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FLORIDA POWER & LIGHT COMPANY i
j 10 CFR 50.59 SAFETY EVALUATION 1
EVALUATION OF TEMPORARY OPERATING CONFIGURATION WITH 1B MAIN TRANSFORMER OUT OF SERVICE i
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l Sr. LUCIE NUCLEAR PLANT l
UNIT 1 i
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JPN-PSL-SFW496-068 REVISION 1 1
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NOT NUCLEAR SAFETY j
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2 9704070103 970325 PDR FOIA BINDER 96-485 PDR
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REVISION 1 PAGE 2 CF 12 REVIEW AND APPROVAL RECORD PLANT ST. LUCIE UNIT 1
TITLE EVALUATION OF TEMPORARY OPERATING CONFIGURATION WITH IB MAIN TRANSFORMER OUT OF SERVICE LEAD DISCIPLINE ELECTRICAL ENGINEERING ORGANIZATION ST. LUCIE ENGINEERING GROUP REVIEW / APPROVAL:
INTERFACE TYPE GROUP PREPARED VERIFIED APPROVED FPL APPROVED
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i PN-PSL-SEES-%-068
- EVISION 1 FAGE 3 0F 12 ABSTRACT While operating at 100% power, a gas detection alarm was received for the 18 Main Transformer. Investigation showed that air was being introduced into the transformer oil. Continued operation in this manner could eventually lead to a breakdown of the insulating oil with resultant loss of the main transformer.
PSL Unit 1 normally operates with both the 1A and 1B main transformers in parallel.
The system design allows for operation at reduced power with a single main transformer, provided certain conditions are met, until repairs can De made and the affected i
transformer tested and returned to service.
Operation with a single main transformer is addressed in FSAR Section 8.2.1.4 and joes not reduce the reouired A.C. electrical power sources as addressed in Tecnnical Specifications 3.8.1.1 or 3.8.1.2.
The conclusion of this evaluation is that operation of Unit 1 with a single main transformer does not represent an unreviewed safety question as defined in 10 CFR i
50.59, does not require a change to plant Technical Specifications and does not adversely affect plant operation or safety; therefore, prior NRC approval is not required.
The main transformers and associated equipment, including the isophase bus and fire f
detection and deluge system, are classified.as Not Nuclear Safety and are not considered important to safety. Therefore, this safety evaluation is classified as Not Nuclear Safety.
Revision 1 of this evaluation is a total rewrite to include a 10 CFR 50.59 evaluation l
and to revise the actions required, i
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.?.br5'.-5EE546-068 REVISION 1 PAGE 4 0F 12 BACKGROUND & PURPOSE In response to a 1B Main Transformer gas detection alarm it was discovered that air is being introduced into the transformer oil.
PSL Unit 1 normally operates with the 1A and 1B main transformers in parallel.
However, system design allows for operation with a single main transformer. provided certain conditions are met.
This evaluation focuses on the raquired cjnfiguration related to coeration of the Unit utilizing only Main Transfcrmer 1A.
This evaluation provides for the temporary coerating con. figuration using only Main Transformer 1A until repair and testing of the Main Transformer 1B cooling system i.s l
satisfactorily completed and the transformer can be ret'urned to service.
LICENSING REQUIREMENTS Technical Specifications Technical Specification 3.8.1.1, applicable in MODES 1. 2. 3 and 4. requires as a minimum that the following A.C. electrical power sources shall be OPERABLE (Ref 3):
a.
Two physically independent circuits between the offsite transmission network and the onsite Class 1E distribution system, and b.
Two separate and independent diesel generator sets eacn with:
1.
Engine-mounted fuel tanks containing a minimum of 152 gallons of fuel.
2.
A separate fuel storage system containing a minimum of 16.450 gallons of fuel. and 3.
A separate fuel transfer pump.
Technical Specification 3.8.1.2. applicable in MODES 5 and 6. requires as a minimum that the,following A.C. electrical power sources shall be OPERABLE (Ref 3):
a.
One circuit between the offsite transmission network and the onsite Class 1E distribution System, and b.
One diesel generator set with; i
1.
Engine-mounted fuel tanks containing a minimum of 152 gallons of l
fuel.
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PN-PEL-SEES-96 063 REVISION 1 PAGE 5 0F 12 i
2.
A fuel storage system containing a minimum of 16.450 gallons of fuel, and i
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A fuel transfer pump.
Updated Final Safety Analysis Report Unit 1 UFSAR Section 8.2.1.4_ describes the main generator, main transformer bank. and p
j generator isolated phase bus.
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The station main generator is a 1000 MVA Westinghouse generator which provides power to the offsite transmission network at various loads to a maximum of 850 MWe, Th'e main j-generator data are given by Table 8.2-1.
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The main generator is direct connected through a 22 kv, 28.000 ampere isolated phase i
bus to the main transformers, where it is stepped up to 240 kv and then tied to one bay l
i of the outdoor switchyard.
1 The main transformer bank consists of two (2), three-phase transformers 475 MVA each.
j forced oil and air (F0A) cooled at 65'C temperature rise, connected in parallel, with separate cooling equipment such.that any one transformer can be uprated to 632 MVA at 65'C rise if the other transformer is out of service and all the cooling equipment is l
applied to the remaining transformer.
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- The generator isolated phase bus _ is forced af r cooled and is rated for both normal (two i
main transformers in service) and emergency coeration (one main transformer ~ out, the i
Other uprated to 632 Mva) all at 65'C rise. Lo 100 percent capacity sets of cooling i
equipment are provided.
The Transformer Deluge system is mentioned in section 9.5A.3.1.3. 9.5A.3.3 and TABLE
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9.5A-3. This system is for fire suppression of the Main Transformers.
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4 ANALYSIS OF EFFECTS ON SAFETY The main transformers, main generator and the isophase bus, as discussed in Section 8.2.1.4 of the UFSAR,.are non-safety related. equipment and do not interact with any i
safety related structure, system, or component. The transformer fire protection deluge i
system is non-safety related. This engineering evaluation is therefore, classified as i,
Not Nuclear Safety.
Disabling Main Transformer 1B does not adversely impact operability of AC power sources as described in Technical Specification 3.8.1.1.
Operation of the Unit in the temporary alignment, utilizing only Main Transformer 1A, does not adversely impact operability of_ the AC power sources. Since the startup transformers are unaffected by t.
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- PN PSL-5EES-96-068 REVISICN 1 FAGE 6 CF 12 this alignment. Two physically independent circuits between the offsite transmission network and the onsite Class 1E distribution system and the two diesel generator sets are maintained operable in the proposed alignment.
FAILURE MODES AND EFFECTS ANALYSIS
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There are no new failure modes created by operation at reduced power with a single main CC transformer, y,
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PLANT RESTRICTIONS:
Loading on the transformer should not exceed 475 MVA unless a Dasis is established from temperature data that provices reasonable assurance that the temperature specifications will not be exceeded. In order to maintain the transformer within its operating capabilities, the hotspot and top oil temperatures should be monitored and verified to be less than 120 and 90 degrees C respectively.
Existing high temperature alarms are sufficient for continuously monitoring the temperatures of the transformer.
Operating limits based on transformer namepiate rating have been determined and are represented in the attached figure, Attachment 3. The Gross Megawatt output and Gross j
Megavar output of the main generator as displayed in the control room are the preferred l
controlling parameters.
Accuracy of this indication is not significant since the generator nameplate ratings are conservative. An assumption of 44 megawatts at a 0.65 power factor is assumed for the load on the auxiliary transformers and the amiiRry transformer losses.
The remaining generator output is power delivered to the gril through the main transformer and the main transformer losses. The Megawatt and Megavar limits for generator operation are determined at several. points by adding the main transformer nameplate limits, and the assumed auxiliary transformer load.
The main transformer losses are assumed to be insignificant and are neglected. The efficiency of the transformers is high, is not a significant influence, and is also neglected.
The main generator gross output limits based on transformer nameplate ratings are estimated to be:
l XFMR PF XFMR OUTPUT AUX LOAD TOTAL l
0.95 451 MW 44 MW 495 MW 148 MVAR 27 MVAR 175 MVAR 0.96 456 MW 44 MW 500 MW 133 MVAR 27 MVAR 160 MVAR E
.::N-PSL-5EES ^5-C6B REVISION 1 PAGE 7 0F 12 O.97 461 MW 44 MW 505 MW 116 MVAR 27 MVAR 143 MVAR 0.98 466 MW 44 MW 510 MW i
95 MVAR 27 MVAR 122 MVAR 0.99 470 MW 44 MW 514 MW 67 MVAR 27 MVAR 94 MVAR 1.00 475 MW 44 MW 519 MW 0
i The result of the above tabulation are represented in graphical form in Attachment 3.
Operation within the bounds defined by this figure assume that the auxiliary transforners are available to supply plant loads.
If during operation with the single i
main transformer plant loads are not supplied through the station auxiliary transformers, main generator output should be limited to approximately 200 MW.
Compensatory measures are required whenever the deluge system is inoperable for the 18 and/or IA transformers.
1 EFFECTS ON TECHNICAL SPECIFICATIONS:
There is no impact to the ability to ci.1 ply with the Technical Specifications nor has the bases of the Technical Specifications been affected by operation with a single main transformer.
UNREVIEWED SAFETY 00ESTION DETERMINATION In accordance with 10 CFR 50.59, the responses to the below listed questions serve to determine if the subject activity constitutes an unreviewed safety question:
1.
Does the proposed activity increase the probability of occurrence of an accident previously evaluated in the SAR?
The probability of occurrence of an accident previously evaluated in the SAR has not been increased. The relevant analyzed event is a loss of external electrical load which is evaluated in FSAR section 15.2.7.
Operation with a single main
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.N 5L-5EES-96-068 REVISION 1 PAGE 8 0F 12 t - *.
i transformer within the guidance provided by this evaluation provides assurance
).f that the transformer is operated within its design capabilities.
Therefore, the reliability of the operating main transformer is not adversely affected and the r;
probability of a transformer failure is not increased.
2.
Does the proposed activity increase tne consequences of an acc1 dent prevfously evaluated in the SAR?
The consequences of an accident previously evaluated in the SAR have not been increased.
This evaluation does not affect any safe snutacwn or accident mitigating equipment. Operation with a single main transformer does not impact the ability of the plant to respond to a loss of external electr7 cal load event.
3.
Does the proposed activity increase the probability of occurrence of a malfunction of equipment important to safety previously evaluated in the SAR?
)
The probability of occurrence of a malfunction of equipment important to safety previously evaluated in the SAR has not been increased.
This evaluation allows power operation with only one of two main transformers in service.
FSAR section 8.2.1.4 discusses system design and describes operation with a single transformer in service "if the other transformer is out of service."
Operation with the single transformer will be in accordance with the requirements provided by this evaluation and will be enveloped by the condition discussed in the' FSAR
- (operation at 632 Mva).
Adherence to the requirements of this evaluation will ensure that the in-service transformer is operated within its design capabilities, thereby ensuring its reliability. No equipment important to safety 3
is affected by this evaluation, f P'#
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removed from service in support of maintenance activities on the 1B main
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sGASKET uATERIAL
- 2. CARSON STEEL usuasR3 3 HALL gg ASTuA38
- 3. PLYWOOD SHALL SE COATED WITH FIRE RETARDANT COATING.
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""I 4.-INNER AND OUTER SECTIONS OF PLUG SHALL SE SCREWED TOGETHER uslNG A MINIMUM OF 4 SCREWS 1* OR 125
- LONG.
ENCLOSURE PANEL s
- 5. GASIET SHALL SE TM3HTLY Fif AGAINST THE EDGE OF THE INNER
& DUCT (TYP)
SECTION OF THE PLUG AND OLUED TO THE SURFACE OF THE OUTER SECTION CAUUC SHALL SE PLACED AROUND THE EDGE OF THE INNER SECTION PRIOR TO INSTALLATION OF PLUG.
SECT. A (AS SHOWN)
S.Oma.L Tite" otA. HOLES ON THE ENCLOSURE PANELS. PLWOOO &
PLATES FOR THE 34* DW BOLTS ( SEE DETAILS FOR LOCATION).
SECT. B (AS NOTED)
3/4*n4* s4*
AS REOUIRED)WDCOEN SLOC8(. WITH A 711s DIA. HOLE IN T)E CF SHALL SE PLACED SETWEEN THE EXTEfuCR SURFACE OF THE ENCLOSURE PANEL AND THE FLAT WASHER MUT OF THE SOLT.
S. 80LTS SHALL Sk SNUG TIGHT.
- _.. _ _ - -.. _ ~ _. -. _ _ _ _, _ _ _ _ _ _.
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i j-l JPN PSL-SEES-96-068 ATTACHMENT 2 REVI' ION 1 S
l PAGE 2 0F 2 i
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- 2. 9NUG TIGHT BOLTS WITHOUT GRUSHNG GA9KET MATL.
- 3. DOLT l-EAD SHALL DE ON NSDE OF PLtNM
- 4. ALL MATERIAL 9 HALL BE PC-4, OR DETTER.
4
JPN-PSL-SEES Oud ATTACHMENT 3 REVISION t PAGE 1 OF I UNIT GENERATOR GROSS OUTPUT LIMITATIONS BASED ON 475 MVA XFMR RATING 180
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l 09/04/96 WED A7:03 FAI 407 694 416A
$8/JB
@oog inw.omas commpondence e
JPN PSL-SEES-96 068 ATTACHMENT 4 PS8L REVISION 1 PAGE 1 0F 4 a
Tm D. J. Denver ones September 4,1996 Fnum B. A. Jaindl Looseen:
SS/JB auttnet:
SLluCIE PLANT UNIT #1 i
The Substation Materials & Design and Protection & Control Departments Engineering and Settinge Sections, under my direction, have evaluated the tempo ary configuration of operating PSL 1 on only the 1 A main transformer.
I, d
Protection & Control has determined that the temporary protection realignment provides the j
necessary protection.
j Substation Materials and Design have determined that the 1 A transformer and it's system of 1
pumps and coolers can be operated separately while the 1B main transformer is out of service for repair and testing.
References:
1-letter dated 09/0446 from R. Shaheen to D. J. Denver 2-letter dated 0944/96 from Tony Figueroa to D. J. Denver 3-JPN PSL-SEES-96-068 REVISION 0 B
Jai
- 1. Director Substation and P&C Copies:
Jim Scarola L. D. Leon C. M. Mennes Tony Figueroa Richard Shaheen Pedro Modia M. R. Rnith John Fischer R. L Hahn C. E. Seitz se a
9, ee.
os/o4/ss wED 17:03 FAI 407 Ss4 6161
$8/JB JPN-PSL-SEES-96-06E i*
ATTADNENT 4 i
i REVISION 1 PAGE 2 0F 4 l
l 553L.
I l
T.:
Dan Denver amen:
September 4,1996 l
neau Tony Figueroa suomen==
SS/JB
}
l msemen Operation of PSL Unit #1 Wlth 18 Main Translormer Out of Service i
i l
SL Luos Main Transformer 1B has dr;;':-;+d air intrusion problems. Unit #1 can operate in a i*
temporary configuration using only Main Transformer 1 A until transformer 1 B is repaired and teseed satisfactority.
Unit #1 can be operated at a reduced level with only one main power tranaformer. WIth transformer 18 out of service, transformer 1A has a nominal rating of 475 MVA. Loading on he transformer should not exceed 475 MVA unless a basis is established from the temperature data that provides reasonable assurance that the temperature specifications will not be exceeded. Existing high temperature alarms are nufficient for conknuous monitonng of the temperatures of te transformer.
In order to maintain the translormer within its operating capabilities, the hotspot and top oil temperatures should be monitored and vertfled to be less than 120' and 90 C, (E;+?;O;.
8 N you have any queglions, please fe61 free 93 call me d 8944572.
db ony Figueroa Manager, Su Operamons & Planning copies:
B. A. Jaindi Dave Wolf John Fecher Ken Veronse Oscar Bello M. R. Smith Pedro Modia Marty Mennes i
l
- r. ann ions (campner emnanme mar. osas f.!:l:7!5 $;!!
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09/04/96 WED 17:03 FAI 407 694 4161 SB/JB
@ 004 Int:r office Cerrerpend:nco JPN PSL-SEES-96-068 ATTACHMENT 4 REVISION 1 PAGE 3 0F 4 To:
Dan Denver Location: SPE/JB ENG/PSL l
From:
R. L Shaheen Date: September 4,1996
Subject:
PROTECTIVE RELAY MODIFICATIONS FOR PSL1 OPERATION WITHOUT MAIN TX _1B 1
Protection & Control has completed their review of the proposed temporary system alteration as mentioned in the above subject. The following conclusions were made:
1.
The followmg temporary circuit alterations will be necessary to allow operation with only the 1A Main Transformer in servce:
- 1) Isolate the 87TB/878 phase A, phase B and phase C BDD differeritial relays for Main Transformer 1B by removing the relay paddles.
- 2) Isolate the 51TNB/878 IAC neutral overcurrent relay by removing the relay paddle.
- 3) Install shorts for the C1, C2 and C3 current transformers for differentsal"s1"in Main Transformer 15. Install isolation strips in the BC isolation device poets 1-12 (six isolation strips).
- 4) Tum off all annunciator points in Main Transformer 18.
II.
No relay setting changes are necessary. The rationale for this conclusion is based on a review of the existing relay settings as described in Attachment A.
If there are any questions or concems, please call me at 694-3745.
7,.7. s W f R. L Shahoon, Supervisor P & C Engineenng RL Copies To:
Warren Busch JPN/JB L O. Leon SP/LFO Pedro Modia SPE/JB M. R. Smith SPG/PSL B. A. Jaindt SBE/JB C. E. Seitz WBPILPS Farm ions (Stocase Rev. 2/te f.f"f!Ylh [:t
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09/04/98 eID 17:04 FAI 407 694 4161 SB/JB id} 005 JPN PSL-SEES-96-06E.
ATTACHMENT 4 REVISION 1 ATTACIMENT A j
PAGE 4 CF 4 (OPERATION OF PSLI WITH MAIN TX IB OUT OF SERVICE) l Relay settings for the following pertinent relays were reviewed:
Genensar.Ost-Of-$ ten (21M/21ST150N) Relays GSY: The sesans criteria takes into account an octage of one of the two transformers. No need to 3
j make any changes.
CEX:Its setting is based on the same parameters as in GSY. Herefore, no change needed.
PJC: The relay already has a very sensitive setting and does not require any change.
1 Malalnesienner1A NeutraLQICl5tTNA1Balar:
The rea:alculated setting for the IAC53 relay is the same as the custma one.
i j
Generatar iada Backun Distarce (21) Relay :
he cnteria used for the KD Il settmg is very conservative. No noen to make any changes, i
Generstar Less-Of-Fleid f@) Protection:
No change required in the CEH52 setting since this settmg is independent of the transformer impedance.
Main Trutsfonner Diff-tial (R7TA) Protection:
I No change required in the BDD15 settag since this setting is independent of the transformer impedance.
l Unit.Diffegatial (87GD Pmecction:
j No change required in the BDD18 setting since this setting is independent of the transformer j
impedance.
i i
Neemdve S-ce (46B) Fmtection:
l No change required in the SGC12 setting since this setting is independent of the transformer j
impedance.
t Reverse.Pewer 02)Rainv:
Ne change required in the GGP53 settmg since this setting is independent of the transformer impedanos.
Overtstitution (SM & $9-2) Pmtsction:
No change required in the STVilA's settmgs since these settings are mdependent of the transformer impedance.
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P0ut.x SUPPLY ADMIN.
TEL: 305-442-5022 Sep ud so JPN PSL. SEES-96 068
[
Isser office Cwi=c::'- :=
ATTACHMENT 5 o n EVISION 1
.N FAGE 1 CF 1 T&.
DAN DENVER DATE:
September 4.1996 FROM:
DON MCINNIS LocxrioN: PS/LFO SUEJET: SETTINGS REVIEW COP &5 TO:
L.D. LEON MINIMUM EXCITATION LIMITER M. SMITH C.M. NuiNNES i
The minimum excitation linuter settings for St. Lucie #1 have been reviewed for operadon with only a sing!c GSU in service. While the margin between the static stability curve and the minimum excitation limiter sening has beco reduced it is still adequate. The settings allow for a fifteen percent margin given an outa5e of. the Midway 500/230kV autotransformer. The margin remains above six pen:ent without the autotransformer. and is at the ten percent point with the transformer in service which is the current case.
If operadon with a single GSU is andeipated to extended beyond the next 4 to 6 weeks the mmimum excitation limiter settings should be revised in order to retum the settings margins to our standard praedce.
bm Don McInnis Supervisor. Operadons Engineering Power Supply bM IN h b IM
c' UNIT 1 - MAIN POWER L'.STRIBUTION SYSTEM BREAKER POSITIONS - NORMAL OPERATION 1
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Figure 6 0711$02. Rev. 8 FOR TRAINING USE ONLY
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Operations Department St. Lucie Nuclear Power Plant Night Order DISTRIBUTION:
Unit 1 Control Room Unit 2 Control Room OPS Support Work Control Group System Specialists Training Simulator From: Operations Supervisor's Office Date: September 20,1996 To:
All Operations Personnel i
l 1.
NPS's please review with your crew the attached Self Assessment of the Mis-aligned ESFAS bistable. The l
following interim actions have been taken:
Unic 1 EFAS Bypass key switches have 1abeled a.
ta match the ESFAS trip unit. For example the S/G 1B Pressure MSIS Bistable trip unit fails to trip. The trip unit is labeled BA410 and the bypass key switch has been labeled BA410.
b.
The tags for the key switches have been i
1abeled.
There are many more trcps 1ef t our there. Please use a questioning attitude, have someone double check what you are about to perform (Peer Check) a and take nothing for granted when performing any task. Time should not be a factor. Al vays take the time to ensure the task is performed correctly.
j 1
2.
Find attached the following memo's:
a.
1B MG set Flywheel Vibration alarm b.
Hurricane Crew Coverage.
c.
ASI control for Unit 2 Down Power on 9/23/96 3.
E/M believes the 1B DC ground that keeps" coming in
)
intermittently is not the ground test switch. Also the l
1 h
Mb d
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ground is - so small the ground buster can not pick it up. Therefore if the ground comes into alarm and stays in, implement the DC ground ONOP.
4.
We are doing a very good job in our pre-job ^ briefings.
Please ensure that job debriefs are being preformed and
.any issues are sent to me if required to resolve.
5.
Find attached the game plan ' for PCV-1100F on ' Unit 2.
l The plan is to begin next Tuesday. See the POD.
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Operatina Crew Self Assessment i
==
Description:==
Misaligned ESFAS bistable bypass
~
~
Unit: 2 Date: 9/18/96 Shift: Peak i
EVENT:
i At 1945 while restoring the instrumentation form the performance of the Area Radiation Monitoring System Periodic Test it was noted that the ATI fault light would not reset.
From the indicator lights that were lit on the ATI panet it appeared to be a B MSIS problem. All other indications on the ESFAS and RTGBs associated with S/G pressure appeared to be normal. The NPS, RMM and l&C were notified.
At approximately 2030 while the ANPS was speaking of the problem with the I&C system supervisor at home on the telephone, it was observed that the D Channel B S/G pressure indicator failed high confirming a fault with the D Channel B S!G MSIS.
At 2045 in accordance with Tech Spec 3.3.2.1, which states that the inoperable channel be placed in bypassed or tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and that all functional units receiving an input from the inoperable channel also be placed in the same condition, the D Channel B S/G MSIS, RPS D channel TM/LP and LO S/G Pressure, and D channel AFAS 1 and 2 were placed in bypass.
At approximately 0705 on 9/19/96 it was noted that the D Channel A S/G MSIS bistable had been mistakenly bypassed instead of the D Channel B S/G MSIS bistable.
Subsequently the A S/G MSIS was restored to normal configuration and the B S/G MSIS bistable was placed in the bypassed condition.
STRENGTHS:
The crew determined that the ATI fault was associated with the one of the B S/G MSIS trip paths.
The problem was promptly reported to Plant Management, the RMM and I&C.
The entire control room crew including the STA was involved in the review and discussion of the Tec.i Sr 9cs as they pertained to this situation.
The administrative control of the paperwork to document the event including entries in
w' i
the controlled key locker log, the equipment OOS log, the switch deviation log and the chronological log was handled correctly.
WEAKNESSES:
The wrong bistable on D Channel ESFAS was incorrectly bypassed and incorrectly independently verified.
The RCO made the assumption that the proper bistable was being bypassed since the bypass key switch lined up with the isolation module that was labeled as the 8 S/G MSIS.
The key number was not compared to the key index located in the key locker, although this comparison is not normally made.
CONTRIBUTING FACTORS:
The first six bypass key switches line up with the corresponding isolation modules, the last three do not. Earlier that evening when performing the Area Radiation Monitor Periodic Test, the RCO successfully bypassed the Containment Hi Pressure bisatables one at a time without incident. That bistable was one of the first six.
The bistable bypass key switches in the ESFAS cabinets are not clearly labeled.
The key switch tags are labeled with numbers and are not clearly labeled with the component description.
A condition report was submitted several months ago to address and upgrade the controlled key labeling deficiencies on both units, this problem has not has not yet been resolved.
There is not an off-normal procedure, other than the annunciator summery, that addresses situations concerning ESFAS cabinets failures or failures of their related -
)
instrumentation.
LESSONS LEARNED:
Avoid making assumptions. Even though something may appear to be straightforward and cor' rect, such as the bistable key switch being in line with the corresponding i
isolation module, always maintain a questioning attitude.
If time permits, compare the key tag with the key locker index.
o
7
- 4. h 1
SUGGESTIONS FOR IMPROVEMENT:
1 Clarify the labeling deficiencies of the ESFAS bypass switches.
Relabel all of the keys in the controlled key lockers ensuring the key tags have the number and component description on them and are also color coded where j
appropriate.
l Develop an off-normal procedure that deals with ESFAS cabinet components and instrumentation problems.
Reenforce the critical differences in the ESFAS component layout between units 1 and 2 during Licenced Operator requal.
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Operations Department Chronological Log Unit 1 04-sep 06 NUMBER.
818 NUC POWER:
0 DATE:
9/1/96 DELTA T POWER:
O SHIFT:
MID MWE:
0 BOARD RCO: SCOTT CEA GROUP #:
7 DESM RCO CONE /KIMPEL POSITION:
0 NWE:
TAYLOrt T AVG:
532 ANPS:
DAUGHTRY BORON:
1126 NPS:
SANDY Xe WORTH:
-3401 MODE:
3 C ALCULATED SD MARGIN: 33600 MAJOR MILESTONES OR ACTIVITIES TO BE PERFORMED DURING THE SHIFT:
COMPLETE ALL PREPERATIONS FOR A RX START UP TIME LOG ENTRIES 23 00 REVElWED LOGS, COMPLETED BOARD WALKDOWN AND ASSUMED THE SHIFT 23'01 ANN. J-11 CLEARED, EXITED ONOP 1-0120034 ( RCP OU NORMAL )
23:03 CHEM. REPORTS DEQ SAMPLE RESULTS ARE NORMAL 2
0:15 START THE WIDE RANGE INSTRUMENTATION CHANNELS FUNCTIONAL TEST IAW OP 1 1210051 0:20 DECLARED THE SJAE RAD MONITOR OOS FOR NPO TO OBTAIN AIR IN LEAKAGE READING 0:23 DECLARED THE SJAE RAD MONITOR B.I S., AIR IN LEAKAGE READING is 3 8 4
0.24 UNABLE TO OBTAIN GENERATOR MW METER READING AT 0000 DUE TO TURBINE OFF LINE. THE PREV READING WAS 4575460 ON 9/1/96 AT 0000. THE READING WILL BE OBTAINED WHEN THE TURBINE IS PLACED ON LINE.
0.30-DECLARED *A* CHANNEL WR NTS OOS DUE TO FUNCTIONAL TEST.
1 O.59 DECLARED *A* CHANNEL WR NrS BIS 1:00 DECLARED *B" CHANNEL WR NrS OOS DUE TO FUNCTIONAL TEST. REMOVED THE BYPASS KEY FROM CHANNEL *A* VAR HIGH POWER BISTABLE, WHICH IS OOS. THE VAR HIGH BISTABLE IS NOT REQUIRED IN MODE 3 AND THE BYPASS KEY IS REQUIRED FOR THE WR FUNCTIONAL TEST. ANPS NOTIFIED.
1:10 DECLARED *B" CHANNEL WR NrS BIS.
1:11 DECLARED *C" CHANNEL WR NrS OOS DUE TO FUNCTIONAL TEST.
1:20.
DECLARED *C" CHANNEL WR NrS BIS.
1:21 DECLARED *D" CHANNEL WR NrS DOS DUE TO FUNCTIONAL TEST.
1:25 T&D REPORTED OIL SAMPLE ON THE 1B MAIN XFRMR SAT.
1:33 DECLARED "D" CHANNEL WR NTS BIS AND COMPLETED WR FUNCTIONAL TEST SAT. PLACED BYPASS KEY BACM INTO *A" CHANNEL VAR HIGH POWER. ANPS NOTIFIED i
f d'
)
Operations Department Chronological Log Unit 1 i
04 swee 1:35 l&C ENTERED CONTAINMENT AND TEST OF THE CONTAINMENT EVAC ALARM SAT. NOTIFIED ANPS AND STA. FILLED OUT A dss 30 FOR THE UNSCHEDULED SURV.
1:56 COMMENCED RPS LOGIC MATRIX TEST PER OP 1 1400059 14:00 INCREASED *A* AND "B" STEAM GENERATOR BLOWDOWN TO 80 GPM NOTIFIED CHEMISTRY AND UNIT 82. ( CORRECT TNE IS 0200 )
1:46 (LATE ENTRY) RCS INVENTORY BALANCE COMPLETED PER DS81, WITH RCS LEAKAGE AT.26 GPM.
CHARGING PUMP LEAKAGE (1 A) AT 1.6 "/HR, (1B) AT - 8 "/HR, (1C) AT 4 "/HR 2:15 LOGIC MATRIX TEST PLACED ON " HOLD
- DUE TO THE BD1 MATRIX HOLD LIGHT NOT EXTINGUISHING IMMEDIATELY LIKE THE OTHER MATRIX HOLD LIGHTS. l&C NOTIFIED TO INVESTIGATE 2:30 ENG REPORTED THAT THE 1B CONTAINMENT FAN COOLER CCW LEAK IS 2 LITERS / HOUR AND STEADY.
2:31 COMMENCED LOSS OF LOAD TEST PER OP 1 1400054 2:45 UNABLE TO LATCH THE TURBINE FROM THE CONTROL ROOui WHEN THE LATCH BUTTON IS RELEASED THE TURBINE TRIPS. THE TURBINE WOULD LATCH FROM THE FRONT STANDARD.
3:05 TRIPPED THE TURBINE AND OPENED ALL TCB'S. LOSS OF LOAD AND LOC 3 MATRIX TESTING ARE TERMINATED AT THIS TIME WHILE CONTROL ROOM CREW DISCUSSES THY IMPACT OF THE BD1 MATRIX HOLD LIGHT.
3:15 CHEM, REPORTS RCS Cb 1053 ppm VIA SAMPLE TAKEN AT 0305 3.30 AFTER DISCUSSIONS WITH UCENSING IT HAS BEEN DEC IDED TO KEEP THE REACTOR TRIP CIRCUIT BREAKERS OPEN UNTIL THE BD-1 MATRIX HOLD RELAY IS REPAIRED, 4 50 DECLARED BD LOGIC MATRIX PANEL OOS DUE TO l&C REPLACING BD1 MATRIX RELAY.
6 45 NO FURTHER ENTRIES THIS SHIFT TIME REVIEWER'S COMMENTS 2:33 NPS Rewow. CDL 2
.t Operations Department Chronological Log Unit 1 o senu NUMBER:
817 NUC POWER:
100 DATE:
8/31/96 DELTA T POWER:
100 SHIFT:
PEAK MWE:
880 SOARD RCO: HOLZMACHER CEA GROUP #:
7 DESK RCO de la Guarde POSITION:
136 NWE:
KLAUCK T AVG:
575 ANPS:
SCALES BORON:
1000 NPS:
STORKE Xe WORTH:
2419 PC MODE:
1 CALCULATED SD MARGIN: >3600 MAJOR MILESTONES OR ACTIVNES TO BE PERFORMED DURING THE SHIFT:
MAINTAIN 100% POWER TIME LOG ENTRIES 15 00 COMPLETED BOARD WALKDOWN, ASSUMED SHIFT 1
15:35 18 BAM TANK BORON SAMPLE RESULT IS 5622 PPM SAMPLE TIME WAS 1525 15.56 SJAE RAD MONITOR 005 WHILE NPO TAKES AIR IN LEAKAGE READING
]
15:59 SJAE RAD MONITOR BIS 16:30 25 17:20 RECElVED ANN J 11 RCP 1B1 OIL PRESS / FLOW /LVL HIGH/ LOW, LIA 1177 READING 2 0 INCHES, ENTERED ONOP 10120034, NOTIFIED ISC AND OPS MANAGEMENT 17:20 NOTIFIED l&C SUPERVISION OF ANN J-11. l&C SUPERVISOR COMMING OUT TO INVESTIGATE AND CORRECT PROBLEM. NOTIFIED HP ON SHIFT AND SECURITY SHIFT SUPERVISOR OF UP COMMING CONTAINMENT ENTRY. TIME SHOULD READ 1725.
17:55 ATTEMPTING TO NOTIFY JPN ENGINEERING OF IMPENDING CONTAINMENT ENTRY TO COORDINATE CCW LEAK INSPECTION ON 1B CONTAINMENT COOLER 18:17 CONTAINMENT PIG OOS FOR HP REMOTE AIR SAMPLE IN PREPERATION FOR CONTAINMENT
iiO3 COMMENCED UNIT #1 SHUTDOWN. LAW OP 10030125 19:20 RPS CHANNEL A VAR Hi POWER, PRE TRi" ALARMS / RESETS 19 40 ORP ALARM, NOTIFIED CHEMISRTY 19 45 RECIEVED ANN 0-15, TURBINE VIBRATION ABNORMAL, #1 BRG ALERT 19 50 DECLARED CHANNEL A RPS, VAR,lABLE -Hi-POWER, OUT OF SERVICE, DUE TO SPURIOUS PRE-TRIPS /PLACED CHANNEL IN BYPASSED 1
1
1 Lh:
Operations Department Chronological Log Unit i 043996 20:06 SECURED 1 A/B HTR DRAIN PUMPS 20.07 PLACED 1B MAIN FEED WATER PUMP ON RECIRC 20:18 MANUALLY TRIPPED REACTOR AND TURBINE DUE TO DETERIORATING CONDITIONS ON 18 MAIN TRANSFORMER i
20:46 EXITED EOP-2 20A0 STARTED HVE-1 AND HVE 2 FOR CONTAINME'NT ENTRY 21:30 KADON SYSTEM AUAM, SYSTEM SHUTDOWN ON LOW FLOW CONDITIOWS 21:50 TURBINE ON TURNING GEAR 22:10 KAIDON SYSTEM BIS ALIGNED TO THE BOTTOM OF RESERVOIR 22:50 COMPLETED NOTIFICATION TO THE NRC 22:55 NO FURTHER ENTRIES THIS SHIFT TIME REVIEWER 1 COMMENTS 22:00 Revwwod log 22 00 Reviewed log R.A. Stome i
i e
i l
2
9 s
Intsr-Office Correspondence e'
FPL JPN-SPSL-96-0399, 9[3 9 (.
To:
D.
A.
Brown Date:
St. Lucie. Plant From D.
J.
Datver f
Department: JPN/PSL Nuclear Engineering Subjects ST. LUCIE PLANT UNIT 1 TITLE:
L*VALUATICN OF TEMPCRARY CPERATING CCNFIGURATICN WITd 1B PAIN TRANSF0FRER OLTT.0F SERVICE PROJECT $e FILE:
This evaluation prc sides for the temporary operating configuration using only Main Transferr..tr 1A until repair and testing of the Main Transformer 1B cooling r,ystem f.s satisfactorily completed and the transformer can be returned to service If you have any qus;ciens, please contact Kino V61ez at 467-7489.
DcD/wAB/mW Co,,i e s :
/