ML20248K029
| ML20248K029 | |
| Person / Time | |
|---|---|
| Site: | Oconee  |
| Issue date: | 03/10/1989 |
| From: | Austin M DUKE POWER CO. |
| To: | |
| Shared Package | |
| ML15224A107 | List:
|
| References | |
| NUDOCS 8904170194 | |
| Download: ML20248K029 (19) | |
Text
. - - _ _ _ _ _ _ _ - _ _ _ _ - _ _ _ _ _ _ _ _ _
Form 34731 (R5-88)
Duke Power Company (1)ID No. OP///A./11 e 2 / 0+
45 to PROCEDURE PROCESS RECORD Change (s}
incorporated PREPARATION (2) Station O c m e*-
Nucb 54b (3) Procedure Title Co e e d,ew at Poe OlB M b k M Date 2-8' M (4) Prepared By (5) Reviewed By Date 3-9
- M Cross-Disciplinary Re By N/R (6) Temporary Approval (if necessary)
By (SRO) Date By Date 2.h u)p 7 (7) Approved By Date (8) Miscellaneous Reviewed /Approed By Date Reviewed / Approved By Date (0) Comments (For procedure reissue indicate whether additional changes, other than previously approved changes, are in-ciuded. Attach additional pages,if necessary.)
AdditionalChanger i'cluded.8Yes O No (10) Compared with ControlCopy Date (11) Requires change to FSAR not identified in 10CFR50.59 evaluation? O Yes if "yes", attach detailed explanation.
JiRNo Completion (12)Date(s) Performed (13) Procedure Completion Verification O Yes O N/A Check lists and/or blanks propody initialed, signed, dated or filled in N/A or N/R, as appropriate?
O Yes O N/A Usted enclosuies attached?
O Yes O N/A Data sheets attached.. empleted, dated and signed?
O Yes O N/A Charts, graphs, etc. attached and property dated, identified and marked?
O Yes O N/A Procedure requirements met?
Verified By Date (14) Procedure Completion Approved Date (15) Remarks (attach additionalpages, if necessary) l 1
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0904170194 890411 PDR ADOCK 05000269 0
Control Copy Checked OP/1/A/1102/04 Date/ Time i
DUKE POWER COMPANY OCONEE NUCLEAR STATION OPERATION AT POWER 1.0 Purpose To describe che operation of the unit at power.
This will include the following:
Operations required to escalate power from 15% to 100% FP, Operations required to reduce power from 100% to 15% FP.
Maneuvering restrictions placed on power ramp rates and Control Rod Withdrawal /APSR movement rates.
Special instructions for operation with less than four RC Pumps.
2.0 Limits and Precautions 2.1 The plant must be operated within the limits of Technical Specifications at all times.
When a limiting condition for operation, Section 3.0 of the Technical Specification is not met, the shutdown rate will be determined by Operations such that the required condition is achieved in a controlled manner within the time specified.
If conditions indicate, a faster shutdown rate should be used up to and including a Reactor Trip.
(Reference OMP 1-4, Actions To Be Taken 'n The Case of Exceeding Limits) 2.2 Maintain Power Imbalance per PT/1/A/600/01 (Periodic Instrument Surveillance).
2.3 In the event of a unscheduled power reduction, the power ', vel shall not be increased until an investigation has been conducteo and any necessary corrective action taken.
Page 2 of 4 OP/1/A/1102/04 OPERATION AT POWER 2.4 Maintain rod positions within a group at the same level to minimize
~
power. tilts.
2.5 AT across the condensers shall not exceed 28'F when the inlet tempe-rature is'< 68'F.
'AT shall not exceed 22*F when the inlet temperature is > 68'F.
The cooling water effluent temperature at the discharge shall not exceed 100'F for a period of time in excess of 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
2.6 Condenser effluent temperature shall not decrease more_than 6'F per hour during the Winter and 10*F per hour during the Spring, Summer, and Fall.
2.7 If any two of the four powe range NI's exceed 2% in the non-conservative direction, calibration it, required to prevent exceeding safety limits.
For planned power changes > 5% FP or planned control rod changes in excess of 15% Ro1 Index, the NI calibration should be checked prior to initiating che power change or control rod movement and 15 minutes after reaching steady conditions.
In no case, should > 4% in the non-conservative direction be exceeded.
2.8 If any two of the four NI's become > 2% non-conservative during power level increases, stop the power increase and h' ave all NI's recalibrates.
Non-conservative is Thermal Power Best > NI's.
2.9 Ensure that the Pressurizer Heaters are in AUTO during any system transients or prior to initiating any system transient.
2.10 Ensure IRC-1 (Spray Control) is in AUTOMATIC and IRC-3 (Spray Control Outlet Block) is open during system transients or prior to initiating any plant transient. Anytime IRC-1 is not in AUTOMATIC and IRC-3 is throttled, ensure a Removal of Station Equipment Form is completed per OP/0/A/1102/06 (Removal and Restoration of Station Equipment).
1 l
Page 3 of 4 OP/1/A/1102/04 OPERATION AT POWER NOTE:
If difficulty is experienced in maintaining the transmission voltage (2.11) within these guidelines, notify the Dispatcher.
-2.11 Maintain the following voltage guidelines:
Minimum Maximum 228 232 in 230 KV switchyard 515 525 in 525 KV switchyard 2.12 When reactor is > 15% FP and Pressurizer level decreases to 200 inches, take immediate manual action to return Pressurizer level to normal.
The Pressurizer high level will be limited to the High Level Alarm Point of 260 inches.
2.13 Maintain Primary and Secondary Chemistry limits as established by the j
Chemistry Manual.
If any (Purification or Deborating) is declared exhausted by either the Unit Coordinator or Site Chemist, de-energize the applicable inlet valves and issue the appropriate out of service stickers and R&R sheets.
2.14 Long term operation of the Condensate System should be with 100%
Condensate Polishing even if this requires a load reduction or operation of three Hotwell Pumps. For short intervals such as transients, Powdex Precoating, etc., operataon at less than 100% Powdex flow is acceptable.
Operation in this mode should not extend beyond the time required to return the plant to normal.
2.15 Both Moisture Separator Reheater Drain Tanks are to be continuously dumped to the Hotwell to prevent Steam Generator Tube fouling.
2.16 '4 hen the body of a controlling procedure refers to another procedure or a section of another procedure, that procedure or section must be l
completed, reviewed by Unit Supervisor and signed as complete by Unit Supervisor prior to proceeding with the controlling procedure. This i
will be documented by the S arvisor signing that step in the controlling i
l procedure.
Page 4'of 4 OP/1/A/1102/04 OPERATION AT POWER
~2.17 Before performing any operation which could cause a power swing,.i.e.,--
-removing / restoring FDW htrs. to and from service, reduce Reactor 3
power ~ 4% below the power-allowable for the present plant conditions.
~
2.18 Individual coolers of the Second Cooler Group on_the Main Transformer-shall be operated as needed to keep the oil temperature from exceeding 75*C.
When the Main Transformer'is energized and its oil temp-is
< 50*C, only one Main Transformer Cooler Group (9 pumps / fans) should be operated.
3.0 Enclosures 3.1 Maneuvering Restrictions for Oconee 1 3.2 Special Instructions for < 4_RC Pump Operation 3.3 Power Escalation (15% to 100% FP) 3.4 Power Reduction (100% to 15% FP) 6
Page 1 of 2 Checked Control Copy
= Date/ Time.
1.
l OP/1/A/1102/04 ENCLOSURE 3.1 l
l MANEUVERING RESTRICTIONS FOR OCONEE 1 l'
(Special restrict' ions for initial startup following a Refueling Outage would be included in the Power Escalation Procedure.)
1.0- Allowable Power Ramp Rates j
1.1 0% FP to 20% FP:
Rate of Power Level Increase < 30% FP/ hour.
1.2 20% FP to 50% FP, or from 20% FP to Conditioned Power Level (CPL) if the CPL is between 20% FP and 50% FP:
Rate of Power Level Increase < 20% FP/ hour.
1.3 50% FP to 90% FP, or from 50% FP to CPL if the CPL is between 50%
FP and 90% FP:
Rate of Power Level Increase < 15% FP/ hour.
1.4 Above CPL or 90% FP, whichever.is lower:
Rate.of Power Level Increase < 3% FP/ hour.
1.5 One control rod misaligned greater than 9 inches for more than 12 EFPH but less than 14 EFPD at a power level between 0-100% F.P:
1.5.1 Reduce Reactor Power to < 60% of the allowable power for the Reactor Coolant Pump combination.
)
i NOTE:
Movement of other control rods should be minimized during withdrawal.
(1.5.2) 1.5.2 Recover rod while maintaining power level throughout I
withdrawal.
1.5.3 Escalate power at < 3% FP/hr after realignment.
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Page 2 of 2 1.
OP/1/A/1102/04
. ENCLOSURE 3.1 MANEUVERING RESTRICTIONS FOR OCONEE 1 1.6 One rod misaligned greater than 9 inches for more than 14 EFPD at a power-level between 0-100% F.P:
Contact Performance Reactor Engineer.for Rod Recovery Guidelines.
2.0' Allowable Rod Rate' Limits 2.1 Rate of Control Rod withdrawal < 20% wd/ hour at > 25% F.P.
No Control.
Rod withdrawal rate restriction below 25% F.P.
2.2 Rate of APSR movement:
2.2.1 No limits when'the Reactor is < 75% F.P.
2.2.2.
<10%/ hour when the Reactor is 75% F.P.
3.0 Definitions
3.1 Conditioned Power Level-(CPL):
The maximum core power level which has been continuously maintained.for at least 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> within the previous 14' day period.
Downtime (suberiticality) is-not to be included in the 14 day period.
At the start of each new cycle, the CPL is 20% FP.
NOTE:
The core power increase should be as linear as possible.
(3.2) 1
-3.2 Ramp Rate:
The core power increase " time averaged" over a maximum period of 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
3.3 APSR Movement: The i % movement from the-initial starting position l
in a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period.
(Example:
For a limit of 10?./hr APSR movement with an initial starting position of 32%, the APSR could be inserted to 22% and withdrawn to 42% within a 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> period).
( a,1
- :e :
u Page.1 of 2 Checked Control Copy Date/ Time OP/1/A/1102/04 ENCLOSURE 3.2 SPECIAL INSTRUCTIONS FOR <4 RC PUMP OPERATION 1.0 Procedure 1.1 Do not exceed.5.7 x 10' #/hr feedwater flow to the SG with two RC pumps.
1.2 Calibrate NI's to Thermal Power Best.
1.3 Follow PT/1/A/600/01-(Periodic Inst. Surv) limits on control rod' position and Power Imbalance. The 100% Power Imbalance curves apply.
for extended run at reduced power. This is to meet assumptions'used for FSAR accident safety analyses.
Have the Performance Group generate specific curves'for two RC pump combinations if necessary.
1.4' Issue work request to I&E to have the high 9 RPS trip setpoint set
- st 79%.
1.5 Perform the following:
1).
Adjust the ICS high'9 limiter to 75%. -This provides control.
protection to minimize a trip on 9/ Flow /Imb or high 9 in the event of an operating transient.
2)
When the ICS high 9 limiter is reduced, adjust the associate'd 4
alarm setpoint.
(The alarm setpoint is adjusted on the power range recorder).
3)
Note on Shift Turnover Sheet (OP/0/A/1102/20) anytime the ICS high 9 limiter is reduced.
.l 1.6 Keep Auxiliary Steam available to the FDW Turbines.
"D" bleed pressure may not be high enough to run the Turbines.
l
Page 2 of 2s OP/1/A/1102/04 ENCLOSURE 3.2 SPECIAL INSTRUCTIONS FOR <4.RC PUMP OPERATION.
1.7 - When performing Turbine Valve movement tests,: reduce load. as necessary.
(approximately'6%) to prevent exceeding 100% flow (5.4 x 10' #/hr) out of the SG with two RC pumps.
1.8 Secure the "E" Heater Drain. Pumps at < 90%~F.P.
Pump suction may be lost at lower loads and cause cavitation damage.-
1.9.Be aware the Quandrant Power Tilt is affected by ATc changes.
Some adjustment of Steam Generator Load Ratio (ATC) Controller setpoint may be required to minimize Quandrant Tilt.
1.10 If ISSH-9 (SSH Disch. CTRL Bypass) is being used to maintain Steam Seal Header pressure, throttle the valve during the load reduction to secure-an RC Pump.
NOTE:
RCS pressure decrease in the loop with two RC pumps is expected.
(1.11).
1.11 RCS pressure decreases in the loop with two RC-pumps causing acceptance.
criteria of'PT/1/A/600/01 (Periodic Inst. Surv.) to be out of specs.
Note thisDon PT/1/A/600/01 (Periodic Inst. Surv.).
Be aware of the l-affect of the indicated pressure on the margin to trip setpoint for l
l the Reactor Protective System on the following:
l 1)
Pressure / Temperature Trip 2)
Low Pressure Trip i
3)
High Pressure Trip 1
p sc Page-1.of 7 p
Control. Copy Checked
?Date/ Time
- r. '
l{
OP/1/A/1102/04 ENCLOSURE 3.3 POWER ESCALATION (15% to 100% FP)
Verify Date Date Init./ Time Init / Time-1.0'. Initial Conditions 1.1 'OP/1/A/1102/01 (Controlling Procedure for Unit Startup),.or OP/1/A/1102/02 (Trip Recovery)-
completed..
NOTE:
Steam Generator Load Ratio (ATc) Controller may or (1.2)'
may not.be in AUTO.
1.2 ICS in the integrated mode.
1.3 The Unit Load Demand Master has been set'for a MAXIMUM, MINIMUM and RATE.
1.4 Limits and Precautions have been reviewed.
2.0' Procedure 2.1 Notify the dispatcher and increase Load Demand
,e t, as desired by depressing LOAD DEMAND SET l
1 INCREASE Pushbutton.
{
l 2.2.1 Limit rate of reactor power increase as per Enclosure 3.1 (Maneuvering Restric-1 i
tions for Oconee 1) j 2.2 Place Power Rango Recorder in HIGH RANGE @ ~ 20%
Rx. Power.
2.3 Set the HIGH Alarm on the Power Range Recorder l
1 at 2-5% above operating power.
i
'Page 2 of 7-8
.0P/1/A/1102/04 ENCLOSURE 3.3 POWER ESCALATION (15% to 100% FP)
Verify l
Date Date Init./ Time Init./ Time NOTE:
Steam Generator Load Ratio (ATc) Controller should q
'(2.4) not be.placed in AUTO when a Steam Generator is on level. control.
2.4 If the Steam Generator Ioad Ratio (ATc) Controller is in HAND, place the Steam Generator Load Ratio (ATc) Controller Setpoint equal to Unit dTc.
2.5 When both Steam Generators have cleared level control:
I 2.5.1 Place the Steam Generator Load Ratio (ATc). Controller in AUTOMATIC.
2.5.2 Adjust Steam Generator Load Ratio (ATc) Controller setpoint to 0.
2.5.3 Verify Unit dTc gauge is at O'F.
CAUTION:
If any CRD Groups are in the restricted region, (2.6) action must be taken to position the rods within required limits. Operation in the restricted i
region is limited to 2 Hours, j
i NOTE:
Power may be increased with rods in the restricted (2.6) region wnile corrective action is being taken.
2.6 Maintain CRD Groups 5-8 within the required position limits during power operation per PT/1/A/600/01 (Periodic Inst. Surv.).
2.7 Maintain Core Power Imbalance and Quadrant Power Tilt per PT/1/A/600/01 (Periodic Instrument
-l I
Surveillance).
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Es
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Page 3 of 7 OP/1/A/1102/04 i
ENCLOSURE 3.3
. POWER ESCALATION (15% to - 100% FP) 1' Verify Date Date Init./ Time Init./ Time 2.8 At 190'HWe close the.following Shell Drain valves on Holsture Separator Reheaters and HP Heater Vent Orifice Bypasses:
1HD-405 (1A1 FSRH SHELL DRAIN).
-1HD-406 (1A2 FSRH SHELL DRAIN).
1HD-407 (IB2 FSRH SHELL DRAIN).
1HD-408 (IB1 FSRH SHELL DRAIN).
1HV-5'("1Al" Heater Vent Orifice Bypass).
1HV-47 ("1B2" Heater Vent Orifice Bypass).
1HV-12 ("1B1" Heater Vent Orifice Bypass).
2.9 At 200.HWe transfer auxiliaries from CT1 to IT per'0P/1/A/1107/02 (Normal Power).
Unit Supervisor 2.10 At ~ 30% Reactor Power, maintain steady state conditions for NI calibration check.
2.10.1.
IF any two of the four NI's are non-conservative, have I&E calibrate all NI's 3 to 5% conservative and resume power increase after calibration.
2.10.2 IF any two of the four NI's become
> 2% non-conservative during the power level increase, stop the power increase, and have all NI's recalibrates 3 to 5%
conservative.
-_2_-____-_-_-.
Pagef4 of 7?
OP/1/A/1102/04 ENCLOSURE 3.3 POWER ESCALATION (15% to 100% FP)
- Verify, Date Date 1
Init./ Time Init./ Time 2'.11 At - 300 MWe, start "D" Heater Drain Pumps per OP/1/A/1106/02 (Condensate and Feedwater System).
Unit Supervisor CAUTION: Never depress"the upper toggle switch, lower toggle
'(2,12) switch is.always used to reset Contact Buffers.
2.12 At'~ 40%' power, verify the Main Turbine' Trip.
Contact Buffers are reset on all four RPS Channels:
A RPS Channel B RPS' Channel C RPS Channel D RPS Channel 2.13 Start the second HWP, CBP and FDW pump per OP/1/A/1106/02 (Condensate and Feedwater System).
Unit Supervisor CAUTION: Never depress the upper toggle switch, lower. toggle (2.14) switch is always used to reset Contact Buffers.
t 2.14 Reset the Contact Buffer on the Main Feedwater f
Pump which was just started on each of the four 1
RPS Channels:
i
)'
l A RPS Channel l'
l B RPS Channel
'k 1
j I
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E -
1Page 5 of 7 OP/1/A/1102/04-
~ ENCLOSURE 3.3 POWER ESCALATION (15% to! 100% FP))
Verify _
Date-
. Da t e --
Init./ Time Init./ Time 2.15' Reset the'" Output Memory" on the " Main Turbine Trip Bypass Bistable" on each of the four RPS
. Channels:
C RPS Channel D RPS Channel 2.16 Reset the " Output Memory" on the " Main Feedpump Trip Bypass Bistable" for each Main Feedpump on each of the four RPS Channels:
A RPS Channel B RPS Channel C RPS Channel D RPS Channel 2.17 After each Main FDWP is operating with suction flow 1-
> 2300 gpm, place the following valves in AUTO:
1FDW-53 ('A' FDWP Min. Flow Recire. Control Valve) 1FDW-65 ('B' FDWP Min. Flow Recirc. Control Valve) 2.18 State additional CCW pumps as required per OP/1/A/1104/12 (Condenser Circulating Water 1
System).
Unit. Supervisor l.
o_ -_ --
Page 6 of.7 p,
0P/1/A/1102/04 ENCLOSURE 3.3 POWER. ESCALATION (15%'to 100% FP)
- Verify Date Date Init./ Time Init./ Time 2.19 When the load reachhs 500.MWe, raise. Machine-Gas pressure to 60 psig per OP/0/A/1106/17 (Hydrogen System).
Unit' Supervisor 2.20 Prior to exceeding 60% Reactor. Power,' verify three HPI pumps-and two HPI flow paths are operable.
Unit Supervisor NOTE:
This should occur when Reactor Power.is between
.(2.21) 65% and 85%.
2.21 When air loading pressure (as indicated on their controllers) to.1MS-112 and IMS-173 (SSRHs 1
Controls) is 30 psig and they are in. AUTO, verify the following SSRH Steam Supply valves are in AUTO and OPEN:
<o f
1MS-77 (MS To 1A1 SSRH).
1MS-78 (MS To 1A2 SSRH).
i 1MS-80 (MS To 1B1 SSRH).
i 1MS-81 (MS To IB2 SSRH).
2.22'At 65% Reactor Power, maintain steady state conditions for - 15 minutes for NI calibration check.
2.23 At ~ 70% power, perform Enclosure for " Steam i
Extraction Check Valve Test" of PT/1/B/290/05 (Secondary System Protection Test).
i
Pags'7 of 7-OP/1/A/1102/04-ENCLOSURE 3.3-POWER ESCALATION-(15% to 100% FP) 1 Verify-
.Date Date Init./ Time Init./ Time 2.24 At - 800 MWe, start "E" Heater Drain Pumps per-OP/1/A/1106/02 (Condensate and Feedwater System).
Unit Supervisor 2.25 Stop the power increase at ~ 90% Reactor Power as
' indicated by Thermal Power.Best and if necessary, calibrate all NI's to Thermal' Power Best.
2.26 Increase LOAD DEMAND SET to final load desired.
-2.27 At ~ 100% Reactor Power, maintain steady state conditions for ~ 15 minutes for NI calibration
- check, l.
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_Page-1 of 3 l
l v
. Control Copy Checked Date/ Time
]
.0P/1/A/1102/04 ENCLOSURE 3.4.
POWER REDUCTION (100% to 15% FP)
Date-
'Init./ Time
.1.0 Initial Conditions 1.1. Auxiliary' Steam Header pressurized per OP/0/A/1106/04 (Auxiliary Boiler) or cross connected with.other units.
l 1.2 NRC notified per the requirements of OMP 1-10 (Usage and Testing the Emergency Notification System (Red
-l Phone)).
1.3 Limits and Precautions have been reviewed.
i a
2.0 Procedure 2.1 If cooldown and depressurization of the R. C. System in preparation for maintenance on the RC System or HPI System is to be performed, degassification per OP/1/A/1102/12 (Degassification of. Reactor Coolant and Pressurizer) should be started 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> prior to the i
-estimated time of placing the LPI System in service.
2.2 Notify the Area Dispatcher of the load reduction.
l 2.3 Advise plant personnel of load reduction as necessary.
I 2.4 Place the Unit Load Demand Station in local control.
2.5' Reduce reactor power to the desired power level.
2.6 Set Load Demand Min. Limit Set at 125 MWe.
1 I
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Page 2 of 3 ~
OP/1/A/1102/04
. ENCLOSURE 3.4 POWER REDUCTION:(100% to 15% FP)
Date Init./ Time 2.7 At approximately 800.thle:
0 2.' 7.1-Stop "E" Heater Drain pumps.
l
.. {
! 2.7.2 Place Recire. Control Switch to AUTO.
2.8 At approximately 400 MWe:
2'. 8.1 Stop "D" Heater Drain _ pumps..
2.8.2' Place Recire. Control Switch to AUTO.
NOTE:
It is preferred that "1B" FDWP be-taken out of service (2.9) f ir s t '. This is due to the differences in High Pressure Discharge Trip Setpoints.
2.9 At approximately 350 MWe, take one Feedwater Pump out of service per 0P/1/A/1106/02-(Condensate and Feedwater System).
' Unit Supervisor
'2.10 At approximately 325 MWe:
2.10.1 Stop all but one Condensate Booster Pump and two Hotwell Pumps.
2.10.'2 '
Place control switches in AUTO.
CAUTION:
If either S/G has a BTU Limit, then a possible FDW (2.11)
Runback could occur.
2.11 Verify that the following are not in alarm before decreasing power below 25%:
ISA-2/C-5 (RC STM GEN "A" BTU LIMIT)
ISA-2/D-5 (RC STM GEN "B" BTU LIMIT) 2.11.1 If either SG has a BTU Limit, then notify the Control Room SR0 for direction on decreasing power below 25%.
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j Page 3 of 3 OP/1/A/1102/04 ENCLOSURE 3.4 POWER REDUCTION (100% TO 15% FP)
Date Init./ Time l
2.12 At 200 MWe, transfer Auxiliaries from 1T to CT1 per OP/1/A/1107/02 (Normal Power).
Unit Supervisor 2.13 At 180 MWe, open the following Shell Drain valves on Moisture Separator Reheaters and HP Heater Vent Orifice Bypasses:
1HD-405 (1A1 FSRH SHELL DRAIN).
1HD-406 (IA2 FSRH SHELL DRAIN).
1HD-407 (1B2 FSRH SHELL DRAIN).
1HD-408 (1B1 FSRH SHELL DRAIN).
1HV-5 ("1Al" Heater Vent Orifice Bypass).
1HV-47 ("1B2" Heater Vent Orifice Bypass).
1HV-12 ("1B1" Heater Vent Orifice Bypass).
2.14 At ~ 135 MWe, if Turbine is to be taken off line:
Close IMS-76 (MS To 1A1 & 1A2 SSRH).
Close IMS-79 (MS To 1B1 & IB2 SSRH).
Verify 1AS-8 (AS To STM SEAL REG) open.
2.15 IF the Turbine / Reactor is to be shutdown, refer to OP/1/A/1102/10 (Controlling Procedure for Unit Shutdown).
_ _ _ _ _ _. _. _. _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _. _. _ _ _ _. _ _ _ _