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OPERATING PROCEDURE OP-204 FLORIDA POWER CORPORATION CRYSTAL RIVER UNIT 3 POWER OPERATION THIS PROCEDURE ADDRESSES SAFETY RELATED COMPONENTS i
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APPROVED BY: Responsible Section Superintendent /
Supervisor Yan Eb-b Or Date $/8 ? fc l
l INTERPRETATION CONTACT: Nuclear Operations Superintendent l
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- l. 8703160138 870305 l PDR ADOCK 05000302
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1.0 PURPOSE 1.1 To describe operation of the plant above 15% of rated power.
Eg[g Section Power Increase 6.0 Steady State Operation 7.0 Power Decrease 8.0 Operation With Three RCP's 9.0 1.2 Procedure cover sheet and applicable section(s) performed will constitute a complete procedure for record purposes.
1.3 This procedure is designed to be perforged by Nuclear Operators l42 reporting to the Shift Supervisor on duty. l
2.0 DESCRIPTION
System Responses:
The expected various parametric system responses for the reac-tor coolant (RC) and steam supply systems are given below.
l Also included are allowable deviations.
2.1 RC SYSTEM (RCS) 2.1.1 RC Pressure During power operations, RC pressure should be saintained at 2155 100 psig by pressurizer heaters and the pressurizer spray valve.
2.1.2 RC Temperature RCS T(ave) will be maintained by control rods. The expected RC temperature (average, inAet and outlet), along with allowable deviations, is specified in Curves 6, and 7 of OP-103A, Operat-ing Curves.
OP-204 Rev. 45 Page 1
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HKC 11/19/85 2.1.3 Pressurizer Level Pressarizer level will be maintained at approximately 200-in.
by the pressurizer level control valve.
2.1.4 When operating in Modes 1 and 2, there must be at least three (3) RC pumps (RCP's) in operation.
2.2 STFlM AND POWER CONVEhSIONS 2.2.1 OTSG outlet Pressure Once-through steam generator (OTSG) pressure versus reactor power, along with expected and allowable deviations, is specified in Curve 8 of OP-103A, Operating Curves.
2.2.2 OTSG Outlet Steam Teacerature OTSG outlet steam temperature versus reactor power, along with expected and allowable deviations, is specified in Curve 9 of OP-103A, Operating Curves.
2.2.3 OTSG Level OTSG (level) versus reactor power for startup range and operating range level instrumentation, along with expected and allowable deviations, is specified in Curves 10 and 11 of OP-103A, Operating Curves, respectively.
2.2.4 Feedwater Flow Feedwater (FW) flow versus reactor poder, along with expected and allowable deviations, is specified in Curve 12 of OP-103A, Operating Curves.
OP-204 Rev. 45 page 2
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s HKC 11/19/85 2.2.5 11 Tenneratures FW temperatures versus reactor power, along with allowable deviations, is specified in Curve 13 of OP-103A, Operating Curves.
2.3 CONTROL RODS Control rod sequencing for the current cycle.
(TS) 2.3.1 control Rod Positionina The operational control rod position limits, as a function of reactor power, are specifie.d in Curves 1 thru 8 of OP-103D, Withdrawal Limit Curves.
3.0 REFERENCES
3.1 OP-603, Condensate System 3.2 OP-605, Feedwater System 3.3 OP-701, Generator Gas System 3.4 OP-304, Soluble Poison Concentration, Control 3.5 AP-116, Pressurizer System Abnormal Conditions 3.6 OP-703, Plant Distribution System 3.7 OP-504, Integrated control System 3.8 OP-208, Plant Shutdown 3.9 OP-103A, Operating Curves 3.9.1 OP-103D, Withdrawal Limit Curves 3.10 OP-501 Reactor Non-Nuclear Instrumentation 3.11 SP-312 Heat Balance Calculation 3.12 SP-113 Power Range Nuclear Instrumentation OP-204 Rev. $ Page 3
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b 4.0 LIMITS AND PRECAUTIONS 4.1 REACTOR CORE LIMITS 4.1.1. Maneuvering Limits 4.1.1.1 The following maneuvering restrictions shall apply during power escalation if reactor power has been < ?0% FP (full power) for greater than 48 hrs., additional restrictions for cycle startuo l39 are given in Step 4.1.1.2. i30
- a. Below 20% FP - 10%/hr.
- b. From 20% to 75 + 2% FP - 30%/hr.
- c. Hold at 75 + 2% FP for a 5 hr. soak.
- d. From 75 to 90% FP - 30%/hr.
- e. Hold at 90 + 2% FP for a 5 hr. soak.
- f. From 90 to 95% FP - 10%/hr.
- g. From 95 to 100% FP-5%/hr.-
i39 i
4.1.1.2 In addition to the above, initial power escalation at cycle startup is subject to the following:
- a. At 40% FP run Incore Detector Correlation test to establisn conservative gain factor.
- b. Power escalation above 40% FP shall not exceed 3% per hour. ,
- c. Hold a minimum of 12 hrs. at 90 + 2% FP.
NOTE: A power level has been reached once that level or higner
' has been maintained at least three (3) days.
OP-204 Rev. 45 Page 4 W
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4.1.2 Tabalance and Ouadrant Power Tilt Limits.
4.1.2.1 Maintain power imbalance per Nuclear Reactor Specialist's Guidance.
4.1.2.2 If the Operator fails to move or moves the axial power shaping rods (APSR's) in the wrong direction, the action could result in a reactor trip.
4.1.2.3 APSR's shall not be inserted or withdrawn more than an incre- .
ment of 5%, after which power imbalance shall be verified.
4.1.2.4 To minimize power tilts, maintain rod position within a group at the same level.
4.1.2.5 Prior to performing a heat balance, insure quadrant power tilt is < 2%.
4.1.2.6 Insure Quadrent Power Tilt is within the limits of S.T.S. l42 3.2.4. l 4.2 REACTOR COOLANT SYSTEM LIMITS 4.2.1 There shall be at least three (3) RCP's in operation.
4.2.2 Reduce reactor power to ( 60'. when initiating four (4) to three (3) RCP operation. Assure prior to tripping the RCP that the T e transmitter is selected for the unaffected cold leg. For RC
- pressure control, select the loop with one (1) RCP in the RPS (reactor protective system) per OP-501, Reactor Non-Nuclear Instrumentation, Section 7.2.
OP-204 Rev. 45 Page 5 l
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NOTE: Te Selector Switch for Punn Shutdown
'A' Loop: For shutdown of RCP 'A", select TT3.
For shutdown of RCP 'B", select TT1.
4.2.3 Do not attempt to start the fourth RCP above 60% FP.
NOTE: Thers is an RCP start permissive interlock that prevents starting above 30t FP.
4.2.4 If pressurizer level falls below the minimum level of Curve 5 l42 of OP-103A, Plant Curve Book, immediately increase makeup flow l to regain level.
4.2.5 Trip the reactor if pressurizer level exceeds 290 inches.
4.2.6 Particular care must be exercised to maintain T h, Tc, and Tave above their lower limits of Curves 6 and 7 of OP-103A, due to the removal of BTU limits. It this can't be done feedwater flow must be reduced.
4.3 SECONDARY PLANT LIMITS 4.3.1 Turbine timits 4.3.1.1 The turbine may not be operated with the reheat stop and/or interceptor valve closed at a load ) 85 MWe. This restriction does not apply for very short periods of time such as when the valves are tested for stem freedos 4.3.1.2 The turbine generator may not be operated below 58.5 Hz. This would result in undue vibration af the last row of turbine blading.
4.3.1.3 Maintain the turbine drains open at 170 MWe load and below.
4.3.1.4 The temperature difference between condenser 3 should not exceed 50'F. If so, the Operator shall trip the turbine.
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vi bration,. limits (double amplitude-mils) are as 4.3.1.5 Turbine follows:
- a. 4.0 mils - Satisfactory
- b. 7.0 mils - Alarm (Investigate if vibration is continuous and of the unbalanced type.)
- c. 14.0 mils - Trip or other suitable action whicn may be load change, speed change, according to specific conditions.
4.3.2 Moisture Seoarator/Reneater limits 4.3.2.1 The reheat temperature should not be allowed to step -chan ge
> 250*F/hr.
4.3.2.2 On startup, increase load above 50% prior to placing the MSR nigh pressure tuce bundles in service.
4.3.2.3 Do not operate for more than 48 continuous hours below 50% loac with the high pressure tube bundle in service. If tne load is reduced and held below 50% for 48 hrs., either increase load to above 50% or remove the MSR nign pressure tube bundle from service.
4.3.2.4 l'or cyclic operation where loads are cycled above anc below 50%
on a daily basis, the MSR hi gh pressure tube bundle snould remain out of service.
4.3.2.5 Infrequent excursions from above 50% load to below 50% load for snort periods of a few minutes to a few hours are not considered cyclical operation on a daily basis. Therefore, tne MSR high pressure tuce bundle need not ce removed from service for these excursions.
45 page 7 OP-204 Rev.
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4.3.2.6 If operating below 50% load with the high pressure tube bundle out of service and the unit is to be shut down, the high pressure tube bundle should remain out of service.
4.3.2.7 If one (1) MSIV is closed, manually reduce power to 60$..
4.3.2.8 Trip the reactor if:
- a. Two (2) or more main steam isolation valves (MSIV's) are closed.
- b. FW flow is lost.
4.3.2.9 Do not change the OTSG startup range level transmitters on both OTSG's at the same time.
4.3.3 Steam and Feedwater 4.3.3.1 Particular care must be taken to ensure OTSG outlet pressure is saintained below the apper limit of Curve 8 OP-103A, due to deletion of BTU limits. Reduce feedwater flow if this can't be done.
4.3.3.2 Feedwater temperature must be maintained at or above the lower limit of curve 13, OP-103A, due to removal of BTU limits. If feedwater temperature decreases below this limit feedwater flow must be reduced.
4.3.4 Generator Limits j44 4.3.4.1 Hydrogen cooler gas outlet temperature shall be maintained 1 l 46*C. l 4.3.4.2 Exciter intake air temperature shall be maintained 1 55*C. l 4.3.4.3 Maximum stator coil discharge gas temperature differential:
l No Load 4 C A T l
214 MWe 5*C AT l 427 MWe ,
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- C AT l 641 MWe 7'C AT l Full Load 7.5
- AT l 4.3.4.3.1 Trip the Main Turbine if the stator coil discharge gas tempera- l ture differential is J. 8'C. l 4.4 ADMINISTRATIVE LIMITS 4.4.1 In the event of an unscheduled load reduction, the power level shall not be increased until an investigation has been conducted and any necessary corrective action taken.
4.4.2 ChenRad must be notified of each power change J.15% in any 1 hr. period.
OP-204 Rev. 45 Page 8 (Continued on Page 8a)
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5.0 SET POINTS 5.1 PRESSURIZER LEVEL:
High - 220 in. Normal - 200 in.
Low - 160 in.
High-High Level Alarm: 275 in. .
Low-Low Level Alarm: 40 in. .
Low-Low Level Interlock: 40 in.
Pressurizer Temperature:
Computer Alarm High - 662*F Normal - 647'F l
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e HKC 11/19/85 5.2 RFACTOR COOLANT SYSTEM NARROW RANGE PRESSURE-High Alara Annunciator: 2255 psig Low Alara: 2055 psig Normal Operating Indicating: 2155 psig 5.3 REACTOR COOLANT SYSTEM WIDE RANGE PRESSURE Alarms on Computer-High: 2255 psig Low: 1600 psig Normal: 2155 psig 5.4 LOOP OUTLET TEMPERATURE-ComputerAlarIHigh: 507'F Normal Operating Temperature: See Curves 6, and 7 of OP-103A, Operating Curves.
5.5 HHIT OUTLET NORMAL TEMPERATURE: See Curves 6, and 7 of Op-103A, Operating Curves.
5.6 LOOP NARROW AND WIDE RANGE INLET TEMPERATURE-Normal Operating Temperature: See Curves 6, and 7 of OP-103A, Operating Curves.
5.7 LOOP DIFFERENTTAL TEMPERATURE INLET TO OUTLET-Normal Operating: 46*F 5.8 LOOP UNIT AVERAGE TEMPERATURE: 579'F T(ave) 5.9 LOOP INLET TEMPERATURE DIFFERENTIAL-Annunciator High: +5 Low: -5 5.10 PRESSURIZER SPRAY LINE TEMPERATURE-Low: 450*F Normal Operation: 480 to 580*F OP-204 Rev. 45 page 9 m__ . _ . _ , . . _ _
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5.11 TOTAL RC FLOW-Low: 125 x 106 lbs/hr.
5.12 CODE RELIEF VALVES-Open at 2500 psig close at 2450 osig 5.13 PRESSURIZER POWER-ACTUATED RELIEF VALVE-Opens at 2450 psig closes at 2380 psig 5.14 PRESSURIZER HEATER BANK SET POINTS-SCR Control .
A B C D E On l2135 2135 2147 l 2120 2105 psig Off 2155 2155 2155 2140 2125 psig 5.15 CONTROL ROD DRIVE (CRD) SPEED-Run: 30 in/ min.
Jog: 3 in/ min.
5.16 CRD RUNBACX FAULT ASYMMETRIC R00:
If the Reactor Control Station is in " Auto" and unit load demand is > 60% FP, the reactor will automatically run back to i
l 60% unit load demand and a rod out-inhibit will exist if any of the following conditions are met:
- a. Any safety rod not out and a > 9-in, fault. l40 i
- b. In limit on any safety rod. l, t
- c. Group 5 in limit and a > 9-in. fault. }
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l 5.17 LETDOWN BLOCX ORIFICE FLOW-Normal Operating: 45 gpm 5.18 Letdown Flow Maximun Operating: 140 gpm 5.19 Letdown Temperature Normal Operation: 120*F 5.20 Letdown Temperature High: 130*F MUV-49 High Temperature Interlock Set Point: 135'F 5.21 RCP SEAL-
- a. Seal Injection Flow Low Alarui: 3 gpm Normal: 8 gpm
- b. Controlled Bleed-Off Flow .
High Alarm: 1.75 gpm Normal: 1.5 gem 5.22 MAKEUP TANK (MUT) LEVEL-High Alarm: 86 in, water Low Alarm: 55 in, water l Normal Operating: 60 to 80 in, water If in the " Bleed" mode, MUV-112 (th ree-way valve) will
, l20 reposition to change flow to the MUT at 21-in. The low-low t
l l level alarm will actuate at 13-in and MUV-58 and MUV-73 *ill l l
open. )
5.23 Loss of one (1) FW pump (FWP) or FW booster pump runback to 55" I unit load demand.
1 0P-204 Rev. page il 45
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HKC 11/19/85 5.24 The temperature difference between multiple condensers alarms at 40*F 5.25 Turbine Exhaust hood high temperature alarm - 175'F 5.26 Turbine Trip on exhaust hood temperature 250*F.
PROCEDURE 6.0 POWER INCREASE laitials 6,1 INITIAL CONDITIONS 6.1.1 The plant is at 15% Rated Thermal Power (RTP) or above.
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Date Time 6.1.2 Plant parameters are within the limits of Curves 6 thru 13 of OP-103A, and Curves 1 thru 9 of OP-103D.
6.1.3 The RCS is approximately 579'T T(ave) and 2155 psig.
6.1.4 Pressurizer level is approximately 200-in. with pressurizer level controller in ' Auto."
6.1.5 MUT level is = 73 inches of water and MUT pressure is
= 10 psig.
6.1.6 All "ICS" (integrated control system) stations may be in
' Auto
- except the idle FWP and Unit Load Demand Station.
6.1.7 The reheater control system is energized.
6.1.8 At least three (3) RCP's are in operation.
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6.1.9 Main FWP (MFWP) tripped bistables in RPS cabinet are reset.
OP-204 Re'v. Page 12 45
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A Initials 6.2 PROCEDURE C&DTION: Maximum steam flow to the high pressure turbine shall not exceed 11.03 MLBS/HR as l43 indicated by computer point $982
- total feedwater flow.'
6.2.1.1 Determine rate of load change from Maneuvering Limits (Section 4.1.1) and systen load dispatcher recommendation and adjust unit master rate limit accordingly.
6.2.1.2 OTSG 'A' and 'B' 1-1/2' drain /blowndown valves in the reactor building must be closed within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after reaching 15\ power per Enclosure I. (See time recorded in Step 6.1.1) 6.2.1.3 If reactor power has been < 20% FP for greater than 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />, the following maneuvering restrictions apply:
- a. Below 20% FP - 10\/hr.
- b. From 20% to 75 2\ FP - 30'./hr.
- c. Hold at 75 29 FP for a 5 hr. soak.
- d. From 75 to 90% FP - 30\/hr.
- e. Hold at 90 2% FP for a 5 hr. soak.
- f. From 90 to 95% FP - 10\/hr.
- g. From 95 to 100% FP - 5%/hr.
OP-204 Rev. 4 5 Page 13 h
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Initials 6.2.2 Start second FW booster pump per OP-605, Feedwater System.
6.2.3 Set load demand to desired MWe power.
6.2.3.1 Maintain terminal voltage at 21.5 kV or as specified by Dispatener.
CAUTION: Veri fy indicated terminal voltage by cross-checking to assure exciter current inc voltage are in appropriate range.
6.2.3.2 Notify Chemistry Department of any power enange y,15t in any 1 hr. period.
l39 6.2.4 At 170 MWe, perform the following:
6.2.4.1 Close the following turoine drain valves:
TDV-1 TDV-2 TDV-3 TDV 4 TDV-5 TDV-6 TDV-7 TDV-8 TDV-9 TDV-10 Page 14 OP-204 Re . 45 _
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Initials 6.2.4.2 Transfer plant auxiliary loads for normal operation per OP-703, Plant Distribution System, 6.2.4.3 Transfer deareator vents to atmosphere by: l45
- a. Close the following valves:
l HVV-1, HVV-3, HVV-4, HVV-7, and HVV-67. l
- b. Open 1/2 turn each: HVV-2, HVV-5, HVV-6, and HVV-8. l
- c. Open HVV-103 until a slight amount of steam is visi-l ble out of the vent on the roof top.
l 6.2.4.4 Place the following valves in ' Auto".
- a. HDV-250, Drain to Condenser 3A
- b. HDV-247, Drain to Condenser 3B
- c. HDV-249 Drain to Condenser 3A
- d. HDV-248, Drain to Condenser 3B 6.2.5 At 225 MWe and only three (3) RCP's are operating, go to Section 9.0 of this procedure if three (3) RCP operation is allowed.
CAUTION: Proceed quickly through FW control mode
( transition to avoid operation in an unstable region.
- l 6.2.6 a. At 350 MWe, start second condensate pump per OP-603, Condensate System.
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HKC 11/19/85 Initials ti . 2. 6.1 If load is to be increased ) 50% MWe, open MSV-484, 485, 486, 487, 29, 30, 31, and 32, then depress " Ramp' for cold startup. Close MSV-59, 60, 61, 62, 477, 478, 479, and 480.
6.2.6.1.1 Insure that all step-up transformer cooling pumps and fans are in ' Manual' and operating.
6.2.6.2 For hot startup with reheat temperature 2 400', place reheater control in ' Manual' and slowly open MSV-49, 50, 51, and 52 by turning centrol knob from 'O' to *10' over a period of 1 hr.
6.2.7 Place the oncoming MFWP control station in " Auto".
6.2.8 Cicse FWV-28, MTVP crosstie.
6.2.9 As necessary, adjust generator hydrogen pressure to capability curve per OP-701, Generator Gas system. Refer to Curve 14 of Op-103A, Operating Curves.
6.2.10 Verify MFW block valve FWV-29 and FWV-30 Man / Auto switches in " Auto".
6.2.11 Set unit load master and load rate ICS modules for steady load increase through block valves.
6.2.11.1 At approximately 450 MWe, and approximately 3x10 6 LBM/hr feed flow in each FW loop observe the following:
6.2.f1.2 ' VERIFY FWV-29 ON AUTO' and ' VERIFY FWV-30 ON AUT0" alarms are lit.
6.2.11.3 Verify that MFW block valves FWV-29 and 30 open normally.
6.2.12 Perform SP-312, Heat Balance Calculations and recalibrate NI's, if required, upon reaching 50% power.
OP-204 Rev. 45 Page 16
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Initisls 6.2.13 Perform SP-312, Heat Ba' lance Calculatic, , and recalibrate nuclear irstruments (NI's), if required, upon reaching 75% power.
6.2.14 Perform SP-312, Heat Balance Calculations, and recalibrate NI's, if required, upon reaching 100% power j.
or highest attainable power level. ;_,
/ 1 7.0 STnDY STATE CONDITIONS 7.1 INITIAL CONDITIONS -
The nuclear steam system has teen brought to a condition where load equals loac' demand.
7.2 PROCEDURE 7.2.1 Maintain the axial pcuer imbalance between -in and 0%
or, preferably, between -10% and 0%. If an oscillation large enough to cause abalance to approach the reactor trip setpoint starts, contact the reactor specialist.
Attempts to dampen an oscillaticn at the wrcng time can amplify the oscillation. The cest time to. correct an oscillation is 1 to 2 hrs, before the peak, deviation and then use rods to force the imbalance to its average j value.
7.2.2 Maintain control rods within the recommended rod configurations per power level versus rod :nsitions 1
(Curves 1 thru 9 of OP-103D, operating Curves, as s t ,
, applicable) by boration or deboration for fuel burnup or
- OP-204 Rev. 45 Page M
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ls>f 1 alares will have to te citanged periodically throughout
. the. life of the core and as a function of RCP configura-
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7.2.3 If a BTU limit alarm occurs, reduce feedwater flow until W.
the alarm condition clears or the alarm is croved to be j invalid. .
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n ,i> 8.0 POWER DECREASE!
8.1 INITIAL CONDITIONS
~ 8.1.1 Powr reduc' tion is desired.
8.2 PROCEDURE 8.2.1 Advise plant personnel of load reduction as necessary.
/ .8.2.2 Comence load decrease.
8.2.2.1 " Inform Chemistry De$artment of any powr change > 15% in any 1 h. . period.
8.2.2.2 If power reduction is being made to allow three (3) pumo operation, have Instruments and Controls (I & C) Techni-cian reduce high RPS trip set point per SP-113, Poner Range Nuclear Instrumentation Calibration, and reduce ICS rseactor Demand high load limiter to 75%.
CAUTION: Proceed quickly through c'4 control mode l transition to avoid operation in an unstable t
region.
8.2>3- If load is to be reduced below 50% MWe for greater than F
l 48 hrs., remove high pressure bundle from service by i ~ clos'ing MSV-29, 30, 31, 32, 484, 485, 486, and 487, then j depress " Reset" on reheat control canel.
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OP-204 Rev. .A$_ Page 18
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! Initials
. o. a 8.2.4 When load is, < 400 MWe, secure one (1) condensate pump N per OP-603, Condensate System.
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3 8.2.5 When load is reduced to < 350 MWe, remove one (1) MFWP and one- (1) FW booster pump from service per OP-605, T
Condecsate System.
t 8.2.6 If turbine is to be shut down, transfer plant auxiliary 6
loads to Unit 3 startup transformer at 225 MWe OP-703, Plant Distribution System.
(
8.2.7 (Deletad) 8.2.8 When load is at 170 MWe, RR.in turbine drain valves.
8.2.8.1 At 179 MWe, verify ASV-21 and 22, auxiliary steam supply
, at MFWp's, are open. 1 8.2.8.2 Reduce gland sealing steam pressure on the main and feed- l45 water pump turbines as far as possible without causing a l significant loss of vacuum.
l 8.2.8.3 Secure venting the deareator to atmosphere and begin l-venting to the condenser by:
- a. Closing HW-2, HW-5, HW-8, HW-6, and HW-103.
- b. Open 1/2 turn each, HW-1, HW-3, HW-4, HW-7.
- c. Fully open HW-67.
8.2.9 When either OTSG goes on low level control, place the Te load ratio control station in ' Hand."
8.2.10 When load is 128 MWe, continue plant shutdown per CP-208, Plant Shutdown.
OP-204 Rev. 45 eage n 2hh ( N*m's 8 E
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4 Initials 9.0 OPERATION WITH THREE RCP'S 9.1 OPERATION WITH TWO RCP'S IN ONE LOOP AND ONE RCP IN THE OTHER LOOP NOTE: Ensure that I & C Tecnnicians have reduced nign ,
RPS trip set point per SP-113, Power Range Nuclear Instrumentation Calibration, and have reduced Reactor Oemand high load limiter to 75t.
9.1.1 Assure running MFWP is in " Auto."
9.1.2 Start the second MFWP per OP-605, Feedwater system.
9.1.3 Increase pump speed until both MFWP discharge pressures are equal and FW system is stacle.
9.1.4 Place second MFWP in " Auto."
9.1.5 Close crosstie, FWV-28.
9.1.6 Assure ICS is stabTe prior to proceeding with the following steps.
i CAUTION: Proceed quickly througn FW control mode f
I
' transition to avoid operation in an unstable region, l
i 9.1.7 Increase power to the point of opening MFW olock valve.
9.1.7.1 At 350 MWe, start second condensate pump per OP-603, l
' Condensate System.
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OP-204 Page 20 Rev. _4 5 l
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Initials 9.1.8 Assure that both steam generators are being controllad above minimum level and 6Te is 'O." [42 9.1.9 Prior to low load control valve exceeding 90% open on the loop with two (2) RCP's, place the MFW block valve toggle switch in the " Auto" position. Assure the other MFW block valve is closed and the toggle switch is in the
' Manual" position.
9.1.10 Set load rate at 3% per minute and increase load to 60'.
plant output. The MFW block valve in the loop with two (2) RCP's should go to the full open position.
9.1.11 Assure the plant is stable, then proceed.
9.1.12 If load is to be increased 50% MWe, open MSV-29, 30, 31, 32, 484, 485, 486, and 487, then depress ' Ramp" for cold startup. Close MSV-59, 60, 61, 62, 477, 478, 479, and 480.
9.1.12.1 For hot startup with reheat temperature J. 400', place reheater control in ' Manual' and slowly open MSV-49, 50, l 51, and 52 by turning control knob from *0' to '10' over i
a period of 1 hr.
l l
9.1.13 As necessary, adjust generator hydrogen pressure to capability curve per OP-701, Generator Gas System. Refer to Curve 14 of OP-103A, Operating Curves.
i 9.1.14 Stop power escalation at approximately 75%.
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OP-204 Rev. 45 page 21
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n ENCLOSURES Enclosure I - OTSG Drain Header Isolations s
OP-204 Rev. 45 page 22 b
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ENCLOSURE I OTSG DRAIN HEADER ISOLATIONS
'A' OTSG OPEN CLOSED MSV-124 MSV-125 -
MSV-126 MSV-127
'B' OTSG MSV-142 MSV-143 MSV-144 MSV-145 Lineup Completed: /
Date ilme OP-204 Rev. 45 _
page 23 (tAST PACE)
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