ML18087A566
| ML18087A566 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 10/22/1982 |
| From: | Office of Nuclear Reactor Regulation |
| To: | |
| Shared Package | |
| ML18087A565 | List: |
| References | |
| NUDOCS 8211090520 | |
| Download: ML18087A566 (8) | |
Text
""UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D. C. 20555 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 14 TO FACILITY OPERATING LICENSE NO. DPR-75 PUBLIC SERVICE ELECTRIC AND GAS COMPANY~
Introducti'on PHILADELPHIA EL~CTRIC COMPANY, DELMARVA* POWER AND LIGHT COMPANY, AND ATLANTIC CITY ELECTRIC COMPANY SALEM NUCLEAR GENERATING STATION, -UNIT NO. 2 DOCKET NO. 50-311
/~fi*
By letter dated September 17, 1982, Public Service Electric &'Gas Company (the licensee} requested an amendment to the Facility Operating License No. DPR-75 for Salem Nuclear Generating Station - Unit.2. This amendment would provide a one-time deferral of certain 18 montfl survefll ance items as required 6y tlie.plant Teclinical Speci"fi"cations.
The situation in whicfl the licensee finds itself results from the 13 month time perfod 6etween the Low Power Testing License and receipt, of the Full Power L icens~~ During 8 months.. of this period tlie Unit w~'~.,in cold *shutdown.**
The letter of Septem5er 17, 1982 included a list of items which would require
- action By January 22, 1983, the date of the first cycle refueling.
The
. list is attached tq this safety evaluation and includes dates by which these actions_, primarily instrument ca 1 i brat ions, are to be performed.
The dates
- ~hown encompass the 25% allowance permitted under Section 4.0.2 of the.
Technical Specifications.
As such, the request for reltef will extend the surveillance periods to as much as 15% over the 25% allowance.
The sur~
v~illances are of the ~ype that would require an extensive power outage to
- . perform and Unit 2 has not experiericed such since full-power operation.
Evaluation Plant Technical Specifications include surveillance requirements for systems and components and specifies the frequency at which they are to be performed.
The longest time interval all owed for ful fi 11 i ng the surveil 1 ance requirement
.is 18 mrinths.
In addition, an allowance is provided such tflat any surveillance may exceed the specified interval by 25%.
The 18 month surveillance interval was established on the basis that it would envelope a* norma~.. fuel* cycle~ The majority of surveillance requirements which are specified to be co~plete~ on an 18 month schedule are items for which it is more pra~tic"al-, as well as safe, to conduct \\</hen the plant is in a shutdown condition.* In a few cases, such as overall system tests, the surveillance requtrem~nts can only be performed when.the plant is in a shutdown -conditioll.* Further, the.calibration bf instru~ent. transmitt~rs on a refueling outage frequency is consistent with manufacturer recommendations.
Thus, fo'r the majority of the 18 month.. survei 11 ance requirements, the basis is that this frequency contributes to the overall
- pl ant safety.
e All of the items listed in the attached fa~~ have been reviewed.
All of these items, except for the Cont*ainment Sump Level and the timing of the 4KV circuit breakers, are subjected to more frequent surveillance tests to ensure their operability during plant operation. The Containment Sump Level is used as one of several methods to detect leaks within conta.inment, and therefore, can be compared against the other leak detection techniques to ensure continuous operability.. The 4KV breakers have been historically satisfactory r~.
J<*
~.~
JP In order to evaluate the request for deferral of the required surveillances, several considerations were addressed.
Each item was reviewed as to its function, importance to safety and ability :for verification by other means.
For those primary Reactor Protection System (RPS) and Engineered Safety Features Actuation System (ESFAS) items, the reduction in the setpoint analysis margin was evaluated.
For primary trip functions, instrument errors are one of many considerations that are used to establish trip setpoints.
Calibrations of transmitters limits the magnitude of the errors which impact on the overali system accuracy.
The transmitter errors are identified as sensor drift in the setpoint analyses.
Since sensor drift is based upon transmitter performance for an 18 month interval, the impact of a longer cali5ration interval may be assessed by lin~~r extrapolation to the longer interval.
Based on these considerations, an ~.aluation was made for alltl'primary trip functions listed.
In all cases~ except one, the calibration~ors due to a longer calibration interval were acceptable due to the available margin to safety limits identified in the Salem Unit 2 setpoint analyses.* The only parameter for*1.,rhich this is not true vtas reactor coolant flow for which
.a negative D.b8% margin was predicted.
For many of the item,s in the list, including those channels that provide input to the RPS and ESFAS, control room indication is provided for redundant channels.
Typically, the licensee is required by Technical Specifications to compare these control room indicators every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />. A failed sensor or even one that nas drifted compared to the others should be identified during this twice-a-day surveillance and any potential problem with that channel noted.
Only if redundant s.. ensors dd ft by exactly the same amount
- and in the same direction would this fail to identify a problem.
The Reactor Coolant Flow RPS (Loss of Flow) channel sensors are due to be calibrated at most only 9 days prior to the refueling outage.
This includes all 3 channels in each of the 4 loops.
The Loss of.F.lovt protect.ion.,-is a primary trip vlith a.1% margin in the setpoint analysis.**.~*U*fi~ar"extrapolation
. of the sensor drift vii 11 result in a negative margin of 0. 08%.
However, the trip is backed up by the Underfrequency and Undervolfag*e trips.
He find that deferment of the calibration of these ~low sensors is a~c~ptable.
- The Pressurizer Pressure RPS protection channel sensors are due to be calibrated between November 26 and November 30, 1982.
The Pressurizer Pressure Low and High reactor trips and Low-Safety 1njection trip have 0.3%, 0.9% and l.6% margins respectively, Based on a 0.75% sensor drift over 18 months.
Thes*e sensors would have to drift well beyond manufacturer specification to exceed the availa5le margin.
Therefore, we find that the sur\\'.;.. :::illance deferral is acceptaole for these sensors.
µ*
Trre Pressurtze~ Level sensors are due to 5e calt5rated 5y January 1, 1983.
Tfley fodicate a RPS* trip on high level.
The level sensors are not used for a primary trip and channel checks are conducted twice daily, thus deferral of surveillance is acceptable.
The Steam Generator Steam Flow sensors are due to be calibrated between November* 14 and Decem5er 14, 1982.
These sensors are used fo.r one primary actio~ - Steamline Pressure - Low.
The Steamline Pressure - Low signal has a 5.9% margin which is more than 7 times the maximum sensor drift for an 18 month period.
Deferment of the 18 month calioration of the Steam Generator Flow sensors is acceptable.
The Steam Generator Level protection sensors calibrations are due starting October 11, 1982.
These sensors PfOVide signals to protectiori-channel s for which credit is taken in the atkident analyses (Steam Genwator Water Level - Low, - Low-Low and - High-High).
The margins in theS&-~hannels are more than five times their. design specification drift limits. Therefore, postponement of these 18 month calibrations is acceptable.
_The four ch*annels that constitute the Containment Pressure - High and -
High-High trips a re primary ESF functions.
They have margtns th.at would permit drift several times over design specifications. Sensor calibration deferral for these cliannels is accepta5le.
The sensors that read the first-stage impulse pressure and the reactor coolant (RC) hot leg pressure are used for certain interlocks. Since the safety function is that of being interlocks, the requested two month deferral is accepta51 e.
The steam generator wide range level channels are used for post accident monitoring.
Since they only perform a monitoring function, one-time deferral of their sensor calibrations is acceptaole.
The turbine auxiliary speed sensor provides backup protectto*n *for turbine overspeed.
The primary trip is a mechanical one.
Being a.secondary trip of a non-safety function, postponement of the scheduled* surveillance is acceptable.
The Source Range, Neutron Flux protection channel is not taken credit for in the safety analyses.
Tlie. deferment of the detector cal tBratfons for this protection feature are accepta5.1 e.
The SSPS External Input Test cfl.ecR.s certatn contacts for manual operation of protective functions such as tfie contacts for the reactor coolant pump Breakers.
The contacts involved tn tflese tests are separate and redundant.
Failure of a s*et of contacts w1'l l not preclude tne protective funr+.ion from occurring.
As sucfl, postponement of tfle test is accepta61 e.
The Hot Shutdown Panel sensor calibrations for steam generator level and pressure and pressurizer level and pressure can also Be accepta51y delayed until the refueling outage. These sensors are separate from t5ose that feed the protection cnannel s.
On a monthly Basis, the output from. these sensors, indicated at the Hot Shutdown Panel, are compared to companion indication in the control room.
The Containment Spray pump automatic start is another test that comes due prior to tne scheduled refueling outage. There are two separate*and redundant trains including separate pumps.
Postponing of the test from January 7, 1983 is* accepta61 e.
The Containment Phase A+B due on January 12, *1983.
level tests are routinely deferment is acceptaBle.
Isolation Tests ~re system level tests thai come The functions have redundant trains _.QJld component cond~cte~.~hat verify compon~nt ope}q_tion.
Test
-~......_-
Jhe Containment Sump Level Monitoring System ~hannel calibration is due on December 13, 1982.. This system does not provide an engineered safety features functiqn, i~ *is one of three means of leak detection of the reactor coolant
-system.
In addition, this system is Backed up *5y water inventory.balancing.
As such., postponing tne calibration is acC:eptaBle.
The Hydrogen Recom6iners are due to be caliBrated on December 5, 1982.
These electrical recombiners perform a safety fUnction to mitigate the potential consequences of a hydrogen build-up inside containment during a post accident situation.
Detailed functional checks are performed every 6 months and during theie checks a severely out-of-caltbration condition will be noted.
- Also, there exists two separate trains and in the event of their use, the'i'r operability can be verified 5y use of the hydrogen monitoring system.
On this basis, deferral of the 18 month calibration is acceptable.
The deferral of all of the aforementioned 18 month tests and calibrations do not impact the other periodic survei 11 ances performe-d on.. these 3ystems.
A 11' other tests related to these systems will be ~onducted in accordance to the
- Salem Unit 2 Technical Specifications.
It should be recognized that for these 18 month surveillances the 25%
extension allowed under Section 4.0.2.a of the-Salem Technical Specifications has been used.
As such, the requirement of Section 4.0.2.5, which states that 11 the com5foed time tnterva 1 for any tftree consecutive survei 11 ance interval shall not exceed 3.25 times tfie specified surveillance interval, 11 for tnes-e and other surveillances that did not use the entire 25% a 11 owance, is still in effect.
Summary For those selected 18 montft surveillance items mentioned above, the staff finds ample justification to accept the requested one-time deferral until tile next refueling outage wfii'cfi_ is scheduled to 5egin January 22, 1983.
Environmental Consideration We have determined that the amendment does not authorize a change in effluent types pr total amounts nor an increase in power level and wil~ not result in any stgnificant environmental impact.
Having made this determination, we have further concluded that the amendment involves an action which is
- insignificant from the standpotnt of environmental imp~ct and, pursuant to 10 CFR §51.5(d}(4}, tllat an environmental impact statement or negative declaration and environmental impact appraisal need not 5e prepared in connection with the issuance of this amendment.
Canel usfon
\\.
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We have concluded, based on the* considerations discussed above, that:
CJ) because the amendment does not involve a significant increase in the
- probability or consequences of an accident previously evaluated, does not
-create *the possibility of an accident of a type different from any evaluated previously, and does not involve a significant reduction in a margin of safety, the amendment does not involve a significant hazards consideration,
(_2) there is rea$onable assurance that the health and safety of the public wil 1 not Be endangered 5*y operation in the proposed manner, and (3) such
- acttvities will 5e conducted in compliance with the Commission 1s regulations and the issuance of the amendments wil 1 not be i ntmica 1 to the common defense and securtty or to the health and safety of the public.
Date:
October 22, 1982 Principal Contributor:
M. Wigdor J. Knox W. Ross
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Attachment SALEM GENERATING STATION UNIT NO. 2 l
Mode 5 -
18 Months Surve'illance due prior to. the next refue~i;I1g ou:tage Operations Department DESCRIPTION Containment Spray Pump Auto Start Containment o A Isolation Test Containment o B Isolation Test Maintenance Department DESCR::):PTION Containment Sump Level Monitoring System Channel Calibration 4kV Breaker Inspection and Timing:
2A4D 2B4D 2C4D I
\\.
DUE DATE
,/~:-* -
1-07-83 fa-
- 1-12-83' 1-12-83 DUE.DATE 12-13-82...
1-:-12-83
. 1-12-83 1-12;..83
! I 125VDC and 28VDC Eight ~our* *Battery Service. Tes-t:_~
2Al28VDC 2A228VDC 2Bl2BVDC 2B228VDC 2Al25VDC 2Bl25VDC 2Cl25VDC
- 21.:..18-82
. 11-18.;..82 11-20-82 *.
11-20-82 11-17-82 11-17-82 11-:-20-~s.2.
SEC Sequencer T~st and -Output Relay Time Response Test:
2A SEC 2B SEC 2C SEC Hydrogen Recombiners Test
- 21
. i22 Diesel Generator Inspection 2A Diesel 2B Die.sel 2C Diesel 11-23-.~2 11-19-82 11-19-82
--12.;..0S-82 12-05-82
- 12-17-82
.12-10-82 12-20-.82*
2
- '* *Attachment SALEM GENERATING STATION UNIT NO. 2 Mode 5 -
18 Months sur-Ve.illance due prior.to the next refueling outage Instrument and Control Department DESCRIPTION DUE DATE First Stage Turb. Impule Press -
CH I Channel Calibr., 12-31-82
£<. r
/~<"
RC Flow -
Loop 1.- CH I Sensor Calibrf RC Flow -
Loop 1 -
CH II RC Flow = Loop 1 -
CH III RC Flow Loop 2 CH I RC Flow Loop 2 CH II RC Flow -
Loop 2 -
CH II.I RC Flow ""'.. Loop 3 -
CH I RC F 0
l9w -
Loop 3 -
CH II RC Flow -
Loop 3 -
CH III 11 RC Flow -
Loop 4 -
CH I 11 RC Flow -*Loop 4 -
CH II RC Flow.- Loop 4 CH III Pzr. Press. Prot. CH I 11 Pzr. Press.
1 Prot. CH II Pzr. Press. Prot. CH III Pzr. Level Prot.
CH I
\\.
1 I
n n...-.~
Pzr. Level Prot.
CH II t~.
- 11 "it~
- Pzr. Level P:Cot.
CH III~*
Pzr. Press Prot.
CH IV*
First Stage Turbine Impule Press -
CH~I 11 First Si;.age Turbine Irnpule Press -
CH ]I 11 '*
11
- 21 S/G Strn Flow Prot. CH I n
II i-16-83 1-13-83 1-13-83 1~20-83 1-14-83 --~?
1:-20-83 1-16-83 1-14-83 1-17-83...
1-17-83 1-14-83 1-17-83 ll..".26-82 11-30-82 11-30-82 1-01-83 l-cil-83 1-:01:..83 11-29-82
- 21 S/G Strn Flow Prot. CH II n
II
- 21 S/G Level Prot.
CH IV
. 'l*l-20-8 2 11-24-82 12-13-82 12-14-82 I ;2 ~CJJ!-f*
- /;t.
tt-e... ): 3..--8-2" 12 ~ 18"-=-S'-Z.*
12-17-82 12-0 5-8.2 12-05-82 lo-21-a2 ~/
12-28-82 12-22-82.
12-07-82 ll...;.14-82 12.;...20-82
- # 21 S/G Level Pr9t.*
CH III 11
- 21 S/G Level Prot.
CH II.
CH IV 11
- 22 S/G Level Prat..
CH I:II tt 122 S/G Level Prot CH I
- 23 S/G Strn Flow Prat. CH I
- n.
II
- 23 S/G Stm Flow Prot. CH II,
- 24 S/G Level Prot.
CH IV n
123.S/G Level Prot.
CH IV
-~
- 23 S/G Level Prot.
CH III n
II
- 23 S/G Level Prot.
CH I f 24 S/G Strn Flow Prot. CH I n
f 24 S/G Stm Flow Prot~ CH II 124 S/G.Level Prot.
CH IV
- 24 *S/~ Level Prot.
- CH III
- l0-'26-82 11-13-82 11~01-82 12-06-'82 11-30-82
. '12-20-82 ll-os~a2
\\-~ *,) *,
Ti. ttac liment Instrument and Control Department (Continued)
DESCRIPTION f 24 S/G Level Prot.
Containmen~ Press.
Containment Press.
Containment Press.
Containment Press.
RC Hot Leg Press.
RC Hot Leg Press~
S/G #21 Wide Range
.S/G i 22 Wide. Range S/G #23 Wide-Range S/G #24 Wide Range Turb. ~ux. Speed Replace WR RTD CH II CH IV CH III CH II CH I Level Level Level Level n
n 11 Source Range Channel I Detector Calibration Source Range Channel II Detector Calibration SSPS External Input Test Hot Shutdown Panel Sensor. Calibrations:~*
I
- 21 S/G Level.
- 22 S/G Level
\\.
'I
- 23 S/G Level
~ "..
- 24 S/G Level..
- 21 S/G Press
- 22 S/G Press
- 23 S/G Press
- 24-S/G Press PZR.Press.
PZR Level
~ -
n n
. f..,~;.~
n
..£!
n n
3 DUE DATE.
11-05:--82 11-.23-82 11-27-82 11-25-82 11-27-82 12-03-'82 12.-04-82 12-30-82 12-31-82."
12-28-82~
12-14-82 12-25'-82*
1-01-03*
1-08-83,.
1-0 8-83.
12-25-82 12-19-82.
12-19-*82 1-03-83 1-02...:.93_
1-01-83
. '1-01-83 1-02-83 *.
1-02-83 1-03-83 1-04-83
,:-..:_:...