ML20205A318
| ML20205A318 | |
| Person / Time | |
|---|---|
| Site: | Millstone, Haddam Neck, 05000000 |
| Issue date: | 08/03/1988 |
| From: | Brinkman S, James Smith CONNECTICUT YANKEE ATOMIC POWER CO. |
| To: | |
| Shared Package | |
| ML20204H467 | List:
|
| References | |
| EOP-2525, NUDOCS 8810250466 | |
| Download: ML20205A318 (17) | |
Text
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. STATION PR0CE0VRE COVER SHEET A. IDENTIFICATION
,r] Numbef: E0P 2525 Rev. 3
Title:
STANDARD POST T' RIP ACTIONS >
Prepared By: STEVE BRINKMAN B. REVIEW I have reviewed the abo've procedure and have found it to be satisfactory.
TITLE SIGNATME DATE
, DEPARTMENT HEAD w 7/fd bbbus bum
- .) '
/v V7 C. SPECIFIC UNREVIEWED SAFETY QUESTION EVALUATION REQUIRED:
Modifies intent of procedure and changes operation of systems as described in design documents. YES ('] NO,((
(If yes, perform written USQ determination and Safety' Evaluation, and contact Manager, Safety Analysis Branch to determine need for Integrated Safety Evaluation.)
ENVIRONMENTAL REVIEW REQUIRED (Adverse environmental impact) YES ( ] NO [%
- 0. SPECIFIC SAFETY EVALUATION REQUIRED Affects response of safety systems, performance
- of systems which may have been credited in the safety analysis or non-credited systems which may indirectly affect safety system response. YES ( ) NO K]
(If yes, perform written Safety Evaluation and contact Manager, Safety Analysis Branch to determine need for Integrated Safety Evaluation.)
E. INTEGRATED SAFETY EVALUATION REQUIRED YES ( ) N0 f)(J F. PROCEDURE REQUIRES PORC/SORC REVIEW (in addition to review, items with a YES response must be documented in the PORC/SORC meeting minutes.) YES % NO ( )
G. PORC/SORC APPROVAL PORC/SORC Meeting Number 7-bbl 3/
H. APPROVAL AND IMPLEMENTATION The attached procedure is hereby approved, and effective on the date below:
Sta isaw n/ Service /yfiit Superintendent vNtr Ef f ec'tive Date SF301/9/s/SES/87-12/lof1 0010250466 081007 PDR ADOCK 05000213 P PDR J
4 . UNIT 2 STANDARD POST TRIP ACTIONS 1
Page No. Eff. Rev. .
1-16 3 a
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l 82 E0P 2525 Page 1 Rev. 3
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STANDARD POST TRIP ACTIONS
- 1. jRPOSE To provide the immediate actions which must be accomplished after an automatic or manual reactor trip. These actions are necessary to ensure the plant response results in stable safe conditions or that the plant is configured to respond to a continuing emergency. This is the entry procedure for the E0P System. .
- 2. ENTRY CONDITIONS O
O Any symptom (s) of a Reactor Trip,
- a. Reactor trip alarm (C04)
- b. CEA Bottom Lights (C04)
- c. Rapid decrease in reactor power (C04)
- d. Reactor trip circuit breakers open (C04/RPS)
()
V E0P 2525 Page 2 Rev. 3 J
STANDARD POST TRIP ACTIONS
()
- 3. IMMEDIATE OPERATOR ACTIONS NOTE Steps 3.1 through 3.7 should be performed by the Primary Plant Operator. Steps 3.8 through 3.21 should be performed by the Secondary Plant Operator. Steps 3.22 through 3.25 should be performed by the SS/SCO. The three designated operators perform their assigned actions in parallel.
PRIMARY PLANT OPERATOR -
Instructions Contingency Actions NOTE Boration times when more than 1 CEA not fully inserted are:
- a. 12 minutes for each additional CEA, using 3 charging pumps
- b. 18 minutes for each additional CEA, using 2 charging pumps
- c. 36 minutes for each additional CEA, using 1 charging pumps 3.1 Ensure the reactor hs tripped by 3.1 depressing the four "Reactor Manual Trip" pushbuttons (C04),
Then
- b. Verify no more than 1 CEA b. Borate by the following:
not inserted (C04)
- 1. Verify BAST level greater than 10% (CO2)
O E0P 2525 Page 3 Rev. 3 i
r Instructions Contingency Actions
- 11. Open bor'ic acid pump I '] discharge t',
charging pump, 2-CH-514 (CO2) 111. Start both boric acid pumps (CO2) iv. Close beric acid pump recirculation valves 2-CH-510 and 2-CH-511 (CO2)
- v. Start all available charging pumps (CO2) vi. If necessary, refer to Functional Recovery of Reactivity Control, E0P 2540A, Step 3.3, for additional pg boration paths.
O vii. When time permits.
- Then complete OPS Form 2208-13, Shutdown Margin NOTE Pressurizer level will normally decrease to 25-30% after reactor trip and will take approximately 30 minutes to regain 35-45% level.
3.2 Verify RCS Inventory Control '.y 3.2 the following:
- a. Pressurizer level between a. Verify that Tavg is g 20 and 65% (C03) decreasing below 525'F (C04) and
- b. Pressurizer level trending b. Manually control charging and s to 35-45% (CO3) letd.own (CO2)
(Q E0P 2525 Page 4 Rev. 3
Instructions Contingancy Actions
( )
display).
NOTE Pressurizer pressare will normally decrease to 1900-2000 psia after a full power reactor trip and take approximately 10 minutes to regain 2225-2300 psia.
3.3 Verify RCS pressure control by 3.3 Do the following
- a. Pressurizer pressure a. Manually control heaters and 1900 - 2350 psia (CO3) and spray to return pressure to 2225-2300 psia (CO3) ,
- b. Pressurizer pressure trending b. M, main spray flow is to 2225 - 2300 psia (C03) excessive, Then stop two RCPs (8 and 0 preferred) (C03)
- c. PORVs and pressurizer c. M pressurizer pressure safeties not open by decreases to 1600 psia (C03),
(]
V Then
- i. Normal quench tank i. Verify or manually level, pressure and initiate SIAS, CIAS, and temperatures (C03) EBFAS (C01/C01X)
- 11. Stop one RCP in each and loop (A and C preferred)
- 11. No acoustic monitor (C03) alarms (C02) lii. Shut the spray valve at the discharge of the idled RCP in loop 1 and leave in manual (CO3)
- d. HT subco h
ling decreases below 30 F (ICC summary display), Then stop all RCPs (C03)
(3 V
E0P 2525 Page 5 Rev. 3
Instructions Contingency Actions
- e. If either PORV is open, Then
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k'
- i. Verify RCS pressure less than 2300 psia (C03) and
- 11. Close the block valve of the open PORV (C03)
- f. Note abnormal conditions on Break Identification Chart, Figure 4.1, to assist in event diagnosis.
NOTE Verification of natural circulation flow is accomplished in .
E0P Recovery Procedures. .
- 3. 4 Verify at least one RCP operating 3.4 If an electrical emergency is in each loop (C03) is diagnostd, Then Complete Standard Post Trip a.
O'- Actions. j and
- b. Consider use of Electrical Emergency, E0P 2528.
l 3.5 Verify normal containment 3.5 Do the following:
conditions by the following: '
- a. Containment pressure less a. Ifcontainmentpressure than 2 psig (C01) increases to 5 psig (C01), . ,
Tnen verify or manually initiate SIAS, CIAS, and EBFAS (C01/C01X).
O E0P 2525 P3ge 6 Rev. 3
- Instructions Contingency Actions
- b. Containment temperature b. Il containment pressure
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f) ,
less than 120*F (computer increases to 27 psig (C01),
"# point CVCONTEMP) Then verify or manually initiate CSAS (C01/C01X).
- c. No increase in containment c. Note abnormal conditions on radiation monitors (RCl4 and Break Identification Chart, C101) Figure 4.1, to assist in event diagnosis.
- d. No unexplained increase in
, containment sump level (C06).
3.6 Verify Steam Jet Air Ejector 3. 6 and Blowdown Radiatiun monitors a. Note abnormal conditions not alarming (RC14), and Main Break Identification Chart, Steam Line Radiation monitors Figure 4.1 .
(RC05E) not alarming, af
- b. H Steam Generator Tube Rup'ture is diagnosed, Then
/S 1. Complete Standard Post Trip Actions 3.ng
- 11. Consider use of Steam Generator Tube Rupture, E0P 2534.
3.7 Verify plant Radiation monitors 3.7 H radiation levels increasing, outside containment not in:reasing Then inyt:stigate for breaks (RC14, C06, C101). outside containment (local)
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E0P 2525 Page 7 Rev. 3
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SECONDARY PLANT OPERATOR Instructions Contingency Actions
/ 3.8 Ensure the turbine has tripped 3.8 E generator megawatts not zero,
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by depressing the turbine "Trip" Then pushbutton (EHC insert panel), a. Close MSIVs (C05)
Then do the following: and
- a. Verify all steam admission b. Verify MSIV bypass valves valves closed (C07) closed (C05) and
- b. Verify generator megawatts indicate zero (C07) 3.9 Ensure the generator ACBs 3.9 a. Manually open ACBs at Remote are open by simultaneously Switchgear Terminal'(C-909, depressing both "8T & 9T Emerg Unit #1) .
Trip" pushbuttons (C07), Then g
- verify generator ACBs indicate b. Direct. Convex to manually open (C07) , trip ACBs by the following:
- 1. Open 15G-8T-2
/' 11. Open 15G-7T-2 U' 111. Open 310-15G-5 iv. Close 15G-8T-2
- v. Open 15G-9T-2 3.10 Verify the transfer of 6.9 KV 3.10 Verify diesel generators start and 4.16 KV buses to the RSST by (or manually start) and energize buses 24C and 240 (C08), Then
- a. NSST breakers open (C08) a. Complete Standard Post Trip Actions.
and 3_nd
- b. RSST breakers closed (C08) b. Consider use of Electrical Emergency, E0P 2528.
O E0P 2525 Page 8 Rev. 3 L m
e Instructions Contingancy Actions NOTE Loss of 125 VOC bus will result in extensive loss of plant instrumentatien.
3.11 Verify 125 VDC load centers, 3.11 201A and 201B, are energized (C08). a. Ccmplete Standard Post Trip Actions l
. aa
- b. Consider use of Electrical Emergency, E0P 2528 3.12 Open heater drain pump subcooling 3.12 Continue with this procedur.e.
valve, 2-HD-106 (C05). '
3.13 Stop both heater drain pumps 3.13 Continue with this procedure.
(C05).
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E0P 2525 Page 9 Rev. 3
Instructions Contingency Actions 3.14 E'stablish proper main feedwater 3.14 DJ the following:
{'s s[vstemconfiguration.
One main feed pump
- a. a. E main feed flow is operating (C05). excessive, Then
- b. Speed control at minimum i. Manually close main feed (C05). regulating valves or
- c. Main Feed regulating valves blocking valves and closed (C05), control feedwater flow
- d. Feed regulating valve using bypass (C05) bypass ve,1ves open to or 70-80% (C05) 11. Trip the main feedpumps
- e. Feed flow decreasing (C05). (C05).
- f. Main feed pump discharge b. . E main feedwater is pressure 50-150 psi greater unavailable, Then than steam generator i,
- Manually start niectric pressure (C05). driven (preferred) or
- g. Feedpump discharge steam driven auxiliary isolation valve, feed pump (C05).
2-FW-38A(B), of the 11. Close main fe,ed pump
\ non-operating pump discharge isolation closed (C05). valves, 2-FW-38A and B (C05).
- c. H high steam generator level trip was initiated, Then open feed regulating valve bypass valves when high level trip clears (C05),
- d. M all feedwater flow is lost, Then
- i. Complete Star.dard Post Trip actions and
- 11. Consider use of Loss of All Feedwater, E0P 2537.
O- E0P 2525 Page 10 Rev. 3 a
Instructions Contingency Actions 3.15 Stop all but one condensate pump 3.15 Continue with this procedure.
[T
( /
by placing switches in "pull to lock". (C05)
CAUTION Do not overreact to low steam generator level. Add feedwater slowly to avoid
- a. excessive pressurizer level and pressure transient
- b. excessive cooldown rate
- c. overfilling steam generators NOTES
- 1. Steam generator level may go below 0% af ter trip, and take .
several minutes to regain level in the indicating range.
- 2. If steam generator level falls below 12%, auxiliary feedwater au'tomatically initiates and will start pumps and commence
(; feeding steam generators, after a 3 minute and 25 second time delay.
3.16 Verify steam generator level 3.16 trending to 70-80% (C05)
- a. Adjust r.ain or auxiliary feed flow to return level to 70-80%
(C05)
Er
- b. If automatic auxiliary .
feedwater initiated Then do the following:
- 1. Verify steam generator level greater than 12%
(C05).
A N~ A E0P 2525 Page 11 Rev. 3
Instructions Contingency Actions
- 11. Position auxiliary J.
(
%j
) feedwater override h69dswitches to "Pull tu Lock" (C05).
iii. Take the "normal reset override" switches to override momentarily, iv. Manually control auxiliary feed regulating valves to return level to 70-80%
(C05) 3.17 Verify proper steam generator 3,17 Do the following heat removal by the following .
- a. When steam generator pressure a. If condenser vacuum (back is less than 950 psia, Then pres.) is not 0-15 in. Hg verify main steam safety abs., Then valves are closed (local) 1. Operate atmospheric dump
{' '- b. When steam generator pressure
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valves to return Tavg to is less than atmospheric dump 530-535 F (C04) valve controller setpoint, and Then verify atmospheric dump 11. Refer to Loss of valves closed (C05) Condenser Vacuum,
- c. Steam dump and bypass AOP 2574 valves functioning to b. If steam generator pressure
- i. Return Tavg to decreases to 850 psia, Then 530-535'F (C04/5) do the following:
and 1. Verify' atmospheric dump
- 11. Control steam valves closed (or generator pressure manually close) (C05) at 880-920 psia (C05) 11. Verify steam dump and bypass valves closed (or manually close) (C05)
O E0P 2525 Page 12 Rev. 3
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- Instructions Contingency Actions iii. Verify steam seal
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t
(~'} pressure 2-6 psig (or
'J manually isolate) (C05) iv. Isolate blowdown (C05)
- v. Start mechanical vacuum pumps (local) vi. Secure steam jet air ejectors (local) vii. Switch to electric dri*en auxiliary feed pamps (;05) and secure main f',ed pump turbine (C05) viii.0ispatch operator,
- outside to look.ft '
steam discharge (li-tal)
- c. E steam generator pressure decreases below 800 psia, Then close MSIVs.
v' ,d. M either steam generator pressure falls to 500 psia, Then verify MSI or manually initiate MS1, by the following (C05)
- 1. Verify MSIVs closed.
- 11. Verify MSIV bypass valves closed, iii. Close main and auxiliary feedwater air assisted check valves, iv. Close both main feedwater regulating valves,
- v. Trip both main feedwater pumps.
O E0P 2525 Page 13 Rev. 3
O e .
Instructions Contingency Actions a
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vi. Close main steam low (v )
(
point draf' alve.
vii. Close main f6adwater regulating valve bypass valves,
- e. Note abnormal conditions on Creal. Identification Chart, Figure 4.1, to assist in event diagnosis.
3.18 Verify instrument air header 3.18 ,
pressure greater than 90 psig (C06) a. Complete Standard Post Trip actions
- a,nj .
1 .
- b. Refer to Loss of Instrument Air, AOP 2563.
2.19
{5 3.19 Verify two RBCCW pumps, operating (C06) a. Complete Standard Post Trip Actions and
- b. Refer to Loss of R8CCW, AOP 2564
__3.20 Verify two service water pumps 3.20 operating (C06) a. Complete Standard Post Trip j Actions
^$
- b. Refer to Loss of Service Water, A0P 2565 l
3.21 verify steam seal pressure 3.21 Hanually control steam seal feed 2-6 psig (C07) valve, 2-MS-1828, or steam seal feed bypass valve, 2-MS 182A, to
, return pressure to 2-6 psig (C07)
U]
E0P 2525 Page 14 Rev. 3
St/SCO Instructions Contingency Actions 3.22 Notify personnel 3.22 Continue with this procedure
[ ') a. SS/SCO and
- b. Outy Officer 3.23 Notify CONVEX of status of plant 3 23 Continue with this procedure 3.24 Re.fer to Shift Supervisor 3.24 Continue with this procedure Procedure, EPIP 4010A, for further guidance.
3.25 g plant responding as expected 3.25 after reactor trip, Then go to Reactor Trip Recovery, E0P 2526 a. Diagnose event and go M the apprbpriate E0P. .
- i. H any break is suspected, then refer to Break Identification Chart, Figure 4.1 to O'd assist diagnosis a n,,g .
- 11. Go to appropriate break E0P EE
- b. H diagnosis of one event is not apparent, Then go to Functional Recovery E0P 2540.
- 4. FIGURES 4.1 Break IdenJ fication Chart
- Final -
E0P 2525 Page 15 Rev. 3 i
FIGURE 4.1 BREAK IDENTIFICATION CHART INITI.*.L CONDITION: PRES $URIZER PRES $URE DECREA51NG EITHER
.YE5 $/G PRESSURE N0. "
<800 pst?
ygg CONTAINMENT NO PRESSURE INCREA51NG7 CONTAINMEN NO YE5 PRESSURE INCREA51NG7 ,
I SECONDARY SECONDAAT ggg $ {g 3REAK ,
BREAK N LINE OR BLOW 00WN YE5 IN51DE OUTSIDE RAD MONITORS CONTAINMENT CONTAINMENT ALAgggget PRIMRY PRIMRY BREAK BREAK INSIDE OUTSIDE CONTAINMENT CONTA!NMENT I J E0P'2532 E0P 2534 10P 2536 LOS$ OF STEAM GENERATOR EXCESS TUBE RUPTURE STEAM PRIMRY COOLANT DEMND UNIQUE SYMPTOM 5_:
e NI RAD IN CONTAINMENT eHI RAD IN $[CONDARY
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.No RAD INCREASE eNORt%L C0!stAthMENT COND1110NS O E0P 2525 Page 16 Rev. 3
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