Rev 14 to Emergency Operating Procedure EOP 8.2, 'Steam ...

•

•

ENCLOSURE 2 ATTACHMENT 5

CONSUMERS POWER COMPANY PALISADES PLANT

DOCKET 50-255

Emergency Operating Procedure EOP 8.2 "Steam Generator Tube Rupture"

(Abridged)

8308230406 830815 PDR ADOCK 05000255 P PDR

NU080983-NL01

August 15, 1983 5 Pages

•

•

PALISADES NUCLEAR PLANT EMERGENCY OPERATING PROCEDURE

Proc No EOP 8.2 Revision 14 Page 1 of 4

TITLE: STEAM GENERATOR TUBE RUPTURE

This procedure assumes a Steam Generator Tube rupture which results in a leak greater than charging capability and~ subsequent Reactor trip, with steam dump operation. ~~

1.0 SYNPTOMS

Any one or more of the following symptoms may be present.

. a. High radioactivity alarm on the following instruments .

1. Steam Generator blowdown monitor **RIA-0707.

• 2. Condenser off-gas monitor ;';-;'•RIA-0631.

3. Waste gas monitor ;'d•RIA-1113.

4. Stack gas monitor ;';-;"RIA-2319.

5. Penetration and Fan Room area monitor **RIA-5710.

b. Decreasing pressurizer level.

c. Standby Charging Pumps on .

d. Decreasing primary pressure.

e. TM/Lo pressure Reactor trip and safety injection initiation after 15-20 minutes.

2.0 AUTOMATIC ACTIONS

a. Standby Charging Pumps start.

b. Reactor trip.

c. Safety injection.

d. Steam Generator blowdown valves shut.

3. 0 IMMEDIATE ACTIONS

3 .. 1 Determine which Steam Generator is leaking.

a. Steam Generator sample.

b. Radiation survey of steam pipe.

c. Steam Generator level .

d. Feedwater system response, i.e., valve position, level recorder trace, etc.

pa0380-0014a-89-93

c>?-'" (f;k

0 u z 0 llml

~

<JI :e ~

•

•

3.2

3.3

3.4

3.5

3.6


TITLE: STEAf1 GENERATOR TUBE RUPTURE


If the Reactor has not tripped, reduce plant load at maximum rate which will not of itself ciuse a plant trip (i.e., from low pressurizer pressure): Turbine ramp down at approximately 2%/minute. PDIL does not apply for emergency power reduction. Attempt to reduce load and remove unit from the ~ine before tripping Reactor, to minimize steam dump. Survey Main Steam Lines to aid in determining which Steam Generator has failed.

Secure Steam Generator blowdowns ('''-:'CV-0767, ,,_-:,cv-0768, -:,-:,cv-0770 and ,·,-:,cv-0771) and ensure blowdown tank vents (">i>PCV-6003 and ,.,,.,PCV-6004) to atmosphere are closed.

Bypass the condensate demineralizers (open '"'''CV-8206 and close '°"''CV-8208 and ;'d>CV-8207).

Use motor driven Auxiliary Feedwater Pump (**P-8A) as the preferred source of auxiliary feedwater. If the Steam Driven Pump (''"''P-8B) must be used, insure that the steam supply is from the good Steam Generator.

If an SIAS occurs, Place Turbine Generator Turning Gear Motor **K-2 Control Switch in "PULL TO LOCK"

_-:..i )_

3.7 ACTIVATE SITE EMERGENCY PLAN. REFER TO SITE EMERGENCY IMPLEMENTATION PROCEDURE EI-1.

4.0 SUBSEQUENT ACTIONS

4.1 After the unit is off-line, reduce T-avg to less than or equal to 532°F and trip' the Reactor, carry out immediate actions of EOP 1 and minimize the use of atmospheric Steam Dumps.

4.2 Confirm by sample which Steam Generator is leaking.

4.3 Request analysis of condenser off gas.

4.4 Close HSIV from failed Steam Generator only by opening solenoid cabinet ·in NE corner of Turbine Building on 607 deck and:

a. To close -:,.,·,cv-0510 from Steam Generator A, manually unlatch and allow to drop to the tripped position ''""SV-0505B and ;'d>SV-0507B.

b. To close **CV-0501 from Steam Generator B, manually unlatch and allow to drop to the tripped position **SV-0505A and **SV-0507A.

4.5 Trip Primary Coolant Pumps on the affected loop to minimize steam generation if they are running.

4.6 Trip all PCP's if an SIAS occurs .

pa0380-0014a-89-93

• TEMPORARY CHANGE TO A PROCEDURE

Proc No 10.41 Attachment 1 Revision 2 Page 1 of 2

Change No 0-'63-0{)9 Change Date 5- / '2- 8' 3 Expiration Date 7-/ 2-83

Procedure Type Oeereif;Ci~1 s Procedure No £OP8, 2 Rev No/Date /# /J2-2c;-'62 I

Procedure Title I

Paragraph No '-;, 15, b Figure/Table No )/4 Other Paye 3cfil ATMS No 1!103ZO-OC>l'la.-8?-9~

Synopsis (Concise reason for this change) ,Delete. va Ive eltJ-f)R. W 7'1fJ

it de.es not exi.sf i 1, S/4 bloudow,, /;.,e 10 A,-sc&l/ayiecos VIA.s-te.

Change: Delete STe () /./. / 5, b, 0

0 z

(Recommended to be made permanent? C!J No) . .(Safety Related (i;;J No)

THE ABOVE DOES NOT CHANGE INTENT OF ORIGINAL PROCEDURE F. //. Du~ hesneg u. ,/'Initiator

Approved ~ l/'IJJ~5- /i6~&§ed-4L'=J3~> -_,A-~d1e-=--l.::J'l~~=---=---S-"---L--/£""""--u--J____,] PRC Member ~e SRO-J5RceJllber Date

Change to become permanent. Yes No

I Department Head Date

PRC Review Meeting Number ------

Approved I --------_!....-----Plant Manager Date (INSTRUCTIONS ON BACK)

ad0582-0003b-93

J tt

le i;i

a l fl . iJ ' fl

f !

4.7

4.8

4.9

4.10

4.11

4.12

4.13

4.14

4.-15


TITLE: STEAf1 GENERATOR TUBE RUPTURE


Maintain Steam Generator level in the faulted Steam Generator at approximately 25% following trip to provide volume for Primary Coolant leakage and prevent flooding of Steam Generator and Main Steam Line. Secure feedwater flow if necessary to prevent refill above 25%.

CAUTION

Take care to insure that PCS pressure remains approximately 100 psi greater than Steam Generator until the Steam Generator can be drained, to preclude dilution of PC with leakage from the Steam Generator.

Initiate plant cooldown at a maximum rate per GOP 9, utilizing shutdown cooling as soon as possible to limit further steam generation.

Route Turbine Building Sump Pumps (;'d,P-45A and ;';;'cP-45B) to the Dirty Water Tank **T-60.

Complete a quick rad;i,ation survey of Auxiliary and Turbine Bufil.dings (Attachment 2). If indications of fuel damage are present, such as abnormally high radiation on Volume Control Monitor (;b'•RI-0202), near NSS samples, etc. secure letdown and see ONP 11.

Notify Plant personnel of any restricted areas established from surveys.

Isolate vents, drains, exhausts and bleed-offs from the steam system (Attachment 3).

If necessary·, the steam dumps on the good Steam Generator may be used to assist in Plant cooldown. Close Air Supply Valves to steam dumps from failed Steam Generator ("A" Steam Generator ;''*CV-0781 and ;'d•CV-0782; "B" Steam Generator ;';;'•CV-0779 and ;b'•CV-0780). Log opening ·time.

IF absolutely necessary, (there is no other heat sink) the affected Steam Gene~ator and associated steam dumps may be used to assist in plant cooldown. Log opening time.

If the leaking _Steam Generator level approaches full scale, drain to the Miscellaneous Waste System by:

a. Isolate the blowdown demineralizer ;':;':T-104. (close ;h'cMV-DRW809).

b. Check open the Header Valve to Miscellaneous System .,.,.,.,r-IV-DRW774.

c. Open Miscellaneous Waste Filter 'Inlet Valve to selected filter j

;';;'•r-IV-DRW768 U•;»r-IV-DRW769).

pa0380-0014a-89

•

•

-.

NOTE:

4.16


TITLE: STEAM GENERATOR TUBE RUPTURE

d. Check open appropriate Filter Outlet Valve ;'•kMV-DRW777 (;'.-.':MV-DRW770).


e. . Verify room in Miscellaneous Waste Hold Tank (;':;'<T-92A, ;'rl<T-92B, **T-92C) or line up to pump to a Filtered Waste Monitor Tank.

f. Jack open the bottom blowdown valve from the leaking Steam Generator ;'n<CV-0771 (;'d<CV-0770) and open its Series Isolation Valve ·k;'<CV-0767 (;b'<CV-0768).

g. Adjust the manual blowdown valve ;'ri<~1V-MS107 (;h'<MV-MS108) as necessary to maintain Steam Generator level on scale.

It may be necessary to use the bypass key at ;",::EC-105 in orde-r to get the blowdown pumps to run.

This procedure is competed with the establishment of PCS pressure and inventory control, and shutdown cooling per SOP 1, however, PCS/SG + 100 psid must be maintained per Step 4.8, CAUTION .

. ~- '

pa0380-0014a-89

•

•

• NU080983-NL01

ENCLOSURE 2 ATTACHMENT 6

CONSUMERS POWER COMPANY PALISADES PLANT

DOCKET 50-255

Off Normal Procedure ONP 21 "Natural Circulation"

(Abridged)

August 15, 1983 8 Pages

ONP 21

NATURAL CIRCULATION

Revision 6

This procedure applies to a loss of all primary coolant pumps while the PCS is hot and pressurized.

1.0 Symptoms ·~ i'

(1) Low primary coolant flow alarm or RPS trip.

(2) "/;;'•P-50A, "l•"l•P-50B, "ld•P-SOC, "ld•P-50D trip (alarms).

(3) Buses lA and lB low voltage and/or trip alarms.

(4) Low PCP motor current.

(5) Initial trending of key parameters:

(a) Reactor Power - Decreasing

(b) Pressurizer Pressure - Decreasing

(c) Average PCS Temperature - Decreasing

(d) Pressurizer Level - Decreasing

(e) Steam Generator Pressure - Increasing

(f) Steam Generator Level - Decreasing

2.0 Automatic

(1) Reactor Trip

(2) Turbine Generator Trip

3.0 Immediate

(1)

(2)

(3)

Verify Reactor Trip. If not, manually trip the reactor. Carry out EOP 1, Immediate Actions.

Verify Steam Dumps and/or Bypass Valve open and are controlling steam pressure at 900 psia.

Initiate Site Emergency Implementing Procedures.

0. 0 u z 0 -... i 0 ~~

z ~

I I I i ! i

I I I I I I

' I

I I i

I

l I

I I

pa0380-0015a-89 1 : ·-··.-, ... ,. -.,.! ·-· ·-·; l

•

•

NATURAL CIRCULATION - .ONP 21, Rev 10

4.0 Subsequent .

(1)

(2)

Verify all immediate actions have been initiated.

Note: This procedµre is to be performed in conjunction with EOP 1.

Establish and maintain hot leg temperature and PCS pressure within the operating region of the 50°F subcooling/saturation curve. (Use EOP 1, Attachment 2, or use curve posted in Control Room.)

(a) Verify that pressurizer heaters a.re functioning to maintain pressurizer pressure. If necessary, manually operate heaters and/or auxiliary spray to restore and maintain pressurizer

.Pressure.

(b)

(c)

(d)

Note: Pressurizer spray valves (;'d•CV-1057 and ;'•kCV-1059) may have to be closed in order to increase auxiliary spray flow to the pressurizer.

Verify that charging and letdown are functioning to maintain pressurizer level. If necessary, manually operate charging and letdown to restore and maintain pressurizer level.

Maintain Steam Generator levels by the addition of auxiliary feedwater.

CAUTION: 't..i' The·· addition of cold fee-dwater substantially ·-increases the cooldown rate.

Operate the Steam Dumps and/or Turbine Bypass to control PCS temperature.

NOTE: Verification of some plant responses to a plant change cannot be accomplished until approximately five (5) to ten (10) minutes following the action due to increased loop cycle times.

(3) Confirm, by the following indication, that natural circulation has been established at approximately ten (10) minutes after PCPs were tripped:

(a) Loop ~T (Th - Tc) less than normal full power ~T (47°F).

(b) Cold leg temperatures constant or decreasing.

(c) Hot leg temperatures stable (ie, not steadily increasing).

(d) No abnormal differences between hot leg RTDs and core exit thermocouples. (Do not depend on a single indication. Use several thermocouples and all RTDs.)

(e) Steam Generator levels are ~ -84%* (on wide range Steam Generator level instruments) .

*NOTE: The desired level indication will change with system temperature and pressure.

pa0380-0015a-89-93 2

(

c

NATURAL CIRCULATION - ONP 21, Rev 9

(4) Start one PCP in ~ach loop per SOP 1 if the following criteria are satisfied:

(a) At least one steam generator is removing heat from the PCS. '.

(b) Pressurizer level and pressure are responding normally to the pressurizer level and pressure control systems.

(c) PCS hot leg temperatures and PCS pressure are within the operating region of the 50°F subcooling/saturation curve. (Use EOP 1, Attachment 2 or use curve posted in Control Room.)

NOTE: In the event that Th is less than 515°F, use thermocouple readings from ~~e Primary Datalogger for the temperature indication.

(d) Verify SIS has been reset.

NOTE: If at anytime a PCP is restarted, this procedure will be concluded. Continue with EOP 1.

(5) Verify shutdown requirements of Technical Specification 3.10.1 have been met by performing EM-04-08.

(6) If total makeup inventory drops below 172,000 gallons and a primary coolant pump cannot be restarted, cooldown must be started within 2 hours. If the decision is made to cooldown, proceed to the following section.

NOTE: Credit may be taken for the contents of the following tanks: ";'n'•T-2, ";';-·kT-0939, *;'•T-81, and ;\-kT-90. Refer to SOP-12.

Natural Circulation Cooldown:

CAUTION: During all phases of the cooldown, PCS temperature and pressure should be continuously monitored to avoid exceeding a maximum cooldown rate of 100°/hour. ·

(7) Borate to cold shutdown concentration.

NOTE: Auxiliary pressurizer spray valve (**CV-2117) may have to be operated to equalize boron concentration between the PCS and pressurizer.

(a) Maintain maximum PCS pressure permitted by Figure SOP 1-2.

(b) After two (2) hours of natural circulation, verify (by sample) the PCS and pressurizer boron at or above cold shutdown concentration.

(8) Follow GOP 9 with the following exceptions:

(a) Ignore any reference to primary coolant pumps.

pa0380-0015a-89-154 3

CONTROLLED COPY

• NATURAL CIRCULATION - ONP 21, Rev 6 I

(b) Any reference to pressurizer sprays shall be interpreted as meaning auxiliary spray.

I::•

(c) PCS conditions for placing the shutdown cooling system in operation will be governed by ONP-21.

(9) Attempt to establish a cooldown rate of 75°/hour to 85°/hour.

(10) Continuously confirm natural circulation flow throughout cooldown process (see Step 3).

(11) During cooldown, maintain maximum PCS pressure permitted by Figure SOP 1-2.

NOTE: A high cooldown rate combined with high PCS pressure will maximize reactor vessel head heat loss while preventing void formation.

(a) If pressurizer heaters become unavailable:

1. Maintain pressurizer bubble as long as possible.

a. Minimize use of pressurizer auxiliary. spray. ~ ;_ ·-

b. Stop all pressurizer sampling if not needed.

c. Minimize pressurizer level fluctuations.

d. Stop PCS degassing through pressurizer.

e. Maintain PCS cooldown rate greater than or equal to the pressurizer cooldown rate caused by pressurizer ambient heat loss until PCS temperatures are cooled down to the shutdown cooling system maximum allowed entrance temperature.

2. Attempt to maintain PCS subcooling margin using charging and letdown system.

3. If PCS subcooling margin drops below operating region of EOP 1, Attachment 2, initiate HPSI system. Terminate HPSI when subcooling margin is restored to operating region and pressurizer level is indicated and can be maintained.

4. Attempt to reform pressurizer bubble (if possible) whenever adequate subcooling is restored.

(b) If auxiliary spray becomes unavailable, perform the following (listed in order of preference):

1. Use pressurizer fill and drain method to cool pressurizer.

2. Allow pressurizer to cool due to ambient heat loss.

pa0380-0015a-89-154 4

c ·> A,

8 z 0 -j 0 Um z ~

(

.,

NATURAL CIRCULATION - ONP 21, Rev 6 · I

(12)

j/ 3. Open bl9ck valve (*1'•PRV-1042B or ;'d•PRV-1043B) and operate

a PORV (1'd•M0-1042A or ;~-kM0-1043A; remove two high pressure bistable trip units) to reduce pressurizer pressure.

\

If a steam generator was isolated following a Steam Generator Tube Rupture event, continue the natural circulation cooldown by performing the following activities (listed in order of preference):

NOTE: Perform Steps 12a and 12b in conjunction with EOP 8.2 .

(a) If criteria of Step 4 can be met, restart one PCP in each loop to establish cooling of the isolated steam generator.

(b) Periodically drain and refill the isolated steam generator with feedwater.

NOTE: If cooling down by natural circulation with an isolated steam generator, an inverted bT (ie, T higher than Th)-may be observed in the idle loop. This is du~ to a small amount of reverse heat transfei~rom the isolated steam generator and will have no affect on natural circulation flow through the intact steam generator.

(13) During cooldown, maintain subcooling margin within operating region of EOP 1, Attachment 2 by the following methods (listed in order of preference):

(a) Control of pressurizer heaters and auxiliary spray.

(b) Operating charging or HPSI pumps.

(14) During cooldown, maintain pressurizer level by control of charging and letdown.

(a) If the charging system becomes unavailable during cooldown:

1. Isolate letdown system.

2. Operate HPSI pumps to compensate for PCS inventory contraction.

3. Isolate any known leakage if possible. (ONP-23)

4. If PCS pressure is above HPSI pump shutoff head, depressurize by continuing PCS cooldown.

(b) If the letdown system is not available, operate charging pumps as needed to maintain pressurizer level. Maintain pressurizer level between 20% and 40%.

(15) CAUTION: Maintain pressurizer level below 100% such that the capability for monitoring for void formation remains available.

pa0380-0015a-89-154 5 CONTROLLED COP\

> ~ 0 u z . o -i 0 u...

•

•

•

NATURAL CIRCULATION - ONP 21, Rev 6

Depressurize the PCS to SDC initiation pressure by manually operating auxiliary spray if the PCS has been cooled to SDC initiation temperature of less than or equal to 325°F and either:

(a) PCS wide range temperatures have been less than or equal to 325°F for 18 hours, or

(b) 21 hours has elapsed since the start of the cooldown and cooldown has proceeded at a rate of approximately 75°F/hour greater.

(16) During PCS depressuration, monitor for void formation. If substantial void formations are indicated by one or more of the following, go to Step 17:

(a) During steady state conditions, charging a known volume of water/boric acid into the PCS does not result in a corresponding increase in pressurizer level.

(b) Pressurizer level increases significantly greater than expected while operating auxiliary spray.

(c) If pressurizer level control system is in automatic, lli~

unanticipated. letdown flow greater than charging flow .

or

NOTE: During periods of abnormal pressurizer level behavior, charging and letdown controls should be placed in manual since automatic actions may be opposite to those which should be taken.

(d) Core outlet temperature readings higher than saturation conditions.

(e) Increased core ~T above full power (47°F).

(f) Startup neutron dectors showing erratic indication.

(g) Incore thermocouples showing erratic indication.

(h) Th increasing or erratic.

(i) T erratic. c

(17) If voiding of the PCS is indicated, increase PCS pressure_ and pressurizer temperature to operating region of EOP 1, Attachment 2.

(a) Stop depressurization. Verify minimum letdown. Insure pressurizer spray valves are closed c-:.--:.-cV-1057, ;';-;'•CV-1059, and -:.-·kCV-2117) .

(b) Stop PCS cooldown. ·Decrease heat removal by closing Turbine Bypass to condenser and/or closing Steam Dumps.

pa0380-0015a-89-154 6

> ~ 0 u z 0 -... le( =e ~ 0 MI. z ~

j

•

NATURAL CIRCULATION - ONP 21, Rev 6·\

(c) Repressurize the PCS to eliminate the void. Verify maximum charging. Operate all pressurizer heaters (check ;h'•PR-0101A and **PRC-0101B output signal is 0). If PCS pressure is low enough (less than 1250 psi) ensure all HPSI pumps are delivering water to PCS.

(d) When void has been eliminated, resume PCS cooldown. However, further depressurization should not be performed for at least two hours after the condensable void is eliminated.

(18) If void indication cannot be eliminated by performing Step 17 or if indication of a relatively constant void persists at the same system pressure, consider the void to contain noncondensable gases and vent the Reactor Vessel head region. The preferred vent path is to the Quench Tank.

(a) Open either ;'d•PRV-1072 to vent to the Quench Tank or id•PRV-1071 to vent to the containment building (if ;'d•PRV-1072 is not available).

NOTE: PRVs are opened by turning the handswitches to the reset position first, then open.

(b) Operate either id•PRV-1067 or -:.-kPRV"'-1068 for a period of approximately 5 to 10 minutes to vent the reactor head.

CAUTION: Assure that PCS pressure and pressurizer level are maintained during venting.

(c) Refer to ONP-22 for Hydrogen Control.

(d) Evaluate effectiveness of the vent on noncondensable gas removal and repeat venting process if necessary after returning PCS pressure and pressurizer level to desired levels.

(19) Normally noncondensable gases can be removed from the pressurizer via the degas system. However, if a significant volume of noncondensable exists in the pressurizer as determined by:

0

0

0

Difficulty in controlling pressurizer pressure (sluggish response) or

Difficulty in maintaining pressurizer level due to growth of the noncondensable void or

Pressurizer sample, then vent the pressurizer.

The preferred vent path is to the Quench Tank .

(a) Open either i;;'•PRV-1072 to vent to the Quench Tank or id•PRV-1071 to vent to the containment building (if ;'••'•PRV-1072 is not available).

pa0380-0015a-89-154 7 CONTROLltr-.n_ copy

•

NATURAL CIRCULATION - ONP 21, Rev 6 [

NOTE: PRVs ate opened by turning the handswitches to the reset positiop. first, then open.

(b) Operate either •'d•PRV-1069 or •'•kPRV-1070 for a period of approximately five to ten minutes to vent the Pressurizer.

CAUTION: Assure that PCS pressure and pressurizer level are maintained during venting.

(c) Refer to follow ONP-22 for Hydrogen Control.

(d) Evaluate effectiveness of the vent on noncondensable gas removal and repeat venting process if necessary after returning PCS pressure and pressurizer level to desired levels.

(20) If natural circulation cannot be established after completing Step 17, 18, and/or 19, then:

(a) Ensure all available HPSI pumps are running.

(b) Ensure all HP Loop Valves are open ("•"•M0-3007, *•'>M0-3009, ·k;'•M0-3011, •'>•'>~10-3013, ""'•M0-3062, •'~•'>M0-3064, •'•*M0-3066 *·~ *"•M0-3068). -

(c) Open both PORVs ("~"M0-1042A, **M0-1043A, remove two high pressure bistable trip units) and corresponding block valves (•'>•'•PRV-1042B and "'"'PRV-1043B) and cool the core by flow into the cold legs, up through the core, into the hot leg and out the pressurizer.

(21) This procedure will be concluded by:

(a) Starting a primary coolant pump per Step 4 or,

(b) Establishing shutdown cooling mode per Step 15 or,

(c) Completing Step 20, followed by EOP 8.1 .

pa0380-0015a-89-154 8

Rev 14 to Emergency Operating Procedure EOP 8.2, 'Steam ...

Documents