Notes and Cautions

Question 1

In AOP-01.06 Excessive RCS Activity, what actions are required if RCS specific activity is NOT less than 51.9 Ci/gram DEQ XE-133 or  0.1 Ci/gram DEQ I-131?

Answer 1

6.1 POSITION V6307, FLASH TANK DIVERT VALVE to FLASH TANK. (RTGB-105)
6.2 NOTIFY Chemistry to provide isotopic samples at the following locations:
 V6120, V6307 DWNSTRM LOCAL SAMPLE ISOL
 V6136, LOCAL SAMPLE OF 1A FLASH TANK PUMP DISCH ISOL
6.3 RAISE letdown flow to maximum per 1-NOP-02.02, Charging and Letdown.

Question 2

Discuss the AOP-01.06 Excessive RCS Activity NOTE concerning Iodine Increase.

Answer 2

NOTE
 Iodine increase that remains significantly above prior levels during steady state operation is indicative of fuel failure.
 Iodine increase concurrent with a Gross Activity increase during a plant load change is indicative of a crud burst.

Question 3

Discuss the AOP-01.09 A1/A2/B1/B2 Reactor Coolant Pumps NOTE concerning Seal Degradation?

Answer 3

NOTE
Seal degradation is occurring when CBO temperature or Lower Seal Cavity temperature exceeds 250F.

Question 4

Discuss the AOP-01.09 A1/A2/B1/B2 Reactor Coolant Pumps NOTE concerning Securing RCPs.

Answer 4

NOTE
If required to secure all four RCPs post trip with the SBCS in service, then the RCPs should be secured after conducting the full one minute board scan for assessing plant status. In all cases, RCPs shall be secured within any specified time requirements (e.g. within 10 minutes of a loss of CCW).

Question 5

Discuss the AOP-01.09 A1/A2/B1/B2 Reactor Coolant Pumps NOTE concerning Valve HCV-14-11A1, SEAL COOLER HX ISOL VALVE.

Answer 5

NOTE
 Valve HCV-14-11A1, SEAL COOLER HX ISOL VALVE, closes on high
seal cooler outlet temperature (200°F) and fails open on loss of instrument air or loss of power.
 Maintaining HCV-14-11A1 control switch in OPEN overrides the automatic closure function on seal cooler outlet high temperature.
 If a high temperature condition exists upon release of the control switch, there is a 1 minute time delay before closure of valve.
 CCW radiation monitors should be closely monitored for indication of RCS to CCW leakage when the control switch is maintained in OPEN.
 Consideration should be given to returning the control switch to the AUTO position once the valves have been opened.

Question 6

Discuss the AOP-01.09 A1/A2/B1/B2 Reactor Coolant Pumps CAUTION concerning Loss of CCW.

Answer 6

CAUTION
 Loss of component cooling water flow to the RCP coolers can result in thermal stress and flashing in the heat exchanger upon re-admittance of cooling water flow.
 If isolation of CCW to the RCP motor is required due to a leak, then CCW flow to RCP pump seal coolers should be maintained to prevent
overheating RCP seals. This will require local manual isolation.

Question 7

Discuss the AOP-01.10 Pressurizer Pressure And Level NOTE concerning Spray Line Temperature Divergence.

Answer 7

NOTE
Divergence of spray line temperatures between 1B1 and 1B2 spray lines may indicate a stuck open spray valve. The stuck open spray valve would have the spray line with the higher temperature approaching cold leg temperature.

Question 8

In AOP-01.10 Pressurizer Pressure And Level, what actions are required if:
 Pressurizer pressure is less than 2275 psia
 Pressurizer pressure is lowering uncontrollably

Answer 8

1.1 IF PCV-1100E, SPRAY VALVE 1B2, is OPEN, THEN PLACE Pressurizer spray valve selector switch in 1100F.
1.2 IF PCV-1100F, SPRAY VALVE 1B1, is OPEN, THEN PLACE Pressurizer spray valve selector switch in 1100E.
1.3 IF spray valve is still failed OPEN AND Pressurizer pressure approaches TM/LP setpoints, THEN PERFORM the following:
A. TRIP reactor.
B. IMPLEMENT 1-EOP-01, Standard Post Trip Actions.
C. IF PCV-1100E, SPRAY VALVE 1B2, is NOT CLOSED, THEN STOP 1B2 RCP.
D. IF PCV-1100F, SPRAY VALVE 1B1, is NOT CLOSED, THEN STOP 1B1 RCP.
E. IF Pressurizer pressure continues to lower, THEN ENSURE both RCPs are stopped:
 1B1 RCP
 1B2 RCP

Question 9

In AOP-01.10 Pressurizer Pressure And Level, what actions are required if Auxiliary Spray Valves are NOT Closed.

Answer 9

2.1 ENSURE auxiliary spray valves CLOSED using control switch:
 SE-02-03, PRESSURIZER AUXILIARY SPRAY (Key 58)
 SE-02-04, PRESSURIZER AUXILIARY SPRAY (Key 59)
2.2 IF auxiliary spray valve(s) still NOT CLOSED, THEN PERFORM the following:
A. CLOSE letdown isolation valves:
 V2515, LETDOWN STOP VALVE
 V2516, LETDOWN CNTMT ISOLATION VALVE
B. STOP all charging pumps and PLACE in AUTO.
C. IMPLEMENT 1-AOP-02.03, Charging and Letdown.
2.3 WHEN plant is stable, THEN EVALUATE documenting auxiliary spray operation per ADM-17.43, Component Cycles and Transients.

Question 10

Discuss restoring Unit 1 Pressurizer heaters.

Answer 10

The following provides general information for restoring Pressurizer heaters:
A. A Safety Injection Actuation Signal (SIAS) will lockout the Pressurizer heaters 4160 VAC breakers. If SIAS has actuated, SIAS must be RESET before
Pressurizer Heaters can be energized.
B. Undervoltage (LOOP) will load shed the 4160V breakers and open all 480 V heater contactors. They may be reclosed after verifying adequate EDG load capacity.
C. Either selected or non-selected Pressurizer level control channel level transmitter failing low, or actual Pressurizer low level, will open all 480 V heater contactors.
D. The Low Level Cutout switch allows a level control channel that has failed low to be disconnected from the low-low level heater cutoff circuit and the 480V heater power supply contactors controlled by the selected channel to be reset.

Question 11

Discuss restoring Unit 2 Pressurizer heaters.

Answer 11

The following provides general information for restoring Pressurizer heaters:
A. A Safety Injection Actuation Signal (SIAS) will lockout the Pressurizer heaters 4160 VAC breakers. If SIAS has actuated, SIAS must be RESET before Pressurizer Heaters can be energized.
B. Undervoltage (LOOP) interlock will load shed the 4160 V breakers and open all 480 V heater contactors. They may be reclosed after verifying adequate EDG load capacity.
C. With less than 27% Pressurizer level on Channel X:
 “A” side breaker 2-20204, PRZR HEATER TRANSFORMER 2A3, trips, de-energizing P1, B1, B2, B3.
 “B” side 480V heater power supply contactors open, de-energizing P2, B4, B5, B6.
D. With less than 27% Pressurizer level on Channel Y:
 “B” side breaker 2-20403, PRZR HEATER TRANSFORMER 2B3, trips, de-energizing P2, B4, B5, B6.
 “A” side 480V heater power supply contactors open, de-energizing P1, B1, B2, B3.
E. LT-1110X(Y), PRZR LEVEL, failing low opens 4160V breaker on the respective side and 480V power supply contactors on the other side. The Backup Interlock Bypass Key Switch, selected to the LEVEL position, allows the 480V heater power supply contactors on the other side to be reset, but does not bypass the interlock for the 4160V breaker on the respective side.

Question 12

Discuss AOP-01.12 REACTOR COOLANT GAS VENT SYSTEM NOTEs and CAUTIONs.

Answer 12

CAUTION
Any operating Reactor Coolant Pumps are to remain running and any non-operating Reactor Coolant Pumps are to remain stopped during venting operations to ensure steady state conditions.

NOTE
Operation of all available Containment air circulation equipment will prevent formation of a hydrogen gas pocket and ensure a representative hydrogen concentration is obtained during sampling.

Question 13

Per AOP-01.13 NATURAL CIRCULATION COOLDOWN, how long does it take to develop natural circulation?

Answer 13

NOTE
It takes approximately 15 minutes for natural circulation to fully develop.

Question 14

Per AOP-01.13 NATURAL CIRCULATION COOLDOWN, how is RCS voiding minimized?

Answer 14

NOTE
Maintaining RCS pressure in upper band of the Acceptable Region of Attachment 2, Normal Pressure Temperature Curve, will help minimize RCS voiding.

Question 15

Per AOP-01.13 NATURAL CIRCULATION COOLDOWN, why are volume changes undesirable if the RCS is water solid?

Answer 15

CAUTION
If the RCS is water solid, any volume changes such as makeup, draining, heatup, or cooldown could cause undesirably rapid pressure excursions.

Question 16

In AOP-01.13 NATURAL CIRCULATION COOLDOWN, what actions are required if RCS parameters are NOT within the limits of Attachment 2, Normal Pressure Temperature Curve?

Answer 16

11.1 IF cooldown rate is greater than:
 50°F/hr
 30F/hr for isolated S/G
THEN RESTORE cooldown rate to within these limits.

11.2 IF RCS subcooling is less than 20°F, THEN REDUCE RCS temperature while holding pressure constant until subcooling is restored.

11.3 IF additional Pressurizer auxiliary spray is required AND MV-02-1, Regen HX Bypass is CLOSED, THEN OPERATE SE-02-4, Pressurizer Auxiliary Spray as needed. (Key 59).

11.4 IF any of the following conditions exist:
 Pressure is lowering uncontrollably
 Pressure is less than the lower limit of Attachment 2, Normal Pressure Temperature Curve THEN PERFORM the following to restore and maintain RCS pressure:
A. START additional charging pumps.
B. ESTABLISH solid pressurizer operating conditions.
C. CONTROL charging and letdown to restore RCS pressure.

11.5 IF subcooling is greater than 200°F, THEN REDUCE pressure while holding RCS temperature constant.

11.6 WHEN RCS parameters have been restored within limits, THEN RESUME RCS cooldown and depressurization.

Question 17

Per AOP-01.13 NATURAL CIRCULATION COOLDOWN, what are indications of voiding?

Answer 17

NOTE
Indications of voiding include any of the following:
 RVLMS level less than 100% on QSPDS REACTOR VESSEL LEVEL screen.
 Pressurizer level rising when reducing RCS pressure or makeup.
 Pressurizer level dropping when raising RCS pressure or makeup.
 CETs indicating superheated conditions.

Question 18

Per AOP-01.13 NATURAL CIRCULATION COOLDOWN, how is void elimination verified?

Answer 18

NOTE
Void elimination is verified if pressurizer pressure is stable or rising AND pressurizer level rises when charging to the RCS.

Question 19

Per AOP-02.01 Boron Concentration Control, how is Boric Acid flow rate determined when using the Emergency Borate Valve?

Answer 19

CAUTION
Prolonged use of V2514, EMERGENCY BORATE, can lead to uncontrolled power reduction rates. Boric acid flow rate is equal to the charging pump flow rate when using the emergency borate valve.

Question 20

Per AOP-02.01 Boron Concentration Control, how is VCT makeup achieved during an UFSAR-hypothesized event in which a tornado damages both the Primary Water Tank and the Refueling Water Tank and
forces a plant shutdown and cooldown with limited VCT makeup.

Answer 20

H. IF all of the following conditions exist:
 RCS pressure is less than 1750 psia
 Plant shutdown OR cooldown is in progress
 VCT is available AND required to support plant
cooldown  BAM tank inventory has been exhausted
 PWT is unavailable
 RWT is unavailable
THEN PERFORM Attachment 1, VCT Makeup from the SITs.

Question 21

Discuss the AOP-02.02 EMERGENCY BORATION NOTE concerning Boric Acid Gravity Feed valves.

Answer 21

NOTE
Both Boric Acid Gravity Feed valves are required to be placed in service when the combined Boric Acid Makeup Tank volumes are being credited as a borated water source. Otherwise, the Gravity Feed valve associated with the Boric Acid Makeup Tank being credited as the borated water source should be opened.

Question 22

Discuss Indications requiring entry into AOP-02.02 EMERGENCY BORATION.

Answer 22

Any of the following conditions exist:
Unanticipated or uncontrolled RCS cooldown in MODES 1 & 2, following a reactor trip, or in MODES 3 & 4 as indicated by:
 Uncontrolled lowering in RCS temperature.
 Uncontrolled lowering in pressurizer pressure or level.
 Uncontrolled lowering in secondary steam pressure.
 Unexplained or uncontrolled reactivity rise as indicated by:
 Abnormal rise in RCS temperature or Reactor power.
 Abnormal rise in Reactor power or count rate when shut down.
Loss of shutdown margin due to excessive CEA insertion as indicated by:
 Power dependent insertion alarm (Ovation).
 Power dependent insertion alarm (RSPT).
 One or more CEA(s) NOT fully inserted following a Reactor Trip as indicated by:
 The CEA Core Mimic Lower Electrical Limit lights (green) indicate One or more CEA(s) NOT fully inserted.
 The CEA Core Mimic Dropped Rod lights (amber) indicate One or more CEA(s) NOT fully inserted.
 RSPT indicates One or more CEA(s) NOT fully inserted.
 One or more full length CEA(s) inoperable due to being immovable as a result of excessive friction or mechanical interference or known to be untrippable in MODE 1 or 2.
 Boration to ensure required shutdown margin is maintained as directed by the Unit Supervisor

Question 22

Discuss Emergency Boration flowpaths

Answer 22

1 CP running Manual 2525 closed.
EB w/ 2514:. 1 B.A pp recirc respective closed. Open V2514 EB vlv. (All A train)
EB w/out 2514: Stop B.A pp. Open BA gravity valve Close 2501 VCT outlet vlv (close off A train only B)
EB w/out BAMT or Gravity feed vlv. : Open V2504 RWT to CP. Close everything else. 2501, gravity feed and 2514

Question 23

Per AOP-02.03 CHARGING AND LETDOWN, why is it important to isolate letdown if charging is lost?

Answer 23

CAUTION
Severe thermal stress and flashing may occur in the Regenerative Heat Exchanger if letdown flow is NOT immediately isolated.

Question 24

Per AOP-02.03 CHARGING AND LETDOWN, what happens to pressurizer level with charging and letdown isolated?

Answer 24

NOTE
With Charging and Letdown isolated, pressurizer level will lower slowly due to RCP controlled bleedoff flow.

Question 25

Per AOP-02.03 CHARGING AND LETDOWN, what is required for letdown operation?

Answer 25

NOTE
All of the following are required for letdown operation:
* Instrument Air
* Non-essential sections of MCCS 1A6 and 1B6
* SIAS and CIAS reset

Question 26

Discuss the AOP-02.03 CHARGING AND LETDOWN NOTE concerning charging pump gas binding.

Answer 26

NOTE
If one or more charging pumps have lost pumping ability, gas binding may have occurred. This can result from pumping the VCT dry (hydrogen binding or nitrogen binding if shutdown) or rupture of a charging pump suction accumulator (nitrogen binding). If this occurred, the charging pumps must be vented after restoring a source of water to the suction.

Question 27

Discuss the AOP-02.03 CHARGING AND LETDOWN NOTE concerning TCV-2223.

Answer 27

NOTE
* TIC-2223, LTDN TEMPERATURE, is a reverse acting controller . Raising output will close TCV-2223, LETDOWN HX DISCH, and increase letdown temperature.
* TCV-2223 has a mechanical stop that limits the valve opening. The stop is set at approximately 46 degrees open to limit CCW flow to 1200 to 1400 GPM. Excessive CCW flow can cause damage to the letdown heat exchanger.

Question 28

Discuss the AOP-02.03 CHARGING AND LETDOWN CAUTION concerning CCW flow.

Answer 28

CAUTION
* Loss of component cooling water flow through the letdown heat exchanger can result in severe thermal stress and flashing in the heat exchanger unless letdown flow is immediately isolated.
* Component cooling water flow to the letdown heat exchanger shall be reestablished slowly with letdown flow still isolated to minimize the thermal stress on the heat exchanger.

Question 29

Per AOP-02.03 CHARGING AND LETDOWN, is letdown available while charging through Auxiliary HPSI header?

Answer 29

NOTE
Letdown will NOT be available while charging through Auxiliary HPSI header due to loss of cooling flow through the regenerative heat exchanger.

Question 30

Discuss the AOP-02.03 CHARGING AND LETDOWN CAUTION concerning use of Alternate Charging Flow Path to RCS Through Auxiliary HPSI Header.

Answer 30

CAUTION
* Use of this flow path has the potential for lifting V3417, 1A/1C HPSI PUMP DISCH AUX HP HDR RELIEF, once a charging pump is started.
* When all charging pumps are in the STOP position, Tech Spec 3.0.3 is applicable.

Question 31

Discuss the Immediate Operator Actions of AOP-04.01 FUEL POOL COOLING SYSTEM.

Answer 31

1. IF the fuel storage pool water level is less than 23 ft over the top of irradiated fuel assemblies seated
   in the storage racks (elevation 58’ 2-7/8”), THEN
   Immediately Suspend movement of irradiated fuel assemblies in the Spent Fuel Storage Pool. ITS
   does not require suspending Crane operations}
2. With the fuel storage pool boron concentration less than 1900 ppm, immediately:
   A. SUSPEND all movement of fuel assemblies in the fuel
   storage pool
   AND
   B. INITIATE action to restore the fuel storage pool boron
   concentration to within the required limit per
   1-NOP-04.04, Fuel Pool Cooling and Purification
   System - Normal Operation.

Question 32

Discuss the AOP-04.01 FUEL POOL COOLING SYSTEM NOTE concerning Spent Fuel Cooling.

Answer 32

NOTE
 The Fuel Pool Cooling System is designed to limit fuel pool temperature to 150F. During normal operations, the fuel pool temperature is maintained less than 120F with one cooling pump in operation; however, due to the enlarged capacity of the fuel racks and possible shorter unloading times for refueling, it will be necessary to operate both Spent Fuel Pool Cooling Pumps after a refueling offload.
 If CCW has been lost due to SIAS, then conditions required to reset the safeguards signal should be met before restoring CCW.

Question 33

Discuss the AOP-04.01 FUEL POOL COOLING SYSTEM WARNING concerning SFP temperature and required PPE.

Answer 33

WARNING
Water temperature greater than 140F can cause severe burns to body parts in less than 6 seconds. Per SA-AA-100, Fleet Industrial Safety Program, if the temperature in the SFP is greater than 126F, then the proper fall restraint SHALL be worn as a replacement for the life vest.

Question 34

Discuss the AOP-04.01 FUEL POOL COOLING SYSTEM concerning SFP piping arrangement.

Answer 34

NOTE
The fuel pool piping is arranged to prevent inadvertent uncovering of the fuel. A leak in the cooling loop could only reduce the water level by 6 feet, which would still leave adequate level to provide shielding. Worst case loss of cooling capability would result in the pool water reaching the bulk boiling point in approximately {4.53} [2.9] hours with a full core offload in the pool.

Question 35

Discuss the AOP-04.01 FUEL POOL COOLING SYSTEM CAUTION concerning maximum SFP level.

Answer 35

CAUTION
Fuel pool level is required to be maintained less than 61’1” to prevent boric acid intrusion into the Fuel Pool Ventilation System.

Question 36

Discuss AOP-04.01 FUEL POOL COOLING SYSTEM NOTEs and CAUTIONs concerning ICW makeup.

Answer 36

NOTE
 2½ inch fire hose is available in Hose House 1, located in the northeast corner outside the FHB, 19.5 elevation north-south roadway, or any other hose house.
 A hose is NOT required to be connected at the 62 ft. elevation in the Fuel Handling Building based upon the proximity of the Emergency Fuel Pool Makeup line outlet to the Spent Fuel Pool.

CAUTION
Make-up capability from the Intake Cooling Water System is available only as a last resort. Seawater will contaminate the Spent Fuel Pool.

Question 37

Per AOP-06.03 WASTE GAS SYSTEM, what actions are required if Oxygen concentration in the in-service gas decay tank is NOT less than 4% by volume.

Answer 37

1.1 IMMEDIATELY SUSPEND all additions of waste gases.
1.2 COMMENCE reduction of oxygen to less than or equal to 2% by volume by opening the appropriate valve to add nitrogen to the in-service gas decay tank:
 SH6588, N2 SPLY TO GDT 1A ISOL VLV
 SH6596, N2 SPLY TO 1B GDT ISOL VLV
 SH6599, N2 SPLY TO GDT 1C ISOL VLV
1.3 IF an unexpected drop or rise in pressure of a gas decay tank occurs, THEN IMMEDIATELY STOP any gas release in progress.

Question 38

Per AOP-06.04 UNCONTROLLED RELEASE OF RADIOACTIVE GAS, how is an Unplanned Gas Release defined?

Answer 38

NOTE
An Unplanned Gas Release per C-200, Offsite Dose Calculation Manual (ODCM), is defined as follows:
 Gas Decay Tank loses greater than 2 psig per 8 hours for 9 consecutive shifts,
OR
 Gas Decay Tank loses 18 psig in 72 hours,
AND
 Losses were to the Reactor Auxiliary Building atmosphere

Question 39

Discuss the AOP-08.01 STEAM LEAK NOTE concerning reactor power during a steam leak.

Answer 39

NOTE
 Variable High Power Trip setpoints shall NOT be reset in response to a steam leak
 Minor excursions up to 100.5% Reactor power require power reduction within 15 minutes
 Lesser excursions up to 100.1% Reactor power require power reduction within 30 minutes

Question 40

Per AOP-08.01 STEAM LEAK NOTE, what actions are required if containment pressure is NOT stable or lowering?

Answer 40

3.1 IF containment pressure is RISING at a controllable rate (less than 1.0 psig per hour), THEN:
A. REDUCE turbine load as required to MAINTAIN T-avg and T-ref deviation less than 6.0 F, while making preparations for a containment entry.
B. REVIEW Tech Spec. 3.6.4, Containment Pressure.

3.2 IF containment pressure is RISING at a rate that a
containment entry is unlikely to be successful (greater than 1.0 psig per hour), THEN:
A. REFER to 1-AOP-22.01, Rapid Downpower.

3.3 IF two out of four RPS channels indicate High Containment Pressure Pre-Trip, THEN PERFORM the following:
A. TRIP Reactor.
B. GO TO 1-EOP-01, Standard Post Trip Actions

Question 41

Per AOP-08.02 STEAM GENERATOR TUBE LEAK, how is the gross magnitude and source of the leak determined expeditiously?

Answer 41

NOTE
A full isotopic analysis of steam generator water activity could take up to an hour. If an expeditious indication of gross activity is required, a frisk in the Secondary Lab or a quick count gamma analysis in the Hot Lab will yield the necessary information to determine the gross magnitude and source of leak.

Question 42

Per AOP-08.02 STEAM GENERATOR TUBE LEAK, what actions are required if the tube leak is NOT less than 75gpd?

Answer 42

1. IF leak rate is NOT LESS THAN 100 gpd:

1.1 IMPLEMENT a rapid downpower at 10 MW/min per 1-AOP-22.01, Rapid Downpower, to attain the following:
 Power equal to or LESS THAN 50% in 1 hour
 Mode 3 within next 2 hours

1.2 GO TO Section 4.2.2, Step 8.

2. If leak rate is LESS THAN 100 gpd but NOT LESS THAN 75 gpd:

2.1 IF leak rate is sustained for GREATER THAN 1 hour, THEN PERFORM the following:
A. BEGIN a controlled downpower per 1-GOP-123, Turbine Shutdown - Full Load To Zero Load.
B. ENSURE Mode 3 is entered within 24 hours.
C. GO TO Section 4.2.2, Step 8.

2.2 IF leak rate is NOT sustained for GREATER THAN 1 hour, THEN CONTINUE to Section 4.2.2, Step 3.

Question 43

Discuss the Immediate Operator Actions of AOP-08.03 STEAM BYPASS CONTROL SYSTEM?

Answer 43

1. IF two out of four RPS channels indicate Reactor Power High Pre-Trip, THEN PERFORM the following:
   A. TRIP Reactor.
   B. GO TO 1-EOP-01, Standard Post Trip Actions.
2. IF a SBCS valve has failed OPEN, THEN PLACE STEAM BYPASS PERMISSIVE switch in OFF. (RTGB-102)

Question 44

Discuss AOP-08.03 General Information.

Answer 44

1. The SBCS is designed to automatically maintain main steam pressure at 900 psia resulting in RCS temperature of 532F.
2. During plant start ups with CEDMS energized and in Mode 1, the SBCS is in the pressure modulate mode of operation only.
3. When placing an SBCS controller in manual to cool down the RCS, the SBCS Permissive Switch must be taken to Manual to ensure a permissive signal is
   maintained when the QO2 permissive is lost at 806 psia.
4. If any controller is in manual and a loss of condenser vacuum occurs, condenser vacuum trip will require reset on SBCS Inputs display.
5. On a reactor trip, the quick open signal lowers TAVG to TAVG at time of trip minus 3F or 555F (whichever is higher), then temperature modulate lowers temperature to 541F. Pressure modulate of PCV-8801 lowers TAVG to 532F (900 psia).
6. SBCS valves operate with overlap.
7. To have a quick open following a reactor trip, the following conditions need to be present:
    TAVG >555F
    Steam Pressure >806 psia
    Individual Valve Controllers in AUTO
8. NO quick open (QO) following a reactor trip if reactor power is less than 51% due to TAVG, if on program, being less than 555F, therefore NO QO-1 signal.
9. Response of SBCS during natural circulation condition may result in PCV-8802/8803/8804/8805 being open due to TAVG approaching 550F as natural
   circulation builds in.
10. For TAVG modulate to function, PIC-8010 must be in automatic with a reactor trip.

Question 45

Discuss the Immediate Operator Actions of AOP-09.01 FEEDWATER CONTROL SYSTEM ABNORMAL OPERATIONS.

Answer 45

1. VERIFY S/G levels between 60% and 70% NR AND stable.
   1.1 IF automatic level control is malfunctioning,
   THEN TAKE manual control of feed flow and STABILIZE S/G levels to 60% to 70% NR.
2. VERIFY S/G levels are greater than 40% NR.
   2.1 TRIP reactor.
   2.2 IF any 100% bypass valve is open, THEN CLOSE it.
   2.3 GO TO 1-EOP-01, Standard Post Trip Actions
3. VERIFY S/G levels are less than {80}[75]% NR.
   3.1 IF affected S/G WR level is stable OR dropping, THEN GO TO Section 4.2.1, Step 1.
   3.2 IF either of the following is met:
    Reactor power is greater than or equal to 15%
    {L-35}[L-29], LOSS OF LOAD TRIP BYPASSED, is CLEAR
   THEN PERFORM the following:
   A. TRIP reactor.
   B. IF any 100% bypass valve is open, THEN CLOSE it.
   C. GO TO 1-EOP-01, Standard Post Trip Actions.
   3.3 IF all of the following are met:
    Reactor power is less than 15%
    {L-35}[L-29], LOSS OF LOAD TRIP BYPASSED, is IN ALARM THEN TRIP turbine.

Question 46

Describe the unit difference concerning 100% feedwater bypass valve on turbine trip.

Answer 46

Unit 2
CAUTION
If a 100% bypass valve is open during a turbine trip or high S/G level event, manual closure will be necessary to prevent S/G overfill.

Unit 1
100% bypass valve closes automatically on turbine trip

Question 47

Discuss 2-AOP-09.01 FEEDWATER CONTROL SYSTEM ABNORMAL OPERATIONS NOTE concerning MFIV operability.

Answer 47

NOTE
 An MFIV is considered inoperable for any of the following conditions:
 Its accumulator nitrogen pressure is below 4150 psig with NO indicated oil leakage OR 4600 psig with ANY indicated oil leakage.
 The ambient temperature at the top of its actuator accumulators is less than 60 F.
 Its air reservoir pressure is less than 70 psig.
 The MFIV accumulator nitrogen pre-charge pressure as a function of ambient temperature is periodically evaluated per 2-OSP-09.14, Main Feedwater Isolation Valves Periodic Test.
 Magnetic temperature pyrometer or equivalent instrumentation will be needed to measure MFIV ambient temperatures at actuator accumulators.

Question 48

Discuss AOP-09.01 FEEDWATER CONTROL SYSTEM ABNORMAL OPERATIONS NOTE concerning LPFRV and HPFRV operation.

Answer 48

NOTE
 The LPFRV gets a close signal at 25% power rising. This signal is removed at 20% power lowering.
 When greater than 20% power, the HPFRVs can control S/G levels with their respective LPFRVs closed.
 A high power M/A station should be in manual anytime its low power M/A station is in manual AND the HPFRV is full closed.
 The initial transfer from the LPFRV in manual to the HPFRV in auto should be continuous and steady until the HPFRV is at least 5% open.
 This step is a continuous action step. If reactor power level is passing through 20%, different parts of this step may apply as power changes.

Question 49

Discuss the unit differences concerning C AFW pump overspeed trip indications.

Answer 49

Unit 1
NOTE
 An electrical overspeed trip results in dual position indication for MV-08-3, 1C AFW PUMP THROTTLE/TRIP, and alarm reset on G-46.
 A mechanical overspeed trip results in dual position indication for MV-08-3, 1C AFW PUMP THROTTLE/TRIP, and alarm G-46 locked in.
 Attachment 6, Mechanical Overspeed Latching, shows correct mechanical overspeed mechanism latching.

Unit 2
NOTE
 An electrical overspeed trip results in closed position indication for MV-08-3, 2C AFW PUMP THROTTLE/TRIP, and alarm reset on G-46.
 A mechanical overspeed trip results in closed position indication for MV-08-3, 2C AFW PUMP THROTTLE/TRIP, and alarm G-46 locked in.

Question 50

Discuss AOP-09.02 AUXILIARY FEEDWATER CAUTION concerning feeding a dry steam generator.

Answer 50

CAUTION
 If Steam Generator level is below 31% NR, then initial feedwater flow should be controlled to less than 150 gpm, when using Aux Feed, for the first 5 minutes or until a level rise is observed, for water hammer and thermal shock concerns. Failure to control flow to less than 150 gpm for at least 5 minutes or until a level rise is observed may require a visual inspection of the feed ring prior to startup.
 Feedwater should NOT be restored to a dry S/G if another S/G still contains water. Feedwater shall only be restored to the S/G that is NOT dry. If both S/Gs become dry, then feedwater shall only be restored to one S/G to reinitiate core cooling.

Question 51

Per AOP-09.03 SECONDARY CHEMISTRY, Describe Level 1 Actions.

Answer 51

1. IMPLEMENT Corrective actions as soon as possible to return parameter from the Action Level 1 condition.
2. IF parameter remains in Action Level 1 condition for more than 21 days following confirmation of excursion, THEN PERFORM the following:
   * IF parameter has an Action Level 2 value, THEN ESCALATE to Action Level 2.
   * IF parameter does NOT have an Action Level 2 value, THEN ENSURE a technical justification is performed to justify continuing to operate above Action Level 1

Question 52

Per AOP-09.03 SECONDARY CHEMISTRY, Describe Level 2 Actions.

Answer 52

1. For all Action Level 2 excursions PERFORM the following:
   A. INITIATE immediate power reduction at a rate between 9 and 11 MW/min to power level between 45% and 49% per 1-AOP-22.01, Rapid Downpower.
   B. WHEN parameter values are below Action Level 2 values THEN TERMINATE power reduction as directed by the US.
   C. WHEN parameter values are below Action Level 1 values THEN RETURN to full power operation as directed by the US.
   D. IF the parameter remains in the Action Level 1 or Action Level 2 condition for more than 300 hours after entering the Action Level 2 condition, THEN ESCALATE to Action Level 3 for those parameters having Action
   Level 3 values.
   E. IF Action Level 2 is entered as a result of being in Action Level 1 for more than 21 days, AND the parameter value has NOT entered the Action Level 2
   condition, THEN CONTINUE operation between 45% and 49% power as directed by US.
   F. After an Action Level 2 excursion, excluding dissolved oxygen, CONSIDER further reductions in power and a low power or hot soak to promote removal of the specific contaminant from the S/G.
   G. CONTACT Chemistry for further recommendations.

Question 53

Describe the strategy of AOP-09.04 FEEDWATER, CONDENSATE, AND HEATER DRAIN PUMP
ABNORMAL OPERATIONS.

Answer 53

 If a pump trips causing feed flow to be less than steam flow, then commence a rapid downpower to balance feed and steam flows.
 If MFW pump flow is low due to closed recirc valve, then open recirc valve.
 If MFW pump suction pressure is low, then start standby condensate pump and heater drain pump and ensure FCV-12-1 is closed. If insufficient number of heater drain pumps running, then commence a rapid downpower to keep suction pressure above 355 psig. If MFW pump suction pressure drops to 230 psig, trip the affected MFW pump.
 If MFW pump oil pressure is low, then ensure its aux oil pump is running. If oil pressure drops to 8 psig, then ensure the MFW pump is tripped. Check pump oil reservoir levels and add oil if required. Check oil flows, clarity, TCW cooling to lube oil coolers.
 If MFW pump high bearing temperature greater than 190F, then confirm bearing temperatures locally. Check pump oil reservoir levels and add oil if required. Check oil flows, clarity, TCW cooling to lube oil coolers. If bearing temperature exceeds 200F with obvious pump degradation conditions and reactor power greater than 60%, then trip the reactor and affected MFW pump.
 If one MFW pump must be stopped and time allows, then commence a normal downpower per 1-GOP-123 and stop the affected MFW pump when power level allows.
 If a Heater Drain Pump flow is less than 1500 gpm, then reduce power as required per 1-AOP-22.01, Rapid Downpower, and when plant conditions allow, stop the affected Heater Drain Pump.

Question 54

Per AOP-09.04 FEEDWATER, CONDENSATE, AND HEATER DRAIN PUMP ABNORMAL OPERATIONS. describe Main Feedwater Trips.

Answer 54

Unit 1
1. MSIS
2. SIAS
3. Electrical fault (overcurrent, differential current, UV)
4. Flow low - less than 4500 gpm for greater than 10 seconds and after pump running for greater than 15 seconds
5. Loss of both running condensate pumps
6. Loss of one condensate pump AND total feed flow greater than 50% (16,500 GPM)
AND both MFW pumps running (loss of condensate pump trips its respective MFW pump)
7. Lube oil pressure low - at 8 psig dropping
8. S/G NR level high-high - greater than 90% rising
9. Suction pressure low - below 230 psig

2.0 CONDENSATE PUMP TRIPS
1. MSIS
2. Electrical fault (overcurrent, differential current, UV)

3.0 HEATER DRAIN PUMP TRIPS
1. MSIS
2. SIAS
3. Electrical fault (overcurrent, differential current, UV)
4. Level low-low in #4 low pressure feedwater heater

Unit 2
1. SIAS
2. Electrical fault (overcurrent, differential current, UV)
3. Flow low - less than 4500 gpm for greater than 10 seconds and after pump running for greater than 30 seconds
4. Loss of both running condensate pumps
5. Loss of one condensate pump AND total feed flow greater than 50% AND both MFW pumps running (loss of condensate pump trips its respective MFW pump)
6. Lube oil pressure low - at 8 psig dropping
7. S/G NR level high-high - greater than 81% rising
8. Suction pressure low - below 230 psig

2.0 CONDENSATE PUMP TRIPS
1. Electrical fault (overcurrent, differential current, UV)

3.0 HEATER DRAIN PUMP TRIPS
1. SIAS
2. Electrical fault (overcurrent, differential current, UV)
3. Level low-low in #4 low pressure feedwater heater

Question 55

Per 1-AOP-09.05 MFIV ACCUMULATOR NITROGEN PRESSURE ABNORMAL OPERATIONS, describe the actions for abnormal MFIV accumulator pressure.

Answer 55

For low MFIV accumulator pressure:
 If MFIV accumulator nitrogen pressure is less than 277 psig, then declare MFIV inoperable.
 Check for nitrogen leaks on MFIV accumulator nitrogen system.
 Change out MFIV accumulator nitrogen bottles as needed.
For high MFIV accumulator pressure:
 Check operation of MFIV accumulator nitrogen PCVs.
 Reduce accumulator nitrogen pressure by local venting.

Question 56

State the major actions of AOP-12.01 LOSS OF CONDENSER VACUUM.

Answer 56

1. VERIFY Condenser Back Pressure less than 8.5 inHgA.
2. VERIFY Condenser Back Pressure below alarm limits of Acceptable Operating Region:
   * Attachment 4, Condenser Pressure Limitations
   OR
   * Display 5605, CONDENSER VACUUM MONITORING.
3. VERIFY CONDENSER DIFFERENTIAL pressure less
   than 2.0 inHgA. (DEH display 5559)
4. IF an unexpected Condenser Back Pressure rise is taking place, THEN PERFORM the following:
   A. IMPLEMENT a unit load reduction per 1-AOP-22.01,
   Rapid Downpower.
   B. CONTINUE unit load reduction until Condenser Back Pressure stabilizes.
5. VERIFY NO circulating water pumps tripped.
6. PLACE a hogging ejector in service per Attachment 3, Placing Hogging Ejectors in Service
7. VERIFY steam to SJAEs between 380 and 420 psig, on PI-12-30, STEAM TO SJAE. (RTGB-101)
8. VERIFY PI-22-21, STEAM SEAL HP, is between 120 to 130 psig.
9. VERIFY PI-22-22, STEAM SEAL SPILLOVER, is between
   17 to 19 psia.
10. DISPATCH NPO to perform Attachment 2, Local Operations for Nuclear Plant Operator (NPO)
11. VERIFY D-24, GLAND SEAL STEAM PRESS HIGH/LOW is CLEAR.
12. VERIFY proper circulating water pump status by evaluating the following:
    * Discharge valves on running pumps OPEN. (RTGB-102)
    * Proper pump running current. (RTGB-102)
    * Proper pump discharge pressure. (locally at intake structure)
13. VERIFY adequate CST inventory by the following indications:
    * LIS-12-11, COND STORAGE TK LEVEL, greater than 20 feet. (RTGB-102)
    * LIS-12-12, COND STORAGE TANK LEVEL, greater than 20 feet. (RTGB-102)
    * Annunciator G-39, CST LEVEL HIGH/LOW is CLEAR.

Question 57

Discuss the Immediate Operator Actions of AOP-13.01 TURBINE COOLING WATER SYSTEM.

Answer 57

IF a TCW pump tripped, THEN VERIFY the other pump is running.

If Not, START the backup TCW Pump if available.

Question 58

Discuss the Immediate Operator Actions of 2-AOP-14.01 COMPONENT COOLING WATER ABNORMAL OPERATIONS.

Answer 58

1. VERIFY CCW pump amps stable for running CCW pumps:
    AM-201, PUMP 2A AMPERES
    AM-205, PUMP 2B AMPERES
    AM-209, PUMP 2C AMPERES
   1.1 IF NOT, STOP affected CCW pump and PLACE Control Switch in PULL TO LOCK.
2. IF CCW flow is lost to the “N” Header, THEN PERFORM the following:
   A. ISOLATE letdown by closing the following:
    V2516, CONTAINMENT ISOL VALVE - IC
    V2522, CONTAINMENT ISOL VALVE - OC
    V2515, STOP VALVE - IC
   B. WHEN letdown is isolated , THEN PERFORM the following:
   (1) STOP the charging pumps.
   (2) RETURN the charging pump control switches to AUTO.
   (3) OPERATE charging pumps with Letdown Unavailable per 2-AOP-02.03, Charging And Letdown.

Question 59

Per 2-AOP-14.01 COMPONENT COOLING WATER ABNORMAL OPERATIONS, is it permissible to run two CCW pumps electrically aligned to the same electrical bus?

Answer 59

NOTE
Operation of two CCW pumps electrically aligned to the same electrical bus for emergency conditions while in MODES 1 through 4, should be limited to 12 hours.

Question 60

Discuss the strategies of AOP-14.01 COMPONENT COOLING WATER ABNORMAL OPERATIONS.

Answer 60

The following strategies are employed:
A. If a CCW pump trips, then CCW Pump 2C is aligned and started on the affected header.
B. If only one CCW pump is available, then the CCW pump is aligned to supply all CCW headers and isolate selected CCW loads to avoid pump runout.
C. If a CCW heat exchanger fails, then CCW Pump 2C suction is aligned from the failed CCW header and discharge to the in-service CCW heat exchanger. Selected CCW loads are isolated to limit CCW heat exchanger flow.
D. If CCW Headers A or B are ruptured, then automatic header isolation is verified, the CCW pump on the ruptured header is stopped and the available header is restored.
E. If CCW Header N is ruptured, then automatic header isolation is verified, and the reactor and RCPs are tripped.
F. If CCW Surge Tank level is abnormal, then tank makeup, temperature change, gas ingress and system leakage are evaluated.
G. If CCW temperatures are unexpectedly increasing, then ICW flow and CCW heat loads are evaluated.
H. If a CCW pump spuriously starts, then a CCW pump is stopped.

Question 61

What happens to RCV-14-1, CCW SURGE TANK TO CHEM DRAIN TANK 3-WAY DIAPHRAGM on high radioactivity in the CCW system?

Answer 61

RCV-14-1, CCW SURGE TANK TO CHEM DRAIN TANK 3-WAY
DIAPHRAGM, diverts from atmosphere to the Chemical Drain Tank on high radioactivity in the CCW system.

Question 62

Discuss the Immediate Operator Actions of AOP-18.01INSTRUMENT AIR MALFUNCTION.

Answer 62

1. VERIFY Instrument Air header pressure equal to or greater than 60 psig as indicated on PI-18-9,
   INSTR/STATION AIR PRESSURE.
   1.1 IF Instrument Air header pressure indicates less than 60 psig and lowering, THEN PERFORM the following:
   A. TRIP reactor.
   B. GO TO 1-EOP-01, Standard Post Trip Actions.

Question 63

Describe the purpose of AOP-18.01 INSTRUMENT AIR MALFUNCTION.

Answer 63

This procedure provides instructions in the event Instrument Air is lost or degraded. The following responses are included during the performance of this procedure:
 Trip reactor if instrument air pressure is < 60 psig
 Ensure service air cross-tie is open and dryers bypassed
 Ensure standby air compressor placed in service
 Identify and isolate leaks or malfunctioning equipment
 Compensate for component malfunctioning due to low air pressure
 Respond to loss of air to containment or air leakage inside containment
 Align construction air to supply instrument air

Question 64

Describe the Instrument Air automatic cross tie feature.

Answer 64

NOTE
 The automatic cross-tie feature of the Instrument Air System occurs at 85 psig lowering on the affected unit. The cross-tie valve on Unit 2 will close if either of the following conditions occur:
 Instrument Air header pressure lowers below 85 psig on the unaffected unit.
 Instrument Air header pressure rises above 95 psig on the affected unit.

Question 65

Per AOP-21.03A,B,C,D A,B,C,D INTAKE COOLING WATER SYSTEM HEADER, what actions are required based on Cold Gas temperature?

Answer 65

• IF Average Cold Gas Temperature rises to 47.7°C, THEN REDUCE MVARS to minimum, but NOT less than (unity) 0 MVARS.
• IF Average Cold Gas Temperature rises to 50.7°C, THEN IMPLEMENT 1-AOP-22.01, Rapid Downpower to REDUCE power as necessary to stabilize main generator cold gas temperature.

Question 66

Discuss ASI control during Rapid downpower.

Answer 66

NOTE
 The procedural limit for ASI control is +/- 0.5 of ESI. It is desired to maintain ASI within a control band of +/- 0.2 of ESI.
 US may direct temporary operation outside of ASI limit.

Question 67

Discuss Tave control during rapid downpower.

Answer 67

NOTE
The procedural limit for TAVE-TREF mismatch is +/- 6.6F. It is desired to maintain a control band of +/- 2F.

Question 68

Per AOP-22.01 RAPID DOWNPOWER, what actions are required if TREF and TAVG can NOT be maintained within 6.6F?

Answer 68

IF TREF and TAVG can NOT be maintained within 6.6F,
THEN NOTIFY US AND:
A. TRIP reactor.
B. GO TO 1-EOP-01, Standard Post Trip Actions.

Question 69

Per AOP-22.02 TURBINE SUPERVISORY, discuss actions required for abnormal turbine vibrations.

Answer 69

2. VERIFY turbine vibration is less than 14 mils.
   2.1 IF annunciator L-35, LOSS OF LOAD CHANNEL TRIP
   BYPASSED, is CLEAR, THEN PERFORM the following:
   A. TRIP reactor.
   B. ENSURE turbine tripped.
   C. IF turbine vibration continues to rise, THEN OPEN MV-10-1A and MV-10-1B, VACUUM BREAKER. (RTBG-101)
   D. GO TO 1-EOP-01, Standard Post Trip Actions.
   2.2 IF annunciator L-35, LOSS OF LOAD CHANNEL TRIP
   BYPASSED, is IN ALARM, THEN TRIP turbine.
   2.3 IF turbine vibration continues to rise, THEN PERFORM the following:
   A. OPEN MV-10-1A and MV-10-1B, VACUUM BREAKER.
   B. TRIP reactor.
   C. GO TO 1-EOP-01, Standard Post Trip Actions.

Question 70

Per AOP-22.04 OVATION TURBINE CONTROL SYSTEM ABNORMAL OPERATIONS, what actions are required if a throttle or governor valve unexpectedly closes?

Answer 70

NOTE
To prevent unacceptable loading on the first rows of reaction blading, reactor power shall be reduced to less than 75% within 60 minutes of a throttle or governor valve unexpectedly closing.

Question 71

Per AOP-22.04 OVATION TURBINE CONTROL SYSTEM ABNORMAL OPERATIONS, what actions are required if a reheat or intercept turbine valve is closed?

Answer 71

NOTE
* The maximum accumulated time for operating the turbine at greater than 75% load with any reheat stop or intercept turbine valves closed is 80 hours total for the previous 12 months.
* If any reheat stop or intercept valve(s) remain closed longer than is necessary for periodic testing, the System Engineer should be requested to determine how long the unit has operated above 75% power with any reheat stop or intercept valves closed within the previous 12 months.
* Power should be reduced to less than or equal to 50% turbine load before exceeding 80 hours total accumulated time for any reheat stop or intercept valves closed within the previous 12 months.

Question 72

Discuss the Immediate Operator Actions of AOP-24.01 RAB FLOODING.

Answer 72

1. PLACE HCV-25-1 THRU 7, DRAIN VALVES TO SFGD
   SUMPS to CLOSE.
2. PLACE HCV-25-1A THRU 7A, DRAIN VALVES TO SFGD
   SUMPS to CLOSE.

Question 73

Per AOP-24.01 RAB FLOODING, discuss why Safeguards Pump Room Sump Pump and Containment Sump Pump discharges from the EDT are aligned to the in service HUT.

Answer 73

NOTE
* This attachment aligns the Safeguards Pump Room Sump Pump and Containment Sump Pump discharges from the EDT to the in service HUT. The normal flow path to the EDT is isolated and the sump pump discharges are aligned with the discharge of the Reactor Drain Pumps which enters the letdown/divert line between V2500, VCT Divert Valve, and
the Flash Tank.

Question 74

Discuss the unit differences concerning aligning the Safeguards Pump Room Sump Pump and Containment Sump Pump discharges from the EDT to the in service HUT.

Answer 74

U1: 3 light valve on CRAC go to Sump pump to RDT position
U2: ESF LEAKAGE COLLECTION AND RETURN VALVES, Take switch to SSP TO RC SUMP position (PACB 2 panel)

Question 75

Discuss the purpose of AOP-25.01 LOSS OF RCB COOLING FANS.

Answer 75

1. This procedure provides instructions for operator action in the event of a malfunction of any of the following cooling fans located in the Reactor Containment Building (RCB):
    HVE-21A and HVE-21B, CEDM Cooling Fans
    HVS-2A and HVS-2B, Reactor Cavity Cooling Fans
    HVE-3A and HVE-3B, Reactor Support Cooling Fans
    HVS-1A, HVS-1B, HVS-1C and HVS-1D, Containment Fan Coolers
2. The following strategy is employed:
   A. If a fan is in standby, then ensure the standby fan starts.
   B. Troubleshoot the electrical alignment.
   C. Perform one start attempt on any available fan.
   D. If required fans do NOT start, then initiate a rapid
   downpower.
   E. If conditions are NOT restored within 45 minutes, trip the unit and cooldown to Hot Shutdown within 5 hours.

Question 76

Why must SJAE exhaust be aligned to the atmosphere before stopping RAB Exhaust Fans?

Answer 76

CAUTION
With both RAB Main Exhaust Fans stopped, moisture accumulation from SJAE exhaust in the Plant Vent Stack radiation monitor sample lines may render the monitors INOPERABLE. Failure to align SJAE exhaust to atmosphere may result in damage to the radiation monitor filter, charcoal cartridge or pump from excess condensation.

Question 77

Per AOP-37.01 EMERGENCY COOLING WATER CANAL, how are UHS barrier valves opened if failure to open remotely is due to binding resistance or buildup of sediment?

Answer 77

IF UHS barrier valve failure to open remotely is due to binding resistance or buildup of sediment, THEN PLACE air assistance on UHS barrier valve actuator as follows:
(1) ATTACH hose between fitting on upper side of UHS barrier valve actuator and fitting at V37221, SPARE CONN FOR FUTURE UHS VLVS ISOL.
(2) UNLOCK and slowly OPEN V37221, SPARE CONN FOR FUTURE UHS VLVS ISOL, to admit air to UHS barrier valve actuator upper piston until valve opens.
(3) LOCK CLOSED V37221, SPARE CONN FOR FUTURE UHS VLVS ISOL.
(4) REMOVE hose carefully.