ML110400166
| ML110400166 | |
| Person / Time | |
|---|---|
| Site: | Callaway  |
| Issue date: | 02/22/2011 |
| From: | Thadani M Plant Licensing Branch IV |
| To: | Union Electric Co |
| Polickoski J, NRR/DORL/LPL4, 415-5430 | |
| References | |
| TAC ME2822 | |
| Download: ML110400166 (18) | |
Text
UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 February 22, 2011 LICENSEE:
Union Electric Company FACILITY:
Callaway Plant, Unit 1
SUBJECT:
SUMMARY
OF JANUARY 25, 2011, MEETING WITH UNION ELECTRIC COMPANY ON RESPONSES TO THE U.S. NUCLEAR REGULATORY COMMISSION STAFF'S QUESTIONS RAISED DURING THE PREVIOUS PUBLIC MEETING ON NOVEMBER 18, 2010 (TAC NO. ME2822)
On January 25,2011, the U.S. Nuclear Regulatory Commission (NRC) staff conducted a Category 1 public meeting with representatives of Union Electric Company, licensee for Callaway Plant, Unit 1, at NRC Headquarters, One White Flint North, 11555 Rockville Pike, Rockville, Maryland. The purpose of the meeting was to discuss the licensee's responses to NRC staff questions raised during the previous public meeting on November 18, 2010, as noticed and summarized in the Agencywide Documents Access and Management System (ADAMS) Accession Nos. ML103020279 and ML103470147 regarding Callaway Plant, Unit 1's license amendment request. The licensee requested revision to Technical Specification (TS) 3.3.2, "Engineered Safety Feature Actuation System (ESFAS) Instrumentation," in its submittal dated November 25,2009 (ADAMS Accession No. ML093290318). A list of attendees is provided in Enclosure 1.
The licensee first answered the three questions the NRC staff raised during the November 18, 2010, public meeting regarding (1) main feedwater flow actuation instrumentation for auxiliary feedwater (AFW); (2) the procedure for inserting the AFW ESFAS channel trip; and (3) the operational implementation interpretation of TS 3.3.2 as currently approved. The licensee also reviewed the main feedwater pump startup and shutdown procedures during plant power level manipulations. Finally, the licensee discussed its proposed TS 3.3.2 wording modification, provided within Enclosure 2, and the precedent for the proposal.
The NRC staff questioned the licensee's TS 3.3.2 modification proposal utilizing the TS proposal annotations provided in Enclosure 3. The staff discussed limits to the TS Limiting Condition for Operation (LCO) Completion Time based on the existing risk-informed analysis; the relevance of the licensee-discussed TS precedence to the proposed TS modifications; and the implication of a TS 3.0.2 exception due to the nature of the TS modification proposed.
Based on this discussion, the staff and licensee extensively examined the merits of various and specific TS 3.3.2 modifications.
The licensee expressed its intention to review the proposed changes internally and to provide an additional supplement to its license amendment request.
- 2 No members of the public were in attendance. Public Meeting Feedback forms were not received.
Please direct any inquiries to me at 301-415-1476 or mohan.thadani@nrc.gov.
Mohan C. Thadani, Senior Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-483
Enclosures:
- 1. List of Attendees
- 2. Licensee proposed TS wording modifications
- 3. NRC TS modification comments to licensee proposal cc w/encl: Distribution via Listserv
LIST OF ATTENDEES JANUARY 25, 2011, MEETING WITH UNION ELECTRIC COMPANY RESPONSES TO THE U.S. NUCLEAR REGULATORY COMMISSION STAFF'S QUESTIONS RAISED DURING THE PREVIOUS PUBLIC MEETING ON NOVEMBER 18,2010 DOCKET NO. 50-483 NRC
Participants:
Michael Markley, Chief, Plant licensing Branch IV Greg Casto, Chief, Balance of Plant Branch Mohan Thadani, Senior Project Manager, Plant Licensing Branch IV Andrew Howe, Senior Reliability and Risk Analyst, PRA Licensing Branch Carl Schulten, Senior Reactor Engineer, Technical Specifications Branch Stanley Gardocki, Reactor Systems Engineer, Balance of Plant Branch Kristy Bucholtz, Reactor Systems Engineer, Technical Specifications Branch Rossnyev Alvarado, Electronics Engineer, Instrumentation and Controls Branch James Polickoski, Project Manager. Plant Licensing Branch IV Union Electric Company
Participants:
Scott Maglio. Manager, Regulatory Affairs Bert Yates, Principal Engineer, Regulatory Affairs Mark Covey, Assistant Operations Manager, Operations Members of the Public:
None
ENCLOSURE 2 LICENSEE PROPOSED TS WORDING MODIFICATIONS WITH BACKGROUND
3.3.2 ESFAS Instrumentation ACTIONS (continued)
J.
One e Main Feedwater pUI'1""ln"'-lrln channel{s) inoperable.
NOTE ------------------
OR J.2 Be in MODE 3.
1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> CONDITION I.
One channel inoperable.
REQUIRED ACTION
NOTE ----------------
The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.
1.1 OR 1.2 Place channel in trip.
Be in MODE 3.
COMPLETION TIME 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 78 hours CALLAWAY PLANT 3.3-29 Amendment No. 196
INSERT A2 CONDITION REQUIRED ACTION COMPLETION TIME J. One channel inoperable.
OR Two channels inoperable within the same separation group.
NOTE--------------
One inoperable channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing of other channels.
J.1 Place inoperable channel(s) in trip.
OR J.2 Be in MODE 3.
24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 30 hours
3.3.2 ESFAS Instrumentation ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME M.
to.iet !:Isee.. '.:ls;Qj ~
- w
- .,
N.
One or more Containment Pressure - Environmental Allowance Modifier channel(s) inoperable.
N.1 OR N.2.1 AND N.2.2 Place channel(s) in trip.
Be in MODE 3.
Be in MODE 4.
72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 78 hours 84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> O.
One channel inoperable.
0.1 AND 0.2 Place channel in trip.
Restore channel to OPERABLE status.
,.-1 R6t:lf :;)4-Antir.
During performance of the next required COT
.r lcontinued}
CALLAWAY PLANT 3.3-31 Amendment No. 168
3.3.2 ESFAS Instrumentation ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME P.
One or more channel(s) inoperable.
P.1 Declare associated auxiliary feedwater pump(s) inoperable.
AND P.2 Declare associated steam generator blowdown and sample line isolation valve(s) inoperable.
Immediately Immediately Q
One train inoperable.
NOTE -----------------
One train may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing provided the other train is INsEI?TQ OPERABLE.
r&.+tQ. ::2./ Be in MODE 3.
AN~
Q.2,.1 Be in MODE 4.
~ours d2 hours R.
One or both train(s)
R.1 Restore train(s) to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> inoperable.
OPERABLE status.
OR R.2.1 Be in MODE 3.
i 54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> AND R.2.2 Be in MODE 4.
160 hours0.00185 days <br />0.0444 hours <br />2.645503e-4 weeks <br />6.088e-5 months <br /> (continued)
CALLAWAY PLANT 3.3-32 Amendment No. 197
INSERTC REQUIRED ACTION COMPLETION TIME Q.1 Restore train to OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> status.
I
~
ESFAS Instrumentation 3.3.2 No
~e~ - f17Vi;ld *r ~ ",,~
Table 3.3.2-1 (page 8 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(s)
- 6.
- a. Manuallniliation 1.2.3 1Ipump P
SR3.3.2.8 NA
- b.
r Automatic Actuation Log ie and Actuation Relays (SSPS)
Automatic Actuation LogiC and Actuation Rela~(BOP ESF
)
1.2.3 1.2.3 2 trains 2 trains G
Q SR3.3.2.2 SR 3.3.2.4 SR3.3.2.6 SR 3.3.2.3 NA NA 1
- d. SG \\/Vater Level Low-Low (1) Steam Generator Water Level Low-Low (Adverse Containment Environment) 1.2.3 4 perSG D
SR3.3.2.1 SR3.3.2.S SR 3.3.2.9 SR3.3.2.10
~ 20.6%(1) of Narrow Range Instrument Span (2) Steam Generator water Level LOW-LOW
~ormal ontainment Environment) 1(r),2(I),3(e}
4 per SG D
SR3.3.2.1 SR3.S.2.5 SR3.3.2.9 SRS.S.2.10
~ 16.6%(') of Narrow Range Instrument Span (a)
The Allowable value defines the limiting safety system setlin9 except for Functions 1.e, 4.e.(1). 5.c, 5.e.(1). 5.e.(2),
6.d.(1), and 6.d.(2) (the Nominal Trip SetpOint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(r)
Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.
(s)
- 1. Ifthe as-found instrument channel setpOint is conservative with respect10the Allowable Value, but outside its as-found test acceptance criteria band. then the channel shall be evaluated to verify that it is functioning as required before returning the channel to servic&. Ifthe as-found instrument channel setpeinl is not conservative with respect to the Allowable Value. the channel shall be declared inopenlble.
- 2. The instrument channel setpoint shall be reset to a value that is within the as-lefi seipoint tolerance band on either side of the Nornioal Trip Setpoint. or to a value that is more conservative than the Nominal Trip Setpolnt; otherwise.
the channel shall be declared Inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.
CALLAWAY PLANT 3.3-45 Amendment No. 197
3.3.2 ESFAS Instrumentation Table 3.3.2-1 (page 9 of 11)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)
- 6.
- d. SG Water Level Low-Low (3) Not used.
(4) Containment 1,2,3 4
!; 2.0 psig Pressure -
SR3.3.2.5 Environmental SR3.3.2.9 Allowance SR 3.3.2.10 Modifier
- e. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.
- f.
Loss of Offsite 1,2,3 2 trains R
SR3.3.2.7 NA Power SR 3.3.2.10
- l f}t;IMtt
- h. Auxiliary 3
~ 20.64 psia to'
~,
Feedwater Pump SR 3.3.2.9 Suction Transfer
~;,,)
SR 3.3.2.10 on Suction SR 3.3.2.12
)
Pressure* Low (al The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.{l), 5.c, 5.e.(1), 5.e.(2).
6.d.(1). and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(n)
Trip function may be blocked just before shutdown of the last operating main feedwater pump and restored just after the first main feedwater pump is put into service following performance of its startup trip test.
(u) :::r::.NSEt<r E CALLAWAY PLANT 3.3*46 Amendment No. 197
INSERT E (u)
Leo 3.3.2 is not applicable for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for the channels associated with placing the second main feedwater pump into service or when removing the first main feedwater pump from service.
AUCA 10-012. Revision 000 Logic diagram of MDAFAS from trip of all Main Feedwater Pumps MfP'A' MfPS' MFP'A' FCPSL25 FCPSL012S FCIlS1.26 IV IltltDf O~ven AIlldliary F~pump
[ArM) 1 ArM otIItr COI1d1l!oru; 6Ignal61'1Om -----,
Note this drawing is simplified. Refer to J-104-00176 for the current design logic diagram Page 1 of2 Page 36 of 38
CALLAWAY PLANT RISK-INFORMED AMENDMENT REQUEST 24-HOUR BOP ESFAS COMPLETION TIME START DIESEL To 'A' Trip&
'B' Bypass Bkrs To 'B' Trip &
'A' Bypass Bkrs CRVIS SIS/CSAS Start -----------1
~
TDAFW ~
SA036C I__ ~
UV and 2/4 SG low UV and 2/4 SG low from SA036D from SA036E SSPSLOGIC SSPS OUTPUT RELAYS SIS/CSAS
~ I BOP ESFAS Input Logic SA036A SA036D START DIESEL NB02 UV B BLACKOUT SGBSIS CRVIS Relay SLiSI FWIS Testing CPIS CISA CRVIS SA036B SA036E L
FBIS SA075B AFAS (LO SG LVL AFAS/SGBSIS UV and 2/4 SG low 2/4 on 1/4
--~-
and 214 on 214)
Input Logic to SA036C B EJ CPIS CRVIS FBIS -
AFAS/SGBSIS UV and 2/4 SG low to SA036C BOP ESFAS
[ - FWlV's ISiNS I
~~
II~
~ r.4meren UC CiIIl:A~PIJi,
ENCLOSURE 3 NRC TS MODIFICATION COMMENTS TO LICENSEE PROPOSAL
EXAMPLE REQUIRED ACTION COMPLETION TIME CONDITION
NOTE--------------
One inoperable channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing of other channels.
J.1 Place channel in trip.
J.
One channel 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable.
M.1 Place channels in trip.
M.
Two channels 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable.
AND AFW actuation on Trip of all Main Feedwater Pumps maintained.
EXAMPLE TABLE APPLICABLE FUNCTION MODES OR OTHER REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE(a)
SPECIFIED
- d. SG water level Low Low (3) not used.
(4) Containment Pressure Environmental Allowance 1, 2, 3 4
N SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 s 2.0 psig Modifier
- e. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.
- f. Loss of Offsite 1, 2, 3 2 trains R
SR 3.3.2.7 NA Power SR 3.3.2.10
- g. Trip of all Main 1, 2(ni J, M SR 3.3.2.8 NA Feedwater Pumps
- h. Auxiliary
- 20.64 psia Feedwater Pump Suction transfer on Suction Pressure Low (a) The allowable Value defines the limiting safety system setting foir Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),
6.d.(1), and 6.d.(2) (the Nominal Trip Set point defines the limiting safety setting for these Functions). See the Bases for the Nominal Trip Setpoints.
(n) Trip function may be blocked just before shutdown of the last operating main feedwater pump and restored just after the first main feedwater pump is put into service following performance of its startup trip test.
(u) During power ascension when one main feedwater pump is in operation supplying feedwater to the SGs and the other main feedwater pump is reset and not supplying feedwater to the SGs the following exception applies: The requirement for four operable channels is met if two required channels are OPERABLE on the associated main feedwater pump in operation supplying feedwater to the SGs and two required channels are in trip on the associated main feedwater pump in reset and not supplying feedwater to the SGs. When both main feedwater pumps are in operation supplying feedwater to the SGs the exception no longer applies.
- 2 No members of the public were in attendance. Public Meeting Feedback forms were not received.
Please direct any inquiries to me at 301-415-1476 or mohan.thadani@nrc.gov.
IRA!
Mohan C. Thadani, Senior Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-483
Enclosures:
- 1. List of Attendees
- 2. Licensee proposed TS wording modifications
- 3. NRC TS modification comments to licensee proposal cc w/encl: Distribution via Listserv DISTRIBUTION:
PUBLIC RidsOgcRp Resource LPLIV r/f RidsOpaMail Resource RidsAcrsAcnw_MailCTR Resource RidsRgn4MailCenter Resource RidsNrrDorl Resource KBucholtz, NRR/DIRSIITSB RidsNrrDorlLpl4 Resource CSchulten, NRR/DIRSIITSB RidsNrrDirsltsb Resource AHowe, NRRIDRAIAPLA RidsNrrDraApla Resource SGardocki, NRRIDSS/SNPB RidsNrrDssSbpb Resource RAlvarado, NRRIDE/EICB RidsNrrDssSnpb Resource CSteger, NRR RidsNrrDeEicb Resource JTrapp, EDO RIV RidsNrrLAJBurkhardt Resource VDricks, OPA RIV RidsNrrPMCallaway Resource
.IPolickoski, NRR ADAMS Accession No. Meetin OFFICE DORLlLPL4/PM DORLlLPL4/PM MThadani NAME JPolickoski 2/16/11 DATE 2/9/11 Notice ML110120470 Meetin DORLlLPL4/LA MThadani 2/22/11