ML20129G507

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Rev 0 to EOP 2525, Std Post-Trip Actions
ML20129G507
Person / Time
Site: Millstone Dominion icon.png
Issue date: 02/24/1984
From: Keenan J
NORTHEAST NUCLEAR ENERGY CO.
To:
Shared Package
ML20129G476 List:
References
EOP-2525, NUDOCS 8506070298
Download: ML20129G507 (17)
v • d • e


Text

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., E.J. Mroczka 8-25-83 Form Approved by Station Superintendent Effective Date b- . STATION PROCEDURE COVER SHEET A. IDENTIFICATION l

Number E0P 2525 Rev. O Title STANDARD POST TRIP ACTIONS Prepared By G. Bischoff B. REVIEW I have reviewed the above procedure and have found it to be satisfactory.

TITLE SIGNATURE DATE DEPARTMENT HEAD NS he&-_-- "A. 84 Cou$ L.

.~ h$ 11 v 7-C. UNREVIEWED SAFETY QUESTION EVALUATION DOCUMENTATION REQUIRED:

(Significant change in procedure method or scope as described in FSAR) YES [ ] NO [ t (If yes, document in PORC/SORC meeting minutes)

ENVIRONMENTAL IMPACT

'(Adverse environmental impact) YES [ ] NO[4-(If yes, document in PORC/50RC meeting minutes)

D. PROCEDURE REQUIRES PORC/SORC REVIEW YES [ t NO [ ]

E. PORC/SORC APPROVAL PORC/SORC Meeting Number 2~7 3-A YO F. APPROVAL AND IMPLEMENTATION The attached procedure is hereby approved, and effective on the date below:

fp &MY (At'ation/Yervice/ Unit Super'intendent Effective Date SF-301 Rev. 6 i

%a 8506070298 850528 PDR ADOCK 05000336 p PDR

. t i STANDARD POST TRIP ACTIONS Page No. Eff. Rev.

1-16 0 v

E0P 2525 Page 1 Rev. O

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, STANDARD POST TRIP ACTIONS

1. PURPOSE 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 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) l

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E0P 2525 Page 2 Rev. 0

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  • STANDARD POST TRIP ACTIONS

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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 min /CEA - 3 chg pumps
b. 18 min /CEA - 2 chg pumps
c. 36 min /CEA - I chg pump 3.1 Ensure the reactor has tripped by 3.1 depressing the four " Reactor a. Open CEDM MG set feeder Manual Trip" pushbuttons (C04), Then breakers (C04)
a. Verify reactor power decreasing or (C04) b. Borate by the following and i. Verify BAST level
b. Verify no more than 1 CEA greater than 10% (CO2) not inserted (C04) ii. Open boric acid pump discharge to charging pump, 2-CH-514 (CO2) iii. Start both boric acid pumps (CO2) mw E0P 2525 Page 3 Rev. O

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Instructions Continaency Actions iv. Close boric 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 boration paths.

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 by 3.2 the following a. Verify that Tavg is not

a. Pressurizer level between decreasing below 525*F 20 and 65% (CO3) (C04).
b. Pressurizer level trending and to 35-45% (CO3) b. Manually control charging and letdown (CO2)
c. RCS greater than 20*F su'a-cooled (RC05E)

E0P 2525 Page 4 Rev. 0

Instructions Contingency Actions NOTE Pressurizer pressure will normally decrease to 2000-2200 psia after 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 1900 - 2350 psia (CO3) and spray to return pressure to 2225-2300 psia (CO3)
b. Pressurizer pressure trending b. If pressurizer pressure to 2225 - 2300 psia (CO3) decreases to 1600 psia (CO3), Then
1. Verify or manually initiate SIAS, CIAS, and EBFAS (C01/C01X)

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11. Stop all RCPS (CO3)
c. PORVs and pressurizer c. If either PORV is open, safeties not open by Then
i. Normal quench tank 1. Verify RCS pressure level, pressure and less than 2300 psia temperatures (CO3) (CO3) and and
11. No acoustic monitor 11. Close the block alarms (CO2) valve of the open PORV (CO3)
d. Note abnormal conditions on Break Identification Chart, Figure 4.1, to assist in event

~! diagnosis

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E0P 2525 Page 5 Rev. 0

. 3 .

i Instructions Contingency Actions NOTE ,

-Verification of natural circulation flow is accomplished in E0P Recovery Procedures.

3.4 Verify at least one RCP operating in 3.4 If an electrical emergency each loop (CO3) is diagnosed, Then

a. Complete Standard Post Trip Actions and
b. Consider use of Electrical Emergency, E0P 2528 3.5 Verify normal containment conditions 3.5 Do the following by the following a. If containment pressure
a. Containment pressure less than increases to 5 psig (C01),

2 psig (C01) Then verify or manually

b. Containment temperature less initiate SIAS, CIAS, than 120*F (computer point K570) and EBFAS (C01/C01X)
c. No increase in containment radiation monitors (RC14 and b. If containment pressure C101) increases to 27.psig (C01),
d. No unexplained increase in Then verify or manually containment sump level (C06) initiate CSAS (C01/C01X)
c. Note abnormal conditions on Break Identification Chart, Figure 4.1, to assist in event diagnosis 4  %%

E0P 2525 Page 6 Rev. 0

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Instructions Contingency Actions 3.6 Verify Steam Jet Air 3.6 Ejector and Blowdown Radiation a. Note abnormal conditions monitors not alarming (RC14) on Break Identification Chart, Figure 4.1 and

b. If Steam Generator Tube Rupture is diagnosed, Then
1. Complete Standard Post Trip Actions and ii. Consider use of Steam Generator Tube Rupture, E0P 2534 3.7 Verify plant Radiation monitors 3.7 ,[f radiation levels increasing,

-( ; 'outside containment not increasing Then investigate-for breaks (RC14, C06, C101) outside containment (local) n w*

E0P 2525 Page 7 Rev. 0

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SECONDARY PLANT OPERATOR

[ Instructions Contingency Actions 3.8 Ensure the turbine has tripped 3.8 If generator megawatts not by depressing the turbine " Trip" zero, 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 are 3.9 a. Manually open ACBs at open by simultaneously depressing Remote Switchgear Terminal both "8T & 9T Emerg Trip" push- (GE/ TAC, Unit #1) buttons (C07), Then verify generator ACBs indicate open (C07) or

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b. Direct Convex to manually.

trip ACBs by the following:

1. Open 15G-8T-2
11. Open 15G-7T-2 iii.Open 348-15G-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 and 4.16 KV buses to the RSST by start (or manually start)
a. NSST breakers open (C08) and energize buses 24C and and 24D (C08), Then
b. RSST breakers closed (C08) a. Complete Standard Post Trip Actions and
b. Consider use of Electrical Emergency, E0P 2528 E0P 2525 Page 8 Rev. 0

s I Instructions Contingency Actions NOTE Loss of 125 VDC bus will result in extensive loss of plant instrumentation.

3.11 Verify 125 VDC load centers, 201A 3.11 and 201B, are energized (C08)

a. Complete Standard Post Trip Actions and
b. Consider use of Electrical Emergency, E0P 2528

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. 3.12 Stop all but one condensate 3.12 Continue with this procedure pump by placing switches in " pull to lock". (C05) 3.13 Open heater drain pump subcooling 3.13 Continue with this procedure valve, 2-HD-106 (C05) 3.14 Stop both heater drain 3.14 Continue with this procedure l

pumps (C05) 1

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l E0P 2525 Page 9 Rev. 0 l

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Instructions Contingency Actions m-3.15 Establish' proper main feedwater 3.15 Do the following ,

system configuration a. If main feed regulating

a. One main feed pump operating (C05) valves fail to close,
b. Speed control at minimum (C05) Then
c. Main feed regulating valves 1. Manually close main closed (C05) feed regulating valves
d. Feed regulating valve bypass or blocking valves and valves open to 50-60% (C05) control feedwater flow
e. Feed flow decreasing (C05) using bypass (C05)
f. Main feed pump discharge or pressure 50-150 psi greater 11. Trip the main feed-than steam generator pumps (C05) pressure (C05) b. If main feed water is unavailable, Then manually start electric driven (preferred) or steam I' driven auxiliary feed pump (C05)
c. If high steam generator trip was initiated, Then open feed regulating valve bypass valves when high level trip clears (C05)-
d. If all feedwater flow is lost, Then
1. Complete Standard Post Trip actions and ii. Consider use of Loss of All Feedwater, E0P 2537 e**

E0P 2525 Page 10 Rev. 0

J Instructions Contingency Actions l ,' CAUTION Do no't overreact to low steam generator level.

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Add feed- .

I water slowly to avoid

a. excessive pressurizer level and pressure transient l
b. excessive cooldown rate
c. overfilling steam generators

- NOTES

1. Steam generator level may go below 0% after trip, and take several minutes to regain level in the indicating range.
2. If steam generator level falls below 12%, auxiliary feedwater automatically-initiates and will start pumps and commence feeding steam generators, after a 3 minute and 25 second time delay.

t 3.16 Verify steam generator level 3.16

( trending to 70-80% (C05) a. Adjust main or auxiliary feed flow to return level to 70-80% (C05)

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b. Ijf automatic auxiliary feed-water initiated, Then do the following
i. Verify steam generator level greater than l

12% (C05) e 11. Position auxiliary feed- ,

I water override hand-switches to " Pull to L

Lock" (C05) iii. Manually control aux-iliary feed regulating l-

! valves to return level to 70-80% (C05)

[. E0P 2525 Page 11 Rev. 0

Instructions Contingency Actions

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{(_ 3.17 Verify proper steam generator heat 3.17 Do the following removal by the following a. If condenser vacuum (back pres.) is not 0-15 in. ,

a. When steam generator pressure Hg abs. , Then is less than 950 psia, Then 1. Operate atmospheric verify steam generator safeties dump valves to return are closed (local) Tavg to 530-535'F (C04)
b. When steam generator pressure and is less than atmospheric dump 11. Refer to Loss of Conden-valve controller setpoint, ser Vacuum, AOP.2574 Then verify atmospheric dump b. If steam generator pressure valves closed (C05) decreases to 850 psia,
c. Steam dump and bypass valves Then do the following functioning to i. Verify atmospheric dump
i. Return Tavg to 530-535'F valves closed (or (C04/5) manually close) (C05) and ii. Verify steam dump and

-( ii. Control steam generator bypass valves closed pressure at 880-920 psia (or manually close)

(C05) (C05) iii. Verify steam seal pressure 2-6 psig (or manus 11y isolate) (C05) iv. Isolate blowdown (C05)

v. Start mechanical vacuum pumps (local) vi. Secure steam jet air ejectors (local) vii. Switch to electric driven auxiliary feed pumps (C05) and secure main feed pump turbine (C05) i s

E0P 2525 Page 12 Rev. 0

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Instructions Contingency Actions

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( viii. Dispatch operator outside look for .

steam discharge (local)

c. If steam generator pres-sure decreases below 800 psia, Then close MSIVs.
d. If either steam generator pressure falls to 500 psia, Then verify MSI or manually initiate MSI, by the following (C05)
1. Verify MSIVs closed
11. Verify MSIV bypasses closed iii. Close main and

(. auxiliary feedwater air assisted check valves iv. Close both main feedwater regulating valves

v. Trip both main feed-water pumps vi. Close main steam low point drain valves vii. Close main feed-water regulating valves bypass valves
e. Note abnormal conditons on Break Identification Chart, Figure 4.1, to assist in event diagnosis E0P 2525 Page 13 Rev. O

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Instructions Contingency Actions 3.18 Verify instrument air header 3.18 pressure g'reater than 90 psig a. Complete Standard Post .

(C06) Trip actions and

b. Refer to Loss of Instrument Air, AOP 2563 3.19 Verify two RBCCW pumps operating 3.19 (C06) y a. Complete Standard Post Trip Actions and
b. Refer to Loss of RBCCW, A0P 2564 3.20 Verify two service water pumps 3.20 operating (C06) a. Complete Standard Post Trip Actions and
b. Refer to Loss of Service Water, AOP 2565 3.21 Verify steam seal pressure 3.21 Manually control steam seal 2-6 psig (C07) feed valve, 2-MS-182B, or steam seal feed bypass valve, 2-MS-182A, to return press-ute to 2-6 psig (C07) i i -

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E0P 2525 Page 14 Rev. 0

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SS/SCO l Instructions Continaency Actions

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3.22 Notify personnel 3.22 Continue with this procedure

a. SS/SCO and
b. Duty Officer 3.23 Notify CONVEX of status of plant 3.23 Continue with this procedure 3.24 Refer to Incident Assessment 3.24 Continue with this procedure and Classification, Unit 2, OP 2501, and Communications, Outside Assistance and Response, ACP 1.07.

3.25 If plant responding as expected 3.25 after reactor trip, Then go to a. If any break is sus-Reactor Trip Recovery, E0P 2526 pected, Then

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i. Refer to Break Identi-fication Chart, Figure 4.1 to assist in diagnosis and
11. Go to appropriate proc-edure SE
b. If diagnosis of one event is not apparent, Then go to Functional Recovery, E0P 2540
4. FIGURES 4.1 Break Identification Chart

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E0P 2525 Page 15 Rev. O

Figure 4.1 h

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SREAK IDENTIFICATION CHART INITIAL -

CONDITION: PRESSURIZER PRESSURE DECREASING

  • ' / EITHER YES V 56 PRESSURE NO

< $00 psia STEAM LINE/  %'

FEED LINE ^

BREAK o CONTAINMENT PRESSURE INCREASING yg3 ' ' C0iiTAINMENT NO PRESSUPE .,

  • INCREASING LOSS OF PRIPARY

/ C00LAtiT SJAE INSIDE DUTSIDE AND BLOWDOWN CONTAINMENT CONTAINMENT NO YES RAD MONITORS ALARMING

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INSIDE OUTSIDE i .

CONTAINMENT CONTAlhMENT

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E0P 26?6 E0P12532 EOP 2534

. EXCESS. LOSS OF STEAM STEAM PRIMARY

' GENERATOR

! DEMAi4D COOLANT TUBE RUPTURE

  • 1 A. ,

EOP 2525 Page 16 Rev. O j .

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