ML20132G745
| ML20132G745 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 06/25/1985 |
| From: | Wilczynski D TOLEDO EDISON CO. |
| To: | |
| Shared Package | |
| ML20132G743 | List: |
| References | |
| 1A-1B, NUDOCS 8508050128 | |
| Download: ML20132G745 (53) | |
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l ACTION PLAN # 1A,1B TITLE: Aux 111arv Feed Pumps Overspeed Trips 1
APPR.
CHAIRMAN FOR REV DATE REASON FOR REVISION BY TASK FORCE IMPL.
See Rev. O for approvals 0 l6/20/85 Initial Issue 1 6/25/85 General Rewrite #g l'
8508050128 850627 PDR ADOCK 05000346 P PDR
(
t TITLE: AUXILIARY FEED PUMPS OVERSPEED TRIPS REPORT BY: Dan Wilczynski, Chuck Rupp Plan No.: 1A and IB DATE PREPARED: 6/24/85 Page 1 of 11 This report has been prepared in accordance with the " Guidelines to Follow When Troubleshooting or Performing Investigative Actions into the Root Causes Surrounding the June 9, 1985, Reactor Trip," Rev. 4. These guide-lines were developed in response to Confirmatory Action Letter 85-05.
I. INTRODUCTION On Sunday, June 9,1985, normal feedwater flow to the steam generators was interrupted. The reactor was automatically shutdown and reactor heat was removed via steaming through the main steam safeties and the I
atmospheric vent valves. The water level in the steam generators was decreasing and at 1:41:03 a Steam and Feedwater Rupture Control System (SFRCS) full trip was initiated on Channel 1 due to a low water level in Steam Generator #1 (SG #1). This SFRCS actuation attempted to initiate auxiliary feedwater flow by opening the steam supply valve, MS 106, from SG #1 to auxiliary feedwater pump turbine (AFPT) #1. Five seconds after the initial SFRCS (1:41:08) the reactor operator inadvertently initiated an SFRCS low pressure trip on both channels and both steam generators. This low pressure trip of SFRCS is intended to respond to a steam line break or other equipment failure resulting in depressurizing a steam generator. The manual low pressure SFRCS trip initiated the following, as designed:
- 1. Sent a close signal to MS 106 (which was partially open at the time) and MS 107 (which was closed at the time).
- 2. Sent a close signal to AF 608 and AF 599, containment isolation valves on auxiliary feedwater path to steam generator #1 and #2, respectively.
- 3. Sent an open signal to MS 106A (steam supply for AFPT #1 from steam generator #2) and MS 107A (steam supply for AFPT #2 from steam generator #1) in an attempt to operate both AFPTs on opposite SGs.
Each AFPT tripped on overspeed (4500 RPM) approximately 25 seconds after initial roll.
Paga 2 of 11 L
( This report documents the review of data from previous unit trips, the 6/9/85 trip, AFPT testing, and other utility overspeed trips to determine possible causes of the overspeed trips which occurred at Davis-Besse on 6/9/85. Based on this review, this report presents hypothesized causes of the observed overspeed.
Based on review of currently available information, we conclude that the most likely hypothesis of those considered is introduction of water slugs into the AFPTs causing overspeed. Based on discussions with Terry Turbine, water slugs flash as they pass through the turbine inlet nozzles resulting in acceleration of the turbine rotor.
(It appears that introduction of excessive amounts of water may slow down the turbine.)
Although introduction of water slugs is judged to be the major cause of the observed overspeed, other factors may have contributed and will be further investigated. These other factors include:
- 1) AFPT governor problems
- 2) " Double start" due to switchover of cteam supply for AFPT #1.
- 3) Pump discharge flow was through the minimum recirculation path only.
II.
SUMMARY
OF DATA In order to determine possible causes of the overspeed trips on 6/9/85, the following data were collected and analyzed. A summary of the analysis for the 6/9/85 plant trip and several previous trips is provided.
For each plant trip and surveillance test, the specific sequen'ce of events was reviewed with particular attention to the following parameters.
AFPT speed vs. time AFP flow and discharge pressure St'eam generator pressure and level Specific valve line-ups Figure 1 and Attachment 1 provide a summary of pertinent steam and l
feedwater system features associated with the AFPTs (for reference).
A. June 9, 1985 Plant Trip Summary During the June 9, 1985 trip transient, the following sequence of events regarding auxiliary feedwater flow initiation occurred:
- Steam flow was initially provided to AFPT #1 via the normal path through MS 106 and turbine speed began increasing.
This was initiated by a steam generator low level trip in the SFRCS at 1:41:03. Steam flow to AFPT #2 was not immediately initiated since a low level condition did not exist in SG #2 at this time.
Page 3 of 11 L
( -
As a result of an operator initiated low steam header pressure SFRCS trip (1:41:08), the steam supply to AFPT #1 was switched to SG #2 through MS 106A. The SFRCS also initiated steam flow through the MS 107A flow path from SG
- 1 to AFPT #2.
The low pressure SFRCS trip resulted in switching the discharge path from the auxiliary feedwater pumps (AF 3870 closed, and AF 3869 and 3871 opened) and AF 599 and AF 608 were closed. The net result of these actions was to isolate the feedwater discharge path of both auxiliary feedwater pumps leaving only the minimum recirculation path available.
The speed characteristics are shown on Figures 2 and 3 of Attach-ment 2. A review of the speed vs. time characteristics for AFPT #1 shows the typical characteristics of several oscil'lations prior to reaching rated speed but the final oscillation was un-controlled and increased turbine speed to the overspeed trip setpoint.
A review of the speed characteristics for AFPT #2 shows an uncharacteristic leveling off at approximately 2500 RPM for about eight (8) seconds from which point turbine speed quickly increases to above 4100 RPM, decreases slightly and then continues to increase to the overspeed trip setpoint. The pause at 2500 RPM could be due to excessive water induction into the turbine.
B. Past Plant Trips and Surveillance / Testing Data Based on our evaluation of previous plant trips and surveillance testing, we have the following observations:
- 1) The AFPT speed vs. time characteristic is relatively uniform for each trip (See Attachment 2).
- 2) The specific steam supply and feedwater flowpath configura-tion encountered during the 6/9/85 trip transient has not previously been duplicated.
- 3) No previous testing had been performed to simulate a " quick start" using only the cross connects (MS 106A and MS 107A) for steam supply to the AFPTs.
Ths~ similarities and differences for each of the previous trips
- and tests compared to the 6/9/85 event are described below with particular attention to the hypothesis judged most likely to have caused the overspeed condition.
- 1. March 2, 1984 Plant Trip A review of the trip data indicates that a SFRCS low
-- - ~ ~
pressure trip was initiated during the event due to a stuck
. open Main Steam Safety Valve. This SFRCS initiation closed
Page 4 of 11 L
l the steam supply valve (MS 107) from SG #2 to AFPT #2 and opened the cross connect valve MS 107A to supply steam to AFPT #2 from SG #1. This switch of steam supply occurred 21 seconds (12:37:55) after both AFPTs had been started via MS 106 and MS 107. A review of the speed vs. time character-istics (see Figures 4 and 5 of Attachment 2), show that AFPT #2 experienced a decrease of approximately 1000 RPM at sixteen (16) seconds after the SFRCS low pressure trip.
This speed decrease may be attributed to' excessive water being picked up from the MS 107A line and being carried to the turbine.
The following differences between the 3/2/84 event and the 6/9/85 event assist in explaining why the AFPTs reached the overspeed trip setpoint on 6/9/85 but not on 3/2/84.
On 3/2/84, since MS 107 was open and heating the line, opening MS 107A introduced only 250' of cold piping, thereby reducing the amount of water introduced to the turbine.
On 3/2/84, additional water may have been introduced by opening MS 107A because the steam lines were not '
drained periodically at this time.
- On 3/2/84, since AFPT #2 was pumping approximately 1000 GPM, if a slug of water occurred from opening of MS 107A, there would have been more resistance to a speed increase as compared to the 6/9/85 event when only a min-recire flow path was availabl.e.
On 3/2/84, both AFPTs had the Woodward PG-PL governors installed.
- 2. January 15, 1985 Plant Trip This event initiated a SFRCS trip on low SG level which, due to valve control changes made during the 1984 refueling outage, opened all four steam supply valves to the AFPTs.
Also, AFPT #2 had the new PGG governor installed during the 1984 refueling outage. The speed characteristics are shown on Figures 6 and 7 of Attachment 2.
The following differences between the 1/15/85 event and the
~6/9/85 event assist in explaining why both turbines tripped on overspeed on 6/9/85 but not on 1/15/85.
- On 1/15/85, due to the pipe configuration, initial steam flow to both turbines would have been via the normal flow paths, MS 106 and MS 107. Therefore, initial heating of the respective lengths (360' and 125') may have occurred prior to steam flow through
--' ~-~
the cross connects resulting in less total mass of
Page 5 of 11
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( water introduced to the AFPTs than postulated for the 6/9/85 event.
On 1/15/85, both pumps had a flow path other than minimum recirculation available, therefore, speed increases would be accompanied by corresponding flow increases, thus maintaining loading on the pump. This flow path was not available on 6/9/85.
- 3. March 21, 1985 Plant Trip This event initiated a SFRCS trip on low SG 1evel that resulted in all four steam supply valves opening at the same time.
The speed characteristics are shown on Figures 8 and 9 of Attachment 2. A review of the speed characteristics for AFPT #1 show the typical characteristics consistently seen on AFPT #1 (i.e. , several oscillations prior to reaching rated speed).
The following differences between the 3/21/85 event and the 6/9/85 event assist in explaining why both turbines tripped on overspeed on 6/9/85 but not on 3/21/85.
On 3/21/85, due to pipe configuration, initial steam flow to both turbines would have been via the normal flow path, MS 106 and MS 107. Therefore, initial heating of the respective lengths (360' and 125')
would have been done prior to steam flow through the cross connects resulting in less total mass of water introduced to the AFPTs than is postulated to have formed during the 6/9/85 event.
On 3/21/85, both pumps had a flow path available other than the minimum recirculation, therefore, any speed increase would be accompanied by a corresponding flow increase, thus maintaining loading on the pump. This flow path was not available on 6/9/85.
i l A review of the speed vs. time characteristics show that AFPT #2 indicates a constant rate of acceleration until approximately 35 seconds after initial roll at which time there was an 800 RPM decrease in 2 seconds followed by an
---1800 RPM increase in 3 seconds. This oscillation may be
- due to slugs of water.
- 4. April 12, 1985 Testing After the change-out of the speed setting bushing from a 30 second rated bushing to a 15 second rated bushing on AFPT
- 2 governor, two quick start tests were performed to verify operability. This-changeout was performed to ensure flow was provided by AFPT #2 within 40 seconds as required by
Page 6 of 11
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Technical Specifications. These tests were run on the i
normal steam supply path via MS 107 and with the pump discharge valves closed (i.e., min-recire path open). Less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to these two (2) tests some additional testing was done on this same turbine using the same valve line-ups. This prior testing was performed for trouble-shooting. Due to the prior testing, the steam lines may not have been cooled to ambient conditions prior to the two (2) operability tests being run. The speed characteristics are shown in Figures 10 and 11 of Attachment 2.
A review of the speed vs. time characteristics shows that the first run exhibited speed increases which appear to be a series of step changes rather than a constant acceleration to rated speed. The second run (performed immediately after the first) shows a constant rate of acceleration to rated speed. This is attributed to the fact that the steam lines were already heated, therefore, there would have been less condensation.
- 5. June 2, 1985 Plant Trip This event initiated a SFRCS actuation on low SG level.
Both AFPTs were supplied steam from their respective steam I generators via MS 106 and MS 107.
i The speed characteristics are shown on Figures 12 and 13 of Attachment 2. . A review of the speed characteristics for i AFPT #1 shows the typical characteristics consistently seen on AFPT #1 (i.e. , several oscillations prior to reaching
- rated speed).
l I A review of the speed vs. time characteristics for AFPT #2 shows a fairly steady increase to rated speed but the speed l continues past the high speed setpoint (3710 RPM) to approximately 4000 RPM for about three (3) seconds. The turbine then decreased speed and controlled at the high speed setpoint. During the initial increase to rated
! speed, the speed increases are seen as step changes rather i than a straight line. These step changes, and the increase i
to approximately 4000 RPM, may be attributable to water j slugs.
F The following differences between the 6/2/85 event and the
---6/9/85 event assist in explaining why both AFPTs reached
- the overspeed trip setpoint on 6/9/85 but not on 6/2/85.
l
- Both AFPTs were running on the normal steam supply
- paths via MS 106 and MS 107, therefore, there could be less condensation reaching the turbines.
I i
Page 7 of 11 r
Both pumps had a discharge path available other than C
the minimum recirculation path, therefore, any speed increase would be accompanied by a corresponding flow increase, thus maintaining loading on the pump. This ,
flow path was not available on 6/9/85. '
- 6. June 9, 1985 Testing (Post Trip)
After the plant trip, a quick start test was performed on each of the AFPTs. These tests were run on the normal supply paths via MS 106 and MS 107. Both pumps discharge valves were closed such that only minimum recirculation flow was provided. These tests were run approximately ten (10) hours after the AFPTs had been shut down, therefore, the lines were still warm and the amount of condensation would be less than expected for ambient temperature lines. .
The speed characteristics are shown on Figures 14 and 15 of Attachment 2. A review of each speed vs. time charac-teristic shows a constant acceleration to rated speed.
AFPT #1 does not exhibit oscillations seen at other times.
The " smoothness" of these graphs may be attributable to the '
fact that minimal condensation would be expected since the lines were already heated.
C. Modifications
-1. During the 1984 refueling outage, the #2 AFPT governor was changed out from a Woodward PG-PL governor to a Woodward PGG governor. The new governor was supplied with 7 lb/in buffer springs and a 30 second speed setting bushing.
Prior to startup from the 1984 refueling outage, the 7 lb/in buffer springs were changed to 26 lb/in buffer springs by a Woodward Governor representative. The speed setting bushing was changed from a 30 second bushing to a 15 second bushing on 4/12/85 to ensure that AFPT #2 could reach rated speed and deliver flow to the steam generators in less than 40 seconds as required by Technical Specifica-tions.
- 2. During the 1984 refueling outage, the control logic for the steam supply valves to the AFPTs was changed to allow all four valves (MS 106, 106A, 107 and 107A) to open simultaneously.
__,After the 3/21/85 plant trip, the change was revised so that MS 106A and MS 107A would open only on a SFRCS low
~~
pressure trip. This revision was made based on the hanger damage found prior to the 3/21/85 trip. This was considered a prudent action, the hanger damage was potentially attribut-able to water slugs.
l Page 8 of 11 s
( D. Maintenance History The maintenance work done excluding oil replacement since the 1984 refueling outage for AFPT 1-1 is as follows:
- 1. Replacement of governor control motor (6-2-85),
MWO# 1-85-1876-03.
NOTE: Investigations are currently underway to determine cause of motor failure.
- 2. Adjustment of governor slip clutch (6-2-85),
MWO# 1-85-1878-00.
- 3. Replacement of low speed stop roll pin (6-2-85),
MWO# 1-85-1878-01.
The maintenance work done excluding oil replacement since the 1984 refueling outage for AFPT 1-2 is as follows:
- 1. Changeout of speed setting bushing (4-12-85),
MWO# 2-83-0136-11 (See Modification Item C.1. above).
A review of these maintenance records does not reveal any evidence that could support the overspeed trips of 6/9/85.
E. Investigation of Overspeed Trip Problems at Other Utilities Various resources have been used to determine if other utilities have experienced overspeed trips of the AFPTs.
NPRDS had only one overspeed trip reported. This occurrence was the result of the failure of a Woodward Governor ramp generator.
A ramp generator is not incorporated in the design of either the PG-PL or PGG governor.
" Nuclear Power Experience" reported a total of 10 overspeed trips which are summarized below:
- 1. Four (4) AFFT overspeeds were reported due to condensation in the line.
- 2. One (1) overspeed was reported due to a " double start" (i.e., interruption and re-introduction of steam supply
~~'when the turbine is already rolling).
- 3. One (1) loss of suction overspeed was reported (i.e., pump loses suction pressure which effectively reduces pump loading).
- 4. Four (4) overspeed trips due to governor problems as listed below:
Page 9 of 11
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Low oil level in governor t -
Me'hanical c misadjustments Failed speed sensor (applicable to electronic EG gov-ernor only)
Apparent governor valve sticking The final source of information was the Nuclear Network System.
One (1) response was received which indicated the possibility of turbine overspeed due to water in the steam lines.
III. CHANGE ANALYSIS The differences associated with the 6/9/85 trip compared to previous trips and actuations are listed below (conditions listed below existed only on 6/9/85 trip).
- 1. Both auxiliary feedwater containment isolation valves (AF 599 and 608) were closed when overspeed occurred. Pump flow was limited to the min-recire flow.
- 2. Both AFPTs were running solely on the cross connect steam supply valves (MS 106A and 107A) at the time of the overspeed trips.
- 3. AFP #1 was started on steam from MS 106 but then was switched to steam from MS 106A.
These differences are discussed in more detail in Section II, Summary of Data.
IV. HYPOTHESIZED CAUSES OF OVERSPEED From the above data and from discussions with the turbine vendor, Terry Turbine (Ken Wheeler); MPR Associates Inc. (Phil Hildebrandt, Bob Fink, and Tim Clarke); the following list of possible causes of overspeed was developed.
A. Water slugs in steam piping to the turbine due to residual condensation or rapid condensation of steam while heating long, cold steam supply path to AFPTs This hypothesis is judged to be a viable description of the cause of the observed AFPT overspeed trips.. Terry Turbine indicates that the introduction of water slugs which flash through the nozzles may result in an oterspeed condition.
The piping between the steam isolation valves (MS 106, 106A, 107, 107A) and the AFPTs is at a temperature near ambient conditions. When the isolation valves are opened, steam at about 500* to 550*F is introduced.
Steam will be condensed in these lines during initial steam introduction and line heating. Preliminary calculations indicate that several hundred pounds of water may be formed in these lines. This condensate is expected to form water slugs, parti-
Page 10 of 11 s
( cularly in the long, approximately horizontal crossover lines downstream of MS 106A or MS 107A.
It is noted that damage to pipe hanger supports on these lines has been experienced previously, apparently due to transient operational loads. Steam flow loads would not be expected to result in hanger damage. Water slug formation or water hammer may produce these loads. (Investigation of the pipe hanger support problem was in process prior to the 6/9/85 event.)
The design for the AFPTs is a single stage turbine configured similar to a bucket type " water wheel". This design is considered susceptible to increased speed excursions when water slugs are introduced. Analyses are currently being performed to confirm this hypothesis.
B. AFPT 1-1 rolling on steam from MS 106 prior to receiving steam flow from crossover (" Double Start")
This mechanism may be a contributor to the overspeed trip on AFPT #1, however, it is not considered likely. Discussions o
with Terry Turbine, as well as an~ther utility, indicate that if the turbine is rolling, and steam flow is stopped and restarted, the turbine may overspeed. This is because the speed setting bushing (the internal piece that controls the acceleration to rated speed) is ineffective due to the prior rotation of the turbine which has increased the governor oil pressure to its operating pressure. Since the governor oil pressure is established and controlling, loss or reduction in steam flow results in the governor valve opening in an attempt to increase steam flow.
When full steam pressure and flow is reestablished, the governor valve is open further than necessary and cannot close quickly enough, resulting in an overspeed condition.
This sequence may have occurred for AFPT #1 as a result of initial roll of the turbine on steam from MS 106 followed by closure of MS 106 coincident with opening of MS 106A. However, examination of the trip event sequence suggests that steam flow would not have been interrupted during switchover from MS 106 to MS 106A as the steam source.
Although considered unlikely, this hypothesis will be tested.
C. Sudden decrease in pump load due to sudden flow reduction when discharge flow is abruptly stopped at the closed valves AF 599
' and 608 ,
This hypothesis, although viable, is judged unlikely to have caused an overspeed trip because discharge piping is assured to be full at all times thereby causing the pumps to operate at min-recire conditions until the discharge valves are open.
Pege 11 of 11 i
g It is noted ,that pump operation on min-recire only may be a j contributing factor to the overspeed because of the decreased I pump load.
D. Governor problems (low oil level, improper settings, etc.),
including governor valve and linkage AFPT #1 has the previously used Woodward PG-PL governor which has experienced speed control oscillation problems, AFPT #2 has the new Woodward type PGG governor design which was installed ,
during the 1984 refueling outage which has not indicated any l oscillation problems. !
Neither governor apparently could respond to prevent the cause of the turbine overspeed. However, it is not considered that failure or malfunction of the governcrs was the cause based on the following:
- 1. The speed vs. time characteristics for the trip indicate that the governors were controlling speed as designed during the initial turbine acceleration.
- 2. Post trip testing shows proper operation of both governors.
- 3. The governor on AFP #1 is a PG-PL model with external .
Bodine motor for remote speed setting, while the AFPT #2 has a new PGG model with an internal motor for remote speed setting. It is considered unlikely that both of these governors would fail at the same time in a manner capable of causing an overspeed trip on the turbines.
- 4. The governor valve was free to move during the trip as evidenced by the initial decrease in speed after both AFPTs began to roll.
Prior to installation, an engineering evaluation was performed on the PGG governor, which concluded that this governor should be functionally similar to the PG-PL governor. However, since we have limited experience with the PGG governor (installed during 1984 refueling outage), we plan to further evaluate whether problems with this governor could have contributed to the overspeed.
E. Loss of pump suction source, resulting in no pump load This is not considered a viable hypothesis, since the control room alarm printer shows no evidence of low pump suction pressure i prior to the overspeed. Also, the 1 psig pressure switch on the pump suctions did not close the steam supply valves. Further, i
there was no decrease in discharge pressure as would be expected l if the suction pressure were lost.
1 DVW:CER:lrh i
i I
i j
s ATTACHMENT 1 s
Steam Supply Piping Layout to AFPTs Figure 1 presents a schematic representation of the steam' supply piping to the Auxiliary Feed Pump Turbines.
The piping configuration downstream of the 4 steam supply isolation valves are described in more detail below.
- 1. MS 106 (SG #1 feed to AFPT #1) - The pipe length of this run is approximately 360 feet. Immediately downstream of MS 106 is a downhill run. The length of the pipe run has several vertical drops interrupted by horizontal runs. Total vertical drop is from elevation 623' to elevation 565'. Any condensation is expected to become entrapped in the steam flow or be carried as small slugs.
- 2. MS 106A (SG #2 feed to AFPT #1) - The pipe length of this run is approximately 650 feet. Immediately downstream of MS 106A is a 290 foot length of essentially horizontal pipe. After the steam / water has traversed the initial length of pipe, it ties into the length of pipe described in item 1 above, which is immediately downstream of MS 106. The 280 foot length of horizontal pipe could allow large water slugs to form prior to entering the downhill run.
- 3. MS 107 (SG #2 feed to AFPT #2) - The pipe length of this run is approximately 125 feet. Immediately downstream of HS 107 is a downhill run. The total length of.the pipe run has an almost continual downhill flow (i.e. , ver pipe) dropping from elevation 623'y few long to elevation 565'.lengths of horizontal Any condensa-tion is expected to become entrapped in the steam flow or be carried as small slugs.
- 4. MS 107A (SG #1 feed to AFPT #2) - The pipe length of this run is approximately 375 feet. Immediately downstream of MS 107A is a -
250 foot length of essentially horizontal pipe except for a 7 foot rise near the end of the run. After the rise is a short horizontal run and then the steam supply line has a 14 foot drop and is tied to the steam supply pipe described in item 3 above, immediately downstream of MS 107. The rise, after a long horizontal run, will enable water slugs to form at the bottom of the rise and be carried downstream after filling the pipe.
e e e b #eh @ W G
ATTACHMENT 1 s
Figura 1 i
Steam Steam Generator t; Generator No. I r' No.2 MSIO7A MSIO6A IMSl06 MSl07 I
AF599 N
AF3870 ,, AF3872 1
'r ' wa a s s V3 t;
.s AF3871 r,
AF3869 Aux. Steam j II AS273 yq >q MS733 MS728
~
\ % /
/ A h . -.
C- - - - - -
-3 AFP AFP No .1 No.1 No.2 No.2 SCHEMATIC REPRESENTATION OF AUXILIARY FEED PUMP TURBINE STEAM PIPING SYSTEM Page 2 of 2
. ATTAC101ENT 2 1
AUX FEED PUMP 1-1 SPEED DATA JUNE 9, 1955 - TRIP c
==========================================
DATA TIME AFP 1-1 SPEED POINT ( S008 )
====================================================== ,
1 01:41:06 07.9 0 01:41:07 435.9 0 01:41:08 807.1 4 01:41:09 94a.7 5 01:41:10 1415.1 6 01:41:11 1793.7 7 01:41:12 2:40.5 8 01:41:13 2472.5 9 01:41:14 1700.3 to 01:41:15 '
NO DATA 11 01:41:16 1793.7 12 01:41:17 2675.2 13 01:41:18 -
3090.6 ,
14 01:41:19 2 11.2 15 01:41:20 - 0471.0 16 01:41:01 2404.2 17 01:41:22 0801.0 18 01:41:23 4:50.9 19 . 01:41:24 4616.6 20 01:41:25 0315.0 21 01:41:26 1915.8 22 01:41:07 1000.3 23 01:41:08 1024.4 e
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AUX FEED PUMP 1-0 SPEED DATA JUNE 9, 1985 - TRIP .
==========================================
DATA TIME AFP 1-2 SPEED POINT ( S018 )
==========================================
1 01:41:11 35.4 2 01:41:12 565.3 ,
3 01:41:13 570.2 4 01141:14 1500.6 -
5 01:41:15 NO DATA 6 01:41:16 2399.3 7 01:41:17 1766.8 8 01:41:18 1923.1 9 01:41:19 2152.6 10 01:41:20 2355.3 11 01:41:21 2389.5 10 01:41:22 2091.9 13 01:41:23 2438.3 .
14 01:41:24 2460.3 15
- 01:41:25, 2396.8 16 01:41:26 2379.7 17 01:41:27 2428.6 18 01:41:28 2433.5 19 01:41:29 2987.8 20 01:41:30 4118.4 21 01:41:31 4362.6 '
22 01:41:32 4172.2 23 01:41:33 4162.4 24 01:41:34 4418.8 25 01:41:35 4540.9 26 01:41:36 4655.7 27 01:41:37 4748.5 28 01:41:38 3820.5 29 01:41:39 2100.9 30 01:41:40 1476.2 31 01:41:41 1175.0 Page 3 of 28
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TIME DATA AFP 1-1 SPEED POINT ( S008 )
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1483.5 14 12:37:52 1459.1 15 12:07:53~ 1415.1 16 12:37:54 1400.5 17 12:37:55 1080.4 18 12:37:56 1381.0 19 12:37:57 1371.2 20 12:37:58 1373.6 21 12:37:59 1360.9 22 12:38:00 1359.0 23 12:38:01 NO DATA 24 12:38:02 NO DATA 25 12:38:03 2057.4 26 12:38:04 2318.7 27 12:08:05 2372.4 28 12:38:06 NO DATA 29 12:08:07 2636.1 30 12:08:08 2782.7 31 12:08:09 2929.2 02 12:38:10 NO DATA 33 12:38:11 0229.5 34 12:08:12 NO DATA 35 12:38:13 NO DATA 4 , 36 ~. 12:38:14 NO DATA
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AUX FEED PUMP 1-1 SPEED DATA JANUARY 15, 1995
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MARCH 21, 1985
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DATA TIME AFP 1-1 SPEED POINT ( S008 )
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==========================================
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,19 , 06:05:39 3149.0 20 06:05:40 3146.5 .
21 06:05:41 3149.0 22 06:05:42 3159.7 23 06:05:43 3170.9 24 06:05:44 3200.2 25 06:05:45 3293.3 ,
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DATA TIME AFP 1-1 SPEED POINT ( S008 )
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-; 38 13:50:20 3622.7 39 13:50:21 NO DATA 40 13:50:22 3639.8 -
41 13:50:23 3639.8 42 13:50:24 3637.4 43 13:50:25 3632.5 Page 25 of 28
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==========================================
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h, Ii PAGE PLAN NUMDEH ACTION PLAN * ' 1A 1 o' 6' nece DATE PREPAREo PREPAREo DY T8 f LE 6/24/85 C.'E. Rupp AUXILIARY FEED-PUMP T RBINE (AFPT) #1 OVERSPEED TRIP (Rev. 1) Wilczynski sPeciPic on;EcTavE
- D. Missig Varify hypothesis to support root cause determination, m DATE PRIME ASSIGNED START TARGET ll TO DATE DATE COMPLETQ STEP - A TION STEPS RESPONS10lLITY fJUMBER ALL STEPS OF TilIS ACTION PLAN ARE TO BE PERFORMED IN ACCORDANCE WITil Tile LATEST REVISION OF " GUIDELINES TO FOLLOW WilEN TROUBLESHOOTING OR PERFORMING INVESTIGATIVE ACTIONS INTO ROOT CAUSES SURROUNDING THE JUNE 9,1985 REACTOR TRIP".
Wilczynski Wilczynski No Act Lon Required 1.0 Test of Ilypothesis D: Governor Malfunction caused _
AFPT #1 to Overspeed.
Wilczynski Thompson 1.1 Prepare Maintenance Work Order (MWO) for removal of
! governor cover, inspection, and reassembly of governor.
i All work to be performed by a representative of I
Woodward Governor Co.
Wilczynski Thompson 1.2 Remove governor cover on AFPT #1.
Wilczynski Thompson 1.3 Perform a visual inspection to determine any obvious damage. .
Wilczynski Thompson 1.4 Check oil level and cleanliness.
Wilczynski Wilczynski i 1.5 Document the as-found condition. -___ ,
I I n -
PLAN NUMHE H PACE ACTION PLAN * - lA 2 5' 6 i m se DATE PREPARED PREPARED OY TITLE 6/24/85 C. E. Rupp AUXILIARY FEED-PUMP TURBINE (AFPT) #1 OVERSPEED TRIP (Rev.1) WilCzyDSki jr SPECIFIC OBJECTIVE D. Missig Varify hypothesis to support root cause determination.
R A I ND START TARGET DATE STEP ff* ACTION STEPS RESPONSIBILITY TO DATE DATE COMPLETE IUMBER Using Woodward Engineering Representative, determine Wilczynski Gradomski 1.6 ,
if any repairs are required prior to testing the governors. The basis for this determination will be:
"If the repairs are required to preclude further damage to th governor, turbine, or pump, then the repairs shall be made. If further operation of the governor will not cause further damage, then the repairs will be made after -
the test for overspeed is run to determine if the failed item could have caused the overspeed on 6/9/85". Document all decisions.
1.7 Prepare MWO and perform repair work as determined in Step Wilczynski Thompson 1.6. All work to be done by Woodward Representative.
1.8 Install a remote manual trip device in case of failure Wilczynski Thompson of the overspeed trip.
[
j Perform " quick start" test of AFPT #1 using ST 5071.02 Wilczynski Missig 1.9 l
Phase 1 to test Hypothesis D.
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D. Missig Varify hypothesis to support root cause determination.
A D START TARGET DATE STEP fl ACTION STEPS R
RESPONSIBILITY TO DATE DATE COMPLETE ZUMBER Wilczynski Wilczynski No Action Required 2.0 Test of Ilypothesis A: Condensate in the Main Steam Crossover Line Caused AFPT #1 to Overspeed. _.
Wilczynski Missig 2.1 Develop a Test Procedure (TP) to simulate as close as practical the actual conditions of the June 9, 1985 3t AFPT '#1 overspeed trip. A brief outline of the TP is chown below:
PURPOSE:
- To verify hypothesis that condensate in the cross connect steam supply lines (MS 106A) can cause an
! overspeed trip of AFPT #1.
EQUIPMENT NEEDED:
l - Existing plant instrumentation l
l
- Back-up system for tripping turbines manually i - Instrumentation to monitor the thermohydraulic conditions in the steam supply piping to the AFPTs.
l
_____._...___.__...-,-,m,,,,-=u h r-ii _ _ . _ __
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'IT LE 6/24/85 C.' E. Rupp_
AUXILIARY FEED-PUMP TORBINE (AFPT) #1 OVERSPEED TRIP (Rev. 1) WilCZynski SPECIFIC OBJECTIVE ll _
D. Missig Verify hypothesis to support root cause determination.
l A I ND AR TARGET DAM
[ STEP lf ACTION STEPS RF.SPONSIBILITY TO DATE DATE COMPLETE [
l UMBER l
l PREREQUISITES: _ _ _
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- - Governor is at its high speed stop.
l
- Steam supply lines to the AFPTs are at ambient conditions.
- Pump discharge valves are closed.
- Ver'i y min-recire valves are open.
- Steam Generator (SG) pressures are greater than 870 psig, s
NOTE: SG pressure will be less than 1050 psig and decreasing -
during testing. This will not exactly duplicate the conditions of 6/9/85.
Wilczynski Missig 2.2 Perform Test Procedure Review test data to verify applicability to hypothesis. Wilczynski Wilczynski 2.3 2.4 Repeat Test Procedure Wilczynski Missig Review test data from second test to verify applicability Wilczynski Wilczynski 2.5 to hypothesis.
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1 a' 5 IB ACTIOfJ PLAN ' . DATE PREPARED PREPARED DY L a ..n 6/24/85 C.~ E. Rupy_
rtTLE 1) WilczynSki f AUXILIARY FEED-PIRIP TURBINE (AFPT) #2 OVERSPEED TRIP (Rev.
SPECIFIC OBJECTIVE D. Missig j it Verify hypothesis to support root cause determination.
START TARGET DATE PRIME ASSIGNED COMPLETEI DATE DATE l STEP ll A Tl N ST PS RESPONSIBILITY TO huMBER ALL STEPS OF TilIS ACTION PLAN ARE TO BE PERFORMED IN ACCORDANCE WITil Tile LATEST REVISION OF " GUIDELINES TO FOLLOW WilEN TROUBLES 1100 TING OR PERFORMING INVESTIGATIVE ACTIONS INTO ROOT CAUSES SURROUNDING Tile JUNE 9,1985 REACT'RO TRIP".
Wilczynski Wilczynski No Action Required 1.0 Test of Ilypothesis D: Govern malfunction caused AFPT #2 to overspeed.
Wilczynski Thompson 1.1 Prepare Maintenance Work Order (MWO) for removal of governor cover, inspection, cad reassembly of governor.
All work to be performed by a representative of Woodward Covernor Co.
Wilczynski Thompson 1.2 Remove governor cover on AFPT #2.
Wilczynski Thompson 1.3 Perform a visual inspection to determine any obvious damsge.
Wilczynski Thompson 1.4 Check oil level and cicanliness.
Wilczynski Wilczynski 1.5 Document the as-found condition.
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AUXILIARY FEED-PUMP TURBINE (AFPT) #2 OVERSPEED TRIP (Rev. 1) 6/24/85 C. E. Ruppj SPECIFIC oDJECTIVE WilCzynSki j,
D. Missig Varify hypothesis to support root cause determination.
PRIME ASSIGNED STAFlT TARGET ~DATE STEP ^ I " I RESPONSIBILITY TO DATE DATE COMPLETEI JUMBER Using Woodward Engineering Representative, determine Wilczynski Gradomski 1.6 ,
if any repairs are required prior to testing the .
governors. The basis for this determination will be:
"If the repairs are required to preclude further damage to th governor, turbine, or pump, then the repairs shall _
be made. If further operation of the governor will not cause further damage, then the repairs will be made after -
the test for overspeed is run to determine if the failed item could have caused the overspeed on 6/9/85." Document -
cli decisions.
Prepare MWO and perform repair work as determined in Step 1.6. Wilczynski Thompson 1.7 All work to be done by Woodward Representative.
1.8 Install a remote manual trip device in case of failure of Wilczynski Thompson the overspeed trip.
Perform " quick start" test of AFPT #2 using ST 5071.02 Wilczynski Missig 1.9 Phase 1 to test Hypothesis D.
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- w. DATE PREPARED PREPARED BY TsTLE AUXILIARY FEED-PUMP TURBINE (AFPT) #2 OVERSPEED TRIP (Rev. 1) 6/24/85 C'. E. Rupg SPECIFIC oDJECTIVE W11Czynski j _
D. Missig Varify hypothesis to support root cause determination.
ASSIGNED START TARGET DATE STEP ff
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PRIME RF.SPONSIBILITY TO DATE DATE COMPLET(2 4 UMBER 1
Wilczynski Missig 1.10 Repeat step 1.9 to prove repeatability.
Prepare MWO for repair of governor for all items that Wilczynski Thompson 1.11 were not repaired under Step 1.7 as determined by Step 1.6.
Review data to verify applicability to hypothesis. Wilczynski Wilczynski 1.12 Condensate in the Main Steam Wilczynski Wilczynski No Action Required 2.0 Test Iof Ilypothesia A:
crossover line caused AFPT #2 to overspeed.
Develop a Test Procedure (TP) to simulate as close as Wilczynski Missig 2.1 practical the actual conditions of the June 9, 1985 AFPT #2 overspeed trip. A brief outlise of the TP is shown below:
PURPOSE:
- To verify hypothesis that condensate in the cross connect steam supply lines (MS 107A) can cause an overspeed trip of AFPT #2.
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ACTION PLAN . PLAN NUMBEH p PAGE ne os 1B - 5 ' ' _5 TITLE DATE PREPARED PffEPARED BY AUXILIARY FEED-PUMP TURBINE (AFPT) #2 OVERSPEED TRIP (Rev. 1) 6/24/85 C. E. Rupp_
- , SPECIFIC OBJECTIVE WilczynSki D. Missig Verify hypothesis to support root cause determination.
STEP ff R A I N D START TARGET DATE ACTION STEPS DATE COMPLETE NUMBER RESPONSIBILITY TO DATE 2.4 Repeat Test Procedure. Wilczynski Missia 2.5 Review test data from second test to verify applicability Wilczynski Wilczynski to hypothesis.
3.0 Evaluate the design of the PGG governor versus the PC-PL Wilczynski Gradomski goverrior to determine differences that may cause undesired performance characteristics. (This action to be independent of all other action steps.)
4.0 Write final report to document root cause. Wilczynski Wilczynski
.