTH
- MFB's UV >20 secs Load Shed Logic Path # 4
- Seal-in (as long as ES or STAR still present)
Load Shed Logic Path # 2a (1 sec TD after logic satisfied)
- Breaker N2 open AND
- Breaker E2 open AND
- UV on MFB # 2 Z phase AND
- ES-2 or STAR-'B' Under voltage Protection SL1 and SL2 Auto-Select switches in "AUTO" AND SL1 and SL2 UV on BOTH Standby Buses.
Degraded Voltage Protection TRIP INTERLOCK DEFEAT switch in "CENTRAL" AND 1st Level 100KV DEGRADED VOLTAGE reached for 9 seconds AND 2nd Level 100KV DEGRADED VOLTAGE reached.
Enclosure 4.38 OP/0/A/1108/001 Condenser Flow And Temperature Data Page 1 of 2
- 1. Initial Conditions NOTE: Manual logging of CCW data is no longer required when affected Unit's CCW checks can be performed per OP/1,2,3/A/1105/014 (Control Room Instrumentation Operation And Information).
_____ 1.1 Manual logging of CCW flow and temperature data is required.
- 2. Procedure 2.1 Log data as required in Table 1 below.
_____ 2.1.1 IF data cannot be gathered as required for Table 1, go to Step 2.2.
_____ 2.1.2 IF Average CCW Outlet Temperature is 100°F OR Station T > 22°F, notify Unit 1 CRS that CCW temperature limits in OP/1,2,3/A/1105/014 could be affected.
_____ 2.1.3 WHEN this enclosure is completed, forward copy to ONS Environmental Chemistry (mail code ON03EN).
Table 1 CCW Flow (A) (1) (2) (3) (4)
For Running Date Performed: {19} Pumps Lowest Available Unit 1 CCW Unit 2 CCW Unit 3 CCW Average CCW Station T (GPM X Station CCW Inlet Discharge Discharge Discharge Outlet 1000) Temperature From Temperature Temperature Temperature Temperature:
Unaffected Units' Affected Unit: _______
OAC Data # CCW Pumps 1 246 OAC points: From Unit 1 From Unit 2 From Unit 3 Data from Data column Running On 2 465 O1P0761, Process Control Process Control Process Control columns (4)-(A)
Time Taker Affected Unit 3 609 O2P0761 or Panel Screen Panel Screen Panel Screen (1)+(2)+(3)/3 4 708 O3P0761
Enclosure 4.38 OP/0/A/1108/001 Condenser Flow And Temperature Data Page 2 of 2 2.2 Log data as required in Table 2 below.
_____ 2.2.1 IF Average CCW Outlet Temperature is 100°F OR Station T > 22°F, notify Unit 1 CRS that CCW temperature limits in OP/1,2,3/A/1105/014 could be affected.
_____ 2.2.2 WHEN this enclosure is completed, forward copy to ONS Environmental Chemistry (mail code ON03EN).
Table 2 CCW Flow Condenser __A Condenser __B Condenser __C Condenser __A Condenser __B Condenser __C For Running Date Performed: {19} Pumps Inlet Temp. Inlet Temp. Inlet Temp. Outlet Temp. Outlet Temp. Outlet Temp.
______________ (GPM X 1000)
Avg.
Affected Unit: _______
Data # CCW 1 246 __A1 __A2 __B1 __B2 __C1 __C2 __A1 __A2 __B1 __B2 __C1 __C2 Outlet 2 465 (TH14) (TH15) (TH16) (TH17) (TH18) (TH19) (TH20) (TH21) (TH22) (TH23) (TH24) (TH25) Temp.
Time Taker Pumps 3 609 On 4 708
Enclosure 4.39 OP/0/A/1108/001 LDST Pressure Vs. Level (All Units) Page 1 of 2 (Instrument Error Included) 100 90 80 LDST Pressure (psig) 70 60 50 Operation above and to the left of Curve 1 NOT PERMITTED: declare BOTH trains of HPI INOPERABLE.
40 30 Re gi on Op.
issibl 20 Pe e
rm 1
rve Cu 10 Operation below and to the right of Curve 2 requires the 2 compensatory actions listed ve Cur on Page 2 of this enclosure.
0 0 10 20 30 40 50 60 70 80 90 100 LDST Indicated Level (inches) LDST lvl vs press.des Rev. 6 RTR 3/01/05
Enclosure 4.39 OP/0/A/1108/001 LDST Pressure Vs. Level (All Units) Page 2 of 2
Reference:
Curve information comes from drawing #ONTC-0-101A-0005-01. {15}
NOTE: If LDST pressure is < 30 psig, leakage from BWST into HPI System may occur.
- 1. When HPI Pumps are operating: {3}
1.1 LDST pressure and level should remain within "Permissible Op. Region" of "LDST Pressure Vs. Level" curves.
- If system operation leaves the "Permissible Op. Region", but is still between Curve 1 and Curve 2, actions should be taken immediately to restore system to acceptable operating region.
- "LDST Pressure Vs. Level" curves are also located on OAC.
NOTE: If LDST Pressure Vs. Level is above and to the left of Curve 1 and HPI emergency injection initiates, gas may be drawn into HPI Pump suctions resulting in HPI Pump damage.
- 2. If LDST Pressure Vs. Level is above and to the left of Curve 1, then declare BOTH trains of HPI INOPERABLE.
2.1 Immediately depressurize LDST below Curve 1.
2.2 Refer to TS 3.0.3 for shutdown requirements.
2.3 Make notifications as required by OMP 1-14 (Notifications).
NOTE: If LDST Pressure Vs. Level is below and to the right of Curve 2, it may be possible to draw a vacuum in LDST resulting in HPI Pump damage due to inadequate NPSH. This could occur even though sufficient LDST level exists.
- 3. If LDST Pressure Vs. Level is below and the right of Curve 2, then perform the following:
3.1 Pressurize LDST back into "Permissible Op. Region" of "LDST Pressure Vs. Level" curve unless LDST is being depressurized intentionally by an approved procedure.
3.2 Carry a note on the Turnover Sheet to the effect that if a transient occurs which requires additional HPI flow, immediately open (1)(2)(3)HP-24 and (1)(2)(3)HP-25 to provide an adequate suction source to HPI Pumps.
3.3 IF LDST pressure CANNOT be maintained 0 psig, a LDST vent path must be established.
- (1)(2)(3)GWD-19 (LDST VENT) AND (1)(2)(3)GWD-20 (LDST Vent Blk) (LDST Hatch Area) must be open.
Enclosure 4.40 OP/0/A/1108/001 ESV System Vacuum Requirements Page 1 of 1 0
5 Tank Pressure (in Hg vacuum) 10 Unacceptable 15 20 Acceptable 25 30 782 784 786 788 790 792 794 796 798 800 Lake Level (Feet)
Esv_vacsp.xls Rev. 5 9/15/99
Enclosure 4.41 OP/0/A/1108/001 CCW Discharge Local Temperature Data Page 1 of 1 Date Performed:______________
- 1. Initial Conditions
_____ 1.1 Logging of CCW discharge local temperature data required.
- 2. Procedure NOTE: Metal cabinet that houses the local CCW discharge digital temperature instruments is located at fence on NE side of CCW discharge structure. Metal cabinet latches are slot headed screws and will need a flat blade screw driver (or other suitable object) to operate.
_____ 2.1 Open metal cabinet and log data as required on chart below.
_____ 2.1.1 IF any Unit discharge temperature OR the average CCW discharge temperature is 100°F, perform the following:
A. Notify Unit 1 CRS that CCW temperature limits in OP/1,2,3/A/1105/014 could be affected.
_____ 2.2 WHEN this enclosure is completed, forward copy to ONS Environmental Chemistry (mail code ON03EN).
Time Data Unit 1 CCW Unit 2 CCW Unit 3 CCW Average CCW Taker Discharge Discharge Discharge Discharge Temperature Temperature Temperature Temperature
.42 OP/0/A/1108/001 (Not Used) Page 1 of 1
.43 OP/0/A/1108/001 (Not Used) Page 1 of 1
Enclosure 4.44 OP/0/A/1108/001 RCS Boron Changes Due To Letdown Temperature Changes {29} Page 1 of 4 NOTE: Information below curve title line denotes resin mix that curves are applicable for; Chemistry Group can verify this information.
Curve file located at \\onsfs00\dwgs\1108 001 rev 107 boron curves
Enclosure 4.44 OP/0/A/1108/001 RCS Boron Changes Due To Letdown Temperature Changes {29} Page 2 of 4 NOTE: Information below curve title line denotes resin mix that curves are applicable for; Chemistry Group can verify this information.
Curve file located at \\onsfs00\dwgs\1108 001 rev 107 boron curves
Enclosure 4.44 OP/0/A/1108/001 RCS Boron Changes Due To Letdown Temperature Changes {29} Page 3 of 4 NOTE: Information below curve title line denotes resin mix that curves are applicable for; Chemistry Group can verify this information.
Curve file located at \\onsfs00\dwgs\1108 001 rev 107 boron curves
Enclosure 4.44 OP/0/A/1108/001 RCS Boron Changes Due To Letdown Temperature Changes {29} Page 4 of 4 Curve file located at \\onsfs00\dwgs\1108 001 rev 107 boron curves
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 1 of 16
- 1. Temperature Measuring Devices 1.1 RCS Temperature is measured using either Resistance Temperature Detectors (RTDs) OR Thermocouples.
1.2 RTDs work by correlating a change in electrical resistance with a change in temperature. As the temperature of the wire increases, its resistance increases. This resistance change is measured and displayed as temperature.
1.2.1 Failure modes are as follows:
- Shorted RTDs will display lower than actual temperature since the resistance of a short is essentially zero.
- Open RTDs will display higher than actual temperature since an open circuit is read as infinite resistance.
- Failure of the RTD bridge source will cause the indication to fail to its minimum nominal value.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 2 of 16 1.2.2 RTDs are powered as follows:
RTD # Description Power Supply RD1A RPS Ch A Th A KVIA RD1B ICS NR A1 Th KI or KU from Auctioneering circuit RD2A ICS NR A2 Th KI or KU from Auctioneering circuit RD2B RPS Ch B Th A KVIB RD3A RPS Ch C Th B KVIC RD3B ICS NR B1 Th KI or KU from Auctioneering circuit RD4A ICS NR B2 Th KI or KU from Auctioneering circuit RD4B RPS Ch D Th B KVID RD5A ICS NR A2 Tc KI or KU from Auctioneering circuit RD5B ICS WR A2 Tc KI or KU from Auctioneering circuit RD6A ICS WR A1 Tc KI or KU from Auctioneering circuit RD6B ICS NR A1 Tc KI or KU from Auctioneering circuit RD7A ICS NR B2 Tc KI or KU from Auctioneering circuit RD7B ICS WR B2 Tc KI or KU from Auctioneering circuit RD8A ICS WR B1 Tc KI or KU from Auctioneering circuit RD8B ICS NR B1 Tc KI or KU from Auctioneering circuit RD84A ICS WR A Th KI or KU from Auctioneering circuit RD84B ICCM WR A Th KVIA RD85A ICS WR B Th KI or KU from Auctioneering circuit RD85B ICCM WR B Th KVIB
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 3 of 16 1.3 Thermocouples work by creating a potential (or voltage) at the junction of two dissimilar metals. Low potential at the contact corresponds to low temperatures, while high contact potential corresponds to high temperatures.
- Shorted thermocouples where the short occurs between the element and well will NOT change the indication, since the potential across the junction does NOT change.
- Shorted thermocouples where the short occurs between the leads and outside the well will cause the indication to read ambient, since the leads are made of the same material as the junction.
- Shorts to ground will cause the thermocouple indication to fail low since the potential across the junction goes to zero.
- Open circuits result in a lower than actual indication due to the decrease in potential across the junction.
1.3.1 Type "J" thermocouples use Iron-Constantine and have a range of 0 - 700°F.
These are typically used to measure the temperature of the pressurizer and its associated piping and connections. (RC-66, RC-67, and RC-68 tailpipes; Pressurizer Surge Line; Pressurizer Spray Line) 1.3.2 Type "K" thermocouples use Chromel-Alumel and have a range of 0 - 2500°F.
Typical applications for these thermocouples are incore temperature measurements. Each core has 52 incore thermocouples (ICTCs); 47 input to various calculations, indications and the OAC. Five are used for SSF indication only. ICCM trains A and B each have 12 ICTCs feeding them. The ICCM indications also feed the OAC. The remainder of the ICTCs feed the OAC but, are NOT considered environmentally qualified.
1.4 Hot Leg Control Room Temperature Indications 1.4.1 Narrow Range Temperatures are used between 520°F - 620°F.
1.4.2 Narrow Range Thot feeds each RPS channels High Temperature AND Variable Low Pressure Trip functions. Channels A and B are measured from Loop A, while Channels C and D are measured from Loop B.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 4 of 16 1.4.3 Median Select signal OR the average of the two NR Thot RTDs feed:
- High Temperature Alarm Circuit
- Loop A and Loop B NR Thot Dixon meter
- Unit Thot NR recorder (the position switch allows the selected Loop A Thot, the selected Loop B Thot, or the average of both Loops Thot to be displayed)
- NR Tave Circuit
- Loop T Circuit
- ICS (Both loop Thot signals will feed)
- Aux Shutdown Panel (Loop B only) 1.4.4 Wide Range Temperatures indicate from 50°F - 650°F.
1.4.5 Two WR Thot are located on each hot leg. One feeds ICCM, the other ICS.
1.4.6 ICCM WR Thot feeds:
- Digital LED meters. Off-scale low indicate LO. Off-scale high indicates HI.
- ICCM Loop Subcooled Margin Monitors.
- Median select circuit.
- OAC Loop Subcooled Margin Monitors.
1.5 Cold Leg and Average Temperature Control Room Indications 1.5.1 Output of the median select circuit OR average of the two NR Tcold feeds:
- Loop A and Loop B NR Tcold meter.
- Loop A and Loop B T meter.
- Loop A and Loop B Tave meter.
- Tc meter.
- Controlling Tave digital meter (green LED).
- Tave Recorder.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 5 of 16 1.5.2 Tave Select Schemes:
- IF RCS flow is normal ( 70E6 lbm/hr) in both loops, the Unit Tave output feeds the Tave control circuit.
- IF RCS flow is normal ( 70E6 lbm/hr) in one loop and low (< 62E6 lbm/hr )
in the other loop, the Loop Tave in the high flow loop becomes the controlling Tave.
- IF RCS flow in both loops is low (< 62E6 lbm/hr), the Unit Tave output feeds the Tave control circuit.
- IF either steam generator is on Low Level Limits, the highest Tave is selected.
1.5.3 WR Tcold feeds:
- Tcold digital meter (selected from A1, A2, B1, or B2 Loops) displays LO/HI IF off-scale low or high.
- Selected Tcold signal feeding the meter also feeds the recorder.
- Fourth Reactor Coolant Pump starting interlock. The lowest Tcold in the A loop feeds the starting circuit for the A1 and A2 RCPs, while the lowest Tcold in the B loop feeds the starting circuit for the B1 and B2 RCPs.
1.6 Pressurizer temperature is measured using three RTDs. Channels A and B feed ICCM.
These temperatures feed the temperature compensation circuits for pressurizer level.
Channel A is used to compensate Pzr Level 1 and Pzr Level 2. Channel B is used to compensate Pzr Level 3. Channel C feeds the OAC only. Additionally, Channel A feeds the pressurizer saturation indication.
- 2. RCS level is measured using three different methods: tygon tubing, Rosemount P cells, and ultrasonic level measurement.
2.1 Tygon tubing is used to provide level indication of the RCS cold legs. It is a manometer type measurement. By connecting the tubing to the bottom of the cold legs, the elevation pressure of the water in the cold leg will force a column of water into the tygon tubing which is equal in height to the cold leg level, provided both legs have equal overpressure.
2.2 A Rosemount P cell compares the pressure of a reference leg to the elevation pressure of a process fluid. This type of instrument feeds the respective unit's LT-5. LT-5 is referenced to the hot leg center line (water level at the centerline is 0").
2.3 Ultrasonic level detectors measure the time required for a sound pulse to travel from the sensor, through a medium, reflect from a surface due to density change, and return to the sensor. This time is correlated to a height of water AND output as inches of water.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 6 of 16
- 3. RCS flow is measured using a gentilli tube. The gentilli tube is used to measure the difference between the static head of the system and the velocity head of the system. The P between these two parameters is transmitted using a Rosemount P transmitter.
3.1 Five pairs of tubes, each pair has one tube pointing in the opposite direction of flow and the other tube pointed in the direction of flow. The tubes pointing in the direction opposite flow feed a common high pressure header. Those pointed in the direction of flow feed a common low pressure header.
3.2 With no flow, each pair of tubes pointing in either direction measure the same pressure; therefore P is 0 psid.
3.3 When RCS flow is present, a P is developed which causes a flow indication to be present.
3.4 Should the low pressure header fail, the pressure in the header will decrease, which increases the measured P, causing RCS flow indication to increase.
3.5 Conversely, should the high pressure header fail, the pressure in the header will decrease, creating a smaller measured P, causing a smaller indicated RCS flow.
3.6 Five P transmitters are attached to the high and low pressure headers, AND are referred to as Channels A - E, respectively. Channels A-D feed the RPS channels A-D. The ICS uses the median selected value between Channel A, B, and E.
3.7 The measured P is used to calculate a volumetric flow rate. This flow rate does NOT change as RCS temperature changes. The P signal is processed through a square root extractor. Flow is proportional to the square root of the P.
3.8 Mass flow rate is derived by temperature compensating the volumetric flow rate. Mass flow rate does change as RCS temperature changes. Loss of temperature compensation typically results in higher than actual flow. However, since mass flow is directly proportional to the density of the RCS, the following rules apply:
- IF Thot fails low, flow indicates HIGHER than actual, since it appears the RCS fluid is more dense.
- IF Thot fail high, flow indicates LOWER than actual, since it appears the RCS fluid is less dense.
3.9 RCS flow is temperature compensated from a WR Hot Leg RTD on the appropriate loop.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 7 of 16
- 4. Rosemount pressure measuring devices work on the principle of measuring a change in capacitance created by movement of a diaphragm between two capacitance plates and converting the output into a pressure signal.
4.1 NR Pressure Range 1700 psig - 2500 psig.
4.2 Loop A has (2) NR pressure transmitters, while Loop B has (3) NR Pressure transmitters.
4.3 Loop A NR pressures feed the RCS Channels A and B, while Loop B NR pressures feed RPS Channels C and D, AND Channel E.
4.4 Median select from RPS Channels A, B, and E feed:
- RC-66 PORV "HIGH" open circuit
- RC-1, PZR SPRAY AUTO circuit
- Pressurizer Heater AUTO circuit
- Auxiliary Shutdown Panel indication
- NR Recorder
4.6 (Old ES System) Five WR Pressure Range sensors are located on the two hot legs.
- Two feed the SSF (one from each loop).
- The remaining (3) feed ES AND Subcooled Margin Monitors. Loop A WR transmitters feed ES Analog Channels A and B. Loop B WR transmitter feeds ES Analog Channel C.
- The OAC core SCM uses the lower of the two pressures feeding ES Channel Analog B and ES Channel Analog C.
4.7 (New ES system) Five WR Pressure Range sensors are located on the two hot legs.
- Two feed the SSF (one from each loop).
- The remaining (3) feed ES AND Subcooled Margin Monitors. Loop A WR transmitters feed ES Channels A and B. Loop B WR transmitter feeds ES Channel C.
- The OAC core SCM uses an input from a Loop A transmitter and a Loop B transmitter, fed from hard-wired OAC points.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 8 of 16 4.8 (Old ES System) WR RCS Pressure recorder displays the signal selected using the amphenol connector in the ES Analog A cabinet. This connector can be plugged into ES Analog Channel A or ES Analog Channel B.
- The amphenol selected signal also feeds the LP-1 open interlock, as well as the ES HP AND LP INJECTION BYPASS PERMIT statalarms.
4.9 (New ES system) WR RCS Pressure recorder displays the signal fed from ES Train 2 which is normally fed from ES WR Channel A. ES Train 2 automatically transfers input to ES Channel B WR pressure upon loss of Channel A signal. Signal may be manually selected to Channel A or B using the GSM. The Open-Permissive interlock to LP-1 is supplied from all three ES channels RCS pressure through three 2MIN blocks. If the output of each 2MIN block is less than the setpoint of 375 psig, then the Open-Permissive is then sent to 2/3 Logic Block located in the ODD Voter Cabinets. The output of the 2/3 Logic Block (1/Subsystem) provides the permissive signal to LP-1 from either Subsystem. The permissive signal is lost when the 2.MIN RCS WR Pressure increases to 400 psig on at least 2/3 of the Input Instrument Channels 2.MIN values in Both Subsystems.
4.10 ICCM Pressure range is 0 psig - 3000 psig.
4.11 Each ICCM train pressure feeds the ICCM SCM and meters. The meters will display HI at 2750 psig.
4.12 RCS Low Range Pressures range is 0 psig - 600 psig.
- The sensor is located on the ICCM RVLIS impulse line.
- Although the instrument is always valved in, the meter is NOT turned on unless RCS pressure is 600 psig or less.
- This signal inputs into the RC-66 LOW AUTO open circuit.
- For the PORV to open on the LOW AUTO circuit, the Low Range Pressure switch must be ON AND the PORV selector switch placed in LOW.
- The digital Dixon meter blinks AND the bar graph is pegged high when the Low Range Pressure Switch is ON AND RCS pressure is greater than 600 psig.
- 5. RCS Level 5.1 Pressurizer Level and Temperature Instrumentation 5.1.1 Three P transmitters are used for measurement and control of Pressurizer Level.
Each of these feed the HI/LO statalarm.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 9 of 16 5.1.2 Levels #1 and #2 are fed through ICCM Train "A". #2 tap also feeds SSF uncompensated Pzr level and Pzr pressure.
A. Level tap #2 has a separate pressure/level transmitter to feed Pzr uncompensated level and Pzr pressure indication to the SSF Control Room.
{4}
5.1.3 Level #3 is fed through ICCM Train "B".
5.1.4 Pressurizer Level control is protected from failure by SASS.
5.1.5 Each transmitter has individual upper and lower instrument taps.
5.1.6 Pzr temperature for compensation is supplied from a single well with three RTD elements located in the well.
A. Pzr Temperature Channel 'A' is fed to ICCM Channel 'A'.
Pzr Temperature Channel 'B' is fed to ICCM Channel 'B'.
Pzr Temperature Channel 'C' is fed to the non-safety OAC only.
B. ICCM develops the temperature compensated signal. This selected signal is supplied to :
- Pzr Chart Recorder
- HP-120 control
- Aux Shutdown Panel
- Low Pzr Level Heater Cutoff
- Emergency HI/LO Statalarm C. RCS Pressure compensated Pzr level is fed to the OAC only.
D. Uncompensated Pzr Level will always read lower than the actual level.
E. Pzr Heaters will return to the mode they were in prior to reaching the cutoff setpoint.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 10 of 16 5.1.7 RCS Level Measurement using LT-5A and LT-5B A. Reference leg is a water filled leg open to the Reactor Building atmosphere.
B. Variable leg is connected to the RCS Cold Leg piping between a RCP and the reactor vessel. At 0 inches, the water level is at the centerline of the hot leg and cold leg.
C. LT-5 Fluctuations with Reactor Building/RCS pressures:
- IF PRCS < PRx Bldg Vessel Level indicates LOWER than actual.
- IF PRCS > PRx Bldg Vessel Level indicates HIGHER than actual.
- IF Rx Building temperature increases, the water in the reference leg swells and may spill out. Should this occur, Vessel Level will indicate HIGHER than actual.
5.1.8 RCS Level Measurement using Ultrasonics A. A sound pulse is transmitted from the bottom of the piping. The wave travels to the surface and is reflected back to a receiver. The time for the wave to travel is measured. Based on this time, a vessel level is inferred.
B. One instrument is placed on one hot leg, and one instrument is placed on one cold leg.
C. Measurement is from -18" to +18" (Hot Leg) and -14" to + 14" (Cold Leg).
0" is the piping centerline.
D. OAC alarms at +10". String checks are performed on levels greater than 0" only.
- 6. Pressurizer Relief Valve Monitor 6.1 The monitor detects flow through the RCS relief valves using a self generating piezoelectric transducer. This means it requires no outside power supply. One detector per valve exists for unit three, while units one and two employ two detectors per valve.
6.2 Alarms on:
- Switch in Test
- 5th lamp (25 % flow) is lit
- Power switch is OFF
- Supplied from: Unit 1 and Unit 2- KVIA; Unit 3- KVIB
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 11 of 16
- 7. SASS Operation 7.1 SASS protects against instrument failures by comparing one signal against another. Should the selected signal suddenly change from the compared signal, SASS automatically selects the alternate signal.
7.2 The OAC provides a MISMATCH alarm upon SASS actuation.
7.3 The following signals are monitored by SASS:
- OTSG "A" Operating Range Level Channel 1 AND Channel 2
- OTSG "B" Operating Range Level Channel 1 AND Channel 2
- Pressurizer Level (Channel 1 OR 2) AND Channel 3 NOTE: If Pzr Level Channel 1 or 2 is selected, SASS input is from the selected level channel and Channel 3. If Pzr Level Channel 3 is selected, SASS input is Channel 3 and Channel 1.
7.4 When SASS is in AUTOMATIC, SASS selects the alternate signal IF the selected signal deviates rapidly from the alternate signal. The action is independent of the selector switch position.
7.4.1 Upon SASS actuation the following will be observed:
- MISMATCH OAC Alarm.
- SASS Panel red TRIP light will be ON.
- SASS Panel green AUTOMATIC light will be OFF.
- SASS Panel amber MISMATCH light will be ON.
- The channel will stay in MANUAL until the signal is good and the channel is manually reset.
- Once channel is manually reset, the AUTO light will be ON, the MISMATCH AND TRIP lights should be OFF.
7.4.2 While SASS is in AUTO, the normal selector switch can be used to select the input signal.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 12 of 16 NOTE: An instantaneous mismatch (rapid mismatch >6 %) can occur and clear immediately. This will cause only a red "trip' light to illuminate without an Amber "Mismatch" light or OAC mismatch alarm. The green "Auto" light will be extinguished also.
7.4.3 Upon receipt of a MISMATCH (triggered by a deviation between signals of 3-6%), SASS swaps to MANUAL, but does NOT select the alternate signal. The following will be observed at the SASS panel:
- SASS Panel green AUTOMATIC light will be OFF.
- SASS Panel amber MISMATCH light will be ON.
- MISMATCH OAC alarm.
- When condition clears, the channel will reset to AUTOMATIC with no operator action.
7.4.4 When SASS is in MANUAL, no protection is provided.
7.4.5 Upon a loss of power to SASS, whichever signal is selected is fed though.
7.4.6 The TEST switch simulates rapid failure. The direction the switch is moved to is the signal being simulated to fail. The alternate signal shall be verified as being accurate prior to testing the trip function.
- 8. Recognizing Problems With Dixon Meters 8.1 Loss of power to an instrument causes the indicator to go blank. Should the input signal fail, the meter may fail either mid-scale or low.
8.2 OVERRANGED
Off scale HIGH with the upper LEDs blinking. (Blinking Digital 8's)
8.3 UNDERRANGED
Analog bottom LED flashing. (Solid Digital 0's OR Low Scale Value)
9.2 Tave feeds Reactor Demand and OTSG Low Level Limit Circuitry.
9.3 WR Thot feeds the temperature compensation for RC Flow.
9.4 WR Tc feeds the RCP starting interlocks.
9.5 Total RC Flow feeds the RC Flow Runback Circuitry.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 13 of 16 9.6 Loop RC Flow feeds:
- FDW Reratio Circuit
- Total Flow Control
- Core Thermal Power Best
- CTP Demand Load Limit
- Tave selection circuit 9.7 RCS and Core Subcooling Margin Programs.
- 10. OAC Program 10.1 Operability requirements are found in TS.
10.2 Each units Surveillance PT checks operability of the inputs.
10.3 Inputs:
- NI NI-8 Power
- Reactor Building Pressure
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 14 of 16 NOTE:
- Core SCM uses the lower of the two Loop WR pressure inputs.
- When NI power > 2%, the program takes the average of operable CETCs NOT used by the SSF. (Total of 47). Operable is typically defined as the indicated value is within 50 degrees of the average. Should the CETC be in "scan lockout" or "inserted value", the calculation will exclude this point.
- When NI power < 2% for > 45 seconds, the program takes the average of the five highest qualified CETCs. The OAC looks at all 24 qualified CETCs.
10.4 The OAC SCM provides the input into the statalarms ("RC APPROACHING SATURATED CONDITIONS"). Listed below are the alarm setpoints:
- IF NI power > 2% , Loop SCM < 15°F OR Core SCM < 10°F.
- IF NI power < 2%, Loop SCM < 15°F OR Core SCM < 15°F.
- The alarm reflashes IF any SCM reaches 5°F.
- The OAC alerts the operator to actual saturated conditions at 0°F SCM.
10.4.1 IF the RCS is subcooled, the indications display solid red numbers indicating the SCM.
10.4.2 IF the RCS is saturated, the indications display flashing red 000's.
10.4.3 IF the RCS is superheated, the indications display flashing red negative numbers indicating the amount of superheat.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 15 of 16 NOTE: Normal alignment is for ICCM to be selected to feed the SCM Meters.
10.4.4 IF the OAC is in Automatic and Reactor Building pressure is < 3 psig, the OAC feeds the Loop 'A', Core, and Loop 'B' indications. The remaining window (third from the left) is the ICCM Train 'B' Core SCM. IF the Reactor Building pressure is > 3 psig, ICCM Loop 'A', ICCM Train 'A' Core, ICCM Train 'B' Core and ICCM Loop 'B' is displayed.
OAC (RB pressure < 3 psig)
OAC OAC OAC Core ICCM B Core Loop A Loop B OAC (RB pressure > 3 psig)
ICCM ICCM ICCM A Core ICCM B Core Loop A Loop B
- 11. ICCM SCM 11.1 Core SCM is calculated from the average of the five highest qualified CETCs for that train and the 0 - 3000 psi RCS pressure transmitter feeding that train.
11.2 Loop SCM is calculated from the ICCM WR Thot and the 0 -3000 psig RCS pressure transmitter.
11.3 ICCM Indications:
11.3.1 A spare CRDM tap is used for one impulse line that splits and feeds one side of two P cells, one for each train.
11.3.2 The other impulse line taps into the decay heat drop line. A separate impulse line exists for each train.
11.3.3 The ICCM channel "A" RCS pressure indication taps are located on the impulse line which feeds the hot leg level P cell.
11.3.4 The ICCM channel "B" RCS pressure indication taps are located on the impulse line which feed the reactor vessel level P cell.
11.3.5 Reactor Vessel and hot leg level indications are NOT valid IF one or more RCPs or LPI pumps are operating since the calculation can NOT compensate for pressure fluctuations caused by forced flow.
Enclosure 4.45 OP/0/A/1108/001 RCS Instrumentation Page 16 of 16 11.3.6 Hot leg level is NOT valid IF Hot Leg vents are open, since the vents tap into the same impulse line.
11.3.7 IF RCPs are running, INVALID is displayed on the ICCM meter, pointer and whole numbers go blank.
11.3.8 MALFUNCTION is displayed IF the RCPs are off and an input sensor fails. The pointer and whole number does NOT go blank.
11.3.9 MALFUNCTION is displayed IF the RCPs are on and an input sensor fails. The pointer and whole number is blank.
11.3.10 FORCED FLOW CONDITION is displayed IF an LPI pump is operating. This is NOT affected, nor does it affect the INVALID indications received when RCPs are running.
11.3.11 CETC indicates in reverse video when > 700°F.
11.3.12 SCMs are displayed in reverse video when saturated or superheated conditions are present.
11.3.13 OFF HIGH indicates a temperature is off scale high or transmitter volts are off scale high.
11.3.14 OFF LOW indicates a temperature is off scale low or transmitter volts are off scale low.
11.3.15 ALARM indicates a hydraulic isolator limit switch is activated.
11.3.16 DISABLED indicates a sensor is disabled.
11.3.17 ICCM can be monitored on the Plasma display, the OAC, the trend recorder on VB2 (train "A" only), and ICCM control cabinets.
11.3.18 IF ICCM is off-line for test, maintenance, or calibration, it displays DATA LINK FAILURE. All other indications freeze as is.
11.3.19 Loss of ICCM main cabinet incoming power results in LOW indication and blank plasma screen. Loss of internal cabinet power results in LOW indication and DATA LINK FAILURE indication on plasma screen.
11.3.20 IF HPI flow < 60 gpm, ICCM indicates 0 gpm.
11.3.21 IF LPI flow < 300 gpm, ICCM indicates 0 gpm.
11.3.22 IF RBS flow < 150 gpm, ICCM indicates 0 gpm.
Enclosure 4.46 OP/0/A/1108/001 Total Loss Of DHR Time To Boil Page 1 of 1 (DELETED- moved to OP/0/A/1108/001 A (Reactor Core And SFP Loss Of Cooling Heatup Tables))
Enclosure 4.47 OP/0/A/1108/001 Maximum SFP Temperature Vs. Total SFC System Flow Page 1 of 2 Unit 1&2 Maximum SFP Temperature vs. Total SFC System Flow 200 190 180 +0.5 Pool Level 170 +0.0 Pool Level 160 Temperature, oF Acceptable 150 Region is Below Applicable Curve 140 130 -0.5 Pool Level 120
-1.0 Pool Level 110 100 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 Total System Flow, gpm OSC-6800 Rev. 1
Enclosure 4.47 OP/0/A/1108/001 Maximum SFP Temperature Vs. Total SFC System Flow Page 2 of 2 Unit 3 Maximum SFP Temperature vs. Total SFC System Flow 200 190 180 +0.5 Pool Leve 170 160 +0.0 Pool Level 150 140 Acceptable Temperature, oF Region is Below 130 Applicable Curve 120 110 100 -0.5 Pool Level 90 80 -1.0 Pool Level 70 60 50 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 Total System Flow, gpm OSC-6800 Rev. 1
Enclosure 4.48 OP/0/A/1108/001 Appendix Page 1 of 2
- 1. PIP O-98-1375 CA #1- added Note to affected enclosures to verify that OAC P/T curves are updated when the P/T curves in these enclosures are updated.
NOTE: Item #2 superseded in Rev. 109 of this procedure; see Item #31.
- 2. PIP O-98-3399 CA #1- updated Enc. 3.1 "BHUT Volume Vs. Level Curve" with curve provided by ONS Engineering.
- 3. PIP O-01-097-3072- additional guidance for LDST level and pressure added.
- 4. PIP O-99-3297 CA #1- Revised steps to match information contained in OTC lesson plan.
- 5. PIP O-00-01273 CA #2- added reference to BAMT level vs. volume calculation.
- 6. PIP O-01-01955 CA #3- included additional notes on CBAST concentration vs. level curves.
- 7. PIP O-99-04378 CA #5- added new note to all Units' Low Range Heatup and Cooldown curves that allows brief periods of operation above LPI curve and below RCP NPSH curve while swapping RCPs.
- 8. PIP O-02-02537 CA# 14- added information for various plant equipment liquid volumes.
- 9. PIP O-02-05298 CA# 2- added information for various plant equipment liquid volumes.
NOTE: Item #10 superseded in Rev. 109 of this procedure; see Item #31.
- 10. PIP O-03-07998 CA #4- limit and Precaution for BHUT level indication and Notes on BHUT curves added.
- 11. PIP O-04-04423 CA #2- Pzr/Surge Line volume information added.
- 12. Not Used
- 13. Changes made to Enclosure 3.23 "Unit 1 Mechanical RB Penetrations (East And West)" and Enclosure 3.24 "Unit 2&3 Mechanical RB Penetrations (East And West)" must also be made to similar drawings in AP/1,2,3/A/1700/026 (Loss Of Decay Hear Removal).
- 14. PIP O-06-05769 CA #2- change made to add Keowee Forebay level/Lake Keowee level conversion.
- 15. PIP O-05-00965 CA #96- added reference in Enc. 3.39 to ONTC-0-101A-0005-01.
- 16. PIP O-07-02505 CA #16- deleted Enclosure (System Boron Concentration Vs. Time For The Purification Demineralizers).
- 17. Not Used
- 18. Not Used
Enclosure 4.48 OP/0/A/1108/001 Appendix Page 2 of 2
- 19. PIP O-03-05920 CA #1- added "Date Performed" block to top of Enc. "Condenser Flow And Temperature Data".
- 20. PIP O-08-01940 CA #77- inserted revised LR Heatup and Cooldown curves in Enc.4.32 and 4.33.
Change was to add new plot #3 for "Minimum RCS pressure for continuous operation of single RCP in a loop" for each Unit.
- 21. Not Used
- 22. PIP O-11-00459 CA #8- made changes to Heatup and Cooldown curves to add limits for both heatup and cooldown to both curves. All limits apply all the time per TS applicability statement.
- 23. Not Used
- 24. PIP O-11-06885 CA #3- changed the Low Range Heatup and Low Range Cooldown curves to make the 375 psig LTOP admin limit more visible.
- 26. PIP O-13-11188 CA #1 - revised information in Enc. 4.27 to help with setting alarm setpoints on U2 NI Recorder.
- 27. PIP O-93-0324, CA# 1- PIP reference carried forward to this procedure from OMP 1-02 (Rules Of Practice) Rev. 085.
- 28. PIP O-14-0110 CA # 4- new enclosure added to provide guidance for removal/restoration of Control Room Statalarms/indications.
- 30. PIP O-14-08430 CA #2- updated CBAST level vs. volume curve using data from the OAC "Online Databook Calculator (DBK)" program and ONS calculation OSC 7129 Rev. 4.
- 31. PIP O-12-03564 CA #3- updated Enc. 4.1 (BHUT Volume Vs. Level Curve) with curve provided by ONS Engineering in OSC 7129 Rev. 4.
Room 208 Seal Supply Filter Survey # M-123106-1 Date/Time 03/18/2012 03:30 RM 208 UNIT 1 SEAL SUPPLY FILTER ROOM Significant Dose Contributor 8
- 50
+30 20 13 4
1 A B 2
22 N
7 3
2 LEWA Summary of Highest Readings Smears Air Samples & Wipes
- 1) 18775 DPM/100 cm2 b/g
- 4) 5k DPM/100 cm2 b/g
- 2) 3k DPM/100 cm2 b/g Symbol Legend (for example only) Type: Job Coverage
- 3) 1k DPM/100 cm2 b/g Dose Rate
- 150 Contact Reading HS-50 Hot Spot RWP: 5007
+75 30 cm Reading RCA Posting Reactor Power = 100%
20 General Area Drip Bag 15 Smear 15 Air Sample 15 Wipe Unless otherwise noted, dose rates in mrem/hr.
Surveyor: W. Walters Approved by: N. Wriston, 03/19/2012
INFORMATION Oconee Nuclear Station INFORMATION USE ONLY Radiation Work Permit USE ONLY Entry For Routine Plant And Systems Operation (Operations) RWP # 23 Rev: 15 Task # 1 Entry For Routine Plant And Systems Operation (Operations)
ED Alarm Set Points:
Dose Alarm: 10 Dose Rate Alarm: 30 RWP Requirements Dress Category/Work Description
- Dress Category "A" Work in a non-contaminated area
- Dress Category "B" Work in a non-contaminated area with contaminated material where there is NO potential for contact with contaminated material other than by hand and durability of surgical gloves is sufficient (e.g., taking smears, etc.).
- Dress Category "C" Work in a non-contaminated area with contaminated material where there is NO potential for contact with contaminated material other than by hand AND durability of surgical gloves is NOT sufficient.
- Dress Category "D" Work of short duration, in open area(s) with NO obstructions that could contribute to contamination of unprotected skin or clothing
- Dress Category "E" Work where: (1) Complete protection of skin and clothing is NOT required; (2) Durability of surgical gloves requires consideration; (3) Radioactive material is handled and/or transported AND the potential for loose surface contamination exist.
- Dress Category "F" Work in a contaminated area where complete protection of skin and clothing is NOT necessary.
- Dress Category "G" Work in a dry contaminated area.
- Dress Category "H" Work in a contaminated area.
- Dress Category "N" Performing work in contaminated wet conditions.
- Modesty garments, top & bottom, are required under protective clothing where personal outer clothing is not worn Contamination Control
- Wipe down AND bag all tools and equipment prior to removal from a contaminated area as directed by RP
- Utilize facial protection (e.g. face shield, hood sock, power visor) as directed by RP
- Install catch containments OR drain rigs to prevent spills if draining components
- If installing a drain rig, use hose clamps or similar device to secure hose OR tubing connections
- If installing a drain rig, secure hose OR tubing to floor drain
- Wear disposable (plastic) booties inside of orex booties for work in wet conditions
- Change outer rubber gloves often when handling highly contaminated material as directed by RP
- Use surgical gloves in lieu of rubber gloves for the manipulation of small or specialty items as directed by RP RP Job Coverage
- Start of Job, Intermittent or No Coverage In Radiation Areas or Less
- RP Coverage Required To Transport All Radioactive Material Outside RCA, And Radioactive Material > 100 Mrem/Hr Contact Inside RCA
- If Hot Particle contamination is identified or expected, Notify RP Supervision and refer to RPSM 4.6 Hot Particle Program and SH/0/B/2000/005 Posting Radiation Control Zones, for guidance
- Continuous RP Coverage required for aggressive work in Alpha Level III or Alpha Level II areas with beta-gamma to Alpha ratios less than 3000 or where conditions could change Approved on 04/16/2012 by OCHOA, RONALD L Printed on 04/22/2012 Activated on 04/16/2012
Dosimetry Requirements
- Monitor ED periodically while inside the RCA/RCZ (once or twice per hour in low dose rate areas). Monitor more frequently in higher dose rate areas, for example every 10 to 15 minutes.
- If dress requirements prevent the monitoring of ED, and RP is not remotely monitoring (via teledose & communications), place ED external to the outmost layer of protective clothing for monitoring Approved on 04/16/2012 by OCHOA, RONALD L Printed on 04/22/2012 Activated on 04/16/2012
Duke Energy Procedure No.
Oconee Nuclear Station 0 OP/ /A/1108/001 CURVES AND GENERAL INFORMATION Revision No.
109 Electronic Reference No.
OX002VHZ Reference Use PERFORMANCE
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format
RP/0/A/1000/001 Page 2 of 6 Emergency Classification NOTE: This procedure is an implementing procedure to the Oconee Nuclear Site Emergency Plan and must be:
- Reviewed in accordance with 10CFR50.54(q) by Emergency Preparedness prior to approval.
- Cross Disciplinary Reviewed by Operations
- Forwarded to Emergency Preparedness within seven (7) working days of approval.
- 1. Symptoms 1.1 This procedure describes the immediate actions to be taken to recognize and classify an emergency condition.
1.2 This procedure identifies the four emergency classifications and their corresponding Emergency Action Levels (EALs).
1.3 This procedure provides reporting requirements for non-emergency abnormal events.
1.4 The following guidance is to be used by the Emergency Coordinator/EOF Director in assessing emergency conditions:
1.4.1 Definitions and Acronyms are italicized throughout procedure for easy recognition. The definitions are in Enclosure 4.10 (Definitions/Acronyms).
1.4.2 The Emergency Coordinator/EOF Director shall review all applicable initiating events to ensure proper classification.
1.4.3 The BASIS Document (Volume A, Section D of the Emergency Plan) is available for review if any questions arise over proper classification.
1.4.4 IF An event occurs on more than one unit concurrently, THEN The event with the higher classification will be classified on the Emergency Notification Form.
A. Information relating to the problem(s) on the other unit(s) will be captured on the Emergency Notification Form as shown in RP/0/A/1000/015A, (Offsite Communications From The Control Room),
RP/0/A/1000/015B, (Offsite Communications From The Technical Support Center) or SR/0/A/2000/004, (Notification to States and Counties from the Emergency Operations Facility).
2
RP/0/A/1000/001 Page 3 of 6 1.4.5 IF An event occurs, AND A lower or higher plant operating mode is reached before the classification can be made, THEN The classification shall be based on the mode that existed at the time the event occurred.
1.4.6 The Fission Product Barrier Matrix is applicable only to those events that occur at Mode 4 (Hot Shutdown) or higher.
A. An event that is recognized at Mode 5 (Cold Shutdown) or lower shall not be classified using the Fission Product Barrier Matrix.
- 1. Reference should be made to the additional enclosures that provide Emergency Action Levels for specific events (e.g., Severe Weather, Fire, Security).
1.5 IF A transient event should occur, THEN Review the following guidance:
1.5.1 IF An Emergency Action Level (EAL) identifies a specific duration AND The Emergency Coordinator/EOF Director assessment concludes that the specified duration is exceeded or will be exceeded, (i.e.;
condition cannot be reasonably corrected before the duration elapses),
THEN Classify the event.
1.5.2 IF A plant condition exceeding EAL criteria is corrected before the specified duration time is exceeded, THEN The event is NOT classified by that EAL.
A. Review lower severity EALs for possible applicability in these cases.
3
RP/0/A/1000/001 Page 4 of 6 NOTE: Reporting under 10CFR50.72 may be required for the following step. Such a condition could occur, for example, if a follow up evaluation of an abnormal condition uncovers evidence that the condition was more severe than earlier believed.
1.5.3 IF A plant condition exceeding EAL criteria is not recognized at the time of occurrence, but is identified well after the condition has occurred (e.g.; as a result of routine log or record review)
AND The condition no longer exists, THEN An emergency shall NOT be declared.
- Refer to AD-LS-ALL-0006 (Notification/Reportability Evaluation) for reportability 1.5.4 IF An emergency classification was warranted, but the plant condition has been corrected prior to declaration and notification THEN The Emergency Coordinator must consider the potential that the initiating condition (e.g.; Failure of Reactor Protection System) may have caused plant damage that warrants augmenting the on shift personnel through activation of the Emergency Response Organization.
A. IF An Unusual Event condition exists, THEN Make the classification as required.
- 1. The event may be terminated in the same notification or as a separate termination notification.
B. IF An Alert, Site Area Emergency, or General Emergency condition exists, THEN Make the classification as required, AND Activate the Emergency Response Organization.
1.6 Emergency conditions shall be classified as soon as the Emergency Coordinator/EOF Director assessment determines that the Emergency Action Levels for the Initiating Condition have been exceeded.
4
RP/0/A/1000/001 Page 5 of 6
- 2. Immediate Actions 2.1 Assessment, classification and declaration of any applicable emergency condition should be completed within 15 minutes after the availability of indications or information to cognizant facility staff that an EAL threshold has been exceeded.
2.2 Determine the operating mode that existed at the time the event occurred prior to any protection system or operator action initiated in response to the event.
2.3 IF The unit is at Mode 4 (Hot Shutdown) or higher AND The condition/event affects fission product barriers, THEN GO TO Enclosure 4.1, (Fission Product Barrier Matrix).
2.3.1 Review the criteria listed in Enclosure 4.1, (Fission Product Barrier Matrix) and make the determination if the event should be classified).
2.4 Review the listing of enclosures to determine if the event is applicable to one of the categories shown.
2.4.1 IF One or more categories are applicable to the event, THEN Refer to the associated enclosures.
2.4.2 Review the EALs and determine if the event should be classified.
A. IF An EAL is applicable to the event, THEN Classify the event as required.
2.5 IF The condition requires an emergency classification, THEN Initiate the following:
- for Control Room - RP/0/A/1000/002, (Control Room Emergency Coordinator Procedure)
- for TSC - RP/0/A/1000/019, (Technical Support Center Emergency Coordinator Procedure)
- for EOF - SR/0/A/2000/003, (Activation of the Emergency Operations Facility) 2.6 Continue to review the emergency conditions to assure the current classification continues to be applicable.
5
RP/0/A/1000/001 Page 6 of 6
- 3. Subsequent Actions 3.1 Continue to review the emergency conditions to assure the current classification continues to be applicable.
- 4. Enclosures Enclosures Page Number 4.1 Fission Product Barrier Matrix 7 4.2 System Malfunctions 8 4.3 Abnormal Rad Levels/Radiological Effluents 10 4.4 Loss Of Shutdown Functions 12 4.5 Loss of Power 14 4.6 Fires/Explosions And Security Actions 15 4.7 Natural Disasters, Hazards, And Other Conditions Affecting Plant Safety 17 4.8 Radiation Monitor Readings For Emergency Classification 20 4.9 Unexpected/Unplanned Increase In Area Monitor Readings 21 4.10 Definitions 22 4.11 Operating Modes Defined In Improved Technical Specifications 27 4.12 Instructions For Using Enclosure 4.1 28 4.13 References 30 6
Enclosure 4.1 RP/0/A/1000/001 Fission Product Barrier Matrix Page 1 of 1 DETERMINE THE APPROPRIATE CLASSIFICATION USING THE TABLE BELOW: ADD POINTS TO CLASSIFY. SEE NOTE BELOW RCS BARRIERS (BD 5-7) FUEL CLAD BARRIERS (BD 8-9) CONTAINMENT BARRIERS (BD 10-13)
Potential Loss (4 Points) Loss (5 Points) Potential Loss (4 Points) Loss (5 Points) Potential Loss (1 Point) Loss (3 Points)
RCS Leakrate 160 gpm RCS Leak rate that results in a loss Average of the 5 highest Average of the 5 highest CETC CETC 1200° F 15 minutes Rapid unexplained containment of subcooling. CETC 700° F 1200° F OR pressure decrease after increase CETC 700° F 15 minutes with a OR valid RVLS reading 0 containment pressure or sump level not consistent with LOCA SGTR 160 gpm Valid RVLS reading of 0 Coolant activity 300 µCi/ml DEI RB pressure 59 psig Failure of secondary side of SG OR results in a direct opening to the RB pressure 10 psig and no environment with SG Tube Leak RBCU or RBS 10 gpm in the SAME SG NOTE: RVLS is NOT valid if either of the following exists:
Entry into the PTS (Pressurized 1RIA 57 or 58 reading 1.0 R/hr
- One or more RCPs are Hours RIA 57 OR RIA 58 Hours RIA 57 OR RIA 58 SG Tube Leak 10 gpm exists in Thermal Shock) Operation running Since SD R/hr R/hr Since SD R/hr R/hr one SG.
2 RIA 57 reading 1.6 R/hr OR AND NOTE: PTS is entered under the other SG has secondary side either of the following: 2 RIA 58 reading 1.0 R/hr
- If LPI pump(s) are 0 - <0.5 300 150 0 - < 0.5 1800 860 failure that results in a direct
- A cooldown below 400°F @ running AND taking opening to the environment
> 100°F/hr. has occurred. 3RIA 57 or 58 reading 1.0 R/hr suction from the LPI 0.5 - < 2.0 80 40 0.5 - < 2.0 400 195 AND is being fed from the drop line.
- HPI has operated in the affected unit.
2.0 - 8.0 32 16 2.0 - 8.0 280 130 injection mode while NO RCPs were operating.
HPI Forced Cooling RCS pressure spike 2750 psig Hydrogen concentration 9% Containment isolation is incomplete and a release path to the environment exists Emergency Coordinator/EOF Emergency Coordinator/EOF Emergency Coordinator/EOF Emergency Coordinator/EOF Director Emergency Coordinator/EOF Emergency Coordinator/EOF Director judgment Director judgment Director judgment judgment Director judgment Director judgment UNUSUAL EVENT (1-3 Total Points) ALERT (4-6 Total Points) SITE AREA EMERGENCY (7-10 Total Points) GENERAL EMERGENCY (11-13 Total Points)
OPERATING MODE: 1, 2, 3, 4 OPERATING MODE: 1, 2, 3, 4 OPERATING MODE: 1, 2, 3, 4 OPERATING MODE: 1, 2, 3, 4 4.1.U.1 Any potential loss of Containment 4.1.A.1 Any potential loss or loss of the RCS 4.1.S.1 Loss of any two barriers 4.1.G.1 Loss of any two barriers and potential loss of the third barrier 4.1.U.2 Any loss of containment 4.1.A.2 Any potential loss or loss of the Fuel 4.1.S.2 Loss of one barrier and potential loss of either Clad RCS or Fuel Clad Barriers 4.1.G.2 Loss of all three barriers 4.1.S.3 Potential loss of both the RCS and Fuel Clad Barriers NOTE: An event with multiple events could occur which would result in the conclusion that exceeding the loss or potential loss threshold is IMMINENT (i.e., within 1-3 hours). In this IMMINENT LOSS situation, use judgment and classify as if the thresholds are exceeded.
Referencing this matrix frequently will aid in determining a fission barrier failure or other upgrade criteria.
7
Enclosure 4.2 RP/0/A/1000/001 System Malfunctions Page 1 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 1. RCS LEAKAGE (BD 15)
OPERATING MODE: 1, 2, 3, 4 A. Unidentified leakage 10 gpm B. Pressure boundary leakage 10 gpm C. Identified leakage 25 gpm
- Includes SG tube leakage
- 2. UNPLANNED LOSS OF MOST OR ALL 1. UNPLANNED LOSS OF MOST OR ALL SAFETY SYSTEM ANNUNCIATION/ SAFETY SYSTEM ANNUNCIATION/ 1. INABILITY TO MONITOR A INDICATION IN CONTROL ROOM INDICATION IN CONTROL ROOM SIGNIFICANT TRANSIENT IN FOR > 15 MINUTES (BD 16) (BD 20) PROGRESS (BD 22)
OPERATING MODE: 1, 2, 3, 4 OPERATING MODE: 1, 2, 3, 4 OPERATING MODE: 1, 2, 3, 4 A. Unplanned loss of > 50% of the following A. Unplanned loss of > 50% of the following A. Unplanned loss of > 50% of the following annunciators on one unit for > 15 minutes: annunciators on one unit for > 15 minutes: annunciators on one unit for > 15 minutes:
Units 1 & 3 Units 1 & 3 Units 1 & 3 1 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, 16, & 18 1 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, 16, & 18 1 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, 16, & 18 3 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, 16, & 18 3 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, 16, & 18 3 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, 16, & 18 Unit 2 Unit 2 Unit 2 2 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, & 16 2 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, & 16 2 SA1, 2, 3, 4, 5, 6, 7, 8, 9, 14, 15, & 16 AND AND AND Loss of annunciators or indicators requires A significant transient is in progress Loss of annunciators or indicators requires additional personnel (beyond normal shift additional personnel (beyond normal shift complement) to safely operate the unit AND complement) to safely operate the unit AND Loss of the OAC and ALL PAM indications (CONTINUED)
Significant plant transient in progress AND OR Inability to directly monitor any one of the following functions:
Loss of the OAC and ALL PAM indications
- 1. Subcriticality (END) 2. Core Cooling
- 3. Heat Sink
- 4. RCS Integrity
- 5. Containment Integrity
- 6. RCS Inventory (END) 8
Enclosure 4.2 RP/0/A/1000/001 System Malfunctions Page 2 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 3. INABILITY TO REACH REQUIRED SHUTDOWN WITHIN LIMITS (BD 17)
OPERATING MODE: 1, 2, 3, 4 A. Required operating mode not reached within TS LCO action statement time
- 4. UNPLANNED LOSS OF ALL ONSITE OR OFFSITE COMMUNICATIONS (BD 18)
OPERATING MODE: All
. Loss of all onsite communications capability (Plant phone system, PA system, Pager system, Onsite Radio system) affecting ability to perform Routine operations
. Loss of all onsite communications capability (Selective Signaling, NRC ETS lines, Offsite Radio System, AT&T line) affecting ability to communicate with offsite authorities.
- 5. FUEL CLAD DEGRADATION (BD 19)
= OPERATING MODE: All:
. DEI - >5µCi/ml (END) 9
Enclosure 4.3 RP/0/A/1000/001 Abnormal Rad Levels/Radiological Effluent Page 1 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY 1 ANY UNPLANNED RELEASE OF 1. ANY UNPLANNED RELEASE OF 1. BOUNDARY DOSE RESULTING FROM 1. BOUNDARY DOSE RESULTING FROM GASEOUS OR LIQUID RADIOACTIVITY GASEOUS OR LIQUID RADIOACTIVITY ACTUAL/IMMINENT RELEASE OF ACTUAL/ IMMINENT RELEASE OF TO THE ENVIRONMENT THAT TO THE ENVIRONMENT THAT GASEOUS ACTIVITY (BD 35) GASEOUS ACTIVITY (BD 39)
EXCEEDS TWO TIMES THE SLC EXCEEDS 200 TIMES RADIOLOGICAL LIMITS FOR 60 MINUTES OR LONGER TECHNICAL SPECIFICATIONS FOR 15 OPERATING MODE: All OPERATING MODE: All (BD 25) MINUTES OR LONGER (BD 30)
A. Valid reading on RIA 46 of > 2.09E+05 cpm or A. Valid reading on RIA 46 of > 2.09E+06 cpm or OPERATING MODE: All OPERATING MODE: All RIA 56 reading of > 175 R/hr or RP sample RIA 56 reading of > 17.5 R/hr or RP sample reading of 6.62E+01 uCi/ml Xe 133 eq for reading of 6.62E+02uCi/ml Xe 133 eq for A. Valid indication on radiation monitor RIA 33 A. Valid indication of RIA-46 of > 2.09 E+ 04 > 15 minutes (See Note 2) > 15 minutes (See Note 3) of 4.06E+06 cpm for > 60 minutes cpm or RP sample reading of > 6.62 uCi/ml (See Note 1) Xe 133 eq for > 15 minutes. (See Note 1) B. Valid reading on RIA 57 or 58 as shown on B. Valid reading on RIA 57 or 58 as shown on Enclosure 4.8 (See Note 2) Enclosure 4.8 (See Note 3)
B. Valid indication on radiation monitor RIA-45 B RIA 33 HIGH Alarm of > 9.35E+05 cpm or RP sample reading of C. Dose calculations result in a dose projection at C. Dose calculations result in a dose projection at
> 6.62E-2uCi/ml Xe 133 eq for > 60 minutes AND the site boundary of:
the site boundary of:
(See Note 1)
Liquid effluent being released exceeds 200 100 mRem TEDE 1000 mRem TEDE C. Liquid effluent being released exceeds two times the level of SLC 16.11.1 for > 15 minutes times SLC 16.11.1 for > 60 minutes as as determined by Chemistry Procedure OR OR determined by Chemistry Procedure C. Gaseous effluent being released exceeds 200 500 mRem CDE adult thyroid 5000 mRem CDE adult thyroid D. Gaseous effluent being released exceeds two times the level of SLC 16.11.2 for >15 minutes times SLC 16.11.2 for > 60 minutes as as determined by RP Procedure D. Field survey results indicate site boundary dose D. Field survey results indicate site boundary dose determined by RP Procedure rates exceeding 100 mRad/hr expected to rates exceeding 1000 mRad/hr expected to continue for more than one hour continue for more than one hour OR OR (CONTINUED)
Analyses of field survey samples indicate adult Analyses of field survey samples indicate adult thyroid dose commitment of 500 mRem thyroid dose commitment of 5000 mRem CDE (3.84 E-7 µCi/ml) for one hour of CDE for one hour of inhalation NOTE 1: If monitor reading is sustained inhalation for the time period indicated in the EAL AND the required assessments (procedure calculations) cannot be completed within NOTE 3: If actual Dose Assessment cannot NOTE 2: If actual Dose Assessment cannot be completed within 15 minutes, then the this period, declaration must be made on the be completed within 15 minutes, then the valid radiation monitor reading should be valid Radiation Monitor reading.
valid radiation monitor reading should be used for emergency classification.
used for emergency classification.
(CONTINUED)
(CONTINUED) (END) 10
Enclosure 4.3 RP/0/A/1000/001 Abnormal Rad Levels/Radiological Effluent Page 2 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY 2 UNEXPECTED INCREASE IN PLANT 2. RELEASE OF RADIOACTIVE 2. LOSS OF WATER LEVEL IN THE `
RADIATION OR AIRBORNE MATERIAL OR INCREASES IN REACTOR VESSEL THAT HAS OR CONCENTRATION (BD 27) RADIATION LEVELS THAT IMPEDES WILL UNCOVER FUEL IN THE OPERATION OF SYSTEMS REQUIRED REACTOR VESSEL (BD 38)
OPERATING MODE: All TO MAINTAIN SAFE OPERATION OR TO ESTABLISH OR MAINTAIN COLD OPERATING MODE: 5, 6 SHUTDOWN (BD 32)
A. LT 5 reading 14 and decreasing with makeup not keeping up with leakage WITH fuel in the OPERATING MODE: All A. Loss of all decay heat removal as indicated by core the inability to maintain RCS temperature A. Valid radiation reading 15 mRad/hr in CR, below 200° F CAS, or Radwaste CR B. Valid indication of uncontrolled water decrease in the SFP or fuel transfer canal with all fuel B. Unplanned/unexpected valid area monitor AND assemblies remaining covered by water readings exceed limits stated in Enclosure 4.9 LT 5 indicates 0 inches after initiation of RCS NOTE: These readings may also be indicative of makeup AND Fission Product Barrier concerns which makes a review of the Fission Product Barrier Matrix Unplanned Valid RIA 3, 6 or Portable Area B. Loss of all decay heat removal as indicated by necessary.
Monitor readings increase. the inability to maintain RCS temperature
- 3. MAJOR DAMAGE TO IRRADIATED below 200° F C. 1 R/hr radiation reading at one foot away from FUEL OR LOSS OF WATER LEVEL THAT HAS OR WILL RESULT IN THE AND a damaged storage cask located at the ISFSI UNCOVERING OF IRRADIATED FUEL Either train ultrasonic level indication less than D. Valid area monitor readings exceeds limits OUTSIDE THE REACTOR VESSEL 0 inches and decreasing after initiation of RCS stated in Enclosure 4.9. (BD 33) makeup OPERATING MODE: All NOTE: This Initiating Condition is also located NOTE: This Initiating Condition is also in Enclosure 4.4., (Loss of Shutdown Functions). A. Valid RIA 3*, 6, 41, OR 49* HIGH Alarm located in Enclosure 4.4., (Loss of Shutdown High radiation levels will also be seen with this * - Applies to Mode 6 and No Mode Only Functions). High radiation levels will also be condition. seen with this condition.
B. HIGH Alarm for portable area monitors on the main bridge or SFP bridge C. Report of visual observation of irradiated fuel uncovered (END))
D. Operators determine water level drop in either (END) the SFP or fuel transfer canal will exceed makeup capacity such that irradiated fuel will be uncovered NOTE: This Initiating Condition is also located in Enclosure 4.4., (Loss of Shutdown Functions).
High radiation levels will also be seen with this condition.
(END) 11
Enclosure 4.4 RP/0/A/1000/001 Loss of Shutdown Functions Page 1 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 1. FAILURE OF RPS TO COMPLETE OR 1. FAILURE OF RPS TO COMPLETE OR 1. FAILURE OF RPS TO COMPLETE INITIATE A Rx SCRAM (BD 44) INITIATE A Rx SCRAM (BD 50)
OPERATING MODE: 1, 2 OPERATING MODE 1, 2, 3 OPERATING MODE: 1, 2 (CONTINUE TO NEXT PAGE) A. Valid Rx trip signal received or required A. Valid reactor trip signal received or required A. Valid reactor trip signal received or required WITHOUT automatic scram WITHOUT automatic scram WITHOUT automatic scram AND AND AND DSS has inserted Control Rods Manual trip from the Control Room was OR DSS has NOT inserted Control Rods NOT successful in reducing reactor power to < 5% and decreasing Manual trip from the Control Room is successful and reactor power is less AND AND than 5% and decreasing Manual trip from the Control Room was NOT Average of the 5 highest CETCs 1200° F successful in reducing reactor power to less on ICCM than 5% and decreasing (END)
- 2. INABILITY TO MAINTAIN PLANT IN 2. COMPLETE LOSS OF FUNCTION MODE 5 (COLD SHUTDOWN) (BD 46) NEEDED TO ACHIEVE OR MAINTAIN MODE 4 (HOT SHUTDOWN) (BD 51)
OPERATING MODE: 5, 6 OPERATING MODE: 1, 2, 3, 4 A. Loss of LPI and/or LPSW A. Average of the 5 highest CETCs 1200° F AND shown on ICCM Inability to maintain RCS temperature B. Unable to maintain reactor subcritical below 200° F as indicated by either of the following:
C. EOP directs feeding SG from SSF ASWP or PSW Pump RCS temperature at the LPI Pump Suction OR (CONTINUED)
Average of the 5 highest CETCs as indicated by ICCM display OR Visual observation (CONTINUED) 12
Enclosure 4.4 RP/0/A/1000/001 Loss of Shutdown Functions Page 2 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 1. UNEXPECTED INCREASE IN PLANT 3. MAJOR DAMAGE TO IRRADIATED 3. LOSS OF WATER LEVEL IN THE RADIATION OR AIRBORNE FUEL OR LOSS OF WATER LEVEL REACTOR VESSEL THAT HAS OR CONCENTRATION (BD 42) THAT HAS OR WILL RESULT IN THE WILL UNCOVER FUEL IN THE UNCOVERING OF IRRADIATED FUEL REACTOR VESSEL (BD 52)
OPERATING MODE: All OUTSIDE THE REACTOR VESSEL (BD 48) OPERATING MODE: 5, 6 A. LT 5 reading 14 and decreasing with makeup not keeping up with leakage WITH fuel in the OPERATING MODE: All .1 A. Loss of all decay heat removal as indicated by core the inability to maintain RCS temperature A. Valid RIA 3*, 6, 41, OR 49* HIGH Alarm below 200° F B. Valid indication of uncontrolled water decrease in the SFP or fuel transfer canal with all fuel *Applies to Mode 6 and No Mode Only AND assemblies remaining covered by water B. HIGH Alarm for portable area monitors on the LT-5 indicates 0 inches after initiation of RCS AND main bridge or SFP bridge Makeup B. Loss of all decay heat removal as indicated by Unplanned Valid RIA 3, 6 or Portable Area C Report of visual observation of irradiated fuel the inability to maintain RCS temperature Monitor readings increase. uncovered below 200° F AND C. 1 R/hr radiation reading at one foot away from D. Operators determine water level drop in either a damaged storage cask located at the ISFSI the SFP or fuel transfer canal will exceed makeup capacity such that irradiated fuel will Either train ultrasonic level indication less than D. Valid area monitor readings exceeds limits be uncovered 0 inches and decreasing after initiation of RCS stated in Enclosure 4.9. makeup NOTE: This Initiating Condition is also located in Enclosure 4.3, (Abnormal Rad NOTE: This Initiating Condition is also located Levels/Radiological Effluent). High radiation NOTE: This Initiating Condition is also located in Enclosure 4.3., (Abnormal Rad levels will also be seen with this condition. in Enclosure 4.3, (Abnormal Rad Levels/Radiological Effluent). High radiation Levels/Radiological Effluent). High radiation levels will also be seen with this condition. levels will also be seen with this condition.
(END)
(END)
(END) 13
Enclosure 4.5 RP/0/A/1000/001 Loss of Power {4} Page 1 of 1 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 1. LOSS OF ALL OFFSITE POWER TO 1. LOSS OF ALL OFFSITE AC POWER AND 1. LOSS OF ALL OFFSITE AC POWER AND 1. PROLONGED LOSS OF ALL OFFSITE ESSENTIAL BUSSES FOR GREATER LOSS OF ALL ONSITE AC POWER TO LOSS OF ALL ONSITE AC POWER TO POWER AND ONSITE AC POWER THAN 15 MINUTES (BD 55) ESSENTIAL BUSSES (BD 57) ESSENTIAL BUSSES (BD 59) (BD 62)
OPERATING MODE: All OPERATING MODE: 5, 6 OPERATING MODE: 1, 2, 3, 4 OPERATING MODE: 1, 2, 3, 4 Defueled A. Unit auxiliaries are being supplied from A. MFB 1 and 2 de-energized A. MFB 1 and 2 de-energized Keowee or CT5 A. MFB 1 and 2 de-energized AND AND AND AND Failure to restore power to at least one MFB SSF fails to maintain Mode 3 Failure to restore power to at least one MFB within 15 minutes from the time of loss of (Hot Standby) {1}
Inability to energize either MFB from an offsite within 15 minutes from the time of loss of both both offsite and onsite AC power source (either switchyard) within 15 minutes. offsite and onsite AC power AND At least one of the following conditions exist:
- 2. UNPLANNED LOSS OF REQUIRED DC (BD 60) Restoration of power to at least one ESSENTIAL BUSSES REDUCED TO A POWER FOR GREATER THAN 15 MFB within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is NOT likely SINGLE SOURCE FOR GREATER THAN MINUTES (BD 56) 15 MINUTES (BD 58) OPERATING MODE: 1, 2, 3, 4 OR OPERATING MODE: 5, 6 OPERATING MODE: 1, 2, 3, 4 A. Unplanned loss of vital DC power to required Indications of continuing DC busses as indicated by bus voltage less than degradation of core cooling based A. Unplanned loss of vital DC power to required A. AC power capability has been degraded to a 110 VDC on Fission Product Barrier DC busses as indicated by bus voltage less single power source for > 15 minutes due to the monitoring than 110 VDC loss of all but one of the following: AND AND (END)
Unit Normal Transformer (backcharged) Failure to restore power to at least one required Unit SU Transformer DC bus within 15 minutes from the time of loss Failure to restore power to at least one required Another Unit SU Transformer (aligned)
DC bus within 15 minutes from the time of loss CT4 (END)
CT5 (END)
(END)
Loss of Power - Emergency Action Levels (EALs) apply to the ability of electrical energy to perform its intended function, reach its intended equipment. ex. - If both MFBs, are energized but all 4160V switchgear is not available, the electrical energy can not reach the motors intended. The result to the plant is the same as if both MFBs were de-energized. {4}
14
Enclosure 4.6 RP/0/A/1000/001 Fire/Explosions and Security Actions {2} {3} Page 1 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 1. FIRES/EXPLOSIONS WITHIN THE 1. FIRE/EXPLOSION AFFECTING PLANT (BD 65) OPERABILITY OF PLANT SAFETY (CONTINUE TO NEXT PAGE) (CONTINUE TO NEXT PAGE)
SYSTEMS REQUIRED TO OPERATING MODE: All ESTABLISH/MAINTAIN SAFE SHUTDOWN (BD 70)
NOTE: Within the plant means:
Turbine Building OPERATING MODE: All Auxiliary Building Reactor Building NOTE: Only one train of a system needs to Keowee Hydro be affected or damaged in order to satisfy this Transformer Yard condition.
B3T B4T Service Air Diesel Compressors A. Fire/explosions Keowee Hydro & associated AND Transformers SSF Affected safety-related system parameter indications show degraded performance OR A. Fire within the plant not extinguished within 15 minutes of Control Room notification or Plant personnel report visible damage to verification of a Control Room alarm permanent structures or equipment required for safe shutdown B. Unanticipated explosion within the plant resulting in visible damage to permanent (Continued) structures/equipment
- includes steam line break and FDW line break (Continued) 15
Enclosure 4.6 RP/0/A/1000/001 Fire/Explosions and Security Actions {2} {3} Page 2 of 2 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 2. CONFIRMED SECURITY CONDITION 2 HOSTILE ACTION WITHIN THE 1. HOSTILE ACTION within the PROTECTED 1. A HOSTILE ACTION RESULTING IN OR THREAT WHICH INDICATES A OWNER CONTROLLED AREA OR AREA (BD 76) LOSS OF PHYSICAL CONTROL OF POTENTIAL DEGRADATION IN THE AIRBORNE ATTACK THREAT. (BD 72) THE FACILITY (BD 79)
LEVEL OF SAFETY OF THE PLANT OPERATING MODE: All (BD 67) OPERATING MODE: All OPERATING MODE: All A. A HOSTILE ACTION is occurring or has A. A HOSTILE ACTION is occurring or has OPERATING MODE: All occurred within the PROTECTED AREA as A. A HOSTILE ACTION has occurred such that occurred within the OWNER CONTROLLED reported by the Security Shift Supervision. plant personnel are unable to operate A. Security condition that does not involve a AREA as reported by the Security Shift equipment required to maintain safety HOSTILE ACTION as reported by the Supervision.
functions Security Shift Supervision. 2. OTHER CONDITIONS EXIST WHICH IN B. A validated notification from NRC of an THE JUDGEMENT OF THE EMERGENCY B. A HOSTILE ACTION has caused failure of B. A credible site-specific security threat AIRLINER attack threat within 30 minutes of DIRECTOR WARRANT DECLARATION Spent Fuel Cooling Systems and notification the site. OF A SITE AREA EMERGENCY. (BD 78) IMMINENT fuel damage is likely for a freshly off-loaded reactor core in pool.
C. A validated notification from NRC providing OPERATING MODE: All information of an aircraft threat 3. OTHER CONDITIONS EXIST WHICH IN THE JUDGEMENT OF THE A. Other conditions exist which in the judgment of 2. OTHER CONDITIONS EXIST WHICH EMERGENCY DIRECTOR WARRANT the Emergency Director indicate that events are in IN THE JUDGMENT OF THE
- 3. OTHER CONDITIONS EXIST WHICH DECLARATION OF AN ALERT (BD 75) progress or have occurred which involve actual or EMERGENCY DIRECTOR WARRANT IN THE JUDGEMENT OF THE likely major failures of plant functions needed for DECLARATION OF A GENERAL EMERGENCY DIRECTOR WARRANT OPERATING MODE: All protection of the public or HOSTILE ACTION EMERGENCY. (BD 81)
DECLARATION OF A NOUE. (BD 69) that results in intentional damage or malicious A. Other conditions exist which in the judgment acts; (1) toward site personnel or equipment that OPERATING MODE: All of the Emergency Director indicate that events OPERATING MODE: All could lead to the likely failure of or; (2) that are in progress or have occurred which involve prevent effective access to equipment needed for A. Other conditions exist which in the judgment an actual or potential substantial degradation of A. Other conditions exist which in the judgment the protection of the public. Any releases are not of the Emergency Director indicate that the level of safety of the plant or a security of the Emergency Director indicate that expected to result in exposure levels which events are in progress or have occurred event that involves probable life threatening events are in progress or have occurred which exceed EPA Protective Action Guideline which involve actual or IMMINENT risk to site personnel or damage to site indicate a potential degradation of the level of exposure levels beyond the site boundary. substantial core degradation or melting with equipment because of HOSTILE ACTION.
safety of the plant or indicate a security threat potential for loss of containment integrity or Any releases are expected to be limited to small to facility protection has been initiated. No HOSTILE ACTION that results in an actual fractions of the EPA Protective Action releases of radioactive material requiring off- loss of physical control of the facility.
Guideline exposure levels.
site response or monitoring are expected (END) Releases can be reasonably expected to unless further degradation of safety systems exceed EPA Protective Action Guideline occurs. (END) exposure levels off-site for more than the immediate site area.
(END)
(END) 16
Enclosure 4.7 RP/0/A/1000/001 Natural Disasters, Hazards and Other Conditions Affecting Plant Safety Page 1 of 3 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 1. NATURAL AND DESTRUCTIVE 1. NATURAL AND DESTRUCTIVE PHENOMENA AFFECTING THE PHENOMENA AFFECTING THE PLANT (CONTINUE TO NEXT PAGE) (CONTINUE TO NEXT PAGE)
PROTECTED AREA (BD 83) VITAL AREA (BD 89)
OPERATING MODE: All OPERATING MODE: All A. Tremor felt and valid alarm on the strong A. Tremor felt and seismic trigger actuates (0.05g) motion accelerograph NOTE: Only one train of a safety-related B Tornado striking within Protected Area Boundary system needs to be affected or damaged in order to satisfy these conditions.
C. Vehicle crash into plant structures/systems within the Protected Area Boundary B. Tornado, high winds, missiles resulting from turbine failure, vehicle crashes, or other D. Turbine failure resulting in casing penetration catastrophic event.
or damage to turbine or generator seals AND (CONTINUED) Visible damage to permanent structures or equipment required for safe shutdown of the unit.
OR Affected safety system parameter indications show degraded performance.
(CONTINUED) 17
Enclosure 4.7 RP/0/A/1000/001 Natural Disasters, Hazards and Other Conditions Affecting Plant Safety Page 2 of 3 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 2. NATURAL AND DESTRUCTIVE 2. RELEASE OF TOXIC/FLAMMABLE 1. CONTROL ROOM EVACUATION AND PHENOMENA AFFECTING KEOWEE GASES JEOPARDIZING SYSTEMS PLANT CONTROL CANNOT BE HYDRO CONDITION B (BD 85) REQUIRED TO MAINTAIN SAFE ESTABLISHED (BD 96) (CONTINUE TO NEXT PAGE)
OPERATION OR ESTABLISH/
OPERATING MODE: All MAINTAIN MODE 5 (COLD OPERATING MODE: All SHUTDOWN) (BD 91)
A. Reservoir elevation 805.0 feet with all A. Control Room evacuation has been initiated spillway gates open and the lake elevation OPERATING MODE: All continues to rise A. Report/detection of toxic gases in AND concentrations that will be life-threatening to B. Seepage readings increase or decrease greatly plant personnel Control of the plant cannot be established from or seepage water is carrying a significant the Aux Shutdown Panel or the SSF within 15 amount of soil particles B. Report/detection of flammable gases in minutes concentrations that will affect the safe C New area of seepage or wetness, with large operation of the plant:
amounts of seepage water observed on dam,
- Reactor Building 2. KEOWEE HYDRO DAM FAILURE dam toe, or the abutments
- Auxiliary Building (BD 97)
- Turbine Building D. Slide or other movement of the dam or
- Control Room OPERATING MODE: All abutments which could develop into a failure
- 3. TURBINE BUILDING FLOOD (BD 93) A. Imminent/actual dam failure exists involving E. Developing failure involving the powerhouse or any of the following:
appurtenant structures and the operator believes the safety of the structure is questionable
- Keowee Hydro Dam OPERATING MODE: All
- Little River Dam
- Dikes A, B, C, or D A. Turbine Building flood requiring use of
- Intake Canal Dike
- 3. NATURAL AND DESTRUCTIVE AP/1,2,3/A/1700/10, (Turbine Building Flood)
PHENOMENA AFFECTING JOCASSEE
- Jocassee Dam - Condition A HYDRO CONDITION B (BD 86)
(CONTINUED)
- 4. CONTROL ROOM EVACUATION HAS OPERATING MODE: All BEEN INITIATED (BD 94)
A. Condition B has been declared for the Jocassee OPERATING MODE: All Dam A. Evacuation of Control Room (CONTINUED)
AND ONE OF THE FOLLOWING:
Plant control IS established from the Aux shutdown Panel or the SSF OR Plant control IS BEING established from the Aux Shutdown Panel or SSF (CONTINUED) 18
Enclosure 4.7 RP/0/A/1000/001 Natural Disasters, Hazards and Other Conditions Affecting Plant Safety Page 3 of 3 UNUSUAL EVENT ALERT SITE AREA EMERGENCY GENERAL EMERGENCY
- 4. RELEASE OF TOXIC OR FLAMMABLE 5. OTHER CONDITIONS WARRANT 3. OTHER CONDITIONS WARRANT 1. OTHER CONDITIONS WARRANT GASES DEEMED DETRIMENTAL TO SAFE CLASSIFICATION OF AN ALERT DECLARATION OF SITE AREA DECLARATION OF GENERAL OPERATION OF THE PLANT (BD 87) (BD 95) EMERGENCY (BD 98) EMERGENCY (BD 99)
OPERATING MODE: All OPERATING MODE: All OPERATING MODE: All OPERATING MODE: All A. Report/detection of toxic or flammable gases A. Emergency Coordinator judgment indicates A. Emergency Coordinator/EOF Director A. Emergency Coordinator/EOF Director that could enter within the site area boundary in that: judgment judgment indicates:
amounts that can affect normal operation of the plant Plant safety may be degraded Actual/imminent substantial core (END) degradation with potential for loss of B. Report by local, county, state officials for AND containment potential evacuation of site personnel based on offsite event Increased monitoring of plant functions OR is warranted Potential for uncontrolled
- 5. OTHER CONDITIONS EXIST WHICH (END) radionuclide releases that would WARRANT DECLARATION OF AN result in a dose projection at the UNUSUAL EVENT (BD 88) site boundary greater than 1000 mRem TEDE or 5000 mRem CDE Adult Thyroid OPERATING MODE: All A. Emergency Coordinator determines potential (END) degradation of level of safety has occurred (END) 19
Enclosure 4.8 RP/0/A/1000/001 Radiation Monitor Readings for Emergency Classification Page 1 of 1 All RIA values are considered GREATER THAN or EQUAL TO HOURS SINCE RIA 57 R/hr RIA 58 R/hr*
REACTOR TRIPPED Site Area Emergency General Emergency Site Area Emergency General Emergency 0.0 - < 0.5 5.9E+003 5.9E+004 2.6E+003 2.6E+004 0.5 - < 1.0 2.6E+003 2.6E+004 1.1E+003 1.1E+004 1.0 - < 1.5 1.9E+003 1.9E+004 8.6E+002 8.6E+003 1.5 - < 2.0 1.9E+003 1.9E+004 8.5E+002 8.5E+003 2.0 - < 2.5 1.4E+003 1.4E+004 6.3E+002 6.3E+003 2.5 - < 3.0 1.2E+003 1.2E+004 5.7E+002 5.7E+003 3.0 - < 3.5 1.1E+003 1.1E+004 5.2E+002 5.2E+003 3.5 - < 4.0 1.0E+003 1.0E+004 4.8E+002 4.8E+003 4.0 - < 8.0 1.0E+003 1.0E+004 4.4E+002 4.4E+003
- RIA 58 is partially shielded 20
Enclosure 4.9 RP/0/A/1000/001 Unexpected/Unplanned Increase In Area Monitor Readings Page 1 of 1 NOTE: This Initiating Condition is not intended to apply to anticipated temporary increases due to planned events (e.g.; incore detector movement, radwaste container movement, depleted resin transfers, etc.).
UNITS 1, 2, 3 MONITOR NUMBER UNUSUAL EVENT 1000x ALERT NORMAL LEVELS mRAD/HR mRAD/HR RIA 7, Hot Machine Shop Elevation 796 150 5000 RIA 8, Hot Chemistry Lab Elevation 796 4200 5000 RIA 10, Primary Sample Hood Elevation 796 830 5000 RIA 11, Change Room Elevation 796 210 5000 RIA 12, Chem Mix Tank Elevation 783 800 5000 RIA 13, Waste Disposal Sink Elevation 771 650 5000 RIA 15, HPI Room Elevation 758 NOTE* 5000 NOTE: RIA 15 normal readings are approximately 9 mRad/hr on a daily basis. Applying 1000x normal readings would put this monitor greater than 5000 mRad/hr just for an Unusual Event. For this reason, an Unusual Event will NOT be declared for a reading less than 5000 mRad/hr.
21
Enclosure 4.10 RP/0/A/1000/001 Definitions/Acronyms Page 1 of 5
- 1. List of Definitions and Acronyms NOTE: Definitions are italicized throughout procedure for easy recognition.
1.1 ALERT - Events are in process 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.
1.2 BOMB - Refers to an explosive device suspected of having sufficient force to damage plant systems or structures.
1.3 COGNIZANT FACILITY STAFF - any member of facility staff, who by virtue of training and experience, is qualified to assess the indications or reports for validity and to compare the same to the EALs in the licensee's emergency classification scheme. (Does not include staff whose positions require they report, rather than assess, abnormal conditions to the facility.)
1.4 CONDITION A - Failure is Imminent or Has Occurred - A failure at the dam has occurred or is about to occur and minutes to days may be allowed to respond dependent upon the proximity to the dam.
1.5 CONDITION B - Potentially Hazardous Situation is Developing - A situation where failure may develop, but preplanned actions taken during certain events (such as major floods, earthquakes, evidence of piping) may prevent or mitigate failure.
1.6 CIVIL DISTURBANCE - A group of persons violently protesting station operations or activities at the site.
1.7 EXPLOSION - A rapid, violent, unconfined combustion, or catastrophic failure of pressurized/energized equipment that imparts energy of sufficient force to potentially damage permanent structures, systems, or components.
1.7 EXTORTION - An attempt to cause an action at the station by threat of force.
1.8 FIRE - Combustion characterized by heat and light. Sources of smoke, such as slipping drive belts or overheated electrical equipment, do NOT constitute fires. Observation of flames is preferred but is NOT required if large quantities of smoke and heat are observed.
1.9 FRESHLY OFF-LOADED CORE - The complete removal and relocation of all fuel assemblies from the reactor core and placed in the spent fuel pool. (Typical of a "No Mode" operation during a refuel outage that allows safety system maintenance to occur and results in maximum decay heat load in the spent fuel pool system).
22
Enclosure 4.10 RP/0/A/1000/001 Definitions/Acronyms Page 2 of 5 1.10 GENERAL EMERGENCY - Events are in process 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 Guidelines exposure levels offsite for more than the immediate area.
1.11 HOSTAGE - A person(s) held as leverage against the station to ensure demands will be met by the station.
1.12 HOSTILE ACTION - An act toward an NPP or its personnel that includes the use of violent force to destroy equipment, takes HOSTAGES, and/or intimidates the licensee to achieve an end. This includes attack by air, land, or water using guns, explosives, PROJECTILES, vehicles, or other devices used to deliver destructive force. Other acts that satisfy the overall intent may be included. HOSTILE ACTION should not be construed to include acts of civil disobedience or felonious acts that are not part of a concerted attack on the NPP. Non-terrorism-based EALs should be used to address such activities, (e.g., violent acts between individuals in the owner controlled area.)
1.13 HOSTILE FORCE - One or more individuals who are engaged in a determined assault, overtly or by stealth and deception, equipped with suitable weapons capable of killing, maiming, or causing destruction.
1.14 IMMINENT - Mitigation actions have been ineffective, additional actions are not expected to be successful, and trended information indicates that the event or condition will occur. Where IMMINENT timeframes are specified, they shall apply.
1.15 INTRUSION - A person(s) present in a specified area without authorization. Discovery of a BOMB in a specified area is indication of INTRUSION into that area by a HOSTILE FORCE.
1.16 INABILITY TO DIRECTLY MONITOR - Operational Aid Computer data points are unavailable or gauges/panel indications are NOT readily available to the operator.
1.17 LOSS OF POWER - Emergency Action Levels (EALs) apply to the ability of electrical energy to perform its intended function, reach its intended equipment. Ex. - If both MFBs, are energized but all 4160v switchgear is not available, the electrical energy can not reach the motors intended. The result to the plant is the same as if both MFBs were de-energized.
1.18 PROJECTILE - An object directed toward a NPP that could cause concern for its continued operability, reliability, or personnel safety.
1.19 PROTECTED AREA - Typically the site specific area which normally encompasses all controlled areas within the security PROTECTED AREA fence.
23
Enclosure 4.10 RP/0/A/1000/001 Definitions/Acronyms Page 3 of 5 1.20 REACTOR COOLANT SYSTEM (RCS) LEAKAGE - RCS Operational Leakage as defined in the Technical Specification Basis B 3.4.13:
RCS leakage includes leakage from connected systems up to and including the second normally closed valve for systems which do not penetrate containment and the outermost isolation valve for systems which penetrate containment.
A. Identified LEAKAGE LEAKAGE to the containment from specifically known and located sources, but does not include pressure boundary LEAKAGE or controlled reactor coolant pump (RCP) seal leakoff (a normal function not considered LEAKAGE).
LEAKAGE, such as that from pump seals, gaskets, or valve packing (except RCP seal water injection or leakoff), that is captured and conducted to collection systems or a sump or collecting tank; LEAKAGE through a steam generator (SG) to the Secondary System (primary to secondary LEAKAGE): Primary to secondary LEAKAGE must be included in the total calculated for identified LEAKAGE.
B. Unidentified LEAKAGE All LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE.
C. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall or vessel wall.
1.21 RUPTURED (As relates to Steam Generator) - Existence of Primary to Secondary leakage of a magnitude sufficient to require or cause a reactor trip and safety injection.
1.22 SABOTAGE - Deliberate damage, mis-alignment, or mis-operation of plant equipment with the intent to render the equipment inoperable. Equipment found tampered with or damaged due to malicious mischief may not meet the definition of SABOTAGE until this determination is made by security supervision.
1.23 SECURITY CONDITION - Any Security Event as listed in the approved security contingency plan that constitutes a threat/compromise to site security, threat/risk to site personnel, or a potential degradation to the level of safety of the plant. A SECURITY CONDITION does not involve a HOSTILE ACTION.
1.24 SAFETY-RELATED SYSTEMS AREA - Any area within the Protected area which contains equipment, systems, components, or material, the failure, destruction, or release of which could directly or indirectly endanger the public health and safety by exposure to radiation.
24
Enclosure 4.10 RP/0/A/1000/001 Definitions/Acronyms Page 4 of 5 1.25 SELECTED LICENSEE COMMITMENT (SLC) -Chapter 16 of the FSAR 1.26 SIGNIFICANT PLANT TRANSIENT - An unplanned event involving one or more of the following:
(1) Automatic turbine runback>25% thermal reactor power (2) Electrical load rejection >25% full electrical load (3) Reactor Trip (4) Safety Injection System Activation 1.27 SITE AREA EMERGENCY - Events are in process or have occurred which involve actual or likely major failures of plant functions needed for the protection of the public. or HOSTILE ACTION that results in intentional damage or malicious act; (1) toward site personnel or equipment that could lead to the likely failure of or; (2) that prevents 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.
1.28 SITE BOUNDARY - That area, including the Protected Area, in which DPC has the authority to control all activities including exclusion or removal of personnel and property (1 mile radius from the center of Unit 2).\
1.29 TOXIC GAS - A gas that is dangerous to life or health by reason of inhalation or skin contact (e.g.; Chlorine).
1.30 UNCONTROLLED - Event is not the result of planned actions by the plant staff.
1.31 UNPLANNED - An event or action is UNPLANNED if it is not the expected result of normal operations, testing, or maintenance. Events that result in corrective or mitigative actions being taken in accordance with abnormal or emergency procedures are UNPLANNED.
1.32 UNUSUAL EVENT - Events are in process 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.
1.33 VALID - An indication or report or condition is considered to be VALID when it is conclusively verified by: (1) an instrument channel check; or, (2) indications on related or redundant instrumentation; or, (3) by direct observation by plant personnel such that doubt related to the instruments operability, the conditions existence, or the reports accuracy is removed. Implicit with this definition is the need for timely assessment.
25
Enclosure 4.10 RP/0/A/1000/001 Definitions/Acronyms Page 5 of 5 1.34 VIOLENT - Force has been used in an attempt to injure site personnel or damage plant property.
1.35 VISIBLE DAMAGE - Damage to equipment or structure that is readily observable without measurements, testing, or analyses. Damage is sufficient to cause concern regarding the continued operability or reliability of affected safety structure, system, or component.
Example damage: deformation due to heat or impact, denting, penetration, rupture.
1.36 VITAL AREA - An area within the protected area where an individual is required to badge in to gain access to the area and that houses equipment important for nuclear safety. The failure or destruction of this equipment could directly or indirectly endanger the public health and safety by exposure to radiation.
26
Enclosure 4.11 RP/0/A/1000/001 Operating Modes Defined In Improved Page 1 of 1 Technical Specifications MODES REACTIVITY % RATED AVERAGE CONDITION THERMAL REACTOR COOLANT MODE TITLE POWER (a) TEMPERATURE (Keff) (°F) 1 Power Operation >0.99 >5 NA 2 Startup >0.99 <5 NA 3 Hot Standby <0.99 NA >250 4 Hot Shutdown (b) < 0.99 NA 250 > T > 200 5 Cold Shutdown (b) < 0.99 NA < 200 6 Refueling (c) NA NA NA (a) Excluding decay heat.
(b) All reactor vessel head closure bolts fully tensioned.
(c) One or more reactor vessel head closure bolts less than fully tensioned 27
Enclosure 4.12 RP/0/A/1000/001 Instructions For Using Enclosure 4.1 Page 1 of 2
- 1. Instructions For Using Enclosure 4.1 - Fission Product Barrier Matrix 1.1 If the unit was at Hot S/D or above, (Modes 1, 2, 3, or 4) and one or more fission product barriers have been affected, refer to Enclosure 4.1, (Fission Product Barrier Matrix) and review the criteria listed to determine if the event should be classified.
1.1.1 For each Fission Product Barrier, review the associated EALs to determine if there is a Loss or Potential Loss of that barrier.
NOTE: An event with multiple events could occur which would result in the conclusion that exceeding the loss or potential loss thresholds is imminent (i.e. within 1-3 hours). In this situation, use judgement and classify as if the thresholds are exceeded.
1.2 Three possible outcomes exist for each barrier. No challenge, potential loss, or loss.
Use the worst case for each barrier and the classification table at the bottom of the page to determine appropriate classification.
1.3 The numbers in parentheses out beside the label for each column can be used to assist in determining the classification. If no EAL is met for a given barrier, that barrier will have 0 points. The points for the columns are as follows:
Barrier Failure Points RCS Potential Loss 4 Loss 5 Fuel Clad Potential Loss 4 Loss 5 Containment Potential Loss 1 Loss 3 1.3.1 To determine the classification, add the highest point value for each barrier to determine a total for all barriers. Compare this total point value with the numbers in parentheses beside each classification to see which one applies.
1.3.2 Finally as a verification of your decision, look below the Emergency Classification you selected. The loss and/or potential loss EALs selected for each barrier should be described by one of the bullet statements.
28
Enclosure 4.12 RP/0/A/1000/001 Instructions For Using Enclosure 4.1 Page 2 of 2 EXAMPLE: Failure to properly isolate a 'B' MS Line Rupture outside containment, results in extremely severe overcooling.
PTS entry conditions were satisfied.
Stresses on the 'B' S/G resulted in failure of multiple S/G tubes.
RCS leakage through the S/G exceeds available makeup capacity as indicated by loss of subcooling margin.
Barrier EAL Failure Points RCS SGTR > Makeup capacity of one HPI pump in Potential Loss 4 normal makeup mode with letdown isolated Entry into PTS operating range Potential Loss 4 RCS leak rate > available makeup capacity as Loss 5 indicated by a loss of subcooling Fuel Clad No EALs met and no justification for No 0 classification on judgment Challenge Containment Failure of secondary side of SG results in a Loss 3 direct opening to the environment RCS 5 + Fuel 0 + Containment 3 = Total 8 A. Even though two Potential Loss EALs and one Loss EAL are met for the RCS barrier, credit is only taken for the worst case (highest point value) EAL, so the points from this barrier equal 5.
B. No EAL is satisfied for the Fuel Clad Barrier so the points for this barrier equal 0.
C. One Loss EAL is met for the Containment Barrier so the points for this barrier equal 3.
D. When the total points are calculated the result is 8, therefore the classification would be a Site Area Emergency.
E. Look in the box below "Site Area Emergency". You have identified a loss of two barriers. This agrees with one of the bullet statements.
The classification is correct.
29
Enclosure 4.13 RP/0/A/1000/001 References Page 1 of 1 1
References:
- 1. PIP O-05-02980
- 2. PIP O-05-4697
- 3. PIP O-06-0404
- 4. PIP O-06-03347
- 5. PIP O-09-00234
- 6. PIP O-10-1055
- 7. PIP O-10-01750
- 8. PIP O-11-02811
- 9. PIP O-12-1590
- 10. PIP O-10-7809
- 11. PIP O-12-9201
- 12. PIP O-12-9198
- 13. PIP O-12-11227
- 15. PIP O-13-6662
Duke Energy Procedure No.
Oconee Nuclear Station 0 OP/ /A/1108/001 CURVES AND GENERAL INFORMATION Revision No.
109 Electronic Reference No.
OX002VHZ Reference Use PERFORMANCE
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format
RP/0/A/1000/002 Page 2 of 10 Control Room Emergency Coordinator Procedure NOTE: This procedure is an implementing procedure to the Oconee Nuclear Site Emergency Plan and must be:
- 1. Reviewed in accordance with 10CFR50.54(q) prior to approval.
- 2. Forwarded to Emergency Preparedness within seven (7) working days of approval.
- 1. Symptoms
_____ 1.1 Events have occurred requiring activation of the Oconee Nuclear Site Emergency Plan.
- 2. Immediate Actions NOTE:
- State and County agencies shall be notified within 15 minutes of E-plan declaration, Classification upgrades, and Protective Action Recommendations.
- For an outside line dial "9" and for long distance dial "1".
_____ 2.1 IF an EAL exists, Declare the appropriate Emergency Classification level.
Classification ___________ (UE, Alert, SAE, GE)
Time Declared: __________
_____ 2.2 IF A Security event is in progress, THEN GO TO Step 2.4.
RP/0/A/1000/002 Page 3 of 10 NOTE:
- For an unusual event classification, or for events with NO EAL classifications, activation of ERO personnel is at the discretion of the SM.
- Qualified Individual can be any person qualified to use ERONS.
- If a "bridges" or "alternate TSC/OSC" page needs to be sent out, it will be done during the follow-up page.
_____ 2.3 IF ERO has NOT yet been activated AND ERO activation is needed, perform the following:
2.3.1 Circle the applicable initial notification code below.
EAL Notification Codes (see Enclosure 4.11 for descriptions) classification DRILL EMERGENCY None F1a NOUE D1a E1a Alert D2a E2a SAE D3a E3a GE D4a E4a 2.3.2 IF a qualified individual is available to notify the ERO, provide the circled notification code above to a qualified individual and direct them to begin Enclosure 4.10 (Activation of the Emergency Response Organization).
_____ 2.4 Direct Control Room Offsite Communicator(s) to perform the following:
- Record Name ___________________________________________________
- REFER TO RP/0/A/1000/015A (Offsite Communications From The Control Room), Immediate Actions steps 2.1 and 2.2 AND Enclosure 4.7 (Guidelines for Manually Transmitting a Message) in preparation for notifying offsite agencies.
{13}
_____ 2.5 IAAT Changing plant conditions require an emergency classification upgrade, THEN Notify Offsite Communicator to complete in-progress notifications per RP/0/A/1000/15A (Offsite Communications From The Control Room),
AND Start a new clean copy of this procedure for the upgraded classification AND stop working on this copy, noting the time in your log that each new copy started.
RP/0/A/1000/002 Page 4 of 10 NOTE: If more than one EAL of the classification level is met, use the EAL description of most interest to offsite agencies. Use "Remarks" (Line 13 of Notification Form) for additional comments from other EAL descriptions that the offsite agencies may need to know.
Additional message sheets listing other information of interest to offsite agencies (e.g. transporting injured personnel) may be sent, if needed.
_____ 2.6 Obtain the applicable Offsite Notification form in the control room and complete as follows:
_____ 2.6.1 Ensure EAL # as determined by RP/0/A/1000/001 matches Line 4.
_____ 2.6.2 Line 1 - Mark appropriate box "Drill" or "Actual Event"
_____ 2.6.3 Line 1 - Enter Message #
_____ 2.6.4 Line 2 - Mark Initial
_____ 2.6.5 Line 6 - A. Mark "Is Occurring" if any of the following are true:
- RIAs 40, 45, or 46 are increasing or in alarm
- If containment is breached
- Containment pressure > 1 psig B. Mark "None" if none of the above is applicable.
_____ 2.6.6 Line 7 - If Line 6 Box B or C is marked, mark Box D. Otherwise mark Box A.
_____ 2.6.7 Line 8 - Mark "Stable" unless an upgrade or additional PARs are anticipated within an hour.
- Refer to Enclosure 4.8 (Event Prognosis Definitions)
_____ 2.6.8 Line 10 - Military time and date of declaration (Refer to date/time in Step 2.1)
RP/0/A/1000/002 Page 5 of 10 NOTE: 1. The following step is used to help determine if an event includes only one unit or all units. The list may not be all inclusive.
- 2. The following is provided by the SM.
_____ 2.6.9 Line 11 - Evaluate the following for classification for all units.
- Security event
- Seismic event
- Tornado on site
- Hurricane force winds on site
- SSF event
- Fire affecting shared safety related equipment Mark or select ALL if event affects the emergency classification on more than one unit.
If event only affects one (1) unit OR one (1) unit has a higher emergency class, select or mark the appropriate unit.
_____ 2.6.10 Line 12 - Mark unit(s) affected (reference Line 11) AND enter percent power for each unit affected. {14}
- If affected unit is shutdown, then enter shutdown time and date.
NOTE: Line number 13 should be used to provide information important to offsite agencies.
The following are examples of information which should be provided:
- Time that fires are extinguished
- Offsite fire departments have been requested to assist with a fire onsite
- The type of natural event which had affected the site (i.e. tornado, seismic, etc.)
- Notification that a radiologically contaminated patient has been transported offsite
- The dam or dike which has resulted in a Condition Bravo or Alpha, if known
- Status of a security threat against the site if known
_____ 2.6.11 Line 13 - If the SM has no remarks, write "None"
RP/0/A/1000/002 Page 6 of 10
_____ 2.6.12 If Condition "A" exists ensure following PARs are included on Line 5.
A. Evacuate: Move residents living downstream of the Keowee Hydro Project dams to higher ground.
B. Other: Prohibit traffic flow across bridges identified on your inundation maps until the danger has passed.
_____ 2.6.13 Line 17 - SM signature, CURRENT Time/Date NOTE:
Their use will enable communications when phone lines are busy or overloaded.
See instructions on back of card.
- For communication failures, see RP/0/A/1000/015A (Offsite Communications From The Control Room), Enclosure 4.9 (Alternate Method and Sequence to Contact Agencies).
They can be used when other means of communication have failed.
- Only an Initial and a Termination Message are required for Unusual Event classifications. No follow-up notifications (updates) are required unless requested by Offsite Agencies.
_____ 2.7 Provide Offsite Communicator with Emergency Notification Form and direct him/her to perform RP/0/A/1000/015A (Offsite Communications From The Control Room). Verify Notifications to State and Counties are completed within 15 minutes.
_____ 2.8 Ensure step 2.3.2 has been completed.
_____ 2.9 Make PA announcement regarding classification (see Enclosure 4.1).
_____ 2.10 IAAT The Hydro Group notifies the Control Room that Condition A, Imminent or Actual Dam failure (Keowee or Jocassee) OR Condition B at Keowee exists or applies, THEN REFER TO Enclosure 4.2 (Condition A/ Condition B Response Actions) for additional protective actions.
AND After the State (SC) and Counties (Oconee and Pickens) have been notified, ENSURE that notification is made to the following:
Georgia Emergency Management Agency 404-635-7000 or 7200 National Weather Service 864-879-1085 or 800-268-7785
RP/0/A/1000/002 Page 7 of 10 NOTE: Activation of the ERO is NOT required for an Unusual Event Classification.
_____ 2.11 IF This is an Unusual Event, AND The SM/Emergency Coordinator does NOT desire that any part of the ERO be activated, THEN GO TO Step 2.15.
NOTE: Activate the TSC and/or OSC Backup Emergency Response Facility (ERF) in the Oconee Office Building, Rooms 316 and 316A, if a fire in the Turbine Building, flooding conditions, Security events (except those involving intrusion/attempted intrusion), or onsite/offsite hazardous materials spill have occurred or are occurring. {4}{16}
_____ 2.12 Notify Security Shift Supervisor (Ext. 2309 or 3636) that the ERO is being activated and obtain his/her recommendations for conducting a site assembly should it be needed.
NOTE:
- This step is required in addition to action taken in step 2.3. {13}
- ERONS Notification Codes are grouped by EAL. ERONS Emergency Notifications begin on page 1 of Enclosure 4.11. ERONS Drill Notifications begin on page 3 of Enclosure 4.11.
- Activation of the ERO during Condition B is done to allow adequate time for the TSC to assess the need to relocate B.5.b equipment in the event of an anticipated upgrade to a Condition A.
- Qualified Individual can be any person qualified to use ERONS.
_____ 2.13 Direct activation of the Emergency Response Organization (ERO) by performing the following:
2.13.1 Determine the appropriate ERONS notification code from Enclosure 4.11 (ERONS Notification Codes and Titles).
2.13.2 Provide the notification code identified above to a qualified individual and direct them to perform Enclosure 4.10 (Activation of the Emergency Response Organization). {8}
_____ 2.14 Implement Enclosure 4.4 (SM Emergency Coordinator Turnover Sheet).
RP/0/A/1000/002 Page 8 of 10 NOTE: Enclosure 4.6 (Radiation Monitoring) may be used to help determine if RIA values, Dose Projections, or Field Monitoring surveys require a classification Upgrade and Protective Action Recommendation.
_____ 2.15 IAAT Abnormal radiation levels or releases are occurring or have occurred, THEN Perform the following:
_____ Notify RP to perform Offsite Dose Calculations, determine Protective Action Recommendations, and initiate radiological field monitoring.
_____ REFER TO Enclosure 4.6 (Radiation Monitoring) to determine if RIA values, Dose Projections, or analysis of Field Monitoring Surveys require a classification Upgrade and Protective Action Recommendation.
_____ 2.16 Perform one of the following:
_____ 2.16.1 Direct a qualified individual to perform Enclosure 4.3 (Emergency Coordinator Parallel Actions):
- Record Name: ___________________________________________
- Notify individual appointed that a Security event (Does/Does Not) exist and a Site Assembly (Is/Is Not) desired
_____ 2.16.2 Perform Enclosure 4.3 (Emergency Coordinator Parallel Actions).
_____ 2.17 IAAT A Site Assembly needs to be initiated, THEN Initiate Site Assembly per RP/0/A/1000/009 (Procedure for Site Assembly).
- 3. Subsequent Actions
_____ 3.1 IAAT An Unusual Event classification is being terminated, THEN REFER TO Enclosure 4.5 (Emergency Classification Termination Criteria) of this procedure for termination guidance.
_____ 3.1.1 Verify that the Offsite Communicator has provided termination message to the off-site agencies.
RP/0/A/1000/002 Page 9 of 10 NOTE: The EP Section shall develop a written report, for signature by the Site Vice President, to the State Emergency Management Agency, Oconee County EPD, and Pickens County EPD within 24 working hours of the event termination.
_____ 3.1.2 Notify Emergency Preparedness Section (Emergency Planning Duty person after hours) of the following:
- The Unusual Event has been terminated
- Conduct a critique following termination of an actual Unusual Event NOTE:
- After normal working hours, Emergency Response Personnel will NOT report to the TSC or OSC until after a Security threat has been neutralized. Emergency Response personnel will report to the Oconee JIC (Alternate Facility) during Security events.
- If the ERO was activated and a Security event involving an intrusion/attempted intrusion DOES NOT exist, then provide turnover to the Technical Support Center.
- If the ERO was activated after normal working hours AND a Security Event involving an intrusion/attempted intrusion DOES exist, then provide Notification turnover information to the EOF Director. After the EOF is activated, the EOF will assume responsibility for classifications, notifications, and protective action recommendations. The SM will remain the Emergency Coordinator for all other activities until the TSC is activated.
_____ 3.2 IAAT The TSC or EOF is ready to accept turnover, THEN Perform one of the following as required:
_____ 3.2.1 IF The TSC is ready to accept Emergency Coordinator responsibilities, THEN Perform turnover using Enclosure 4.4 (SM Emergency Coordinator Turnover Sheet).
Time TSC Activated:__________________
A. Turn over all emergency response procedures in use to the TSC.
B. Direct all available Auxiliary Operators (AOs) to report to the OSC to support damage repair efforts.
RP/0/A/1000/002 Page 10 of 10 NOTE: The EOF Director will notify the Control Room Emergency Coordinator when the EOF is operational and ready to initiate turnover.
_____ 3.2.2 IF The EOF is ready to initiate turnover information, THEN Verify notification turnover information from the EOF Director:
_____ A. Fax Enclosure 4.4 (SM Emergency Coordinator Turnover Sheet).
_____ B. Obtain current copy of Emergency Notification Form and plant status.
_____ C. Verify the information being provided by the EOF Director from Enclosure 4.4 and the current Emergency Notification Form.
_____ D. WHEN Control Room Emergency Coordinator verification of Notification turnover information from EOF Director is complete AND the EOF is activated, turnover Notification responsibility to the EOF and log:
Time EOF Activated:__________________
_____ E. Direct NRC Communicator to notify the NRC Operations Center that the EOF is activated.
- 4. Enclosures 4.1 Plant Public Address Announcements 4.2 Condition A/ Condition B Response Actions 4.3 Emergency Coordinator Parallel Actions 4.4 SM Emergency Coordinator Turnover Sheet 4.5 Emergency Classification Termination Criteria 4.6 Radiation Monitoring 4.7 Summary of IAAT Steps 4.8 Event Prognosis Definitions 4.9 References 4.10 Activation of the Emergency Response Organization 4.11 ERONS Notification Codes and Titles
Enclosure 4.1 RP/0/A/1000/002 Plant Public Address Announcements Page 1 of 1
- 1. Select from the following and announce over the Plant Public Address System:
_____ Drill Message:
Attention all site personnel. This is __________________(name). I am the Emergency Coordinator.
This is a drill. This is a drill.
- As of ________ (time declared), a(n) ___________________ (emergency classification) has been declared for Unit(s) ________ (affected unit(s)).
- Plant condition for Unit(s) ________ (affected unit(s)) is ______________________
_______________________ (stable, degrading, improving, what has happened, etc.).
- IF A release has occurred or is suspected AND/OR a site assembly has been activated THEN Announce the following:
No eating or drinking until the area is cleared by RP.
- IF TSC/OSC activation is necessary AND TSC/OSC has not yet been activated THEN Announce one of the following, as applicable:
Activate the TSC/OSC Activate the Backup TSC/OSC
_____ Emergency Message:
Attention all site personnel. This is __________________(name). I am the Emergency Coordinator.
This is an emergency message.
- As of ________ (time declared), a(n) ___________________ (emergency classification) has been declared for Unit(s) ________ (affected unit(s)).
- Plant condition for Unit(s) ________ (affected unit(s)) is ______________________
_______________________ (stable, degrading, improving, what has happened, etc.).
- IF A release has occurred or is suspected AND/OR a site assembly has been activated THEN Announce the following:
No eating or drinking until the area is cleared by RP.
- IF TSC/OSC activation is necessary AND TSC/OSC has not yet been activated THEN Announce one of the following, as applicable:
Activate the TSC/OSC Activate the Backup TSC/OSC
Enclosure 4.2 RP/0/A/1000/002 Condition A/ Condition B Response Actions Page 1 of 3
- 1. Condition A Response - Immediate Actions NOTE: The Hydro Group will notify the Control Room/SM when Condition A/B conditions apply.
Condition A - Failure is Imminent or Has Occurred - A failure at the dam has occurred or is about to occur and minutes or days may be allowed to respond dependent upon the proximity to the dam. (Keowee or Jocassee)
Condition B - Potentially Hazardous Situation is Developing - A situation where failure may develop, but preplanning actions taken during certain events (major floods, earthquakes) may prevent or mitigate failure. (Keowee)
_____ 1.1 IF Condition A, Imminent or Actual Dam Failure (Keowee or Jocassee) exists.
THEN Perform the following actions:
_____ 1.1.1 Provide the following Protective Action Recommendations to Oconee County and Pickens County for imminent/actual dam failure.
NOTE: State and County Agencies shall be notified within 15 minutes of Protective Action Recommendations.
_____ A. Provide the following recommendation for Emergency Notification Form Section 5 (B) Evacuate: Move residents living downstream of the Keowee Hydro Project dams to higher ground.
_____ B. Provide the following recommendation for Emergency Notification Form Section 5 (E) Other: Prohibit traffic flow across bridges identified on your inundation maps until the danger has passed.
_____ 1.2 IF Condition A, Imminent or Actual Dam Failure (Keowee or Jocassee) exist, THEN Notify the following after the State and Counties are notified:
Georgia Emergency Management agency 404-635-7000 or 7200 National Weather Service 864-879-1085 or 800-268-7785
- 2. Condition A Response - Subsequent Actions
_____ 2.1 Notify Hydro Central and provide information related to the event.
_____ 2.1.1 REFER TO Page 5 of the Emergency Telephone Directory, Keowee Hydro Project Dam/Dike Notification. {2}
Enclosure 4.2 RP/0/A/1000/002 Condition A/ Condition B Response Actions Page 2 of 3
_____ 2.2 Relocate Keowee personnel to the Operational Support Center (OSC) if events occur where their safety could be affected.
_____ 2.2.1 IF Keowee personnel are relocated to the OSC, THEN Notify Hydro Central at 704-382-6836 or 6838 or 6839.
_____ A. REFER TO Page 5 of the Emergency Telephone Directory, Keowee Hydro Project Dam/Dike Notification. {2}
NOTE: A loss of offsite communications capabilities (Selective Signaling and the Wide Area Network - WAN) could occur within 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> after Keowee Hydro Dam failure.
Rerouting of the Fiber Optic Network through Bad Creek should be started as soon as possible.
_____ 2.3 Notify Telecommunications Group in Charlotte to begin rerouting the Oconee Fiber Optic Network.
_____ 2.3.1 REFER TO Selective Signaling Section of the Emergency Telephone Directory (page 13).
_____ 2.4 Request Security to alert personnel at the Security Track/Firing Range and Building 8055 (Warehouse #5) to relocate to work areas inside the plant.
NOTE:
- Plant access road to the Oconee Complex could be impassable within 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> if the Keowee Hydro Dam fails. A loss of the Little River Dam (Newry Dam) or Dikes A-D will take longer to affect this road.
- PA Announcements can be made by the Control Room using the Office Page Override feature or Security.
_____ 2.5 Make a PA Announcement to relocate personnel at the following locations to the World Of Energy/Operations Training Center.
Oconee Complex Oconee Garage Oconee Maintenance Training Facility
_____ 2.6 Dispatch operators to the SSF and establish communications.
Enclosure 4.2 RP/0/A/1000/002 Condition A/ Condition B Response Actions Page 3 of 3
_____ 2.7 Initiate the following actions for a Condition A for Keowee OR Jocassee:
_____ 2.7.1 Direct SPOC to initiate relocation of Appendix R equipment and Hale Fire Pump to the ISFSI or Elevated Water Storage Tank areas.
_____ 2.7.2 Notify Security Supervision to be prepared to relocate Security Officers due to flooding within the protected area and to waive security requirements as needed to support relocation of Appendix R equipment and Hale Fire Pump.
_____ 2.7.3 Recall off shift Operations personnel to assist with shutdown of operating units.
_____ 2.8 GO TO Enclosure 4.3 (Emergency Coordinator Parallel Actions) Step 1.11.
- 3. Condition B Response - Immediate Actions
_____ 3.1 IF Condition B at Keowee exists, THEN Notify the following after the State and Counties are notified:
Hydro Central 704-382-6836 Georgia Emergency Management Agency 404-635-7000 or 7200 National Weather Service 864-879-1085 or 800-268-7785
_____ 3.2 GO TO Enclosure 4.3 (Emergency Coordinator Parallel Actions) Step 1.11.
Enclosure 4.3 RP/0/A/1000/002 Emergency Coordinator Parallel Actions Page 1 of 4
- 1. Emergency Coordinator Parallel Actions
_____ 1.1 IAAT Changing plant conditions require an emergency classification upgrade, THEN Re-start with a clean copy of this enclosure and stop the current copy of the enclosure.
NOTE: An open line to the NRC may be required.
Notifications to the NRC are required within one (1) hour of declaration of the emergency classification level.
_____ 1.2 Direct an SRO to make notifications to the NRC.
CR NRC Communicator (SRO) Name ______________________________
_____ 1.3 Direct the CR NRC Communicator to complete the OMP 1-14 NRC Event Notification Worksheet and Plant Status Sheet.
NOTE: The NRC Communicator is responsible for activating ERDS.
Activating ERDS is NOT required for an Unusual Event classification.
_____ 1.4 Direct the CR NRC Communicator to start the Emergency Response Data System (ERDS) for units(s) involved, within one (1) hour of an emergency classification of Alert or higher. REFER TO RP/0/A/1000/003A (ERDS Operation).
NOTE: Notifications per AD-LS-ALL-0006 (Notification/Reportability Evaluation) for 10CFR50.72 require ALL reportable items that are met or exceeded to be reported in addition to the NRC Event Notification Worksheet and Plant Status Sheet required within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of the event declaration.
_____ 1.5 IAAT Plant conditions require NRC notification under 10CFR50.72, THEN Direct the CR NRC Communicator to provide this notification using the guidance in OMP 1-14 (Notifications).
_____ 1.6 IF The Emergency Response Organization is NOT needed to assist with the Unusual Event emergency activities, AND Personnel accountability is NOT desired, THEN GO TO Step 1.8.
Enclosure 4.3 RP/0/A/1000/002 Emergency Coordinator Parallel Actions Page 2 of 4 WARNING: Conducting Site Assembly during a Security Event may NOT be prudent.
_____ 1.7 IAAT The SM directs that a Site Assembly be initiated, THEN Initiate Site Assembly per RP/0/A/1000/009 (Procedure For Site Assembly).
_____ 1.8 IAAT Any Area Radiation Monitor is increasing or is in ALARM, OR Steam Line Break has occurred, THEN Contact shift RP to dispatch onsite monitoring teams.
_____ 1.9 IF This is a General Emergency, THEN Initiate evacuation of all non-essential personnel from the site after personnel accountability has been reached. REFER TO RP/0/A/1000/010 (Procedure for Emergency Evacuation/Relocation of Site Personnel).
_____ 1.10 IAAT If notified by the Hydro Group that Condition A Imminent or Actual Dam Failure (Keowee or Jocassee),
OR Condition B (Keowee) exists, THEN REFER TO Enclosure 4.2 (Condition A/ Condition B Response Actions) for additional PAR and/or response actions.
_____ 1.11 IAAT Major damage has occurred or is occurring, THEN Initiate RP/0/A/1000/022 (Procedure for Major Site Damage Assessment and Repair) and/or RP/0/A/1000/029 (Fire Brigade Response - OSC).
_____ 1.12 IAAT A Security Event is in progress, THEN Verify that the 15 minute notification for the Security event has been made to the NRC. {12}
_____ 1.13 IAAT A hazardous substance has been released, THEN Initiate RP/0/A/1000/017 (Spill Response).
Enclosure 4.3 RP/0/A/1000/002 Emergency Coordinator Parallel Actions Page 3 of 4 NOTE: Priority should be placed on providing treatment for the most life-threatening event (i.e., medical versus radiation exposure - OSC procedure RP/0/B/1000/011 (Planned Emergency Exposure)). The Emergency Coordinator may authorize (either verbal or signature) exposures greater than 25 rem TEDE (Total Effective Dose Equivalent) for life saving missions.
_____ 1.14 IAAT A medical response is required, THEN Initiate RP/0/A/1000/016 (MERT Activation Procedure For Medical, Confined Space and High Angle Rescue Emergencies).
_____ 1.14.1 Document verbal approval of Planned Emergency Exposures required for life saving missions in the Control Room Emergency Coordinator Log.
CAUTION: Use of the Outside Air Booster Fans during a Security Event may introduce incapacitating agents in the Control Room.
NOTE: The Outside Air Booster Fans (Control Room Ventilation System - CRVS) are used to provide positive pressure in the Control Room to prevent smoke, toxic gases, or radioactivity from entering the area as required by NUREG-0737.
Chlorine Monitor Alarm will either stop the Air Booster Fans or will not allow them to start.
Items to consider for operation of the Outside Air Booster Fans: Security events, Smoke or toxic gases may enter the Control Room, RIA-39 in ALARM, Dose levels in CR/TSC/OSC
_____ 1.15 Evaluate operation of the Outside Air Booster Fans.
Enclosure 4.3 RP/0/A/1000/002 Emergency Coordinator Parallel Actions Page 4 of 4 NOTE:
- 10CFR50.54(x) allows for reasonable actions that depart from a License Condition or Technical Specification to be performed in an emergency when this action is immediately needed to protect the health and safety of the public and no action consistent with the License Condition or Technical Specification that can provide adequate or equivalent protection is immediately apparent.
- 10CFR50.54 (y) requires approval of any 10CFR50.54(x) actions by an SRO at minimum. (Anyone more senior than the SRO may approve.)
- Implementation of Oconee Severe Accident Guidelines (OSAG) requires the use of 10CFR50.54 (x) and (y) provisions.
_____ 1.16 IAAT Plant conditions require a decision to implement 10CFR50.54(x),
THEN Perform the following Steps:
_____ 1.16.1 Document decision and actions taken in the affected unit's log.
_____ 1.16.2 Document decision and actions taken in the Emergency Coordinator Log.
NOTE: NRC must be notified of any 10CFR50.54(x) decisions and actions within one (1) hour.
_____ 1.16.3 Direct the CR NRC Communicator to report decision and actions taken to the NRC.
_____ 1.17 Ensure Site Assembly has been considered, is in progress, or complete. Refer to RP/0/A/1000/009 (Procedure for Site Assembly).
Enclosure 4.4 RP/0/A/1000/002 SM Emergency Coordinator Turnover Sheet Page 1 of 1 Unit 1 Unit 2 Unit 3 Rx Power RCS Pressure RCS Temp. Rx Power RCS Pressure RCS Temp. Rx Power RCS Pressure RCS Temp.
Auxiliary Power From ES Channels Actuated Auxiliary Power From ES Channels Actuated Auxiliary Power From ES Channels Actuated Jobs In Progress: Jobs In Progress: Jobs In Progress:
Major Equipment Out of Service: Major Equipment Out of Service: Major Equipment Out of Service:
ERDS Activated? Yes/No CR Booster Fans On? Yes/No ERDS Activated? Yes/No ERDS Activated? Yes/No CR Booster Fans On? Yes/No Abnormal/Emergency Procedures Currently In Progress Emergency Response Procedures in Progress Yes No List Any EOP/APs In Progress RP/0/A/1000/002 (Control Room Emergency Coordinator) 9 RP/0/A/1000/009 (Site Assembly)
RP/0/A/1000/010 (Emergency Evacuation/Relocation of Site Personnel)
RP/0/A/1000/016 (MERT Activation for Medical, Confined Space and High Angle Rescue Emergency)
RP/0/A/1000/017 (Spill Response)
RP/0/A/1000/022 (Major Site Damage Assessment and Repair)
RP/0/A/1000/029 (Fire Brigade Response - OSC)
Emergency Dose Limits for AP/EOP actions in effect?
IF Condition A, Dam Failure, has been declared for Keowee Hydro Project, THEN Provide the following information to the TSC Emergency Coordinator:
- Status of Offsite Agency Notifications ___________________________________________________________________________________________
- Recommendations made to offsite agencies _______________________________________________________________________________________
- Status of relocation of site personnel_____________________________________________________________________________________________
Status for answering 4911 emergency phone call: Remains in Control Room __________ Responsibility of Ops in OSC __________
Status of Site Assembly (Needed only if after hours, holidays, or weekends)_________________________________________________________________________
Time Next message is due to Offsite Agencies ___________ (Attach all completed Emergency Notification Forms)
Emergency Coordinator/TSC ___________________________________ SM ___________________________________ Time of Turnover _________________
Enclosure 4.5 RP/0/A/1000/002 Emergency Classification Termination Page 1 of 1 Criteria IF The following guidelines applicable to the present emergency condition have been met or addressed, THEN An emergency condition may be considered resolved when:
_____ 1. Existing conditions no longer meet the existing emergency classification criteria and it appears unlikely that conditions will deteriorate further.
_____ 2. Radiation levels in affected in-plant areas are stable or decreasing to below acceptable levels.
_____ 3. Releases of radioactive material to the environment greater than Technical Specifications are under control or have ceased.
_____ 4. The potential for an uncontrolled release of radioactive material is at an acceptably low level.
_____ 5. Containment pressure is within Technical Specification 3.6 requirements.
_____ 6. Long-term core cooling is available.
_____ 7. The shutdown margin for the core has been verified.
_____ 8. A fire, flood, earthquake, or similar emergency condition is controlled or has ceased.
_____ 9. Offsite power is available per Technical Specification requirements.
_____ 10. All emergency action level notifications have been completed.
_____ 11. Hydro Central has been notified of termination of Condition B for Keowee Hydro Project. {2}
REFER TO Page 5 of the Emergency Telephone Directory (Keowee Hydro Project Dam/Dike Notification).
_____ 12. The Regulatory Compliance Section has evaluated plant status with respect to Technical Specifications and recommends Emergency classification termination.
_____ _____ 13. Emergency terminated. Request the Control Room Offsite Communicator to Date/Time Initial complete an Emergency Notification Form for a Termination Message using guidance in RP/0/A/1000/015A (Offsite Communications From The Control Room) and provide information to offsite agencies.
GO TO Step 3.1.
Enclosure 4.6 RP/0/A/1000/002 Radiation Monitoring Page 1 of 1 NOTE: Refer to the appropriate enclosures in RP/0/A/1000/001 (Emergency Classification) to determine the Emergency Classification.
Indication Value Reference Enclosure RIA-3 Valid High Alarm 4.3 RIA-6 Valid High Alarm 4.3 RIA-7 > 150 mRad/Hr 4.3 RIA-8 > 4200 mRad/Hr 4.3 RIA-10 > 830 mRad/Hr 4.3 RIA-11 > 210 mRad/Hr 4.3 RIA-12 > 800 mRad/Hr 4.3 RIA-13 > 650 mRad/Hr 4.3 RIA-15 > 5000 mRad/Hr 4.3 RIA-16 is or has been in High or Alert alarm (>2.5 mR/Hr) N/A RIA-17 is or has been in High or Alert alarm (>2.5 mR/Hr) N/A RIA-33 > 4.06E06 cpm for > 60 minutes or in High Alarm 4.3 RIA-41 Valid High Alarm 4.3 RIA-45 > 1.33E06 cpm for > 60 minutes 4.3 RIA-46 > 2.09E04 cpm or 2.09E05 or 2.09E06 for > 15 minutes 4.3 RIA-49 Valid High Alarm 4.3 1,3RIA-57 > 1.0 R/Hr 4.1 2RIA-57 > 1.6 R/Hr 4.1 1,2,3RIA-58 > 1.0 R/Hr 4.1 RIA-57/58 RP/0/A/1000/001 Encl. 4.8 values 4.3 Projected Dose Calculations > 100 mrem TEDE or > 500 mrem CDE Adult Thyroid at Site Boundary 4.3, 4.7 Analyzed Field Monitoring Surveys > 500 mrem CDE Adult Thyroid on one hour of inhalation 4.3 Field Monitoring Indications > 100 mRad/Hr at Site Boundary expected to continue for > one hour 4.3 Control Room, CAS, or Radwaste CR Radiation Levels Valid Reading 15 mRad/Hr 4.3 Damaged Spent Fuel Storage Cask at ISFSI 1 R/Hr reading at 1 foot 4.3 Portable Monitor on Main or Spent Fuel Bridge Unplanned Valid Reading Increase or High Alarm 4.3 Liquid Release > SLC 16.11.1 values 4.3 Gaseous Release > SLC 16.11.2 values 4.3
Enclosure 4.7 RP/0/A/1000/002 Summary of IAAT Steps Page 1 of 1 IF AT ANY TIME:
Immediate Actions (2.5) changing plant conditions require an emergency classification upgrade...
(2.10) The Hydro Group notified the Control Room that Condition A, Imminent or Actual Dam Failure (Keowee or Jocassee) or Condition B at Keowee exists...
(2.15) abnormal radiation levels or releases are occurring or have occurred...
(2.17) site assembly needs to be initiated...
Subsequent Actions (3.1) an Unusual Event classification is being terminated...
(3.2) the TSC or EOF is ready to accept turnover... .3 (Emergency Coordinator Parallel Actions)
(1.1) changing plant conditions require an emergency classification upgrade...
(1.5) plant conditions require NRC notification under 10CFR50.72...
(1.7) the SM directs that a Site Assembly be initiated...
(1.8) any Area Radiation Monitor is increasing or in ALARM, OR a Steam Line Break has occurred, (1.10) if notified by the Hydro Group that Condition A, Imminent or Actual Dam Failure (Keowee or Jocassee) OR Condition B (Keowee) exists...
(1.11) major damage has occurred OR is occurring...
(1.12) a Security Event is in progress...
(1.13) a hazardous substance has been released...
(1.14) a medical response is required...
(1.16) plant conditions require a decision to implement 10CFR50.54(x)...
Enclosure 4.8 RP/0/A/1000/002 Event Prognosis Definitions Page 1 of 1 The following definitions apply when determining Event Prognosis for completing line #8 on the Emergency Notification Form.
Degrading: Plant conditions involve at least one of the following:
- Plant parameters (ex. temperature, pressure, level, voltage, frequency) are trending unfavorably away from expected or desired values AND plant conditions could result in a higher classification or Protective Action Recommendation (PAR) before the next follow-up notification.
- Site conditions (ex. wind, ice/snow, ground tremors, hazardous/toxic/radioactive material leak, fire, Security event) impacting plant operations or personnel safety are worsening AND plant conditions could result in a higher classification or Protective Action Recommendation (PAR) before the next follow-up notification Improving: Plant conditions involve at least one of the following:
- Plant parameters (ex. temperature, pressure, level, voltage, frequency) are trending favorably toward expected or desired values AND plant conditions could result in a lower classification or emergency termination before the next follow-up notification.
- Site conditions (ex. wind, ice/snow, ground tremors hazardous/toxic/radioactive material leak, fire, Security event) have become less of a threat to plant operations or personnel safety AND plant conditions could result in a lower classification or emergency termination before the next follow-up notification.
Stable: Plant conditions are neither degrading nor improving. {10}
Enclosure 4.9 RP/0/A/1000/002 References Page 1 of 1
- 1. PIP O-01-01395
- 2. PIP O-01-03460
- 3. PIP O-01-03696
- 4. PIP O-02-01452
- 5. PIP O-02-03705
- 6. PIP O-04-06494
- 7. PIP O-04-04755
- 8. PIP O-04-07469
- 9. PIP O-05-01642
- 10. PIP O-05-03349
- 11. PIP O-05-02980
- 12. PIP O-05-04697
- 13. PIP O-07-06549
- 14. PIP O-08-01712
- 15. PIP O-13-01001
- 16. PIP O-12-03091
Enclosure 4.10 RP/0/A/1000/002 Activation of the Emergency Response Page 1 of 4 Organization
- 1. Instructions
_____ 1.1 Obtain the notification code(s) from the SM and record below:
Notification Code: __________________
_____ 1.2 IF a security event is NOT in progress AND security can be reached at 6002, perform the following:
_____ 1.2.1 Notify Security at extension 6002 to activate ERO.
_____ 1.2.2 Provide Security with the notification code(s) recorded in Step 1.1.
_____ 1.2.3 Inform the Emergency Coordinator that Security has been notified to activate the TSC and OSC.
_____ 1.2.4 Exit this Enclosure.
NOTE: Only one person can be signed onto EverBridge at a time. If a second person logs onto EverBridge, the first person will be logged off.
_____ 1.3 IF a security event is in progress OR security CANNOT be reached at extension 6002, perform the following to activate the ERO:
1.3.1 IF AT ANY TIME the following steps CANNOT be accomplished, GO TO step 1.4.
NOTE: Login and Password can be obtained from the Password Card in the Control Room.
1.3.2 Obtain the Login Username and Password for EverBridge.
NOTE: Everbridge can be accessed by selecting either the EverBridge icon on the desktop, selecting ERONS from the DAE, or entering "manager.everbridge.net" without the quotations into the Internet Explorer address bar.
1.3.3 From a Duke Energy computer, open the EverBridge application.
1.3.4 On the Everbridge login page, enter the username (NOT case sensitive) and password (case sensitive) obtained in step 1.3.2 into the corresponding fields.
1.3.5 Click the "Sign-In" button.
Enclosure 4.10 RP/0/A/1000/002 Activation of the Emergency Response Page 2 of 4 Organization 1.3.6 Select "Proceed" on the "Welcome" screen in order to select the proper notification message.
1.3.7 Select the "Notification Templates" tab.
1.3.8 IF AT ANY TIME a message is sent in error AND the message must be retracted, repeat steps 1.3.9 - 1.3.14 with "C1" as the notification code.
NOTE: Steps 1.3.9 - 1.3.14 can be repeated for each code that is required to be sent.
1.3.9 Perform one of the following to locate the proper notification:
A. Type the "notification code" identified in step 1.1 into the search box and select "ENTER."
B. Select "Title" to sort Notifications alpha-numerically.
1.3.10 WHEN the proper notification has been found, select the checkbox of the desired notification number.
1.3.11 Select "Send".
1.3.12 WHEN the box labeled "Include the notification as part of an event?" appears, select the radio button for "No, send as individual notifications."
NOTE: Completion of the following step will cause the ERO notification to be sent.
1.3.13 Select "Send".
NOTE: The second verification below is done by selecting 'Active/History' in the EverBridge application, (If a rotating timer icon appears, refresh the screen) and selecting the hyperlinked title of the notification (s) initiated.
1.3.14 IF either of the following CANNOT be verified, notify the Emergency Coordinator and GO TO step 1.4.
An ERO notification call has been received in the Control Room EverBridge has names listed under 'Contacts Name' heading in the appropriate archived history.
1.3.15 Inform the Emergency Coordinator that ERO has been activated per ERONS.
Enclosure 4.10 RP/0/A/1000/002 Activation of the Emergency Response Page 3 of 4 Organization
_____ 1.4 IF step 1.3 could NOT be completed successfully, perform the following to use the EverBridge Live Operator method to activate ERO:
1.4.1 IF AT ANY TIME the following CANNOT be completed, GO TO step 1.5.
1.4.2 Contact the EverBridge Live Operator by calling one of the following:
- 9-1-877-220-4911
- 9-1-818-230-9797 1.4.3 Note date and time of call initiation:
______________________________/__________
Date / Time NOTE: It may be prudent to ask for a repeat-back of the Notification code provided to the EverBridge Live Operator to ensure the proper notification is sent.
1.4.4 Provide the following information to the EverBridge Live Operator when prompted:
Information Requested Response EverBridge Organization "Oconee Nuclear Station" Name username "ONSactivation" city or town of your birth "Charlotte" How may the Everbridge "I want to send a priority notification using a Operator help? Mass Notification Template."
Notification Title Provide Live Operator with only the code(s) of the notification to be sent. This can be obtained from step 1.1.
Is the broadcast ID "YES."
desired? Record the Broadcast ID: ______________
1.4.5 Terminate phone call and record date and time of call completion:
1.4.6 IF ERO notification call has NOT been received in the Control Room, perform the following:
A. Notify the Emergency Coordinator B. GO TO to step 1.5.
Enclosure 4.10 RP/0/A/1000/002 Activation of the Emergency Response Page 4 of 4 Organization 1.4.7 Inform the Emergency Coordinator that ERO has been activated per ERONS.
_____ 1.5 IF ERO activation using ERONS is NOT successful, perform the following:
_____ 1.5.1 Notify Security to activate ERO using the Nuclear Callout System.
_____ 1.5.2 Notify the SM that ERO activation using ERONS was unsuccessful and Security has been notified to use Nuclear Callout System.
Enclosure 4.11 RP/0/A/1000/002 ERONS Notification Codes and Titles Page 1 of 4
- 1. General ERONS Notification Codes:
ACTIVATION ERROR Notification Title Description Code C1 CANCEL ACTIVATION To retract any ERONS message sent in error. This notifies the entire ERO.
- 2. Emergency ERONS Notification Codes:
Notification of Unusual Event (NOUE) - E1 Notification Title Description Code E1a ONS Emergency - ERO Activation - NOUE Activates the TSC, OSC, and EOF.
E1f ONS Emergency - Security Event - NOUE Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
E1g ONS Emergency - Security Event - Post Attack Security event under control. Activate the TSC and
E1h ONS Emergency - Bridges - NOUE Bridges may be affected. Activate the TSC, OSC, and EOF.
E1i ONS Emergency - TSC/OSC not available - TSC/OSC is NOT available. Activate the Backup NOUE TSC/OSC.
ALERT - E2 Notification Title Description Code E2a ONS Emergency - ERO Activation - ALERT Activates the TSC, OSC, and EOF.
E2f ONS Emergency - Security Event - ALERT Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
E2g ONS Emergency - Security Event - Post Attack Security event under control. Activate the TSC and
- ALERT OSC.
E2h ONS Emergency - Bridges - ALERT Bridges may be affected. Activate the TSC, OSC, and EOF.
E2i ONS Emergency - TSC/OSC not available - TSC/OSC is NOT available. Activate the Backup ALERT TSC/OSC.
Enclosure 4.11 RP/0/A/1000/002 ERONS Notification Codes and Titles Page 2 of 4 Site Area Emergency (SAE) - E3 Notification Title Description Code E3a ONS Emergency - ERO Activation - SAE Activates the TSC, OSC, and EOF.
E3f ONS Emergency - Security Event - SAE Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
E3g ONS Emergency - Security Event - Post Attack Security event under control. Activate the TSC and
E3h ONS Emergency - Bridges - SAE Bridges may be affected. Activate the TSC, OSC, and EOF.
E3i ONS Emergency - TSC/OSC not available - TSC/OSC is NOT available. Activate the Backup SAE TSC/OSC.
General Emergency (GE) - E4 Notification Title Description Code E4a ONS Emergency - ERO Activation - GE Activates the TSC, OSC, and EOF.
E4f ONS Emergency - Security Event - GE Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
E4g ONS Emergency - Security Event - Post Attack Security event under control. Activate the TSC and
E4h ONS Emergency - Bridges - GE Bridges may be affected. Activate the TSC, OSC, and EOF.
E4i ONS Emergency - TSC/OSC unavailable - GE TSC/OSC is NOT available. Activate the Backup TSC/OSC.
EVENT TERMINATION - E6 Notification Title Description Code E6a ONS Emergency - Event Termination Conditions have improved. the Emergency Response Organization may stand-down. NO further response required.
DISCRETIONARY FACILITY ACTIVATION - F1 Notification Title Description Code F1a ONS Facility Activation Activate the TSC and OSC as a precautionary measure when no EAL applies.
Enclosure 4.11 RP/0/A/1000/002 ERONS Notification Codes and Titles Page 3 of 4
- 3. Drill ERONS Notifications:
Notification of Unusual Event (NOUE) DRILL - D1 Notification Title Description Code D1a ONS Drill - ERO Activation- NOUE Activates the TSC, OSC, and EOF.
D1f ONS Drill - Security Event - NOUE Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
D1g ONS Drill - Security Event - Post Attack - Security event under control. Activate the TSC and NOUE OSC.
D1h ONS Drill - Bridges - NOUE Bridges may be affected. Activate the TSC, OSC, and EOF.
D1i ONS Drill - TSC/OSC unavailable - NOUE Oconee TSC/OSC is NOT available. Use the ONS Backup TSC/OSC.
ALERT DRILL - D2 Notification Title Description Code D2a ONS Drill - ERO Activation- ALERT Activates the TSC, OSC, and EOF.
D2f ONS Drill - Security Event - ALERT Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
D2g ONS Drill - Security Event - Post Attack - Security event under control. Activate the TSC and ALERT OSC.
D2h ONS Drill - Bridges - ALERT Bridges may be affected. Activate the TSC, OSC, and EOF.
D2i ONS Drill - TSC/OSC unavailable - ALERT Oconee TSC/OSC is NOT available. Use the ONS Backup TSC/OSC.
Site Area Emergency (SAE) DRILL - D3 Notification Title Description Code D3a ONS Drill - ERO Activation- SAE Activates the TSC, OSC, and EOF.
D3f ONS Drill - Security Event - SAE Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
D3g ONS Drill - Security Event - Post Attack - SAE Security event terminated. Activate the TSC and OSC.
D3h ONS Drill - Bridges - SAE Bridges may be affected. Activate the TSC, OSC, and EOF.
D3i ONS Drill - TSC/OSC unavailable - SAE Oconee TSC/OSC is NOT available. Use the ONS Backup TSC/OSC.
Enclosure 4.11 RP/0/A/1000/002 ERONS Notification Codes and Titles Page 4 of 4 General Emergency (GE) DRILL - D4 Notification Title Description Code D4a ONS Drill - ERO Activation- GE Activates the TSC, OSC, and EOF.
D4f ONS Drill - Security Event - GE Security event in progress. Activate the EOF only.
TSC and OSC personnel assemble off-site.
D4g ONS Drill - Security Event - Post Attack - GE Security event under control. Activate the TSC and OSC.
D4h ONS Drill - Bridges - GE Bridges may be affected. Activate the TSC, OSC, and EOF.
D4i ONS Drill - TSC/OSC unavailable - GE Oconee TSC/OSC is NOT available. Use the ONS Backup TSC/OSC.
STAFF AUGMENTATION DRILL- D6 Notification Title Description Code D6a ONS Augmentation Drill - TSC & OSC Only Activate the TSC and OSC.
D6b ONS Augmentation Drill - All Facilities Activates the TSC, OSC and EOF.
EVENT TERMINATION - D7 Notification Title Description Code D7a ONS Drill Termination Conditions have improved. the Emergency Response Organization may stand-down. NO further response required.
Radioactive Effluent Monitoring Instrumentation 16.11.3 16.11 RADIOLOGICAL EFFLUENTS CONTROL 16.11.3 Radioactive Effluent Monitoring Instrumentation COMMITMENT Radioactive Effluent Monitoring Instrumentation shall be OPERABLE as follows:
- a. Liquid Effluents The radioactive liquid effluent monitoring instrumentation channels shown in Table 16.11.3-1 shall be OPERABLE with their alarm/trip setpoints set to ensure that the limits of SLC 16.11.1.a are not exceeded.
- b. Gaseous Process and Effluents The radioactive gaseous process and effluent monitoring instrumentation channels shown in Table 16.11.3-2 shall be OPERABLE with their alarm/trip setpoints set to ensure that the limits of SLC 16.11.2.a are not exceeded.
- c. The setpoints shall be determined in accordance with the methodology described in the ODCM and shall be recorded.
NOTE-------------------------------------------
Correction to setpoints determined in accordance with Commitment c may be permitted without declaring the channel inoperable.
APPLICABILITY: According to Table 16.11.3-1 and Table 16.11.3-2.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Alarm/trip setpoint less A.1 Declare channel Immediately conservative than inoperable.
required for one or more effluent OR monitoring instrument channels. A.2 Suspend release of Immediately effluent monitored by the channel.
16.11.3-1 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME B. One or more required B.1 Enter the Condition Immediately liquid effluent monitoring referenced in Table instrument channels 16.11.3-1 for the inoperable. function.
AND B.2 Restore the 30 days instrument(s) to OPERABLE status.
C. One or more required C.1 Enter the Condition Immediately gaseous effluent referenced in Table monitoring instrument 16.11.3-2 for the channels inoperable. function.
AND C.2 Restore the 30 days instrument(s) to OPERABLE status.
D. Required Action and D.1 Explain in next Annual April 30 of following associated Completion Radiological Effluent calendar year Time of Required Action Release Report why B.2 or C.2 not met. inoperability was not corrected in a timely manner.
16.11.3-2 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1.1 Analyze two Prior to initiating Action B.1 and independent samples subsequent release referenced in Table in accordance with 16.11.3-1. (RIA-33) SLC 16.11.4.
AND E.1.2 Conduct two Prior to initiating independent data entry subsequent release checks for release rate calculations AND E.1.3 Conduct two Prior to initiating independent valve subsequent release lineups of the effluent pathway.
OR E.2 Suspend release of Immediately radioactive effluents by this pathway.
F. As required by Required F.1 Suspend release of Immediately Action B.1 and radioactive effluents by referenced in Table this pathway.
16.11.3-1. (RIA-54)
OR F.2 Collect and analyze Prior to each discrete grab samples for gross release of the sump radioactivity (beta and/or gamma) at a lower limit of detection of at least 10 µCi/ml.
-7 16.11.3-3 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME G. As required by Required -----------------NOTE------------------
Action B.1 and Not required during short, referenced in Table controlled outages of liquid 16.11.3-1. (Liquid effluent monitoring Radwaste Effluent Line instrumentation. Short controlled Flow Rate Monitor) outages are defined as planned removals from service for durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, for purposes of sample filter changeouts, setpoint adjustments, service checks, and/or routine maintenance procedures. This guidance may be applied successively, provided that time between successive short, controlled outages is always at least equal to duration of immediately preceding outage.
G.1 Suspend release of Immediately radioactive effluents by this pathway.
OR G.2 Estimate flow rate Immediately during actual releases.
AND Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> thereafter 16.11.3-4 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required -----------------NOTE------------------
Action B.1 and Not required during short, referenced in Table controlled outages of liquid 16.11.3-1. (RIA-35, #3 effluent monitoring Chemical Treatment instrumentation. Short controlled Pond Composite outages are defined as planned Sampler and Sampler removals from service for Flow Monitor (Turbine durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, Building Sumps for purposes of sample filter Effluent)) changeouts, setpoint adjustments, service checks, and/or routine maintenance procedures. This guidance may be applied successively, provided that time between successive short, controlled outages is always at least equal to duration of immediately preceding outage.
H.1 Suspend release of Immediately radioactive effluents by this pathway.
OR H.2 Collect and analyze Immediately grab samples for gross radioactivity (beta AND and/or gamma) at a lower limit of detection Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> of at least 10 µCi/ml.
-7 thereafter 16.11.3-5 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME I. As required by Required -----------------NOTE------------------
Action C.1 and Not required during short, referenced in Table controlled outages of gaseous 16.11.3-2 for effluent effluent monitoring releases from waste gas instrumentation. Short controlled tanks (RIA-37, RIA-38) outages are defined as planned or containment purges removals from service for (RIA-45). durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, for purposes of sample filter changeouts, setpoint adjustments, service checks, and/or routine maintenance procedures. This guidance may be applied successively, provided that time between successive short, controlled outages is always at least equal to duration of immediately preceding outage.
I.1.1 Analyze two Prior to initiating independent samples. subsequent release AND I.1.2 Conduct two Prior to initiating independent data entry subsequent release checks for release rate calculations AND I.1.3 Conduct two Prior to initiating independent valve subsequent release lineups of the effluent pathway.
OR I.2 Suspend release of Immediately radioactive effluents by this pathway.
16.11.3-6 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME J. As required by Required ---------------NOTE--------------------
Action C.1 and Not required during short, referenced in Table controlled outages of gaseous 16.11.3-2. (Effluent effluent monitoring Flow Rate Monitor (Unit instrumentation. Short controlled Vent, Containment outages are defined as planned Purge, Interim removals from service for Radwaste Exhaust, Hot durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, Machine Shop Exhaust, for purposes of sample filter Radwaste Facility changeouts, setpoint Exhaust, Waste Gas adjustments, service checks, Discharge)) and/or routine maintenance procedures. This guidance may be applied successively, provided that time between successive short, controlled outages is always at least equal to duration of immediately preceding outage.
J.1 Suspend release of Immediately radioactive effluents by this pathway.
OR J.2 Estimate flow rate Immediately AND Once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> thereafter 16.11.3-7 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME K. As required by Required -----------------NOTE------------------
Action C.1 and Not required during short, referenced in Table controlled outages of gaseous 16.11.3-2. (RIA-45, effluent monitoring RIA-53, 4RIA-45) instrumentation. Short controlled outages are defined as planned removals from service for durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, for purposes of sample filter changeouts, setpoint adjustments, service checks, and/or routine maintenance procedures. This guidance may be applied successively, provided that time between successive short, controlled outages is always at least equal to duration of immediately preceding outage.
K.1 Suspend release of Immediately radioactive effluents by this pathway.
OR K.2.1 Collect grab sample. Immediately AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AND K.2.2 Analyze grab samples 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from collection for gross activity (beta of sample and/or gamma).
16.11.3-8 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME L. As required by Required -----------------NOTE------------------
Action C.1 and Not required during short, referenced in Table controlled outages of gaseous 16.11.3-2. (Unit Vent effluent monitoring Monitoring Iodine instrumentation. Short controlled Sampler, Unit Vent outages are defined as planned Monitoring Particulate removals from service for Sampler, Interim durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, Radwaste Building for purposes of sample filter Ventilation Monitoring changeouts, setpoint Iodine Sampler, Interim adjustments, service checks, Radwaste Building and/or routine maintenance Ventilation Monitoring procedures. This guidance may Particulate Sampler, Hot be applied successively, Machine Shop Iodine provided that time between Sampler, Hot Machine successive short, controlled Shop Particulate outages is always at least equal Sampler, Radwaste to duration of immediately Facility Iodine Sampler, preceding outage.
Radwaste Facility -------------------------------------------
Particulate Sampler)
L.1 Suspend release of Immediately radioactive effluents by this pathway.
OR L.2.1 -----------NOTE-----------
The collection time of each sample shall not exceed 7 days.
Collect samples Immediately continuously using auxiliary sampling equipment.
AND L.2.2 Analyze each sample. 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> from end of each sample collection 16.11.3-9 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 CONDITION REQUIRED ACTION COMPLETION TIME M. As required by Required -----------------NOTE------------------
Action C.1 and Not required during short, referenced in Table controlled outages of gaseous 16.11.3-2 for effluent effluent monitoring from ventilation system instrumentation. Short controlled or condenser air outages are defined as planned ejectors. (RIA-40) removals from service for durations not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, for purposes of sample filter changeouts, setpoint adjustments, service checks, and/or routine maintenance procedures. This guidance may be applied successively, provided that time between successive short, controlled outages is always at least equal to duration of immediately preceding outage.
M.1 Continuously monitor Immediately release through the unit vent.
OR M.2 Suspend release of Immediately radioactive effluents by this pathway.
OR M.3.1 Collect grab sample. Immediately AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AND M.3.2 Analyze grab sample for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from collection gross activity (beta of grab sample and/or gamma).
16.11.3-10 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 16.11.3.1 ------------------------NOTE----------------------------
The Channel Response check shall consist of verifying indications during periods of release.
Channel response checks shall be made at least once per calendar day on days in which continuous, periodic or batch releases are made.
Perform Channel Response Check. During each release via this pathway SR 16.11.3.2 ------------------------NOTE----------------------------
The Channel Response check shall consist of verifying indications during periods of release.
Channel response checks shall be made at least once per calendar day on days in which continuous, periodic or batch releases are made.
Perform Channel Response Check. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR 16.11.3.3 Perform Source Check. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR 16.11.3.4 Perform Source Check. 31 days SR 16.11.3.5 Perform Source Check. 92 days 16.11.3-11 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 SURVEILLANCE FREQUENCY SR 16.11.3.6 -----------------------NOTE----------------------------
The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway and control room annunciation occurs if any of the following conditions exist:
- 1. Instrument indicates measured levels above the alarm/trip setpoint.
- 2. Circuit failure (downscale only).
Perform CHANNEL FUNCTIONAL TEST. 92 days SR 16.11.3.7 ------------------------NOTE----------------------------
The CHANNEL FUNCTIONAL TEST shall also demonstrate that control room annunciation occurs if any of the following conditions exist:
- 1. Instrument indicates measured levels above the alarm/trip setpoint.
- 2. Circuit failure (downscale only).
92 days Perform CHANNEL FUNCTIONAL TEST.
SR 16.11.3.8 Perform CHANNEL FUNCTIONAL TEST. 92 days 16.11.3-12 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 SURVEILLANCE FREQUENCY SR 16.11.3.9 -------------------------NOTE---------------------------
The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate in measurement assurance activities with the National Institute of Standards and Technology (NIST). The standards shall permit calibrating the system over its intended range of energy and measurement. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used. (Operating plants may substitute previously established calibration procedures for these requirements.)
12 months Perform CHANNEL CALIBRATION.
SR 16.11.3.10 Perform CHANNEL CALIBRATION. 12 months SR 16.11.3.11 Perform leak test. When cylinder gates or wicket gates are reworked SR 16.11.3.12 Perform Source Check. Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to each release via associated pathway 16.11.3-13 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 Table 16.11.3-1 LIQUID EFFLUENT MONITORING INSTRUMENTATION OPERATING CONDITIONS AND SURVEILLANCE REQUIREMENTS CONDITION REFERENCED MINIMUM FROM OPERABLE SURVEILLANCE REQUIRED INSTRUMENT CHANNELS APPLICABILITY REQUIREMENTS ACTION B.1
- 1. Monitors Providing Automatic Termination of Release
- a. Liquid Radwaste Effluent 1 At all times SR 16.11.3.1 E Line Monitor, RIA-33 SR 16.11.3.3 SR 16.11.3.6 SR 16.11.3.9
- b. Turbine Building Sump, 1 At all times SR 16.11.3.2 F RIA-54 SR 16.11.3.4 SR 16.11.3.7 SR 16.11.3.9
- 2. Monitors not Providing Automatic Termination of Release Low Pressure Service Water 1 At all times SR 16.11.3.2 H RIA-35 SR 16.11.3.4 SR 16.11.3.7 SR 16.11.3.9
- 3. Flow Rate Measuring Devices
- a. Liquid Radwaste Effluent 1 At all times SR 16.11.3.1 G Line Flow Rate Monitor SR 16.11.3.10 (0LW CR0725 or 0LW SS0920)
- b. Liquid Radwaste Effluent NA NA SR 16.11.3.1 NA Line Minimum Flow SR 16.11.3.10 Device
- c. Turbine Building Sump NA NA SR 16.11.3.1 NA Minimum Flow Device SR 16.11.3.10
- d. Low Pressure Service NA NA SR 16.11.3.1 NA Water Minimum Flow SR 16.11.3.10 Device 16.11.3-14 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 Table 16.11.3-1 LIQUID EFFLUENT MONITORING INSTRUMENTATION OPERATING CONDITIONS AND SURVEILLANCE REQUIREMENTS CONDITION REFERENCED MINIMUM FROM OPERABLE SURVEILLANCE REQUIRED INSTRUMENT CHANNELS APPLICABILITY REQUIREMENTS ACTION B.1
- e. Keowee Hydroelectric NA NA SR 16.11.3.11 NA Tailrace Discharge (a)
- 4. Continuous Composite Sampler
- 3 Chemical Treatment 1 At all times SR 16.11.3.2 H Pond Composite Sampler SR 16.11.3.10 and Sampler Flow Monitor (Turbine Building Sumps Effluent)
(a) Flow is determined from the number of hydro units operating. If no hydro units are operating, leakage flow will be assumed to be 38 cfs based on historical data.
16.11.3-15 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 Table 16.11.3-2 GASEOUS EFFLUENT MONITORING INSTRUMENTATION OPERATING CONDITIONS AND SURVEILLANCE REQUIREMENTS MINIMUM CONDITION OPERABLE REFERENCED CHANNELS FROM (PER RELEASE SURVEILLANCE REQUIRED INSTRUMENT PATH) APPLICABILITY REQUIREMENTS ACTION C.1
- 1. Unit Vent Monitoring System
- a. Noble Gas Activity 1 At All Times SR 16.11.3.2 I Monitor Providing Alarm SR 16.11.3.4 and Automatic SR 16.11.3.7 Termination of SR 16.11.3.9 Containment Purge Release (RIA Purge Isolation Function)
- b. Noble Gas Activity 1 At all times SR 16.11.3.2 K Monitor Providing Alarm. SR 16.11.3.4 (RIA Vent Stack SR 16.11.3.7 Monitor Function) SR 16.11.3.9
- c. Iodine Sampler 1 At All Times SR 16.11.3.2 L
- d. Particulate Sampler 1 At All Times SR 16.11.3.2 L
- e. Effluent Flow Rate 1 At All Times SR 16.11.3.2 J Monitor (Unit Vent Flow) SR 16.11.3.10 (MSC CR0001)
- f. Sampler Flow Rate 1 At All Times SR 16.11.3.2 NA Monitor (a) (Annunciator) SR 16.11.3.10
- g. Effluent Flow Rate 1 During Containment SR 16.11.3.2 J Monitor (Containment Purge Operation SR 16.11.3.10 Purge)(MSC CR0001)
- h. CSAE Off Gas Monitor 1 During Operation SR 16.11.3.2 M (RIA-40) of CSAE SR 16.11.3.5 SR 16.11.3.8 SR 16.11.3.9
- 2. Interim Radwaste Building Ventilation Monitoring System
- a. Noble Gas Activity 1 At All Times SR 16.11.3.2 K Monitor (RIA - 53) SR 16.11.3.4 SR 16.11.3.7 SR 16.11.3.9
- b. Iodine Sampler 1 At All Times SR 16.11.3.2 L
- c. Particulate Sampler 1 At All Times SR 16.11.3.2 L
- d. Effluent Flow Rate 1 At All Times SR 16.11.3.2 J Monitor (Interim SR 16.11.3.10 Radwaste Exhaust)
(GWD FT0082)
- e. Sampler Flow Rate 1 At All Times SR 16.11.3.2 NA Monitor(a) (Annunciator)
SR 16.11.3.10 16.11.3-16 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 Table 16.11.3-2 GASEOUS EFFLUENT MONITORING INSTRUMENTATION OPERATING CONDITIONS AND SURVEILLANCE REQUIREMENTS MINIMUM CONDITION OPERABLE REFERENCED CHANNELS FROM (PER RELEASE SURVEILLANCE REQUIRED INSTRUMENT PATH) APPLICABILITY REQUIREMENTS ACTION C.1
- 3. Hot Machine Shop Ventilation Sampling System
- a. Iodine Sampler 1 At All Times SR 16.11.3.2 L
- b. Particulate Sampler 1 At All Times SR 16.11.3.2 L
- c. Effluent Flow Rate 1 At All Times SR 16.11.3.2 J Monitor (Hot Machine SR 16.11.3.10 Shop Exhaust)
(Totalizer)
- d. Sampler Flow Rate 1 At All Times SR 16.11.3.2 NA Monitor (a) (Annunciator) SR 16.11.3.10
- 4. Radwaste Facility Ventilation Monitoring System
- a. Noble Gas Activity 1 At All Times SR 16.11.3.2 K Monitor (4-RIA-45) SR 16.11.3.4 SR 16.11.3.7 SR 16.11.3.9
- b. Iodine Sampler 1 At All Times SR 16.11.3.2 L
- c. Particulate Sampler 1 At All Times SR 16.11.3.2 L
- d. Effluent Flow Rate 1 At All Times SR 16.11.3.2 J Monitor (Radwaste SR 16.11.3.10 Facility Exhaust) (0VS CR2060)
- e. Sampler Flow Rate 1 At All Times SR 16.11.3.2 NA Monitor (a) (Annunciator) SR 16.11.3.10
- 5. Waste Gas Holdup Tanks
- a. Noble Gas Activity 1 During Waste Gas SR 16.11.3.1 I Monitor - Providing Holdup Tank Releases SR 16.11.3.6 Alarm and Automatic SR 16.11.3.9 Termination of Release SR 16.11.3.12 (RIA-37,-38)b
- b. Effluent Flow Rate 1 During Waste Gas SR 16.11.3.1 J Monitor (Waste Gas Holdup Tank Releases SR 16.11.3.10 Discharge Flow) (MSC CR0001)
(a)Alarms indicating low flow may be substituted for flow measuring devices.
(b)Either Normal or High Range monitor is required dependent upon activity in tank being released.
16.11.3-17 11/20/08
Radioactive Effluent Monitoring Instrumentation 16.11.3 BASES The radioactive liquid effluent instrumentation is provided to monitor and control, as applicable, the releases of radioactive materials in liquid effluents during actual or potential releases. The alarm/trip setpoints for these instruments shall be calculated in accordance with NRC approved methods in the ODCM to assure that the alarm/trip will occur prior to exceeding 10 times the limits of 10 CFR Part 20. The operability and use of this instrumentation is consistent with the requirements of General Design Criteria 60, 63, and 64 of Appendix A to 10 CFR Part 50.
The radioactive gaseous effluent instrumentation is provided to monitor and control, as applicable, the releases of radioactive materials in gaseous effluents during actual or potential releases. The alarm/trip setpoints for these instruments shall be calculated in accordance with NRC approved methods in the ODCM to assure that the alarm/trip will occur prior to exceeding applicable dose limits in SLC 16.11.2. The operability end use of this instrumentation is consistent with the requirements of General Design Criteria 60, 63, and 64 of Appendix A to 10 CFR Part 50.
For certain applicable cases, grab samples or flow estimates are required at frequencies between every 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> end every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> upon RIA removal from service. SLC 16.11.3 does not explicitly require Action (grab samples or flow estimates) to be initiated immediately upon RIA removal from service, when removal is for the purposes of sample filter changeouts, setpoint adjustments, service checks, or routine maintenance. Therefore, during the defined short, controlled outages, Action is not required.
For the cases in which Action is defined as continuous sampling by auxiliary equipment (Action L) initiation of continuous sampling by auxiliary sampling equipment requires approximately 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. One hour is the accepted reasonable time to initiate collect and change samples.
Therefore. for the defined short, controlled outages (not to exceed 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />), Action is not required.
Failures such as blown instrument fuses, defective indicators, and faulted amplifiers are, in many cases, revealed by alarm or annunciator action. Comparison of output and/or state of independent channels measuring the same variable supplements this type of built-in surveillance. Based on experience in operation of both conventional and nuclear systems, when the unit is in operation, the minimum checking frequency stated is deemed adequate.
REFERENCES:
- 1. 10 CFR Part 20.
- 4. UFSAR, Section 7.2.3.4.
16.11.3-18 11/20/08
PAM Instrumentation 3.3.8 3.3 INSTRUMENTATION 3.3.8 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.8 The PAM instrumentation for each Function in Table 3.3.8-1 shall be OPERABLE.
APPLICABILITY: MODES 1, 2, and 3.
ACTIONS
NOTES---------------------------------------------------
- 1. LCO 3.0.4 is not applicable.
- 2. Separate Condition entry is allowed for each Function.
CONDITION REQUIRED ACTION COMPLETION TIME A. -----------NOTE----------- A.1 Restore required 30 days Not applicable to channel to OPERABLE Functions 14, 18, 19, status.
and 22.
One or more Functions with one required channel inoperable.
B. Required Action and B.1 Initiate action in Immediately associated Completion accordance with Time of Condition A not Specification 5.6.6.
met.
(continued)
OCONEE UNITS 1, 2, & 3 3.3.8-1 Amendment Nos. 350, 352, & 351
PAM Instrumentation 3.3.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. -----------NOTE----------- C.1 Restore one channel to 7 days Not applicable to OPERABLE status.
Functions 14, 18, 19, and 22.
One or more Functions with two required channels inoperable.
D. Not Used D.1 Not Used Not Used E. -----------NOTE----------- E.1 Restore required 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Only applicable to channel to OPERABLE Function 14. status.
One required channel inoperable.
(continued)
OCONEE UNITS 1, 2, & 3 3.3.8-2 Amendment Nos. 350, 352, & 351
PAM Instrumentation 3.3.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME F. -----------NOTE----------- F.1 Declare the affected Immediately Only applicable to train inoperable.
Functions 18, 19, and 22.
One or more Functions with required channel inoperable.
G. Required Action and G.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C or Table 3.3.8-1 for the E not met. channel.
H. As required by H.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Required Action G.1 and referenced in AND Table 3.3.8-1.
H.2 Be in MODE 4. 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> I. As required by I.1 Initiate action in Immediately Required Action G.1 accordance with and referenced in Specification 5.6.6.
Table 3.3.8-1.
OCONEE UNITS 1, 2, & 3 3.3.8-3 Amendment Nos. 350, 352, & 351
PAM Instrumentation 3.3.8 SURVEILLANCE REQUIREMENTS
NOTE---------------------------------------------------------
These SRs apply to each PAM instrumentation Function in Table 3.3.8-1 except where indicated.
SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK for each required In accordance with the instrumentation channel that is normally Surveillance Frequency energized. Control Program SR 3.3.8.2 --------------------------NOTE-------------------------
Only applicable to PAM Functions 7 and 22.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program SR 3.3.8.3 -------------------------NOTES------------------------
- 1. Neutron detectors are excluded from CHANNEL CALIBRATION.
- 2. Not applicable to PAM Functions 7 and 22.
Perform CHANNEL CALIBRATION. In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.8-4 Amendment Nos. 372, 374, 373
PAM Instrumentation 3.3.8 Table 3.3.8-1 (page 1 of 1)
Post Accident Monitoring Instrumentation CONDITIONS REFERENCED FROM FUNCTION REQUIRED CHANNELS REQUIRED ACTION G.1
- 1. Wide Range Neutron Flux 2 H
- 2. RCS Hot Leg Temperature 2 H
- 3. RCS Hot Leg Level 2 I
- 4. RCS Pressure (Wide Range) 2 H
- 5. Reactor Vessel Head Level 2 I
- 6. Containment Sump Water Level (Wide Range) 2 H
- 7. Containment Pressure (Wide Range) 2 H
- 8. Containment Isolation Valve Position 2 per penetration flow path(a)(b)(c) H
- 9. Containment Area Radiation (High Range) 2 I
- 10. Not Used
- 11. Pressurizer Level 2 H
- 12. Steam Generator Water Level 2 per SG H
- 13. Steam Generator Pressure 2 per SG H
- 14. Borated Water Storage Tank Water Level 2 H
- 15. Upper Surge Tank Level 2 H (d)
- 16. Core Exit Temperature 2 independent sets of 5 H
- 17. Subcooling Monitor 2 H
- 18. HPI System Flow 1 per train NA
- 19. LPI System Flow 1 per train NA
- 20. Not used
- 22. Low Pressure Service Water Flow to LPI Coolers 1 per train NA (a) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.
(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.
(c) Position indication requirements apply only to containment isolation valves that are electrically controlled.
(d) The subcooling margin monitor takes the average of the five highest CETs for each of the ICCM trains.
OCONEE UNITS 1, 2, & 3 3.3.8-5 Amendment Nos. 350, 352, & 351
Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS
NOTES------------------------------------------------------
- 1. Penetration flow paths except for 48 inch purge valve penetration flow paths may be unisolated intermittently under administrative controls.
- 2. Separate Condition entry is allowed for each penetration flow path.
- 3. Enter applicable Conditions and Required Actions for system(s) made inoperable by containment isolation valves.
CONDITION REQUIRED ACTION COMPLETION TIME A. -----------NOTE------------ A.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Only applicable to penetration flow path penetration flow paths by use of at least one with two containment closed and isolation valves. de-activated automatic
valve, one closed and de-activated One or more non-automatic power penetration flow paths operated valve, closed with one containment manual valve, blind isolation valve flange, or check valve inoperable. with flow through the valve secured.
AND (continued)
OCONEE UNITS 1, 2, & 3 3.6.3-1 Amendment Nos. 300, 300, & 300
Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 -----------NOTE-----------
Isolation devices in high radiation areas may be verified by use of administrative means.
Once per 31 days for Verify the affected isolation devices outside penetration flow path is containment isolated.
AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. ----------NOTE------------ B.1 Isolate the affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Only applicable to penetration flow path penetration flow paths by use of at least one with two containment closed and isolation valves. de-activated automatic
valve, one closed and de-activated One or more non-automatic power penetration flow paths operated valve, closed with two containment manual valve, or blind isolation valves flange.
(continued)
OCONEE UNITS 1, 2, & 3 3.6.3-2 Amendment Nos. 300, 300, & 300
Containment Isolation Valves 3.6.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. -----------NOTE----------- C.1 Isolate the affected 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> Only applicable to penetration flow path penetration flow paths by use of at least one with only one closed and containment isolation de-activated automatic valve and a closed valve, one closed and system. de-activated
non-automatic power operated valve, closed One or more manual valve, or blind penetration flow paths flange.
with one containment isolation valve AND inoperable.
C.2 ----------NOTE------------
Isolation devices in high radiation areas may be verified by use of administrative means.
Verify the affected Once per 31 days penetration flow path is isolated.
D. Required Action and D.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OCONEE UNITS 1, 2, & 3 3.6.3-3 Amendment Nos. 300, 300, & 300
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 48 inch purge valve is sealed In accordance with the closed. Surveillance Frequency Control Program SR 3.6.3.2 -------------------------NOTE--------------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.
Verify each containment isolation manual and In accordance with the non-automatic power operated valve and blind Surveillance Frequency flange that is located outside containment and Control Program not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.
SR 3.6.3.3 --------------------------NOTE--------------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.
Verify each containment isolation manual and Prior to entering MODE 4 non-automatic power operated valve and blind from MODE 5 if not flange that is located inside containment and performed within the not locked, sealed, or otherwise secured and previous 92 days required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.
(continued)
OCONEE UNITS 1, 2, & 3 3.6.3-4 Amendment Nos. 372, 374, 373
Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.3.4 Verify the isolation time of each automatic In accordance with the power operated containment isolation valve is Inservice Testing within limits. Program SR 3.6.3.5 Verify each automatic containment isolation In accordance with the valve that is not locked, sealed, or otherwise Surveillance Frequency secured in position, actuates to the isolation Control Program position on an actual or simulated actuation signal.
OCONEE UNITS 1, 2, & 3 3.6.3-5 Amendment Nos. 372, 374, 373
Distribution Systems - Operating 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems - Operating LCO 3.8.8 AC, DC, and AC vital electrical power distribution systems shall be OPERABLE as follows:
- a. Two main feeder buses each connected to two or more ES power strings;
- b. Three ES power strings;
- d. For Units 2 or 3, 125 VDC Vital I&C power panelboards 1DIC and 1DID;
- e. 230 kV switchyard 125 VDC power panelboards DYA, DYB, DYC, DYE, DYF, and DYG; and
- f. 120 VAC Vital Instrumentation power panelboards KVIA, KVIB, KVIC, and KVID.
APPLICABILITY: MODES 1, 2, 3, and 4.
ACTIONS
NOTE---------------------------------------------------
The Completion Times for Required Actions A through F are reduced when in Condition L of LCO 3.8.1.
CONDITION REQUIRED ACTION COMPLETION TIME A. One main feeder bus A.1 Restore main feeder 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable or not bus to OPERABLE connected to two ES status and connect to power strings. at least two ES power strings.
(continued)
OCONEE UNITS 1, 2, & 3 3.8.8-1 Amendment Nos. 300, 300, & 300
Distribution Systems - Operating 3.8.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B. One ES power string B.1 Restore ES power 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable. string to OPERABLE status.
C. One of the unit's 125 C.1 Restore panelboard to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> VDC Vital I&C power OPERABLE status.
panelboard inoperable.
D. ----------NOTES---------- D.1 Restore required 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />
- 1. Separate panelboards to Condition entry is OPERABLE status.
allowed for each 230 kV switchyard 125 VDC power panelboard.
- 2. Not applicable to the following loss of function combinations:
DYA and DYE, DYB and DYF, and DYC and DYG.
One or more required 230 kV switchyard 125 VDC power panelboards inoperable.
(continued)
OCONEE UNITS 1, 2, & 3 3.8.8-2 Amendment Nos. 300, 300, & 300
Distribution Systems - Operating 3.8.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E. -----------NOTE------------ E.1 Restore panelboard to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Only applicable to OPERABLE status.
Units 2 and 3.
One required 125 VDC Unit 1 Vital I&C power panelboard inoperable.
F. One 120 VAC Vital F.1 Restore panelboard to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> when Condition Instrumentation power OPERABLE status. due to KVIA or KVIB panelboard inoperable. being inoperable AND 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> when Condition due to KVIC or KVID being inoperable G. Required Action and G.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND G.2 Be in MODE 5. 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> H. Entry into two or more H.1 Enter LCO 3.0.3 Immediately Conditions that result in a loss of function.
OCONEE UNITS 1, 2, & 3 3.8.8-3 Amendment Nos. 300, 300, & 300
Distribution Systems - Operating 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 3.8.8.1 Verify correct breaker alignments and voltage In accordance with the to required main feeder buses. Surveillance Frequency Control Program 3.8.8.2 Verify correct breaker alignments and voltage In accordance with the availability to required ES power strings, 125 Surveillance Frequency VDC Vital I&C power panelboards, 230 kV Control Program Switchyard 125 VDC power panelboards and 120 VAC Vital Instrumentation power panelboards.
OCONEE UNITS 1, 2, & 3 3.8.8-4 Amendment Nos. 372, 374, 373