ML19308C005
| ML19308C005 | |
| Person / Time | |
|---|---|
| Site: | Crane, Davis Besse  |
| Issue date: | 11/29/1978 |
| From: | Cartin L BABCOCK & WILCOX CO. |
| To: | Karrasch B BABCOCK & WILCOX CO. |
| References | |
| TASK-TF, TASK-TMR NUDOCS 8001170746 | |
| Download: ML19308C005 (15) | |
Text
.- _
THE BABC0CK & WILCOX COMPANY O/
POWER GENERATION GROUP i
B. A. Karrasch, Manager, Plant Integration j
From Q ik g-805 663 3 L. R. Cartin, plant Integration (2835)
File No.
Cust.
or Ref.
Date Subj.
November 29, 1978 TECo - B&W Meeting Minutes ln.....,................................
Re:
1)
E. W. Swanson to W. H. Spangler, " Auxiliary Feedwater Setpoints,"
NSS-14, November 15, 1978.
2)
L. R. Cartin to W. H. Spangler, "TECo Operating Instructions,"
T3.3.1, November 28, 1978.
OniNovmeber 27, 1978 a, meeting was held between TEco and B&W personnel (listing of attendees is given in Attach =ent 1) to discuss the design and require =ents for DB-1 AFW Syste= operation. This meeting was required to identify and resolve present proble=s associated with establishing. steam generator level.
control setpoints which:
1.
Maintain indicated pressurizer level during normal reactor trip events.
2.
Maintain pressurizer level during moderate frequency. events.
3.
Provide secondary system performance consistent with LOCA and other DBA event analysis assu=ptions.
The above problems have arisen from TECo's need to ; reduce.the steam generator level setpoints..(to 35") for natural circulation and maintenance of indicated pressurizer level and B&W's need to maintain a high steam generator level (at least 10 feet). because of small LOCA requirements. Reference 1 provides a summary of ar.tivities that preceded the 11/27/78 ceeting. provides the meeting agenda. To provide an orderly and concise summary of the discussions which took place, a synopsis of each major agenda section is provided below:
Section I: Definition of the problem Table 1 provides a listing of the principal (primarily technical) problems identified.
In the short ter=, effort to: resolve Items 7-and 8 to NRC's satisfaction is of primary importance so as to achieve continued operation of DB-1.
Followon work will be required to implement permanent design changes and to finali:a ECCS concerns.
8 0 ^ 1170 7 96
Cartin to Earrasch Page Two TECo - 3G?!!cetina Minutes November 29, 1978 Further discussion of short,and lens ter= activities to resolve identified proble=s is presented below.
Section II:
Auxiliary Feedwater (AFR) Svstem Descriotion Fred Miller (TICo) provided a description of the major components of AFW System, the SFRCS which actuates and controls AFW, and possible AFW/STRCS operating = odes.
i 1.
AFW Svstem: Figure 1 is a simplified sketch of the AFW System assuming AFW addition to both steam generators. Two steam driven AFW pu=ps are supplied.
Steam to drive the pump turbines is extracted from the main steam lines upstream of the MS!V's. Cross-connection for the steam supplies to the pump turbines and for AFW injection lines downstream of the ATW pumps are also provided to achieve.FOGG capabilities during steam and feedwater
.line breaks. Each AFW pump is designed to. deliver 800 gym at 1050 psis'
[(actual delivery is approximately 1200 gpa at 900 psig).'
2.
Steae and Feedvater Line Ruoture Control Svstem (SFRCS): The design goals of the SFRCS are:
l a.
Prevent release of high energy steam.
b.
To auto =atically start AFN in the event of a steam or feedwater line, loss of both main feed pumps, or the loss of all four RC pumps.
c.
To ensure adequate AFW to remove decay heat during pettods when the normal feedwater supply and/or electric power supply to essential auxiliaries has been lost.
d.
To provide essential steam generator level control when AFW is required.
Station variables which require actuation of AFW are:
a.
Low steam line pressuer (< 591.6 psig).
b.
Low steam generator level (< 17 inches).
c.
Stean generator pressure greater than main feedwater line pressure by 197.6 psi.
d.
Loss of all RC pumps as indicated by the RC pump monitors.
[For ali actuation signals excep't chil$ss. of all RC pumps', the STRCS will close both main steam isolation valves, close both r.ain feedwater
, control,andstop. valves, initiate.AFWanccontrolAFWadditionto[maintaik a 120" level in the steam. generators.
Furthermore, if one steam generator remains depressurized'(<591.6 psig) the SFRCS will also align both the AFU pump turbines and,AT'.!_ injection lines _ to the pressuri:ed steam generator p(SLB and FWL3).. If.alloss,of all RC. pumps,(only signal) signal occurs, 6the SFRCS.only; initiates.AFW; steam and feedwater isolation is not actuated.
~
Cartin to Karrasch Page Three TCCo - B W ::eeting l41nutes November 29, 1978 l
3.
AF'.USFRCS Oncrational Asnects:
Followin; SFRCS ac:uation and AFW system alignment (FOGC), steam generator level control is achieved by controlling :he AFW pump turbine speed.
- o changes in valve position are instigated by SFRCS to achieve level con
- rol.
TECo indicated tha: level control within i 6" of the se: point is typically encountered. TECo further indica:ed that redue: ions seen in stea= generator pressure following ATM actuation are due to the large quan:ity of cold AFW introduced into the steam generators and are not due to steam usage by the ATW pump turbines.
See:1on III: Criteria for Pressuriser Sizing The need to maintain pressurizer. level during normal accident conditions was discussed at length. Table 2 presents, for condition I-IV events, criteria for pressurizer level and the. required steam generator level control setpoints.
Both B&W and TECo agreed that these conditions uculd ' allow safe operation of the plant without violation of Safety An ilyses assumptions. This position is to serve as a basis to counteract NRC's inquiry (GDC-13) about TECo's ability to maintain indicated pressurizer level-during nor=al and upset conditions.
Also noted on Table 2 are action items to provide analysis support to the ATW/ pressurizer level position.
TECo indica:ed that the position reflected iniTable 2 would probably satisfy the regional reviewer; however..they were not_so optimistic about DOR acceptance.
If DOR insists that indicated pressurizar level' be~ maintained for.both condition I and II' events,- additional design ~ changes such, as reducing the rate of AFW addition may have-to be pursued.:
Section IV:
Interim Actions In the interim, site instructions will be prepared to direct the operator to assume manual control of the AFW when actuated by SFRCS and maintain 35 inches.
(indicated) on the startup range instrumentation when no ESFAS actuation of HPI occurs. For SFRCS actuations followied by' ESFAS actuation of the HPI system, the operator shall ensurelautomatic control of AFW by.SFRCS to 120 finches (96 inches indicated) on the startup range instru=entation. No operator actions are required if main feedwater remains available following a reactor trip event, even with ESFAS actuation of the HPI.
The revised site instructions are provided in Reference 2 and are consistent with the AFW/ pressurizer level position given in Table 2.
An alternative [ to the above was discussed.
This was sn'oly to change the present
~
SFRCS setpoint _ (10 feet) to_35. inches and to rely on operator action to' manually (control AFW at.10 feet if, post LOCA.condi: ions are present (HP! actuation).
This alternative was not adopted because:
- 1) :;RC acceptance of a timely and continuous manual control function to mitigate a LOCA may be difficul to obtain, and 2)
- he preferred in:eric measures are = ore similar to present operating procedures.
Action items for B&W :o supply analysis and/or test data to suppor: the in:crim site operating ins ructions from a safety standpoint are given in Tacle 2.
Cartin to Karrasch Page Four TECo - B&W Meeting Minutes November 29, 1973 Section V: Criteria for Desitn of AFW Svstems The present problem on TECo is a clear indication that the A?n* system now performs =any more functions than.its original design purpose of decay heat
,re= oval.? Ma internal review (generic) of S&W requirements on the AF system n
- may.be desirable to eli=inate si=ilar problems in the future. Of particular interest would be to li=1t dependence on steam generator perfor=ance for LOCA mitigation.
Section VI: Permanent Design Change (Long Term)
The dual setpoint concept for STRCS control of AFW (automation of interim site instructions) was deemed the most desirable per=anent fix.
Several modifications were noted, however, to provide greater protection from loss of pressurizer level.
These included the possible use of a 10 foot level only if:
- 1) STRCS-ESTAS-RC pumps of f only or, 2)
STRCS-ESFAS (4 psig and 1600 psig) where both ESFAS signals are required to indicate the existence of a small break.
These considerations will be reviewed in the long term.
TECo indicated that their next planned outage is March, 1980.and any pe~sanent design changes would be made at that time because the incorporation of a dual setpoint will require plant shutdown. This long lead time is. advantageous for
. dcaign of a pernanent solution, however, the NRC may not accept this schedule; iwhich would rely on operator action for over one year to meet CDC-13.
If the NRC inquires about plans for a permanent.fix in tho' short. term, it was decided to indicate an automatic control scheme similar to the present site instructions would be implemented. This approach will allow review and possible use of the modifications noted above.
To summarize discussions in previous sections, Table 3 has been developed to illustrate TECo's present AFW control schemes and the proposed =odifications during several accident situations.
Note:. If the NRC does not accept the proposed position on. GDC-13 (Pressurirer:
Level Indication) in Table 2, additional design changes may be required.
One possible change would be to limit AFW flow rates.
Section VII:
Licensing Concerns Although not specifically addressed,Jehe.small LOCA concern-(32 foot steam.
,; generator;1evel in1 Topical. compared co present STRCS design which will allow lonly 10 f eet))is not considered to be o PSC.
B&W will supply technical argu=ents to support the adequacy of the 10 foot level if required.
For the past year. TECo site operators have been instructed to manually control l
lAFW at the 35 inch level following all SFRCS actuations.
Since B&W site instructions will require the achievement of a 10 foot level for SFRCS-HPI events, the present site instructions are considered _to be inconsistent with
- Safety Analysis assumptions, but not considered to be a saf ety problem.
This inconsistency is interpreted to be an unreviewed safety issue. At
Cartin to Karrasch Page Five
.!ecting Minutes November 29, 1978 TECo - BG:
, the time :TICo. revises their ' site procedures, they' will also. inform the NRCl
= of the unreviewed safety issue.
It is hoped that NRC will accept this report as a mere formality to document =easures to assure future plant operation consistent with past safety analysis assu=ptions.
Section VIII:
Schedule / Plan for Problem Resolution
[TEcoistocontacttheNRCon.11/28/18' and present the revised site instuccions hand position on GDC-13 given in Table 2.
Action items noted in Table 2 are to proceed on an "as soon as possible" schedule to provide TECo support to anticipated NRC questions. Plant Integration will coordinate these short term activities.
NRC's reaction to TECo proposals will ultimately control any short or long term activities sci.wdules. For the long term, work activities and schedules will be developed following receipt of feedback from TECo.
LRC:dh Attach cc:
B. M. Dunn R. C. Luken W. H. Spangler E. W. Swanson R. O. Vosburgh/D.W. Labelle R. W. Winks E. A. Womack J. D. Carlton i
TABLE 1:
PRINCIPLE PROBLEYS ASSOCIATED WITH STEAM GE"ERATOR LEVEL CONTROL SETPOINT
- 1., Pressurizer level indication will be lost for normal and upset conditions
.with STRCS actuation and control of AW to 10 foot level.
(NRC GDC-13 concern.)
2.
Pressurizer drains with addition of 4 feet (steam generator level) of AW at low power levels ($15ll) with the RC pumps on.
3.
ECCS requires at least 10 feet (steam generator level of AW for small breaks when LOOP assumed (RC pump off). Limited analysis is available assuming a 10 foot level.
- 4. ;Saall LOCA's have not been analyzed assuming main feedwater, controlled Lat 2 foot level by the ICS, and RC pumps operative (no LOOP).
5.
If a loss of pressurizer level occurs due to addition of AW co a.10 foot steam generator level,!the effect of displacing the pressurizar steam
}bubbleintotheloopsisunanalyzed. Outstanding concerns include: a) i the ability to regain pressurizer level with the low her' RPI system, and b) the ability to maintain natural circulation for LOOP events.
6.
Transients that constitute the design basis for pressurizer sizing and level indication requirements need.to be defined so that present or.
future steam generator level setpoints can be justified.
7.
Present TECo operating procedures instruct the operator to limit (manually)
AW addition to 35 inches on the startup range, level instrumentation.
, Revised instructions to acquire a 10. foot steam generator level for ESTAS 1 events (small LOCA mitigation) may represent an unreviewed safety problem.
8.
TECo must. contact the NRC on 11/28/78 and provide a compliance position.
on GDC-13 and assurance that no safety analyses are violated.
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- k -- ;' r,c. A m e # 2-.
PROPOSED AGENDA FOR TECO - B&W MEETING ON NOVE!'EER 27, 1978 I.
Definition of the Problem (s)
(TECO)
A.
TECO Perception of Problems 1.
Recent Operational Occurrances 2.
Testing Requirements 3.
NRC Involvement a.
NRC Positions on SG Level Control Setpoints b.
Summary of Recent NRC-TECO Discussions c.
Level of Problem Escalation Within the NRC d.
TECO Commitments, if any, to Supply the NRC Information e.
Time Restraints B.
B&W Perception of the Problem 1.
Loss of Pressurizer Level Indication (NRC concern) 2.
Loss of Level (pressurizer draining) 3.
Potential for Spurious Initiation of ESFAS on Loss of Level 4
Needs for Steam Generator High Level for ECCS 5.
Need to Maintain Natural Circulation II.
Auxiliary Feedwater (AFW) System Descripticn (TECO)
A.
Physical Laycut - Major Compenents B.
Present System Modes of Operation 1.
Initiating Signals (SFRCS, ICS, etc.)
2.
SG Level Control Set;oints 3.
Expected Flew Rates
.T
PROPOSED AGENDA (CONTINUED) i C.
System Operation 1.
AFW System Operatien to Achieve and Control SG Level (Interaction of Pump Speed Controls and AFW Injection Valve Operation; with SG Level Control ano FW Demand Signals; System Response Times; Sequence of Contrcl Events; etc.)
2.
AFW - Secondary S'ide Interaction a.
Impact of AFW System Operation on SG Pressure y
b.
Level Control Stability with Off-Cn AFW Cperatien III.
Criteria for Pressurizer Sizing (B&W)
A.
Need to Maintain Indicated Level for:
1.
Normal Reactor Trip Events 2.
Upset Condition (LCMFW, Secondary Side Steam-Feedwater Malfunction, etc) 3.
Design Basis Events (SLB, LOCA, etc.)
B.
Past and Present NRC Positions on Criteri; 13.
Following this discussion, a position will be developed by TEC0/E&W for future use in NRC discussions.
IV.
Interim Actions to Achieve Pressurizer Level Control and to Maintain Validity of Safety Analysis (Short Ter=)
A.
Discussion of Recent Site Instructions 1.
Situations Requiring Op. Action to Control SG Level 2.
Basis for Operator Intervention -
- Maintenance of Pressurizer Level
- LOCA Mitigation
- Etc.
B.
Probability of Success Based on Operation Exp.
C.
Anticipated NRC Reaction to Proposed Accinistrative Procedures 2
(
g, PROPOSED AGENDA (CONTINUED)
V.
Criteria for Design c' AFW System A.
At the Time of TECO Design 1.
Decay Heat Removal (LOFW) 2.
Establish Natural Circulation B.
Present (in addition to A) i 1.
Maintain Hot Shutdown Decay Heat Removal After Abnormal Transients i
2.
Small Break LOCA Mitigation C.
Future (Poss!bles in addition to A and 5)
.t 1.
Loss of All AC Power 2.
Safety Grade Cooldown VI.
Permanent Design Change Alternatives (Long Term)
A.
Dual Setpoints - Control of SG Lavel at 120" for ESFAS Transients Only
(
1 B.
AFW Flow Rate Reduction 1.
Injection Valve Throttling 2.
Pump Speed Reduction 3.
Increased Bypassed Flow i
C.
Other Alternatives VII.
Licensing Concerns A.
Present NRC Commitments - FSAR, Verbal, etc.
B.
Is Problem A Preliminary Safety Concern? -
C.
Licensing Action to Implement Permanent Design Change VIII.
Development of Schedule and Program Plan for Problem Resolutien A.
Short Ter= TECO & B&W Actions l
B.
Long Ter: TECO & GIU Actions 1
3
-