ML17054B068
| ML17054B068 | |
| Person / Time | |
|---|---|
| Site: | Nine Mile Point  |
| Issue date: | 10/31/1984 |
| From: | NIAGARA MOHAWK POWER CORP. |
| To: | |
| Shared Package | |
| ML17054B069 | List: |
| References | |
| PROC-841031, NUDOCS 8410110094 | |
| Download: ML17054B068 (190) | |
Text
NINE
- MILE POINT UNIT 2 PLANT SPECIFIC EMERGENCY PROCEOURE GUIOELINE REV. 0*
BWR 5 October 1984 8410110094 841005 PDR ADOCK 05000410 F
- Subject to Verification
It II
TABLE I ABBREVIATIORB Automatic Depressurization System APRM Average Power Range Monitor ARM Area Radiation AMonitor CRD Control Rod Drive DRMS Digital Radiation Monitoring System ECCS Emergency Core Cooling System HCU Hydraulic Control Uni t HPCS High Pressure Core Spray HVAC Heating, Ventilating and Air Conditioning LCO Limiting Condition for Operation LOCA
Los s o f Coo lan t Acc iden t LPCI
Low Pressure Coolant Injectio'n {mode of RHR)
Low Pressure Core Spray MSIV
Main Steamline Isolation Valves NDTT
Nil-Ducti1 it y Transition Temperature NPSH Net Positive Suction Head RCIC
Reactor Core Isolation Cooling RHR
Residual Heat Removal RPS Reactor Protection System RPV Reactor Pressure Vessel RSCS Rod Sequence Control System Rtv'CU Reactor Mater Cleanup SBGT Standby Gas Treatment S LC S tandby Liquid Control SORV Stuck Open Relief Valve Safety Relief Valve
{I-4)
-18 May 1984
OPERATOR PRECAUTIONS GENERAL 1
This section l.ists "Cautions" which are general ly applicable at all times.
CAUTIOiN !'1 Monitor the general state of the plant.
It an entry condition for - n Emergency Operation Procedure
- occurs, enter that procecure.
Vhen i,t is determined that an emergency no longer exists, enter normal operating p rocedures.
CAUTION:.'Ii2
,'monitor RPV water level and pressure ano primary containment temperatures
'nd pressure from multiple indications
~
CAUTION:;3 I f a safety
~ unction initiates automaticaliy, assume a true ini:iating event has occurred unless-otherwise confirmec by at least two indepencent ind icat inns CAL"TKGil !:4 iv'her eve.
R:-:R is in the LPCI mode, inject through the heat excnangcr~
o~
soon as possible.
4,
OPERATOR PRECAUTIONS (Cont. )
CAUTION Pi5 Suppression pool temperatue is determined by calculated process computer point
~
Drywel 1 temperature is determinea by calculateo process computer point.
If the process computer is unavailable the hignest avaziaoje indication of Drywel 1 or Suppression Pool temperature is assumea to be the average temperature.
CAUTION iso whenever Drywell temperature exceeds the temperature in the table and
'he instrument reads below che indicated level in the table, the actua l.
RPV water level may be anywhere below the elevation of the lower instrument tap.
Terr. erature
("")
) 80'F 193' 549'F Indicated Level 236 in.
250 in ~
Downscale Instrumen t Shutaown Ran:= Level Upset Range Ride Range Level 147 to 547 in.
147 to 327 in ~
-~ to 267 in.
549' 549'F Downscale Downsca le Narrow Range Leve 1 I
Fuel Zone Level 147 to 247 in.
to 36 in,
'CAUTION if7 Continuously monitor operating
- RHR, LPCS and HPCS pumps for signs o f cavitat on when suppression pool level is less than 16 feet anc temperature exceeds "12'F.
Continously monitor RCIC pump for signs of cavitation when suppression pool temperature exceeds 170'F
~
Throttling system flow is one means of lowering requirea NPSh
OPERATOR PRECAUTIONS (Cont.)
CAUTION //8 If signals of high suppression pool water level or low condensate storage tank water level occur, confirm automatic transfer of or manually transfer HPCS and RCIC suction from the conaensate storage tank to the suppression pool.
'PEC1FIC This section lists "Cautions" Which are applicable at one or more speci'ic points within the guidelines
~
Where a "Caution" is applicable, it is identified with the symbol /
'r /
~
(.ACTION !F9 Do not secure or place an ECCS in MANUAL mode u"..'.ass, by at'east two independent indicatons," (1) misoperatior. in AUTO.".ATIC mode is confirmed, or (2) adequate core cooling is assurea.
If an
=CCS is placea in HANUA'ode, it will not initiate automatically
~
Make frequent checks of the initiating or controlling parameter.
When manual operat on is no longer required, restore the system to AU'OMATIC STANDBY mode i f possible
~
GAUTIui~ ~;-'10 I r a h;=.h crywell pressure ECCS initiation signaL l.oo psi=
cours or exists while depressurizing, prevent injection from those LPCS anu LPC 1 pumps not required to assure adequate core cooling prior to r~acning their maximum injection pressures
~
When the high drywel i pressure ECCS initiation signai clears, restore LPGA and LPCI to AUTOMATIC/STANDBYmode.
I-7
-21 Mav 1984
OPERATOR PRECAUTIONS (Cont. )
CAUTIOh till Do not throttle the RCIC system below 2200 rpm
~
CAUTL(ph >F12 Cooldown rates above LOO'F/nr may be requirea r,o accompixsn thxs step.
CAUTION </L3 Do not depressurize the RPV below 50 psig unless motor driven pumps sufficient to maintain RPV water Level are running and available for xn lee t xon
~
CAUTIUb >F14 Open SRVs in the following sequence i f possioxe:
PSV-x2o,
- L33, 12~,
- 136, 131,
- 122, 120,
- 132, 125,
- 121, 135, 1"6, 1.30, 127>
1"".>
L37>
L34
~
(AUTIOh i.>15 Bypassing
'low RPV water Level
>1SLV isolatxon int~rloc~s.ay be recuxreu to accompixsh thxs step.
CAUTIOYi >P16 Cooldown rates above L00'F/nr may be requirea to conserve RPV water inx'.tory, protect primary containment integrity, or limit radioactive release to the environment.
I-
-22 Mav 1984
OPERATOR PRECAUTIONS (Cont.)
CAUTIOh d17 If continuous LPCI operation is required to assure adequate core
~
CAUTION 818 Confirm automatic trip or manually trip SLC pumps ac "Zero" level in the SLC tank.
CAUTION ipl9 Defeating RSCS interiocks may be required co accompl.ish this. step.
CAUTION r 20-Elevated suppression chamber pressure may trip the RCIC turbine on high pressure.
CAUTION Defea'ting isolation interlocks may be required co accompli.1sn this seep
~
CAUTION <-'22 Bypassing high drywell pressure and low RPV water level secondary containment hVAC isolat1on interlocks may be requxreo co acccmpl1sn ch1,s seep
~
-23 Hay 19S4
OPERATOR PRECAUTIONS (Cont.)
CAUTIOh l723 A rapid increase in injection into the RPV may induce a large power excursion and result in substantial core damage
~
CAUTION ~<'>w Large reactor power oscillations may be observec while executing t'nx~
1 step.
( I-lO)
-24 Mav 1984
RPV CONTROL GUIDELINE PURPOSE The purpose of this guideline is to'.
o Haintain adequate core cooling, o
Shut down the reactor, and o
Cool down the RPV to cold shutdown conditions 100'F RPV Rater Temp.
200'F.
ENTRY CONDITIONS The entry conditions for this guideline are any of the following:
o
~
RPV water level below 159,3 in.
o RPV pressure aoove 1037 psig o
Drywell pressure above 1.68
~
~
~
o A conaition which requires HSIV isolation o
A condition which requires reactor
- scram, ann reactor power abov~
4~.
o r cannot be determined.
OPERATOR ACTIONS RC-1 E
If reactor scram nas not initiated, initiate reactor scram.
'.rrespective of the entry condition, execute (Steps RC/L, RC/P, arc
.C/Q) c onc "trent }.y.
RC/L.'monitor and control R?V water l.evel
~
RC/L-1 C nfirm initiaton of any oi tne following:
o iso lat icn o
ECCS initiate any of these which should have inxtiateo but die not.
-25 Hay 1984
OPERATOR ACTIONS (Cont)
If while executing the following steps:
o Boron Injection is required, enter (procedure developed from CONTINGENCY
)F 7)
~
o RPV water level cannot be determined, RPV FLOODING IS REQ1 lb~b; enter (procedure developed from CONTINGENCY ri6)
~
o RPV flooaing is required, enter (proceaure developed from CONTINGENCY iP6)
~
RC/L-2 Restore and maintain RPV water level between 159
~ 3 in. ano 202.3 in..
with one or more oi the following systems:
i 8 l) 9 o
Condensate/feedwater system 1 "05-0 psig.
o CRD system 1205-0 psig.
o RCIC system 1130-50 psig.
o HPCS system 1160-0 psig
~
o LPCS system 289-0 psig.
o LPCI svstem "80-0 psig
~
lf RPV water level cannot oe restorea ana maintaanec aoov~
159
~ 3 L n~ ~
maintain RPV water level above
-14 in.
( RC-2)
-26 May 1984
OPERATOR ACTIONS (Cont)
If RPV water level can be maintained above -14 in. and the ADS timers have initiated, prevent automatic RPV depressurization by resetting-the ADS timers
~
If RPV water level cannot be maintained above
-L4 in., enter (procecure deve lope d from CONTINGENCY
~i1 ).
If Alternate Shutdown Cooling xs required, enter (proceaure developec i
from CONTINGENCY ~F5).
RC/L-3 Proceed to cold shutdown in accordance with N2-0P-iGL.
RC/P
.'monitor and control RPV pressure.
1 I
If while executing the following steps:
0 Emergency RPV Depressurization is anticipated, rapidly:;L2
~
depressurize the RPV witn the main tur'oine bypass va ves.
0 Eme "ency RPV Depressurization or RPV Flooding is requirec and Less than 7
SRVs are open, enter (proceuure deveiopec from CONTINGENC Y P2 )
~
RPV Flooding is required and at least 7
SRVs are open, enter (procedure developed from CONTINGENCY i:6)
~
RC/P-1 If any SRV is c:cling, manu'ally'pen SRVs until RPV pressure drops to 940 psig.
( RC-3)
-27 Hay 1984
OPERATOR ACTIONS (Cont)
If while executing the following steps:
o Suppression pool temperature cannot be maintained below the Heat Capacity Temperature Limit, maintain RPV pressure below the Limit~
See Figu're 9
I R
o Suppression pool water level cannot be main==inca below the Suppression Pool Load Limit, maintain RPV pressure below the limit.
See Figure 2
o Steam Cooling is required, enter (procedure developed fr<<
CONTINGENCY (P 3 ).
(RC-4 )
-28 Hay 1984
OPERATOR ACTIONS (Cont)
If while executing the following steps:
o Boron Injection is required>
and o
The main condenser is available, ana o
There'as been no indication of gross fuel failure or sceam line
- break, I
open.'iSIVs co re-establisn the main condenser as a heat sink.
j:-'t5 RC/P-2 Control RPV pressure below 1076 psig with che main turbine bypass valves.
RPV pressure concro 1 may be augmenced by one or more of che following syscems:
l I '.-l~
,i o
SRVs only wnen suppression pool wacer ievei is aoove 6 ft ~ If the continuous SRV pneumatic supply is or becomes unavailable, depressurize wic'.". suscaineo
<<<<I SRV opening.
o RCIC R4'Cl: (recirculacion moae) if no boror. has been in'~ccec inco che RPV.
.':ain sceam line drains R'~CU (blowdown node) it,no boron has been injeccea inc o che
- RPV, Refer to sampling procedures prior co initiating blowdown.
If while execucing che following steps che reactor is noc
- shutdown, return to (Step RC/P-2)
~
(RC-5)
-29 Hay 1984
OPERATOR ACTIONS (Cont )
RC/P-3 When either:
o All control rods are inserted beyond position 00, or o
608.5 pounds of boron have been injected into the
- RPV, o
The reactor is shutaown and no boron has been injected into the
RC/P-4 When the RHR shutdown cooling interlocks clear, initiate the shutdown cooling mode oi RHR.
If the RHk shutaown cooling mooe cannot be estaolishea and further cooldown is required, continue to cool down using one or more oi the systems used for depressurizatxon.
if RPV cooldown is required but cannor be accomplished and all contro i rods are inserted beyond position 00, R. QUIRED t ALTERLATE SHU1DGWii CUGLiiiO Ih enter (procedure ceveloped from CGNTILXGiXCY:;.5).
RC/P-5 Proceed to cold shutdown in accordance with N"-CP-'.Ol RCIQ
.'!onitor and control reactor power.
If whi'le executing the following steps o
0 All control rods are inserted beyona posit won 04, ter"...xn~te borui injection and enter (scram procedure).
The reactor is snutaown and no boron has been in;ectec into the RPV, ente r (scram procedure).
(RC-b)
-30 Mav 1984
OPERATOR ACTIONS (Cont )
RC/Q-1 RC/Q-2 Confirm or place the reactor mode switch in SHUTDGWb;.
If the main turbine-generator is on-line and the HSIVs are open, confirm or initiate recirculation flow runback to minimum.
RC/Q-3 If reactor power is above 4% or cannot be determined, trip the recirculation pumps.
Execute (Steps RC/Q-4 and RC/Q-5) concurrently.
RC/Q-4 If the reactor cannot be shutdown before suppression pool vl6 temperature reaches ill'2, BORON INJEC'IIOh IS REQUIRED; inject boron into the RPV with SLC and prevent automatic initiation of ADS.
I f boron cannot be injected with SLC, injec" boron into the RPV by on or more of the following alternate metnods:
o CRD o
HPCS o
R'~C L' Peec'ater o
- ".varo Pump RC/Q-4
~ 1 I: boron is not being injected into the RPV b r R'n'CL, confirm automatic isolation of or manually isolate RVCL' RC/Q-4.2 C ntinue to ingect boron until 6QS.5 pounos oi boron nave been injected into the RPV.
RC/Q-4.3 Enter (scram procedure).
(RC-7)
-31 Nay 1984
OPERATOR ACTIONS (Cont)
RC/Q-5 Insert control rods as follows:
RC/Q-5.
1 If any scram valve is not open:
o Remove Fuses:
C71-F1SA (P609)
Cil-F18E (P609)
Cjl-F18C (P609)
Cjl-F18G (P609)
C71-F18B (P611)
C71-F18F (P611) o Close C12-F095 C71-FIED (P61 1)
Cjl-F18H (P61 1)
Close CI.2-FOSS Remove RDS-PI13 3 Open C12-F088 Nhen control rods are not moving inward:
o Rep lac e ruses:
C7).-F18A
( P609
)
C71-FISE (P509)
Cil-F18C (F609)
Cjl-F18G (P609)
C71-F1SB (P6l.l)
Cil-F18F (F611)
Cil-F18D (P611)
Cjl-FlbH (P611) o Close C12-F088 Replace RDS-P1133 Open C12-F088 Open C12-F09 5 (RC-8)
-32 May 1984
OFERATOR ACTIONS (Cont)
RC/Q-5.2 Reset the reactor scram If the reactor scram cannot be reset Start all CRD pumps.
If no CRD pump can be startea, continue in this procecure
'7l
~
at (Step RC/Q-5.6.1)
~
Close C12-F034
'apidly insert control rods manually until the reactor scram can be reset.
Reset the reactor scram.
5.
Open C12-F034.
RC/Q-5.3 If the scram discharge volume vent and drain valves are open, initiate a manual reactor scram.
l.
If control rods moved inward, return
".. (Step RC/Q-5.2)
~
2.
Reset the reactor scram.
Ii tne reactor scram cannot be reset, continue in this procedure at (St'ep RC/Q-5.5.1).
3.
Open the scram discharge volume vent anu drain valve~.
RC/Q-5
~ 'ndividually open the scram test switches for cont.oi roos not insertec beyona position 00.
4ihen a control rod is not moving inwarc, c)ose its scram tes c
switches RC/Q-5.5 Rese-the reactor scram.
If tne reactor scram cannot be reset 1.
Start all CRD pumps.
If no CRD pump can be started, continue in this proceaure at (Step RC/Q-5.6.1).
2.
Close C12-F034, HCU accumulator charging water header valve (RC-9)
-33 Nay 1984
OPERATOR ACTIONS (Cont)
RC/Q-5.6 Rapidly insert control rods manually untii aii concror siy~
rods manually until all control rods are inserted beyond position 00.
IE any control rod cannot be inserteo beyonc position 00:
1.
Individually direct the ef fluent from C12-F102 to a
contained radwaste drain and open C12-FGli Eor eacn control rod not inserted beyond position 00.
2.
'Khen a control rod is not moving inwara, c lose its C12-F102 CRD withdraw line vent valve
~
( RC-10)
.-34 Hay 1984
PRIMARY CONTAINMENT CONTROL GUIDELINE PURPURE The purpose of this guideline is to:
o Maintain primary containment integrity, and o
Protect equipment in the primary containment.
ENTRY CONDITIONS The entry cnditions for this guideline are any of the following:
o Suppression pool temperature above 95'F
~
o Drywell temperature above 135'F.
o Suppression pool water level above 25'.
o Suppression pool water level below 23'6".
o Drywell pressure above 1.68 psig
~
OPERATOR ACTIONS Irrespective of the entry condition, execute (Steps SP/'1, DW/T, PC/P, and SP/L) concurrently.
SP/T Monitor and control suppression pool temperature.
SP/T-l Close all SORVs.
SP/T-2 If any SORV cannot be closed, scram the reactor.
When 'suppression pool temperature exceeds 95'F, operate available suppression pool cooling.
SP/T-3 Before suppression pool temperature reaches 111'F, scram the reactor.
-35 May 1984
OPERATOR ACTIONS (Cont. )
SP/T-4 If suppression pool temperature cannot be maincainea below the Heat Capacity Temperature Limit, maincain RPV pressure below the Limit ~
ri 12
- r13 If suppression pool. temperature and RPV pressure cannot be rescorea and maincained below the Heac Capacity Temperacure Limit, Ehiki Eel.h RPV DEPRESSURIZATION IS REQUIRED: enter (procedure developers from che RPV Concrol Guideline) at (Seep'C-1) anc execuc<<
1 c one rr<<nt;y D+'/ T O'/T-1 wicn this procedure
~
.'1onicor ana control d rywel 1 temperature.
'~hen drywel 1 temperature exceeds 135'F, operate available dry.ell cooling.
< -':n Execute (Steps D4'/T-2 and DV/T-3) concurrently.
(PC-2)
-36 Mav 1984
OPERATOR ACTIONS (Cont. )
DW/T-2 If drywell temperature (near the cold reference leg instrument vertical runs) reaches the RPV Saturation Temperature, RPV FLOODING IS REQUIRED; enter (procedure developed from the RPV Control Guideline) at (Step RC-1) and evecure it concurrently with this procedure.
-37
.fay 1984
OPERATOR ACTIONS (Cont
~ )
DW/T-3 Before drywell temperature reaches 340'F but only if suppression chamber temperature and drywel 1 pressure are below the Drywell Spray Initiation Pressure
- Limit, shutdown recirculation pumps and drywell cooling fans and initiate drywell sprays restricting flow rate to less than 268 gpm.
See Figure 4
dry'we 1 1 temperature cannot be maintained be low 3-v't',
E.~b~v='~i'c RP'V DEPRESSURIZATION IS REQUIRED; enter (procedure developeu from tne RP'V Control Guideline) at (Step RC-1) and execute it con urrett ".y watn this rocedure.
( pC-4)
-38 Hay 1984
OPERATOR ACTIONS (Cont.)
pc/p monitor and control primary containment prcssure'C/P-1 Operate SBGT as
- required, only when the temperature in the space being evaluated is -below 212'F.
Use OP-61A.
- P20
'C/P-2 Before suppression chamber pressure reaches 17.22 psig and suppression pool water level is below 55 Et., in;t'.at=
'i L I suppression pool sprays'c/p-3 suppression chamber pressure exceeds
- 17. 'u" if suppression chamber temperature ana drywell pressure L I are below the Drywell Spray Initaatxon Pressure
- Lxmrt, shut down recirculation pumps ann drywel 1 cooling fans and initiate drywell spray restrxctang flow rate rc less tnan 26o gpm.
See Figure 4
(PC-5)
-39 May 1984
OPERATOR ACTIONS (Cont.)
PC/P-4 Ii suppression chamber pressure cannot be maintained below the j
Pressure Suppression
- Pressure, EMERGENCY RPV DEPRESSURIZATION IS REQUIRED.
See Figure 1
(PC-6)
-40 Mav 1984
OPERATOR ACTIONS (Cont
~ )
PC/P-5 If suppression chamber pressure cannot be maintainea below the Primary Containment Design Pressure
~
RPV FLOODING IS REQUIRED.
See Figure 5
PC/P-6 Ii suppression chamber pressure cannot be
.". ~intaineu beiow the Primary Containment Pressure Limit, then irrespective of whethe r adequate core cooling is assured:
(PC-7) Draf t
-41 Nay 1984
OPERATOR ACTIONS (Cont. )
0 0
If suppression pool water level is below 55 ft, initiate suppression pool sprays
~
If suppression chamber temperature and drywell pressure are below the Drywel 1 Spray Initiation Pressure Limit, shutdown recirculation pumps and drywel 1 cooling fans anc initiate drywell sprays restricting flow rate to less than 26b gpm e
See Figure 4
PCIP-7 If suppresion cnamber pressure exceeds the Pri...ary C:nta nment Pressure Limit, vent tne Primary-Contains cnt in accordance with OP-61A to reduce and maintain pressur~
below the Primary Containment Pressure Limit ~
(pc-8)
-42 May 1984
OPERATOR ACTIONS (Cont.)
SP/L Monitor and control suppression pool water level.
SP/L-1 Maintain.suppr'ession pool water level between 23f t 6in.
t and 23ft. ~ Refer to sampling procedure prior to f17 )
~F8 discharging water.
If suppression pool water level cannot be maintaanea above 3ft 6 in =execute
( Ste p SP/L-2)
~
If suppression pool water level cannot be.aintainec below 25ft, execute (Step SP/L-3)
~
SP/L-2 SUPPRESSION POOL '~ATER LEVEL BELO'4 23r't 6 in.
.'!aintain suppression pool water
}eve 1 above tne Yeat Capacity Level Limit.
See Figure
=u"pression
" o'ater ieve 1 cannot be ma.'ntained above the
';'.eat Capacit:
Level Li-...it, E.'!ERGEICY R.=
~E?~E~.!.RIZATIwb IS R" QL'IREE; enter (procedure developea fry-... the RP" Contro I buidel';ne) at (Step RC 1) ana execute it concu en av wt n this procedure.
SP/L-3 SUPPRESSION POOL MATER LEVEL ABOVE 25ft Execute t Steps SP/L-3.1 and SP/L-3.2) concurrently.
SP/L-3.1 Maintain suppression pool water level below the Suppression Pool Load Limit.
(PC-9)
-43 May 1984
OPERATOR ACTIONS (Cont. )
If suppression pool water level cannot be maintained below the Suppression Pool Load I.imit, maintain RPV pressure below the Limit.
If suppression pool water level and RPV pressure cannot be maintained below the Suppression Poo 1 Load Limit but only if adequate core cooling is assurea, cerminate in~ection into che RPV from sources excerna
- 1. to the primary containment except from boron injeccion syscems and CRD.
if suppression pool wacer level and RPV pressure cannot be restorea ana maincainea beiow tne Sup1ressxon Pool Loaa Limic, EAERGEibCY RPV DEPRESSURIZATIOh IS RE/i;IRED; encer (proceaure ceveioped from che RP':ncro1.
Guiaeiine) ac (Step RC-'.) and execuce ic concurrenc ly wicn this procedure
~
SP/L-i.2 Be:ore s "".ession poo.:
wacer levei reaches 122fc 9in, buc onl: i f adec ace core cooling is assured
> cerminace injection nco che RPV:rom sources excernal co ci e p"..-..ary concainme..c excepc:r f boron inieccion svscems ana CRD.
SP/L-i.3 '~'hen ?ri;..ar:
Concainmenc wacer 1eve1 reaches 1 2ic 9in.,
ce.-'.'naca.'n'ace ion into che RPV from sources externa'o Pr;.,ary C ncaxnment irrespecc ive o f whecner aaec core ccc>:;.g xs ssured.
( PC-10)
-44
'Hay 1984
SECONDARY CONTAINMENT CONTRO L GUIDELINE PURPOSF.
The purpose of chis guideline is co:
o protect equipment in the secondary containmenc, Limit radioactivicy re lease to the secondary concainment, and e itner:
o
'maintain secondary containment incegrity, or o
Limit radioactivity release from the secondary concainmenc.
ENTRY CONDITIONS The entry conditions for this guideline are any of che following Seconuary Containmenc conditions:
o Differential pressure ac or above 0 in ~ of water o
An area cemperacure above the maximum normal operating temperature A HVAC cooler differential. temperacure above the
...aximum normal operating differential cemperature o
A HVAC exhaust radiacion level above the maximum normal operacxn6 radiation level o
An area radiation level above cne maximum normaa operation-raurac ion level o
A floor drain sump water leve 1 above the maximum..erma'. operating wacer 1 eve 1.
o An area "acer level above che maximum normal operating wa<<r '.evel
-45 Mav 1984
OPERATOR ACTIONS If while executing the following steps Secondary Containment hVAC exhaust radiation level exceeds Secondary Containment HVAC isolation setpoint:
o Confirm or manually initiate isolation of Secondary Containment HVAC, and o
Confirm initiation of or...anua1ly initiate SBG'1
~
If while executing the following steps:
l o
Seconaary Containment HVAC isolates, and o
Secondary Containment HVAC exhaust radiation leve 1 is below Secondary Containment HVAC isolation;etpoint, restart Secondary Containment
- HVAC, Irrespective of the entry condition, execute (Steps SC/T, SC/w, and SC/L) concurrently'C/T
.'lonitor and control. Secondary Containment temperatures.
SC/T-1.
SC/T-2 Operate available area coolers.
1 I f Seconcary Containment HVA(.'xhaust rauiat.on levee is below Secondary Containment HVAC isolation setpoint, operate a vai lao le Seconaary Containment HVAC.
~
'C/T-3 If any area temperature exceeds its maximum normal operatit "
temperature, isolate all systems that are dischargxrg into the 1
area except systems required to shut down the reactor, assure adequate core cooling, or suppress a working fire ~
NOTEI:
Tables will be added during EOP development.
(SC-2 )
-46 Mav 1984
OPERATOR ACTIONS
/ -
p'rys'stem is discharge:in@ into an area, th 1
area temperature reaches its maximum safe operating temperature enter (procedure developed from the RPV Control Guiaelrne)
(Step RC-1) and execute it concurrently with this procedure.
SC/T-5 If a primary system is discharging into an area ana an area temperature exceeds its maximum safe operating temperature
~ in SC/R SC/;R-1 SC/R-2 more than one area, EMERGENCY
'3EPRESSURIZATIVN IS REgUlRED.
Monitor and control Secondary Containmemt radiation levels
~
If any area radiation level exceeds its maximum normal operating radiation levell, isolate all systems that are discharging into the area except systems required to shut down the reactor, assure adequate core cooling, or suppress a working fire.
If a primary system is discharging into an "-rea, then before any area radiation level reaches i ts maximum sa;e operating raaxat ion level enter (procedure developea from the RPV Control Guideline) at (Step RC-1) and execute it concurrently witn tnis procecure
~
SOIR-3 I" a pr'-...ary system is discnarging into an area anu a
radiation level exceeds its maximum safe operating radiation 1 eve'.1 in'ore than one area",
EMERGE<ICY RPV DEPaE>>Lali.A'1ivi4 IS REQUIRED'OTE1.
Tables will be added during EOP development.
(SC-3)
-4 7 Mav 1984
OPERATOR ACTIONS SC/L Monitor and control Secondary Containment water levels.
SC/L-l If any floor drain sump or area water level is above its maximum 1
normal operating water level operate available sump pumps t o restore and maintain it below its maximum normal o'perating water SC/L"2 level
~
If any floor drain sump or area water level cannot be restorea and maintained below its maximum normal. operating water leve 1 1 isolate all systems that are discharging water into the sump or area except systems required to shut down the reactor, assure adequate core cooling, or suppress a working fire.
If a primary system is discharging into an area, then before any floor drain sump or area water level reacnes its max<mum safe SC/L-3 operating water level enter (proceaure dev=.opea from the RPV Control Guideline) at (Step RC-1) ann execute it concurrently witn tnis procedure.
li a primary system is discharging into an area and a floor crai n sump or area water level exceeds its maximum safe operating water i.evel.'n more than one area, E.'fERGENCY R.V DEPRi SSLc(I2AIIvb RENDU IRE D.
NOTEl.
Tables will be addeo during E.O.P.
cevelopr,:ent.
(SC-4 )
-48 May 1984
RADIOACTIVITYRELEASE CONTROL GUIDELINE PURPOSE urpose of this guideline it to limit radioactivity release into areas e pur outside the Primary and Secondary Containments.
ENTRY CONDITIONS The entry condition for this guideline is:
o Offsite radioactivity release rate above release rate whicn requires an Alert.
OPERATOR ACTIONS R R-1 Isolate all primary systems that are discharging into areas outsiae the Primary 'and Secondary Containments except systems required co, assure adequate core cooling or shut down
".':e reactor.
If offsite radioactivity release rate apprc=ches or exceeos release rate which requires a General Emergency ana a primary system is discharging into an area outside the Primary and Secondary Containments, E~(ERGENCY RPV DEPRESSLRIZATlVb IS R (,( iK'""u,'nter (procedure developed from the RPV Control Guicei.inc) at (Step RC-1) anc execute it concurrently with tnis proceu (RR-1)
-49 May 1984
CONTINGENCY /F1 LEVEL RESTORATION If while executing the following steps'.
o Boron Injection is required, enter (procedure developed from CONTIiVGENCY 87).
o RPV water level cannot be determined, RPV FLOODING IS REqUIRED; enter (procedure developed from CONTINGENCY 'P6)
~
o RPV Flooding is required, enter (procedure developed from CONTINGENCY !i6).
Cl-1 Line up for injection and start pumps in 2 or more oi the following injection subsystems:
0 Condensate HPCS o
LPC I-A o
LPCI-B o
LPC I-C o
( Cl-1)
-50 way 1984
CONTINGENCY 81 (Cont)
If less than 2 of the injection subsystems can be lined up, commence lining up as many of the following alternate injection subsyscems as possible:
o Service Water co RHR Crosscie o
Fire syscem o
ECCS keep-full systems o
SLC (test tank) o SLC (boron tank)
C 1 -.2
~1onitor RPV pressure and water level
~
Concinue in this prooeaure ac che seep indicated in che following cable.
RPV PRESSURE REGION 495 psig 5O psig H IGH INTER~IE.D IATE L04 R?V LEVEL liNCREAS IiVG I
I
.'D ECREAS ING l
C1-3 C'6 Cl-4 C 1-5 Cl-7 if while executing the following seeps:
o ihe RPV water l.evel crena reverses or RPV pressure cnanges
- region, recurn co (Step Cl-2) ~
o a? V wacer level drops below 17. bin., prevenc a
~ ccc ac xc irl t Lac LBn of ADS ~
(Cl-2)
-51 Nay 1984
CONTINGENCY dl (Cont)
Cl-3 RPV WATER LEVEL IhCREASIhG>
RPV PRESSURE HIGH Enter (procedure developed from the RPV Control Guideline) at
( Step RC/L).
RPV WATER LEVEL INCREASING, RPV PRESSURE INTER~iEDIATE, If HPCI and RCIC are not available and RPV pressure is increasing E>EGENCY RPV DEPRESSURIZATION IS REQUIRED.
When RPV pressure is decreasing, enter (procedure developed from the RPV Control Guideline) at (Step RC/L)
~
If RCIC is not available and RPV pressure is not'ncreasing, enter (procedure developed from the RPV Control Guideline) at (Step RC/L).
Cl-5 Otherwise, when RPV water level reaches 159
~ 3 in, enter (proceaure developed from the RPV Control Guideline) a" (Step RC/L)
~
RPV WATER LEVEL INCREASING>
RPV PRESSURE Le'f RPV pressure is increasing, EMERGENCY RPV DEPRESSURIZATIOi4 IS REQUIRED.
When RPV pressure is decreasing, enter (proceoure developed from the RPV Control Guideline) at (Step RC/L)
~
Otherwise, enter (procedure developed from the RPV Control Guideline) at (Step RC/L),
RPV 'n'ATER LEVEL DECREASING, RPV PRESSURE HIGH OR
.l>TEwlED1ATc',
If RCIC is not operating, restart RCIC
~
I f no i,.ject on subsvstem is lined up for injection witn at least one pump running, star t pumps in alternate injection subsystems which a re 1 ined up
."or injec t ion.
-52 Nay 1984
CONTINGENCY 01 (Cont)
~. WheniRPV-",water,. level drops to -14in.
~~ >*0,'~~,
a',-'-;."Xf'no'system, injecton subsystem or alternate injection subsystm is lined up with at least one pump running, STEAM COOLING IS REQUIRED.
When any system, injection subsystem or alternate injection subsystem is lined up with at least one pump running, return to (Step Cl-2).
o Otherwise, EMERGENCY RPV DEPRESSURIZATION IS REQUIRED.
When RPV water level is increasing or RPV pressure drops below 50 psig, return to (Step Cl-2)
~
Cl-7 RPV WATER LEVEL DECREASING, RPV PRESSURE LOW If no HPCS or LPCS subsystem is operating, start pumps in alternate~
injection subsystems which are lined up for injection ~
If RPV pressure is increasing, EMERGENCY RPV DEPRESSURIZATION IS REQUIRE D.
When RPV ~ater level drops to -14" fuel zone, enter (procedure developed from contingency 84).
( C1-4
-53 May 1984
hl ternate Format fo Steps CI-3 tlirougli 01-8 Cl-2 MONITOR Rl'V I'Rl'.SSURF. AND Whl'I'.R I.I'.Vl'.I" (ONTNUE I N TIIIS PROCEDURI'. AT 'I'IILI'KP INDICA'I'KD I N TIIK FOLLOW1NG TABLE:
Rl'V PRI'.SSUkK RK('10H 111 Gl1 I NTI'.RHI'.DIA'I'I'.
LOW C1-3 C I -4 01-5 ENTER (PROCFDURI'.
Dl'.Vl'.I.OI'I'.D FROM 'I'IIF.
c I
RPV CONTROI. GUIDKI.INI'.) Al'O'I'KI'C/I,)
'u)
Q4 I
l4 I
1F RC IC ARE NOT AVAIl.hl3I.F. AND RPV PRI.SSURK IS I NCRKASING, Fl'IKICGKNCY Rl'V DKI'ICKSSUkll-7.A'I'ION 1S RKQUIRl:,D ~
Will'.N ICI'V I'ICK.SSUkK I S DKCRKAS I NG, KN'I'KIC ( PI(OUI'.DUICI; Dl'.VKI,()l'I'.D FROM TIIK Rl'V CON'I'ICO I- (iUI DKI.I Nl'. ) h'I' S'I'I'.I' F Ic('1c Alcl'. NO'I'vAI I hill-I'ND lepv pl(i'ssUlcl'S NOT INCRFASING, I'.Nl'Kk (PROCEDUICI'.
DEVI'I.OI'LD FROM TIIK Rl'V CONTkOI-OUI Dl':l.lNI'-)
AT (STEP RC/I.).
OTIIFRWISK, WIIEN RPV WA'I'KR l,l'.Vl'.I-RKACIII.D 159.3 in.,
FN'I'ER (PROCEDURF Dl'.VKI.OPED FROM l'IIE ICPV CONTROL GUIDI'.1.1NE) A'I'STEP RC/I.)-
I F ICPV Plel SSUICI'S INCREASING, EHEGE Iel'V I)l':I'lel SSUIe lib'I'10N IS REQUlRED, Wl ICPV I'lel'.SSUICI'- IS DECREASlNG, ENTER
( I'ICO(:I:DUICI': Dl':VlLOPED FROM THE RPV
. (:()O'I'le() I. (IUIDl'.l.lNE) AT (STEP RC/L)-
O'I IIKICWI Sl, Eh'I'KIC ( PICOCKDURE DEVELOPS I
FICOH 'I'III': Rl'V CONTROL GUIDELINE) AT
,'S'll I R(:/I.).
0 f4 u-e IF RCIC IS NOT OPERATING, RESTART RCIC.
WHEN RPV WATER LKVI'.L DROPS 1'0 -14i n:
0 0
IF NO SYSlTM, INJKC'I'ION SUIISYS'I'I'.H OR AI.Tl:.RNA'I'E 1NJECTION SUBSYS'I'KH I S I.INI'.D UP WIl'll A'I'KAS'I'NI'. PUMI'UNNIN(',
S'I'IAH COOI 1NG 1S RKQUIRI'-'D.
Will'-'N ANY SYS'I'LH 1NJFC'I'10N SUI3SYS'I'I'.H OR Al.l'I:.RNATE INJF( I'ION SUBSYSTI'.H 1S LlNL'D UP WI'I'll h'I'.l'.AS'I'NE PUHP RUHNI NG, RK'I'URN l'0 S'I'I'.I'l-3)~
)
OTHERWISE, EHI'.RGENCY Rl'V DKI'RKSSUR17hl'ION IS Rl'.QUIICI'.D, Will:.N Rl'V WA'I'I'.ll I.KVKI.
IS INCREASING OIC RPV I'RKSSUICK DROPS 13EI OW 50 I'SI.G RK'I'Uleh 'I'0 S'I'El'1-3
~
IF NO INJFCTION 'SUBSYS'I'I'.H IS I.INFD UP FOR INJECTION WI'I'll hl'.EAST ONL PUMP RUNNING, START PUMPS 1N hl.l'ERNhl'I'. I NJK( I'ION SUIISYSTI HS Will(:II hlel l.l Nl';D UP FOIC 1NJL("I'l()N-(: I -7
( I F NO IIPCb Ok LPCS SUBSYSTEM IS
()I'I RA'I IhG, ) S'I'ART PUMPS 1h ALTERNA'lh INJECl'ION SUBSYSTEMS WlllCN ARE LlNEI' I'OIC I NJ KC'I 10H.
I F RPV PkKSSURL'S 1NCkEAS1NG, EMERG RPV DKPRI SSUklZATlON IS REQUIRED.
IIKN RPV WATEk I.KVEL DROPS TO -14 in I:.N'I'L'R (I'ICOCKDURI'-'L'VELOPED FROM CON'I'I NGKNCY //4).
IF WHILE EXECUTING 'lllE FOI.I.OW1NG S'I'El S llIF. Rl V WAlER 0'.VKL TRI:.ND ICFVKRSKS ole lel v Plel'.SSUICK CIIAN(;I:.S Iel'.(:ION, RETURN TO (STEP C1 (Cl-5)
-54 Ha y 19I34
CONTINGENCY fP 2 EMERGENCY RPV DEPRESSURIZATION C2-1 When either:
o Boron Injection is required and all injection into the RPV except from boron injection systems ann CRD has been terminated and prevented, or C2-1. 1 o
Boron Injection is not required, If suppression pool water level is above 6it.
o Open al 1 ADS valves.
o If any ADS valve cannot be openeo, open otner S~Vs until 7 valves are open C2-1..2 If less than 3
SRVs are open ana RPV pressure is at least
i 50 psig above suppression chamber pressure, rapidly depressurize the RPV using one or;..
re of the following systems (use in order which will minimize radioactive release to the environment):
o
'Hain condense r o
RHR (steam condensing mode) o
.'!ain steam line drains o
RCii steam line o
Head vent If RPV Flooding is required, enter (procedure 'dev~lopeu f ror,.
CONTINGENCY.;-6)
~
Enter (procedure developed from the RPV Control Guioeline) at (Step RC/P4).
-55 May 1984
CONTINGENCY 03 STEAM COOLING If while executing the following steps Emergency RPV Depressurization is required or any system> injection subsystem, or alternare injection subsystem is linea up for injection with at least one pump running, enter (procedure developed from CONTINGENCY !i 2).
When RPV water level drops to -67.5 fuel zone or if RPV water level cannot be determined, open one SRV.
When RPV pressure drops below 70G psig, enter (procedure developea from CONTINGENCY !'>2).
-56 May 1984
CONTINGENCY
$P4 CORE COOl.ZNG WITHOUT LEVEL RESTORATIO>
Open all ADS valves.
If any ADS valve cannot be openea, open otner SRVs until l; l. 2 7 valves are open.
Operate HPCS and LPCS subsystems witn suction from the suppression pool.
When at least one core spray subsystem is operatirg witn suction from tne suppression pool and RPV pressure is below 289 psig, terminate injection into the RPV from sources external to the Primary Containment
~
When RPV water level is restored to -14 in. enter (proceaure developed from the 'RPV Control Guideline) at (Step RC/L).
-57 May 1984
4 CONTINGENC Y 0 5 ALTERNATE SHUTDOWN COOLING C5-1
~ Initiate suppression pool cooling.
C5-2 Close tne RPV head vents, MSIVs, main steam line drain alv RCIC isolation valves.
C5-3 Place the control switch for one SRV in the open posxtaon.
C5-4 I
Slowly raise RPV water level to establish a flow path through the open SRV back to the suppression pool.
I C5-5 Start one LPCS or LPCI pump with suction from the suppression pool.
C 5-6 Slowly increase LPCS or LPCI injection into the RPV to the maximum.
C5-6. )
If RPV pressure does not stabilize at least 161 psig above suppression chamber pressure, start anotner LPCS or LPCl pump.
C5-6.2 If RPV pressure coes not stabilize below 230 psig, open another SRV ~
C5-6.3 If the cooldown rate exceeds 100'F/hr, rea~ce LPCS or LPCl injection into the RPV until the cooldown rate decreases below 100'F/hr
~
C5-7 C 5-8 Control suppression pool temperature to matntain RPV water te...perature above 70'F.
Proceed to cold shutdown in accoraance witn bZ-OP-10i..
(C5-1)
-58 May 1984
CONTIVGENCY 4'6
. RPV FLOODIbG C6-1 C 6-2 If at least 3 SRVs can be opened c r if HPCS or motor driven feedwate r pumps are available for injection, close the NSIVs, main steam line drain valves, RCIC and RHR steam condensing isolation valves.
If any control rod is not inserted beyond position QQ.
C6-2.1 Terminate and prevent all injection into the RpV except from boron injection systems and CRD until RPV pressure is below the Minimum Alternate RPV Flooding Pressure.
4i'umber of open SRVs ilinimum Alternate RPV I
Flooding Pressure (psig )
7 or more 160 23U 285 400
>GQ If less than 3
SRVs can be openea, continue in tnis procedure.
If while executing the following step, RPV water level can be determined and RPV Flooding is not requirea, enter (proceaure cevelopec from CONTIYGKNCY
- 7) and (procedure developed from the RPV Control Guideline) at (Step RCMP-4) and execute these procedures concurrently.
(C6-1. )
-59 May 1984
CpNTINGENCY iP6 (Cont.)
C6-2
~ 2 Commence and slowly increase injection into the RPV with following systems until at least 2 SRVs are open and RPV is above the Minimum Alternate RPV Flooding Pressure:
the pressure I
~pZ 3 o
Motor driven feedwater pumps o
Condensate booster pumps o
Condensate pump s o
CRD If at least 2
SRVs are not open or RPV pressure carrot be increased to above the Minimum Alternate RPV Flooding Pressure, commence and slowly increase injection into the RPV with the following systems until at least 2 SRVs are open and RPV pressure is
~
above the Minimum Alternate RPV Flooding Pressure:
o HPCS o
LPCS o
LPCI/RHR o
Service water to RHR crosstie o
Fire System o
ECCS keep-full systems C6-2. 3
.'!aintain a
least.
2 SRVs open and RPV pressure above the
~! inrmum Alternate RPV Flooding Pressure by throttling injection.
C6-2.4
'v'hen o
All. control rods are insertea beyono posit ion 00 or,"
o The reactor is shutdown and no boron has been injected into the
- RPV, continue in this procedure (C6-2)
-60 May 1984
CQNTINGENC Y if6
( Cont
~ )
C6-3 If RPV'water level cannot be determined:
Commence and increase injection into the RPV with the following systems until at least 3
SRVs are open and RPV pressure is not decreasing and is at least 80 psig above suppression chambe r pressure o
HPCS o
Motor driven feedwater pumps o
L?CS o
LPC I o
Condensate booster pumps o
Condensate pump s o
CRD o
Service water to RHR crosstie o
Fire System o
ECCS keep-full systems o
SLC (test tank) o SLC (boron tank)
C6-3."
Maintain at least 3 SRVs open anu RPV pressure a-least Su psig aoove suppression chamber pressure by throttling injection
~
( C6-3)
-61 May 1984
e
CONTINGENCY <>6 (Cont. )
ff C6-4 If RPV water level can be determined, commence and increase injection into the RPV with the following svstems until RPV water
! =vel is increasing o
HPC S'otor driven:eedwater pumps L?CS L?C I 4oncensat'.
ourn?a Concensate ooste pumps CRD RHR service water crosstie Fire System ECCS keep"tu Il svs ems SLC (test tank)
Cb-5 o
SLC (boro.. tank) ffIf RPV water leve 1 cannot be determined
<6.5.1 Fill all RPV water level instrumentation reference columns.
C6-5.2 Continue injecting water into the RPV until drywell tempe ature is below 212'F and RPV water level instrumentaticn is avaiiable
~
If while executing the following steps, RPV water level can be determined, continue in this procedure at
( Step Co-6).
C6-5.3 If it can be determined that the RPV is fillea or if RPV pressure is at least 80 psig above suppression chamoer
~
(C6-~)
-62 May 1984
CONTINGENCY 06 (Cont. )
C6-5.4 If RPV water level indication is not restored within the Maximum r
Core Uncovery Time Limit after commencing termination of injection into the RPV, return t.o (Step C6-3).
C6-6 Rhen suppression chamber prMsure can be maintained below the Primary Containment Oesign Pressure, enter (procec re developea from the RPV Control Guidel~ at (8teps RC/L and RC/P--') and execute these steps concurrently.
See Figure 5
(C6-5)
-63 May 1984
CONTINGENCY 87 LEVEL/POWER CONTROL If while executing the following steps RPV Flooding is required or RPV water level cannot be determined, control injection into the RPV to maintain reactor power above 8% but as low as practicable.
However, i f reactor power cannot be determined or maintained above 8'i.',
RPV FLOODING IS REQUIRED; enter (procedure developed from CONTINGENCY
$ 6).
C7-1 If:
o Reactor power is above 4% or cannot be determinea, ana o
Suppression pool temperature is above 111'F, ana o
Either an SRV is open or opens or drywell pressure is above
- 1. 68 ps ig, lower RPV water level by terminating and preventing all injection into the RPV except from boron injection systems fF c,4 and CRD until either:
Reactor power drops below 4%, or RPV water level reaches
-14 in., or All SRVs remain closed and drywell pressure remains below 1.68 psig.
(C7-1)
.64 May 1984
(Cont.)
If while executing the following steps Emergency RPV Depressurization is required, continue in this procedure at (Step C7-2.1)
~
If while executing the following step:
o Reactor power is above 4% or cannot be determined, and o
RPV water level is above -14 in., and o
Suppression pool temperature is above 111'F, and I
o Either an SRV is open or opens or drywell pressure is above 1.68 psig
'eturn to (Step C7-1).
C7-2 Maintain RPV water level either:
o If RPV water level was deliberately lowered in g9, 010,
/38,
/323 (Step C7-1), at the level to which it was lowered, or o
If RPV water level was not deliberately lowered in (Step C7-1), between 159.3 in. and 202.3 in.,
with the following systems:
o Condensate/feedwater system 1205-0 psig o
CRD system 1205-0 psig o
RCIC system 1130-0 psig If RPV water level cannot be so maintained> maintain RPV water level above -14 in.
(C7-2)
-65 May 1984
CONTINGENCY 87 (Cont. )
If RPV water level cannot be maintained above
-14 in.,
EMERGENCY RPV DEPRESSURIZATION IS REQUIRED:
C7-2.1 Terminate and prevent all injection into the RPV except from boron injection systems and CRD until RPV pressure is below the Minimum Alternate RPV Flooding Pressure.
tI Number of open SRVs I
Minimum Alternate RPV Flooding Pressure (psig )
7 or more 160 185
. 230 285 400 590 If less than 2
SRVs can be openea, continue in thxs proceaure.
(C7-3)
-66 May 1984
0
CQNTINGENCY 87 (Cont ~
)
C7-2.2 Commence and slowly increase injection into the RPV with the following systems to restore and maintain RPV water 823 level above -14 in.
o Condensate/feedwater system o
CRD o
RCIC If RPV water level. cannot be restorea ann maintainec above
-1~ in.,
commence and slowly increase injection into the RPV with the following systems to restore and maintain RPV water level above,-14 in.:
o HPCS o
LPCS LPC I Fire System ECCS keep-full systems Service water to RHR crosstie If while executing the following step "reactor power commences ann continues to increase, return to (Step C7-1)
~
Ci-3
@hen 362.5 pounds of boron have been injectea or all control roas are inserted beyond positxon 00, restore ana maintain RPV water level between 159.3 in. and 202.3
~ in
~
-67 Hay 1984
CONTINGENCY 07 (Cont. )
If RPV water level cannot be restored and maintainea above h
159.3 in., maintain RPV water level above -14 in
~
If RPV water level cannot be maintained above -14 in.,
EMERGENCY RPV DEPRESSURIZATION IS REQVIRED; return to (Step C7-2.1)
~
If Alternate Shutdown Cooling is required, enter (proceaure developed from CONTINGENCY
$r'5).
C7-4 Proceed to cold shutoown in accoraance with N2-0P-1G1.
(C7-5)
-68 May 1984
'F~iuzes Figure Figure Figure Figure Figure Figure Figure Figure Figure Figure 1
Pressure Suppression Pressure Suppression Pool Load Limit 3
Drywell Spray Initiation Pressure Limit (RB1 Cont. hP) 4 Drywell Spray Initiation Pressure Limit (WM/DM hp) 5 Primary Containment Design Pressure 6
RPV Saturation Pressure 1 Temperature 7
Primary Containment Pressure Limit 8
Heat Capacity Level Limit 9
Heat Capacity Temperature Limit 10 Maximum Core Uncovery Time
-69 May 1984.
gl
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FIGURE 1 PRESSURE SUPPRESSION PRESSURE
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I 20 30 40 SO 60 SUPPRESSlON CAUSER LEVEL (fe) 70
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Ot 50 Figure 2
SUPPRESSION POOL LOAD LIMIT St 40 LI 9L 30 00 C0 NN 20
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I 600 800 1000 1200 Reactor Pressure Vessel Pressure (psig)
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E 0
0 0
NINE MILE POINT UNIT 2 NUCLEAR STATION EMERGENCY OPERATING PROCEDURES PROCEDURE NO. N2-EOP-1 EMERGENCY OPERATING PROCEDURE DEVELOPMENT Summar of Pa es Revision NIAGARA lQHAWK POWER CORPORATION THIS PROCEDURE NOT TO BE'SED AFTER SUBJECT TO PERIODIC REVIBf
)
~
k Section Table of Contents Pa<ac 1.0 Introducti on
- 2. 0 References 3.0 Definitions
- 4. 0 Responsibilities 5.0 Plant Specific Technical Guideline
- 6. 0 Emergency Operating Procedures 7.0 EOP Training Guide
- 8. 0 Documentati on EOP-FORM 1 -
EPG Change Form EOP-FORM 2 - Step Documentation
I
~
~
~
1.0 Introduction 1.1
~Pur ose.
The purpose of this procedure is to prov ide gui dance for the development of Emergency Operating Procedures for Nine Mile Point Unit 2.
- 1. 2 ~Sco e
This procedure appl ies to the initial development of EOPs and revisions.
This process involves development of a
Plant Speci fic Technical Guideline and Emergency Operating Procedures.
2.0 References 2.1 Nine Mile Point Unit 2 FSAR 2.2 Emergency Operating Procedures Implementation Guideline (INPO 82-016, Rev. 1)
- 2. 3 Response t Suppl ement 1 to NUREG 9737, Item 7.2b, page 15
~
~
~
3.0 Definitions 3.1 Emer enc Procedure Guideline (EPG)
This is a generic
- document, developed by the BAR Owners Group (BMROG),
on which the Plant Specific Technical Guideline is based.
- 3. 2 Plant S eci fic Technical Guidel ine (PSTG)
This is the document on which the Emergency Operating Procedures is based.
It is developed by incor porating pl ant speci fic information into the EPG.
4
- 3. 3 Emer enc eratin Procedures This document provides operation actions necessary to mitigate the consequences of transients and accidents.
3.4 Nine Mile Point Unit 2 EOP Writers Guide This document provides ins tructi ons to the EOP Writers concerning format and content of the Emergency Operating Procedures.
3.5 Yeri fication This is the evaluation per formed to verify technical accuse acy of the
- PSTG, and the technical accuracy and written correctness of the EOPs.
3.6 Validation This is the process which provides assurance that the EOPs can be used successfully in emergency situations.
4.0
~mobil i
4.1 Station Su erintendent The Station Superintendent shall have the overall responsibility for development of EOPs.
4.2 0 erations Su rvisor The Opera ti ons Supervisor shall assi gn the res pons ibility of EOP development to EOP Writers.
4.3 EOP Writers EOP Writers shall develop Fmergency Operating Procedures in accordance with'his procedure.
5.0 Plant S ecific Technical Guideline (PSTG)
A PSTG will be developed by the EOP Writers using the latest revision of the General El ectric Boil ing Water Reactor Owners Group Emergency Procedure Guideline for which a
Safety Evaluation Report (SER) has been issued by the NRC.
The EOP writers will obtain and review the following plant specific technical information (EOP source documents) as required to develop the PSTG:
l.
2.
3.
4 5.
6.
EPGS; with Appendices A,
8 and C,
Nine Mile Point Unit 2 FSAR, Operating Procedures, Technical Speci fication, Plant-specific drawings which form the date base for tes ting and opera ti on of the pl ant, Engineering approved vendor documents.
The EOP writers wil 1 revi ew the EPG step-by-s tep, adding speci fic information where
- required, and making
~
del etions where required.
Additions and deletions will be documented, along with justifications, on an EPG Change Form (EOP-FORMl ).
The EPG-PSTG, applicable EPG Change Forms and calculation procedures shall be considered the PSTG package.
6.0 Emer enc 0 eratin Procedures The EOP writers w>ll follow, the PSTG step-by-step
- and, using the Nine Mile'oint Unit 2
EOP Writer's Guide (N2-EOP-4),
develop a set of Emergency Operating Procedures.
Differences between the PSTG steps and EOP steps wil 1 be documented, wi th justi ficati on, on Step Documentati on forms (EOP-FORM 2).
All Step Documentation forms will be submitted wi th the EO Ps for ver ifica ti on.
Additions to Oper ating Procedures wil 1 be made as requir ed to assur e adequate support of the EOPs.
The EO Ps shal 1
be verified in accordance wi th the EOP Verifica tion Procedure (N2-EOP-2).
The EOPs shall be val idated in accordance wi th the EOP Yal idation Procedure (N2-EOP-3).
7.0 EOP Trainin Guide Concur rent with the development of the Plant-Specific Guideline and
- EOPs, a Training Guide will be developed.
The Training Guide will contain the fo 1 1 owing:
GE BWR Owner's Group Generic Emergency Procedure Guideline.
The Plant-Speci fic Technical Guidel ine (including Addition/Deleti on Forms ).
The Step Documentation forms.
The EOPs.
A step-by-step breakdown of the technical bases for the EOP decisions and operator actions.
The calcul ati onal procedures and references for data used in developing EOPs.
Using the Training
- Guide, the Training Department, assisted by the EOP Writing Team where requir ed, can develop 1 esson plans for the Training Progr am.
- 8. 0 Documentati on The following will provide documentation of the EOP development process:
1.
Generic
- EPG, 2.
PSTG package, 3.
PS TG Verification Package (s ee EO P Ver ifica ti on Procedure),
4.
EOP Veri fication Package (see EOP Verification Procedure),
5.
Step Documentation
- forms, 6.
EOP Validation Package (see EOP Validation procedure).
The above shall be maintained as part of the Permanent Plant file.
~l
GENERIC EPG STEP:
DESCRIPTION OF CHANGE:
JUST IFI CAT ION:
EOP MRITER:
t 0,
STEP DOCUMENTATION EOP-FORM 2
EOP No.
Rev.
No.
EOP STEP:
NP II PSTG STEP:
JUSTIF ICATION OF DIFFERENCES:
EOP WRITER:
DATE:
~
S C
r
NINE MlLE 'POINT UNIT 2 NUCLEAR STATION EMERGENCY OPERATING PROCEDUPES PROCEDURE NO. N2-EOP-2 EMERGENCY OPERATING PROCEDURE VERIFICATION Summar of Pa es Revision NIAGARA NHNK PO'vlER CORPORATION THIS PROCEOURE Nor TO BE USED AFTER SUBJECT TO PERIODIC REVIEW
Table of Contents Section
- l. 0 Introduction 2.0 References
- 3. 0 Definitions 4.0 Responsibil ities 5.0 Plant Specific Technical Guideline Verification 6.0 Emergency Operating Procedure Verification
PSTG Discrepancy Form EOP-FORM 5 -
EOP Verification Form EOP-FORM 6 -
EOP Verification Discrepancy Form
~Pa e
I
~,
~
~
~
- 1. 0 Intro due ti on 1.1
~Per ose The purpose of this procedure is to provide guidance for the process of verification of the Plant Specific Technical Guideline (PSTG) and the Emergency Operating Procedures (EOPs) at Nine Mile Point Unit 2.
1.2 ~Sco e
This procedure will describe and direct the verification process.
The verification process is meant to ensure the technical accuracy of the Plant Speci fic Technical Guidel ine and the
- EOPs, and the correct impl emen ta tion of the Writer '
Gui de in the EOPs.
This procedure applies to the initial PSTG and
- EOPs, and revisions.
- 2. 0 Re ferences 2.1 E'mergency Operating Procedure Verification Guidel ine (INPO 8-3-004) 2.2 Nine Mile Point Unit 2 EOP Writer's Guide 2.3 Nine Mile Point Unit 2 FSAR
- 3. 0 Oefiniti ons
~
~3.1 Emer nc Procedure Guideline (EPG)
This is a
generic
- document, developed by the BWR Owners
- Group, on which the Plant Speci fic Techni cal Guideline is based.
3.2 Plant S ecific Technical Guideline (PSTG) 3.3 This is the document on which the E'mergency Operating Procedures is based.
It is developed by incorporating plant specific into the EPG.
Emer enc 0 eratin Procedures This document provides operator actions necessary to mitigate the consequences of transients and accidents.
- 3. 4 Nine Mile Point Unit 2 EOP Writer's Guide This document provides instructions to the EOP Writers concerning format and content of the Emergency Operating Procedures.
3.5 Veri ficati on This is the evaluation performed to technical accuracy of the
- PSTG, and the technical accuracy and written correctness of the EOPs.
~
~
ons ibilities 4.0
~R 4.1 Station Su erintendent The Station Superintendent shall have the overall responsibility for the development of EOPs.
He shall assign the responsibility for EOP veri ficati on.
4.2 0 erations Su rvisor 4.3 The Operations Supervisor shall determine the requirement for, and scope of, verification and approve veri fication resolutions.
He shall assign the responsibility of EOP writing.
EOP Writers EOP Writers shall normally be members of the pl ant operating department desi gna ted by the Opera tions Supervisor.
Writers shall have the responsib ility of resolving any discrepanci es disci osed during the verification process.
5.0 Plant S ecific Technical Guideline Verification 5.1 Veri fica tion R
uiremen ts The Plant Specific Technical Guideline will be verified using the following criteria:
1.
Generic Emergency Procedure Guidel ines have been properly impl emen ted.
2.
Plant specific numbers are correct.
3.
Gal culati onal procedures are correct.
5.2 Verification Process
- Steps, cautions and notes will be verified using the criteria listed in Section 5.1.
A PSTG Verification Form will be prepared each time a
verification is performed in order to document the process.
EOP-FORM 3 is the PSTG Verification Form.
The following information will be included:
1.
PSTG revision being verified.
2.
The appl icab1 e Generic Emergency P rocedur e Gui del ine revision.
nudzh er
- 3. Start date 4.
Scope of verification (specific steps or "all")
5.
Source documents used 6.
Name of person(s) performing verification 7.
A list of discrepancies including step, caution or calculation
- number, and discrepancy sheet number 8.
Discrepancy Form nurrbers applicable (entered upon approval of resoluti ons )
- 9. Signature of approval of verification process 10.
Date of approval.
Part I of a PSTG Discrepancy Form (EOP-FORM
- 4) will be completed by the person performing the verification for each discrepancy.
The following information will be included:
l.
2.
3.
5.
Discrepancy Form nuaber Step/cauti on/ca 1 cul ati on number Description of discrepancy Signature of the person who identified the discrepancy Da te.
5,3 The Discrepancy Form number will consist of two parts.
The first part will be the revision nuober of the PSTG being reviewed.
The s econ d number wi1 1 be the sequen tia 1 number assi gn ed to th e discrepancy.
For example, the first discrepancy of the revision "0" PSTG uouI d be numbered:
Number 0
I The person performing the evaluation will be provided with the.
appl icabl e revision of the Generic Emergency Procedure Gui del ine, EPG Change
- Forms, the PSTG and cal culational procedures (PSTG Package ).
The person per forming the veri fica ti on shall independently review any source documents required to veri fy the technical accuracy of the PSTG.
All PSTG Discrepancy Forms will be attached to the PSTG Verification Form.
This will be the PSTG Verification Package.
When the review process is compl ete, the Verification Package (Verification Form and Discrepancy sheets) and PSTG Package will be returned to the Operations Supervisor for resolution.
Resoluti on When the PSTG Package and Verification Package are returned to the Opera tions Supervisor, he wil 1 assi gn the res pons ibility of resolution.
Assigned personnel are EOP Writers (see Section
- 3. 3).
The EOP Writers will resolve each discrepancy and complete Part II of each Discrepancy Form, entering the following information:
1.
Description of resolution 2.
Si gnature 3.
Da te.
5.4 ~Ri
/A The compl eted Veri fica ti on Package wi 1 1 then be retur ned to the Operations Supervisor for review and approval.
The Operations Super visor, after reviewing the Verification Package, will return it to the EOP Writers if a resolution is found to be unsatisfactory, or approve it by compl eting in the Verifica ti on Form wi th the applicable discrepancy sheet
- numbers, signature and date.
6.0 E'mer enc 0 eratin Procedure Veri fication
~
~
~
~
6.1 Veri fication R
uiremen ts The EOPs shall be verified using the following criteria:
1.
The PSTG has been properly impl emented.
2.
The EOPs have been written in accordance with the EOP Writer' Guide.
3.
The in forma ti on required in the EO Ps is avail ab 1 e to the operator in the control room.
4.
The parameter values required by the EOPs are consistent with the available control room indi cati ons.
5.
The controls and indications required to perform tasks called for in the EOPs are available to the control room operator.
6.
The nomenclature used in the EOPs is consistent with that used in the control room and plant.
7.
The language and level of information is compatible with the qualifications, training and experience of a licensed operator.
8.
Differences be@/een the PSTG and the EOP are properly justified (Step Documentation Forms).
6.2 Verification 'Process Each
- step, caution, graph and note will be verified using the criteria listed in Section 6.1.
As many EOP Verifi cation Forms (EOP-FORM 5) as requir ed will be compl eted for each EOP verified to document the process.
The following information will be included:
l.
EOP number 2.
PSTG revision nuober 3.
EOP revision number
- 4. Start date 5.
Scope of verification (specific steps or "all")
6.
Name of person(s) performing verification and initials 7.
A list of all steps verified with either initials indicating acceptance, or a
Discrepancy Form nurrber indicating a
discrepancy.
- 8. Sheet number (if more than one form is required) 9.
Discrepancy Form numbers
- entered upon approval of resolutions 10.
Signature of approval of the verificationprocess 11.
Date of approval.
- Notes, cautions and graphs will be verified as par t of the step to which they apply.
Par t l of an EOP Verification Discrepancy Form (EOP-FORM 6) will be completed by the person performing the veri fication for each step not in compl iance wi th the Secti on 6.1 criteria.
The following informati on will be included:
l.
EOP being verified 2.
Discrepancy Form nuA er 3.
The EOP step number
4.
A description of the discrepancy 5.
Signature of the person identifying the discrepancy 6.
Date.
The Discrepancy Form number will consist of two parts.
The first is the revision number of the EOP being verified.
The second is the sequential nuober assi gned to the discrepancy.
For exampl e, the first discrepancy in revision "0"
of EOP-RL would be number:
NurA>er 0
1 The persons assigned the responsibility of EOP verification will be provided with the following material:
1.
The EOP(s ) to be verified
- 2. 'he PSTG 3.
The EOP Writer's Guide 4.
Step Documentation forms.
The person (s )
responsib1 e for the verifi cation wi1 1 review these documents, any other source material required and the control room to assure that the Section 6.1 criteria is met for each EOP step.
All EOP Verification Discrepancy Forms will be attached to the EOP Verification Form, this will be the EOP Verification Package.
Upon compl eti on of the review by the person (s )
res pons ible for ver ifica tion, the Verifica tion P ack age, PS TG and Step Documenta tion Forms will be returned to the Opera tions Supervisor.
6.3 Resoluti on When the Verification Package is returned to the Operations Supervisor, he will assi gn the respons ibility of resolution.
Assigned personnel are EOP Writers (see Section
- 3. 3).
The EOP Writers will resolve each discrepancy and complete Part II of the Discrepancy Forms, entering the following information:
l.
A description of the resolution 2.
Si gnature 3.
Date.
- 6. ~i The compl eted EOP Verification Package is returned to the Operations Supervisor for review and approval.
The Operations Supervisor, after reviewing the package, will return it to the EOP Writers if a resoluti on is found to be unsatisfactory, or approve it by compl eting the Verification Form.
Compl etion of the form requires entering the appl i cable Discrepancy Sheet
- numbers, si gnature and date.
- 7. 0 Documen tation The PSTG Verification Package and the EOP Verification Package provide documentation of the veri fication process.
Plant S ecific Technical Guideline EOP-FORM 3
PSTG Rev.
No.:
EPG Rev.
No.:
Start Date:
Scope of Veri fication:
Per son (s ) Performing Verification:
Source Documents:
PSTG:
- Step, PSTG:
- Step, Cauti on, Discrepancy Cauti on, Cal culationt Form 0 Cal culationt PSTG:
- Step, Discrepancy Cauti on, Form 0 Cal culati one Discrepancy Form 0 Discrepancy Form No.:
to Res ol ved sa tis fa ctor ily:
Si gnature of Operations Supervisor:
Date:
I
PS TG D IS CRE PANG Y FORM u
er:
EOP-FORM 4 Part I to be com 1 eted b
ersone er formin veri ficati on)
PSTG Step/Caution/Cal cul ati on Number:
Description of Discrepancy:
Si gnature:
Part II: (to be com leted b
EOP Writer)
Description of Resolution:
Date:
Si gna ture:
Date;
l~
EOP VERIFICATION FORM EOP-FORM 5
EOP Rev.
PSTG Rev.
No.:
Start Date:
Scope of Veri fication:
Person(s)
Performing Verification:
arne n1 tla s
arne arne nit>a s
/
nltla s
Sheet No.:
Sect. t'.t Sect.
to'-l Sect.
1o'. I Step Criteria Met Discrepancy Step Criteria Met Discrepancy Step Criteria Met Discrepancy No.
( Initials )
Number No.
( Initials )
Number No.
( Initials )
Number Dis ncy Form No.:
to Reso 1 ved sa tis fac torily; Si re of Operations Supervisor:
Date:
EOP VERIFICATION DISCREPANCY FORM EOP-FORM 6
Part I (to be com leted b
erson erformin the verification)
EOP Step Number:
Description of Discrepancy:
Signature:
Part II: (to be com leted b
EOP Writer)
Description of Resolution:
Date:.
EOP Writer:
Si gnature:
Date:
~
~
~
~
0 0
NINE MILE POINT UNIT 2 NUCLEAR STATION EMERGENCY OPERATING PROCEDURES PROCEDURE NO.
2-EOP-3 EMERGENCY OPERATING" PROCEDURE VALIDATION Summar of Pa es Revision NIAGARA NHNK POWER CORPORATION THIS PROCEDURE HOT TO BE USED AFTER SUBJECT TO PERIODIC REVIE'A
Section 1.0 Introduction 2.0 References 3.0 Definitions 4.0 Responsibil ities 5.0 EOP Validation 6.0 Documentati on Table 1 - Evaluation Criteria Table of Contents
~Pa e
EOP-FORM 7 -
EOP Validation Form EOP-FORM 8 -
COP Assessment Form EOP-FORM 9 - Validation Discrepancy Form 10 12
- l. 0 Introducti on 1.1
~Pur ose The purpose of this procedure is to provide guidance for the process of val idation of the Emergency Operating Procedures at Nine Mile Point Unit 2.
1.2 ~Sco e
This p'rocedure wil 1 descr ibe and direct the val idation process.
Val idati on provides assurance that the Emergency Operating Procedures are
- accurate, sound and usabl e.
This procedure appl ies to the initial Emergency Procedures and revisions.
- 2. 0 Re ferences 2.1 Emergency Operating Procedures Validation Guideline (INPO 83-006) 2.2 Nine Mile Point Unit 2 FSAR 3.0 Definitions 3.1 Emer enc eratin Procedure (EOP)
A plant procedure which provides the operator actions necessary to mitigate the consequences of transients and accidents.
- 3. 2 Validation A
process which ensures that EOPs can be used succes fu1 ly in emergency situations.
- 3. 3 Su rt Procedures Procedures (other
3e 4 Scenario An event or sequency of events devel oped to test an
- EOP, or a
speci fic section of an EOP.
3e 5 Tab 1 e-To Val ida ti on A discussion method of checking EOPs using specific criteria.
3.6 Walk-Throu h Validation A simulated response to a scenario done in the plant control room.
3.7 Simulator, Validation A
res pon se to a
real time s imul ate d scenar io done on a
pl ant reference simulator.
4.1 Station Su erintendent The Station Superintendent shall have the overall responsibility for the development of Emergency Operating procedures.
- 4. 2 0 era tions Su cry is or The Operations Super visor shall determine the requirement for, the scope of, and method (or methods
)
of, val idati on, and approve val idati on resoluti ons.
He shall assign the responsibility of EOP writing.
He shall assign
.the responsibility of val idation.
- 4. 3 Reviewers Persons per forming the val idati on shall be referred to as reviewer s.
They shall complete the process as directed by this procedure.
4.4 EOP Writers EOP writers shal 1
normal ly be members of the pl ant operati on department designated by the operations supervisor EOP writer s shall have the responsibil ity of r esoluti on of discrepancies disclosed during the validation process.
5.0 Emer enc eratin Procedure Val idati on 5.1 Val i da tion Re uiremen ts The Emergency Operating Procedures will be validated using specific cr iteria.
The appl i cabil ity of the criteria is dependent on the method.
Each validation method will use the acceptance criteria as presented in Table 1.
The validation methods are:
1.
Tab 1 e-To p, 2.
Wal k-through, 3.
Simul ator.
5.2 Val idation Process The validation process will be initiated by the operations supervisor (see Section
- 4. 2).
He will complete Part I of the
Validation form (EOP-FORM 7).
The following information will be included:
l.
EOP Title, 2.
EDP Number, 3..
EOP Revision, 4.
Scope of Validation (specific steps or "All),
5.
Method(s) to be used, 6.
Names of reviewer(s),
7.
Signature of the operations supervisor, 8.
Date.
An EOP Assessment Form (EOP-FORM 8) shall be fil1 ed out by a
reviewer for each method of assessment util ized.
The following information will be included:
l.
EOP Number, 2.
EOP Title, 3.
EOP Revision, 4.
Assessment
- method, 5.
Name of reviewer(s),
- 6. Date, 7.
Names of Operations personnel
- involved,
- 8. Position held by
- operator, license held by operator (enter "None" if not licensed),
- 9. Check-off for compl eti on of step-by-step discussion (Table-Top method only),
- 10. Description of scenari o(s )
(a brief description of scenar io(s )
used to test the procedure).
Par t I of a Verification Discrepancy Form (EOP-FORM 9) shall be filled out by the reviewer for each discrepancy disclosed during assessment.
The following information will be included:
1.
Assessment
- method, 2.
Discrepancy number (a sequential number will be assigned to each discrepancy disclosed during a specific method of assessment),
3.
EOP Number, 4.
EOP Revision, 5.
Descripti on of discrepancy (the descripti on should include sufficient detail to properly define
- problem, and suggested resolution(s) resul ting from discussion wi th Operations personnel ),
6.
Signature of Reviewer, 7.
Date.
Val idation Discrepancy Forms should be attached to the appl icable EOP Assessment Form.
The reviewer or reviewers will be responsible for the preparation and assessment phases of the val ida tion.
The prepara ti on and assessment for each method is described in the following sections.
- 5. 2.1
~
~ ~b1-h Preparati on for the tabl e-top method for val idati on involves the fol 1 owing:
2.
3.
4.
Selection of operating personnel to participate (minimum of 3, SRO or RO),
Obtaining copies of the EOP to be validated, Obtaining any suppor t procedures whi ch mi ght be required during discussion, Reviewing EOP and acceptance criteria with Operations personnel.
- 5. 2.2 An EOP Assessment Form shall be completed by the reviewer.
The asses sment shoul d involve a
step-by-step discuss i on of the procedure, talk-through of poss ibl e scenari os involving use of the procedures, and documentation of discrepancies.
Possible resolution of discrepancies shoul d be discussed.
The step-by-step discussion should involve identification of the operator tasks required for each step.
The discussion of possible scenarios may be done during or after the step-by-step discussion.
The reviewer may specify equipment failures as required to test the procedures.
Discussion of possible discrepancies should involve causes and resolu tions.
Al 1 di screpanci es shoul d be documented on a
Verificati on Discrepancy Form.
Walk-Throu h Method Preparation for the walk-through method of validation involves the fo1 1 owin g:
1.
Sel ecti on of operating personnel to parti ci pate.
The number and qualifications of people used to staff the control room should be consistent with the staffing in an actual situation.
Others can be involved for cogent and discussion.
2.
Obtaining copies of the EOP to be validated.
3.
Assuring availability of support procedures in the control room 4.
Reviewing the EOP and acceptance criteria wi th the oper ati ons personnel.
5.
Preparation of scenario(s
) to be used for assessment of procedures.
6.
Arranging use of the control room with the operations supervisor.
An EOP Assessment Form should be compl eted.
The walk'-through should involve a
simulated response to symptoms or conditions specified in the scenario.
The walk-through can be interupted for discussion of tasks and possible discrepancies;
- however, an attempt should be made to maintain the continuity of the exercise.
At the conclusi'on of each scenario exer cise, discrepancies should be identified, discussed and documented on a Validation Discrepancy Form
( EOP-FORM 6).
4-
- 5. 2.3 The number of different scenarios required is that necessar y to test procedure being verified, branches from the procedure and references to other procedures.
Simulator Method Preparation for the simulator method includes the following 1.
Selection of oper ations personnel to parti ci pate.
The number and qual ifica ti ons of peopl e used to staff the simulator shoul d be consistent with the staffing in an actual situation.
Others can be involved for comment and discussion.
2.
Obtaining copies of the EOP to be verified.
3.
Obtaining any support procedures required.
4.
Reviewing the EOP and acceptance criteria with the operations personnel 5.
Preparation of scenario(s) to be used for assessment of procedures.
6.
Reserving s imul a tor time wi th the Nine Mile Point Training Depar tment.
An EOP Assessment Form should be completed by the reviewer.
The s imul a tor assessment shoul d involve real time response to the scenario(s) developed to validate the EOP.
The reviewer should present initial pl ant condi tions to the opera tions personnel prior to each exerci s e.
5.3 The exercise (response to a
simulated inci Cent) shoul d run wi thout interuption until completion, or as long as required to complete the assessment.
Notes can be taken by the reviewer and non-participating opera ti on s personnel concerning poss ibl e procedure di s ere pan ci es.
At the conclusion of each
- exercise, the possible discrepancies should be discussed.
Discussion should include possible causes and resolutions, and differences between the simulator and pl ant equipment which would affect the response.
Discrepancies should be documented on a Validation Discrepancy Form.
The number and type of scenarios is dependent on the procedure being validated, and should be sufficient to test the
- EOP, branches to other procedures and references to other procedures.
Resolu ti on Upon compl eti on of the required assessments, Part I I of the EOP Val idation Form shall be completed by a
reviewer.
The EOP Assessment Form/Validation Discrepancy Form group(s) should be attached to the EOP Val i da ti on Form.
Thi s shal 1
be the EOP Val i da ti on Package.
The Validation Package is then returned to the operations supervisor.
The operations supervisor will assign the responsibility of resolution to EOP writers.
The EOP writers wi1 1 resolve al 1 discreganci es and complete Part II of each Validation Discrepancy Form.
The following
information shall be included:
1.
Description of the resolution, 2.
Si gna ture, 3.
Date.
Mhen resolutions are compl eted, the EOP Validation Package is returned to the operations supervisor for review and approval.
After reviewing the
- package, the operations supervisor will return the Validation Package to the EOP writer s if any resolu tion is unsa tis fac tory, or complete Part III of the EOP Validation Form
( with his signature and date) denoting approval of the Validation process.
6.
Documenta ti on The EOP Validation package shall provide documentation of the Validation process.
I
TABLE 1
E VALUATION CR ITER IA
~Le end:
x - applicable to the validation method o - not applicable to the validation method T-T - table-top validation method W-T - walk-through val idation method S - simulator validation method TT WT S
X X
X
- 1. There is sufficient information to perform the specified actions.
X X
X 2.
The labeling, abbreviations, and locations as provided in the EOP are sufficient to enable the operator to find the needed equipment.
X X
X 3.
The EOP is not missing information needed to manage the emergency con dition.
X X
X 4.
The contingency actions are sufficient to address the symptoms.
X X
X 5.
The titles and number are sufficiently descriptive to enable the operation to find referenced and branched procedures.
X.
X X
6.
The EOP is easy to interpret and follow.
X X
X 7.
The figures and tables are easy to read with accuracy.
T T WT S
X X
X 8.
The values on figures and char ts can be easily determined.
X X
X
- 9. Caution and note statements are readily understandable.
x x
x 10.
The acti ons speci fied in the procedure can be performed in the designated sequence.
x x
x
- 11. All systems or components which could be utilized for given symptoms are used.
o x
x 12.
The information from the plant instrumentation can be
- obtained, as specified by the EOP.
o x
13.
The plant symptoms specified by the EOP are adequate to enable the operator to select the applicable EOP.
o o
x 14.
The EOP entry conditions are appropriate for the plant parameters displayed to the operator.
0 0
X 16.
The plant responses agree with the EOP basis.
o x
x 17.
The instrument readings and tolerances stated in the EOP are cons is tent wi th the ins trument values displayed on the instruments 0
X 0
18.
The instrument readings and tolerances specified by the EOP for remotely located instruments are accurate.
0 X
X
- 19. If time intervals are specified, the procedure action steps can be performed on the plant within or at the desi gnated time intervals.
0 X
X 20.
The procedure action steps can be per formed by the operation shift.
0 X
X 21.
The operating shift can follow the designated action step sequences.
TT WT S
t x
x x
22.
Procedure branches can be entered at the correct point.
x x
x 23.
EOP exit points are specified adequately.
x x
x 24.
Adequate support procedures ar e available.
EOP VALIDATION FORM EOP-FORM 7
Part I (to be com 1 eted b
erations Su rvisor)
Title:
EOP Number:
EOP Revision:
Sco pe of Val i da tion:
Validation Method(s):
Reviewer
(s ):
Si gna tur e:
Da te:
Part II (to be com leted b
reviewer)
Table-To Validation Assessment com 1 ete-Nuober of discrepancies:
Si gna tur e; Date:
Walk-Throu h Validation Assessment com 1 ete-Nuaber of discrepancies:
Signature:
Date:
Simulator Validation Assessment com 1 ete Nurser of discrepancies:
Si gna ture:
Da te:
Part III (to be com leted b
0 erations Su ervisor)
This validation package has been reviewed.
Al 1 discrepancies have been resol ved sa tis fac torily.
Si gnature:
Date:
EOP ASSESSMENT FORM EOP-FORM 8 EOP-Nues er:
EOP Revision:
Reviewer(s):
Operations Personnel:
Name EOP
Title:
As ses sment Me thod:
Position Date:
License Step-by-Step discussion completed:
(Check i f done, Table-Top Method only)
Oescription of Scenario(s):
'I
VALIDATION DISCREPANCY FORM EOP-FORM 9 Part I (to be com leted b
reviewer)
Assessment Method:
EOP Nurser:
Discrepancy No.
EOP Revision:
Description of Discrepancy:
)
Si gnature:
Date:
Part II (to be com 1 eted b
EOP writer)
Description of Resolution:
Si gnature:
Da te:
Ly 4.C E
t