Text

Forwards marked-up Tech Spec 3/4.7.5, UHS, for Inclusion in Final Draft 840827 Tech Specs.Addl Changes Result of 840927 Discussions W/Nrc & Sargent & Lundy Engineering Re Min Rock River Flow & Level
	ML20093H766
Person / Time
Site:	Byron
Issue date:	10/03/1984
From:	Farrar D; COMMONWEALTH EDISON CO.
To:	Harold Denton; Office of Nuclear Reactor Regulation
References
	NUDOCS 8410160376
	Download: ML20093H766 (39)
	v • d • e

.-

Ccmmonwocith Edison O

One First National Plata, Chicago. Illinois O/

Address Reply to: Post OTGe Box 767 Chicago, Ilknois 60690 October 3,1984 Mr. Harold R. Denton, Director Office of Nuclear Reactor Regulation U.s. Nuclear Regulatory Commission Washington, D. C.

20005 f

l

SUBJECT:

Byron Generating Station Units 1 and 2, Technical Specifications, NRC Docket Nos.so-454 and 50-455 Dear Mr.

Denton:

The continuing review of the Byron Station Technical Specifications has identified additional changes as noted on the enclosed attachments.

It is requested that these changes be incorporated i.nto the final draft of the Technical Specifications dated August 27, 1984, from B.J. Youngblood to D. Farrer.

Very tdly yoursC

/

. c-Dennis L. Farrar Director, Nuclear Licensing cc:

Byron Resident Inspector Senior Tech Spec Coordinator Calvin Moon 00 8410160376 841003 PDR ADOCK 05000454 A

PDR

ATTACHMENT 29 Byron Station proposes to modify Technical Specification 3/4.7.5

" Ultimate ' Heat Sink" as indicated on the attached page.

JUSTIFICATION These revisions are requested based on discussions held on 9/27/84 between Gary Staley (NRC - E p ironmental and Hydrologic Engineering Branch) and Sargent & Lundy Engineering concerning Minimum Rock River flow and corresponding Rock River level, t

I i

~

^'

--Al'6 : - ;+; -

/htf8W FINAL DRAFT 3/4.7.5 ULTIMATE HEAT SINK LIMITING CONDITION FOR OPERATION 3.7.5 The ultimate heat sink (UHS) shall be OPERABLE with:

An essential service water pump discharge water temperature of less a.

than or equal to 98*F, and b.

A minimum Rock River water level at or aboveDM', feet Mean Sea Level, USGS datum, at the Byron Screenhouse, with two essential service water make up pumps OPERABLE, and Two deep wells OPERABLE 2 tr r. L ^'...

c.

- ~ :..:

'M '.. t ". x R. '.. '. C;; u wm,

m u

6.. c y..

a...._.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTION:

With the essential service water pump discharge water temperature not a.

meeting the above requirement, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

e t

With only/e. -ssential service water make-up pump OPERABLE restore tw c.

essential service water make-up pumps to OPERABLE status within 72 j

hours or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in I

COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

d.

With*8U deep well restore N deep wells to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.5.1 The UHS shall be determined OPERABLE at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying the essential service water pump discharge water temperature and the Rock River water level to be within their limits.

4.7.5.2 The deep wells shall be demonstrated OPERABLE:

At least once per 31 days by starting each pump and operating it for a.

at least 15 minutes and verifying that each valve (manual, power-operated, or automatic) in the flow path is in its correct position, and b.

At least once per 18 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.

b.

With Rock River water le' vel.less than 670.6', verify Rock River flow is greater than 700 cfs and Rock River level is greater than 664.7'.

Otherwise, be in HOT STMOBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months and implement proper plant procedures.

3/4 7 -13 7

ATTAQ9 ert 35 I

Byron Station proposes to modify Table 2.2-1. Table Notations (pages 2-7 and 2-8) as indicated on the attached copies.

Justification These revisions are requested based on recent changes to the Setpoint-Study as provided by Westinghouse letter CBW-4769 (8/17/84) W. E. Kortier to J. D.

Deress.

t 1

(0567M)

t IABLE 2.2-1 (Continued)

,y TABLE N01ATIONS

=

e c

NOTE 1: OVERTEMPERATURE AT z

I I

{

[T (3,

AT (3, ysg) i AT, [K

-K2 g) - I'] + K (P - P') - f (al))

3 i

g Where:

AT Measured AT by RIO Manifold Instrumentation,

=

j lead-lag compensator on measured AI,

=

13. I2 Time constants.tilized in lead-lag compensator for al, 1: = 8 s.

=

l.

12=3s.

I Lag c spensator n measured AT,

=

1 15 3

7

= Time constants utilized in the lag compensator for AT, i3=0s, 13 AT, Indicated AT at RAIE0 THERMAL POWER,

=

K

= 1.13 "- 1,14f i

K

=

2 0.0265/*f, I * **

The function generated by the lead-lag compensator for I,yg

=

dynamic compensation, Time constants utilized in the lead-lag compensator for I,,g, 1 - 33 s,,

M te, is

=

4 is = 4 s, gl M

I Average temperature

F, e

=

Q l*t[5 Lag c opensator on measured I,,g,

=

4

'h 4

IABLE 2.2-1 (Continued)

E TABLE NOTATIONS (Continued) x NOTE 1:

(Continued)

E line constant utilized in the measured l lag g ensa W. Ju = 0 s, Is

=

avg T'

588.4*F (Nominal I,yg at RATED IllERMAL POWER),

Ks 0.00134,

=

P

=

Pressurizer pressure, psig, P'

2235 psig (Nominal RCS operating pressure).

=

S

=

Laplace transform operator, s 8, and f (AI) is a function of the indicated difference between top and bottoe detectors of the power range neutron ion chambers; with gains to be selected based on measured instrument T

response durin0 Plant SIARIUP tests such that:

- oo 7,

+io%

(i) for qt g between -49f3nd @,(at) = 0, where q and qb E*'C'"'

b t

RATED THERNAL. POWER in the top and bottom halves of the core respectively, and qt

g I'

b total TilERNAL POWER in percent of RAIED IllERMAl POWER; 44i) nr ;ec;.,,..s..t ihai ihr

g..i t;.Jc--d g g ;x;;;Ja ia, iii. 4i i.,. 0;t,-.u[ ~

-;;. ii ue automatically icuusso "

2. o;,% o.' it; s;&_,

t RA.;;.is.....

ivos;, _ a2 *

~

q

.,y

i o'I.

V (4

for each percent that the magnitude of q q exceeds the AT Trip Setpoint Q>

mumm shall be automatically reduced by M (f its value at RAIED TilERHAL POWER.

h f., b 2.o%

j F

NOTE 2:

The channel's maximus Trip Setpoint shall not exceed its comin.ted Trip Setpoint by more than N

3.3% of AT span.

m W

ATTAQ9 TENT 36 Byron Station proposes to modify Table 3.3-6 Table Notations (pg 3/4 3-41) as shown on the attached copy.

Justification j

Cuttently ACTION STATEMENT 29 tequires that if both channels are inoperable, a portable monitor be provided and in accordance with ACTION b of Specification 3.9.12 all operations involving movement of fuel oc loads over the storage pool be suspended.

This change is based upon conversation with Fred Anderson (NRC) on 9/27/84 When a portable monitor is used, there is no means to automatically place the Fuel Handling Building Exhaust System in the emergency mode and exhaust through the HEPA and chatcoal filters. Therefore, at least one Fuel Handling Building Exhaust filter plenum must be operating in the emergency mode whenevet a portable monitor is used. The change proposed would requite that if both channels were inoperable a portable monitor would be provided and the Fuel Handling Building Exhaust System would be placed in operation in the emergency mode. It is not necessary to suspend movement cf fuel or loads over the storage pool because the radiation monitors have been replaced by a portable monitor. Only if the Fuel Handling Building Exhaust System could not be placed in operation then the requirements of ACTION b of Specification 3.9.12 would be met.

4 (0567M) 1 i

h u} (s)..D D }t a 7 ""

u.rS TABLE NCTAT*:NS

.i,r wa/s if",.

fo "With new fuel or irraciated fuel in the fuel storage areas or fuel builcine.

"" Trip Setpoint is to be estaolished sucn that tne actual suomersion cose rate would not exceed 10 mR/hr in the containment builcing.

For containment ourge or vent the Setpoint value may be increased up to twice tne maximum concentra-tion activity in the containment determineo oy tne samole analysis performec prior to each release in accordarce witn Table 4.11-2 provicec the value coes not exceed 10% of the equivalent limits of Specification 3.11.2.1.a in accorc-ance witn the'methodo':gy and parameters in tne 00CM.

ACTION STATEMENTS ACTION 26 With less than the Minimum Channels OPERABLE requirement, operation may continue provided the containment purge valves are maintained closed.

ACTION 27 With the number of OPERABLE channels one less than tne Minimum Channels OPERABLE requirement, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolate tne Control Room Ventilation System and initiate operation of the Control Roca Make-up System.

ACTION 28 Must satisfy the ACTION requirement for Specification 3.4.6.1.

ACTION 29 With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, ACTION a. of Specification 3.9.12 must be satisfied.

With both enannels inoperable, provide an appropriate portable continuous monitor with the same Alarm Set-point in the fuel pool area ond sati5fy ACTION b. ;f ;a; 'f;;

-J7 tien 3.0.12 with one Fuel Handling Suilding Exhaust filter plenum in operation. o w e s se. saHsh AcncM b. o r-r SpedAce Hm s.9.i2_

BYRON - UNIT 1 3/4 3-4,1

~

s ATTACIMENT 37 Byron Station proposes to change the definition of DIGITAL CHAlWEL OPERATIOIRL TEST (page 1-2) and Table Notations (1) and (2) of Tables 4.3-8 (page 3/4 3-65)-

and 4.3-9 (page 3/4 3-74) and the Bases (page B3/4 3-3) as shown on the attached pages.

Justifications Standard Technical Specifications do not define a DIGITAL QUUWEL OPERATIONAL TEST or describe what will be required in table notations for a DIGITAL CHANNEL OPERATIONAL TEST. The cuttent versions in the table notations were originally taken from the requirements and definitions of an ANALOG CHANNEL OPERATIONAL TEST. As such, they are ambiguous and open to various interpretations when applied to a digital system. To avoid this ambiguity and possible misinterpretation, the proposed changes clearly state what is meant by a DIGITAL CHAW EL OPERATIONAL TEST and what the requirements of this test will be.

I l

1 (0567M)

)

&$'aha[3 4

INITIONS

ILwa nNh' CONTAINMENT IMIEGRITY n"w

~ " ~

-a

.ww

1. 7 CCNTAINMENT INTEGRITY sna11 exist wnen:

All penetrations required to be closed during accident conditions a.

are either:

1)

Capable of being closed by an OPERABLE containment automatic isolation valve system, or 2)

Closed by manual valves. blind flanges, or deactivated automatic valves secured in their closed positions, except as provided in Table 3.6-1 of Specification 3.6.3.

b.

All equipment hatches are closed and sealed, Each air lock is in compliance with the requirements of c.

Speci fication 3.6.1.3, i

The containment leakage rates are within the limits of Specification d.

3.6.1.2, and The sealing mechanism associated with each penetration (e.g., welds, e.

bellows, or C-rings) is OPERABLE.

CONTROLLED LiAKAGE

1. 8 CONTROLLED LEAKAGE shall be that seal water flow supplied to the reactor coolant pump seals.

CORE ALTERATION

1. 9 CORE ALTERATION shall be the movement or manipulation of any component within the reactor vessel with the vessel head removed anc fuel in the v Suspension of CORE ALTERATION shall not preclude completion of movement of a component to a safe conservative position.

DIGITAL CHANNEL OPERATIONAL TEST d,.2iM eAb 1

M c.10 A DIGITA QCHNEL OP RATIONA1.g ES Lshall consist o Lexercising the digital e M &arg asing ostic or M nd h simulated process data to. tne enannefto verify OPERASILITY of alarm and/or trip functions.

00SE EQUIVALENT I-131 1.11 which alone would produce the same thyroid dose as the qu mixture of I-131 I-132, I-133, I-134, and I-135 actually present.

dose conversion factors used for this calculation shall be those listed inThe thyroid Table III of TID-14844, " Calculation of Distance Factors for Power and Test Reactor Sites."

BYRON - UNIT 1 1-2

N

15 h%p-TAELE 4.3-8 (Continued)

. i.c4 j

i

'* H J.a g)

TABLE NOTATIONS m e,n nn _

nuo<*bH.m x

(1) The DIGITAL CHANNEL OPERATIONAL TEST shall also demonstrate that automatic isolation of this pathway and control room alarm annunciation occur if any of the following conditions exists:

a.

Instrument indicates measured levels above the Alarm / Trip Setpoint, or I.

".... 5 i 7.. I.. w,

wr-

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v.

3C* IN###~7

......msu6 n......

.a q

? : t;..;c.; ;...;..L..

. ; ' ;,;;. :. : f:.

a (2) The DIGITAL CHANNEL OPERATIONAL TEST shall also demonstrate that control room alarm annunciation occurs if any of the folicwing conditions exists:

Instrument indicates measured levels above the Alarm Setpoint, or a.

"k:d't's""*-

o.

s e e 2%s e rT

+

T % woi.u....J.

.;., e de c.-;.1: ' - " - -

"c-h W :..;t;.....ia. controls na m

.n we.....

(3) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards shall permit calibrating the system over its intended range of energy and measurement range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

(4) CHANNEL CHECK shall consist of verifying indication of flow during periods of release. CHANNEL CHECK shall be made at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months on days on which continuous, periodic, or batch releases are made.

s BYRON - UNIT 1 3/4 3-65

TABLE 4.3-9 (Continued) p(,it,f ",

z,

,,,1 y sc

.kj 9<

TABLE NOTATIONS u lj j

../ dry

At all times.

any O 3 g During WASTE GAS HOLOUP SYSTEH operation.

(1) The DIGITAL CHANNEL OPERATIONAL TEST shall also demonstrate that automatic isolation of this pathway and control room alarm annunciation occur,1f any of the following conditions exists:

a.

Instrument indicates measured levels above the Alarm / Trip Setpoint, or l

l h.

C'r: ft *:i? r:, er

~

Znses*r S e. e

!c.;^.ca.;c^. ' din'-

= d~a "'" * * " " - - :-

h u.

Anstrument con 1.ro i s

..v..4 ' :; es.a.ta mode,-

j (2) The DIGITAL CHANNEL OPERATIONAL TEST shall also demonstrate that control room alarm annunciation occurs if any of the following conditions exists:

a.

Instrument indicates seasured levels above the Alarm Setpoint, or,

'b.

u rcuu saisu,

S e e. _En a ser v.-

f ! Nr:,

r c.; ^. c a.;..:. ;..d. s. 6 =

oownsceir s.

__ g

--,at s.

e (3) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards (NBS) or using standards that have been obtained from suppliers that participate in measurement assurance activities with NBS. These standards shall permit calibrating the system over its intended range of energy and seasurement range. For subsequent CHANNEL CALIBRATION, sources that'have been related to the initial calibration shall be used.

(4) The CHANNEL CALIBRATION shall include the use of standard gas samples containing hydrogen and nitrogen.

(5) The CHANNEL CALIBRATION shall include the use of standard gas samples containing oxygen and nitrogen.

4 l

.j BYRON - UNIT 1 3/4 3-74 i

2

l0 Y

L //2 7 P. ?

l)

G N L. Y ), on b.

l10Noto" Les3 or consn uu s co r son S

4* M C.

Dr1CCTOA s.o ss of e e st u r s, as O s t rcr o t.

C h rC et.

$0uteF TEST r/la "tf,

On t.

'IAostn*wngur s nSS of p o wtK, Ok

[.

Ostrcred C,h a uu rt af or SFee Vec f oc 3

Han, san uns or sa nea ru o w.

3 b.

[1cusrot Locc or conr,uv o cartons,- 02.

C.

orrre roa.

uss or cco~ rs,

.e J.

brsecren cesea.

s o u nca resr rasu ure, ce c.

Insuup rur s.e s s or

powrk, or I.

Ortre. tom c u 4 u u rt.

Ow7 or Efavsef g.

non, r.a iose or t nra ra w.

D

- +. -

Y j1 h ? i ;=r s

.} f

,,t, 2 / J '17-

.j

,,/,.

.57K,."ENTATION c. r-

.ES Encineered Safety Features Actuation System Interlocks The Engineered Safety Features Actuation System interlocks perform the following functions:

P-4 Reactor tripped - Actuates Turbine trip, closes main feedwater valves on T,yg below Setpoint, prevents the opening of the main feedwater valves which were closed by a Safety Injection or High Steam Generator Water Level signal, allows Safety Injection block so that components can be reset or tripped.

Reactor not tripped prevents manual. block of Safety Injection.

P-11 On increasing pressure P-11 automatically reinstates Safety Injection actuation on low pressurizer pressure and low steamline pressure and automatically blocks steamline isolation on negative steamline pressure rate.

On decreasing pressure; P-11 allows the manual block of Safety Injection low pressurizer pressure and low steamline pressure and allows steamline isolation on negative steamline pressure rate to become active upon manual block of low steamline pressure SI.

P-12 On increasing reactor coolant loop temperature, P-12 automatically provides an arming signal to the Steam Dump System.

On decreasing

.. reactor coolant loop temperature, P-12 automatically removes the arming signal from the Steam Dump System.

P-14 An increasing steam generator water level, P-14 automatically trips all feedwater isolation valves and inhibits feedwater control valve modulation.

3/4.3.3 MONITORING INSTRUMENTATION 3/4.3.3.1 RADIATION MONITORING FOR PLANT OPERATIONS TRIP Tkg eTla d The OPERABILITY of the radiation monitoring instrumentation for plant operations ensures that: (1) the associated ACTI " will be initiated when the radiation level monitored by each channel er ec-tinctie-ther::f eaches its setpoint, f?} : :prei:d ;;in:id:n; Ivwiw

....mio.n e,

and

) suffi-cient redundancy is maintained to permit a channel to be out-of-service for testing or maintenance.

The radiation monitors for plant operations senses radiation levels in selected plant systems and locations and determines whether or not predetermined 1.imits are being excee'ded.

If they are, ;..

cal; ;r; iv3 w: .;;7'::: :# ti., is wvmvina

.wo.

I ou. w. J...

" "# cut

...s...s

.nov

.. ;.;; :nd 25 - :' :;nditier.;.

Co.=

7;;_':d';;

ww.~.

. ti;r it-w...

;1,;;d, the sys}gm sends actuation signals to initiate alarms 8/' automatic i::!:ti:r :: tier ; ; actuation of Emergency Exhaust or Ventilation Systems.

The radiation monitor Setpoints given in the requirements are assumed to be values established above normal background radiation levels for the particular area.

BYRON - UNIT 1 8 3/4 3-3 s

ATTAQ MENT 38 Byron Station proposes to modify Table 3.3-11 Fire Detection Instruments (page 3/4 3-59), Table 3.7-5 Fire Hose Stations (pages 3/4 7-37 and 3/4 7-38) and Table 3.8-1 Containment Penetration Conductor Oveccurrent Protective Devices (pages 3/4 8-19 to 3/4 8-27) as indicated on the attached copies.

Justification These changes are requested basrd on recent review by Byron Station as part of s

the Technical Specification certification process.

l (0567M)

I

TABLE 3.3-11 (ContinueF)I

. ca j

a 2~dA 5 u

A*d as

/0/r/?Y FIRE DETECTION INSTRUMENTS

= ^

~.

enso a c knr INS'RUwSNT LOCATION INSTRUMENT TvoE' 0*AL NUMBER OF INSTUUMENTS 1

l Heat Flame Smoke 6.

Station Battery Rcom Zone 67 Elev 451 Detection 13 7.

Diesel Generator Room Zone 37 Elev 401 Suopression A" 4 Zone 38 Elev 401 Suppression JW 4 Zone 71 Elev 401 Detection 1

Zone 72 Elev 401 Detection 1

8.

Diesel Fuel Storage Zone 39 Elev 401 Suppression 1

Zone 40 Elev 401 Suppression 1

Zone 27 Elev 383 Suppression 3

Zone 28 Elev 383 Suppression 3

Zone 10 Elev 383 Detection 6

9.

Safety Related Pumps Zone 41 Elev 383 Suppression 2

Zone 42 Elev 383 Suporession 1

Zone 16 Elev 364 Detection 2

Zone 18 Elev 364 Detection 4P 10 Zone 19 Elev 364 Detection f 25 Zone 20 Elev 346 Detection 3

Zone 21 Elev 346 Detection 3

Zone 52 RSH Suppression 8

10.

Fuel Storage Zone 39 Elev 401 Detection 29 Zone 38 Elev 426 Detection 3

TABLE NOTATIONS

A single cetector in a zone marked " Detection" will alarm in the Main Control Room.

A single detector in a zone marked " Suppression" will initiate suppression and alarm in the Main Control Room.

- These are Containment Ventilation temperature switches. Upon receipt of a Hi-Hi temperature, suppression must be manually initiated.

These switches are not 720 supervised.

- "The fire detection instruments located within the containment are not required to be OPERABLE during the performance of Type A containment leakage rate tests.

BYRON - UNIT 1 3/4 3-59

'l TABLE 3.7-5 (Continued) as FIRE HOSE STATIONS

a:

e LOCATION ELEVATION HOSE RACK REEL ANGLE VALVE E

Aux. 81dg. (Continued)

[

M-18: By Aux. Feedwater motor driven pump 1A 387 108 0FP383 N-23: By remote shutdown panel U-1 387 111 0FP376 Q-15:

By 480V MCC 132X3 38/

113 0FP382 V-18: By letdown heat exchanger 387 114 0FP379

^

P-7:

West Wall 6.9 kV switchgear room

'455 20 0FP324 L-11:

In UC HVAC Rm OA of LCSR C-1 455 22 0FP332 m

E N S E 'LT A M-8:

South wall of battery room 451 279 0FP638 '

M-26:

South wall of battery room 451 280 0FP639 M-18:

North wall U-l A8 by door 444 238*

OFP463 5

L-7:

East wall LCSR A-1 443 207" 0FP330 M-10:

In the southeast corner o( LCSR 8-1 443 208*

OFP327 7

P-10:

In the southwest corner of LCSR 8-1 443 209*

OFP325

!U M-13:

South wall of LCSR C-1 443 210*

OFP326 P-13 D-15: West wall of LCSR 0-1 443 211" CFP328 5-21:

By cabinet 2RY0lEC (elec. pen. area) 431 229 0FP45Y 9 S-24:

By U-2 cont. shield wall (elec pen. area) 431 230 0FP45F 5

._ 2:4sser 6 S-12: By U-l cont. shield wall (elec pen. area) 431 237 0FP462 '

.r N 5C CT C.

P-ll:

Outside Laundry Room 430 52 0FP313 Q-19:

By U-2 VCT valve aisle 430 54 0FP342 P-24:

By radwaste evaporator 4JO SS OfP343' V-17: By east door to decon/ change area 430 58 OIP319

'"T1 V-17:

By west door to decon/ change area 430 61 OIP320

- tH5Egr D l

L-ll:

By waste oil tank room 405 90 0FP315 I

P-18:

By elevator 405 91 CTP318 D

l P-23: By spent resin pumps 405 92 0FP349 Q-ll: By laundry tanks 405 93 OfP314 S-21:

East of U-2 hydrogen recombiner 405 94 OIP348

J Js V-21: West of U-2 hydrogen recombiner 405 95 0FP345 o

V-15: West of U-l hydrogen recombiner control O

panel 405 96 0FP316 D0%

CFire hoses that do not supply the primary means of fire suppression.

%l b M

e' TABLE 3.7-5 (Continued)

E B

FIRE HOSE STATIONS

=

LOCATION ELEVATION HOSE RACK REEL ANGLE VALVE k

Aux. Bldg. (Continued)

[

S-15:

East of U-l hydrogen recombiner 405 97 OTP317 N-ll:

By the recycle holdup tanks 368 130 OfP373 M-t3 J H 4: By the U-l stairs 368 131 0FP374 D-14: By panel IPL84J8 368 132 OfP369 P-13 l

l L-20: By the U-2 stairs 368 133 0FP355 P-21:

By the blowdown condenser 368 134 OfP356 L-25: By the PW K pumps 7 gfu 368 135 OfP361 N-25:

By chemical drain tank 368 136 OfP357 S-18:

By panel IPL86J 368 138 OfP362 Q-11:

By Aux. Bldg. floor drain tanks 368 139 OfP368 U-15:

By~U-1 spray add tank 368 140 OfP372 mucIE mD P-11:

By recycle evaporator feed pumps 350 151 OfP381 p

M-13:

By U-1. stairs 350 152 OIP370 g,

N-23:

By gas decay tanks 350 154 0FP352 Q-19: By "B" Aux. 81dg. Equip. drain tank 350 155 OfP365 Q-17: By "A" Aux. Bldg. Equip. drain tank 350 156 0FP3/1 Q-13:

By collection sump pumps 350 157 OfP380 S-18:

Between moderating heat.xchangers 350 158 OfP354 V-18:

Between BR chiller units 350 161 OIP353 W-15:

By CS pump 1A 150 163 OfP367 i

F M-13:

By leak detection sump 334 165 OfP448 Mg M

P-18:

By elevator ait 334 166 OfP449

-C e

ammmme Fuel Hand. 81do.

2 2-15:

South of decon. area 430 170 OfP389 g

jg X-21: North of spent fuel pool 430 171 OfP386

.ama 7-15:

By 480V HCC 134X6 405 1/2 OfP368

~c3 l

AA-19: Outside FC pump room 405 1/3 OfP38/

i.

Cont. #1 sg R-17:

By reactor head assembly area 430 62 IfP163 g

h R-2:

By accumulatur tank IC 430 63 IfP154

L

~

~qM b g 3/4 7-57 J.f/'t 7-50 j

~-

HOSE j

MAct.

I L OCATloN Et.EVATloN REEL.

ANGLE YAL VC Aux. Bid 3 INSEF.T A L-2 5: By CE l' HVAC room 955 27 pFP33S INSERT 8 y Pze htr. +ransformer-

'f 31 13 (.

OFP461 5 -15 :

B (elee.. pen. area)

I N s e n.T-C Q-lo:

Sock. of Div.11 sw3r room

'f 3 0 283 OFP640 IHss:nr D 5 -15 :

B Pz.r. hh. trans kemer-

'f f i 1Tf OFP 3 22.

y (el ec.

pen. arco)

Q-lo:

By elecMcel genetralia oreg

'f l 3 205 0FP321 INSEE.T E V-18 :

By U-2. cent ch. pomp rocm 3 68 141 OFF364 3

INSERT F P-18:

Sy 18 SX pump room 334

/b7 OFP35)

M-23:

By 18 3x porwp room 359 168 0F'P350 b

l FINAL DRAFT TABLE 3.8-1

/o/,/pp Alle o a m,

CONTAINMENT PENETRATION CONDUCTOR

~

OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE 1.

6.9 kV Switchgear 1RC01PA-RCPA Primary Bus 157 Cue 1 Bus 157 Norm. Feed Backup ACB 1571 Bus 157 Emerg. Feed Backup AC8 1572 1RC01PB-RCPB Primary Bus 156 Cub 2 Bus 156 Norm. Feed Backup ACB 1561 Bus 156 Emerg. Feed Backup ACB 1562 1RC01PC-RCPC Primary X

Bus 158 Cub 5 Bus 158 Norm. Feed Backup AC8 1582 Bus 158 Emerg. Feed Backup AC8 1581 1RC01PO - RCPD Primary Bus 169 Cub 5 Bus 159 Norm. Feed Backup AC8 1597 2.

X Bus 159 Emerg. Feed Backup ACB 159/ I Y

2.

480V Switchgear 1RYO3EA - Pzr.

Primary Htr. Backup Group A Compt. Al-A6, 81 Backup l

1RYO3E8 - Pzr.

Primary l

Htr. Backup Group 8 Compt. 81-86, A1 Backup m.m m

1 MlhY

.ac vu

~;'t FINAL MAFT TABLE 3.8-1 (Continued)

CCNTAINMENT PENETRATION CONDUCTOR l

OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICE NUMBER AND LOCATION OEVICE 2.

480V Switchgear (Continued) 1RYO3EC - Pzr.

Primary Htr. Backup Group C h

Compt. Al-A6 g Backuo 1RYO3E0 - Pzr.

Primarv Htr. Backup Grouc 0

~

X Compt. 81-86#

Backuo 3.

480V A.C. Ckt. Skrs.

IVP01CA - RCFC Fan 1A Low Speed Feed Bkr Swgr 131X Primary Cub 4C Hi Speed Feed Skr Primary Swgr 131X Cub SC 1VP01CC - RCFC Fan 1C Low Speea y

Feed Skr Swgr Primary 131X Cub Ae 2C.

Hi Speed Feed Skr D-imary X

Swgr 131X Cub Se 3C Bus 131X Norm.

Feed 141 Swgr..

Backup k

Cub W,19 K

ACB 1415X IVP01CB - RCFC Fan IB Low Speed Feed Bkr Primary Swgr 132X Cub 4C Hi Speed Feed Skr Primary Swgr 132X Cub SC IvP01CD - RCFC Fan 10 Low Speed Feed Bkr Primary Swgr 132X Cub 2C avenu. sm n,

A k'

mHM

\\

AUG ?. o ~J l

TABLE 3.8-1 (Continued)

CONTAINMENT PENETRATION CONOUCTOR i5-OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICE NUMBER ANO LOCATION DEVICE 3.

48QV A.C. Ckt. Skrs. (Continued)

,- Hi Speed Feed Skr Primary Swgr 132X Cub 3C l

Sus'132X Norm. Feed Backup

142 Swgr., Cub 14, s

ACB 14Ha.1%5X W

4.

480V Molded Case Ckt. Bkts. (MCCB)

MCC 133X4 IRC01PA-A 3 Primary Cub B1,'

Backup 1RC01PA-B

. Cub B2 Primary Backup 1HC22G Cub B3 Primary Backup 1FH03[G Cub B4 Primary y1 Backup IVP05CA Primary Cub C1 l

Backup 1RF03P Primary Cub C2 Backup 1RC01PD-A Primary Cub 01 Backup IRC01PO-B Primary Cub 02 Backup 1RF02PB Primary Cub 04 Backup i

1RF01P Primary Cub 05 Backup l

f BYRON

. UNIT 1 3/4 8-21

aa n

lOf/hY A t le O m e'

Pt V W M Q HAPT FIN..s'uDR6 EFT a

TABLE 3.8-1 (Continued) u

'e l, CCNTAINMENT PENETRATION CCNDUCTOR OVERCURRENT PROTECTIVE CEVICES PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE 4

480V Molded Case Ckt. Bkts. (MCCB) (Continued)

MCC 133M D

1RE01PA Primary Cub 06 Backuo IVP02CA Cub El Primary Backuo IVPO4CA Cub E2 Primary Backup IVPO4CC Cub F1 Primary Backup 1EW11EA,B, C-Primary Y

Cub F3 Backup

'g P 4 3,;. o_

2g

.w ra o w k o-0 -

e b P' 4 4 in.

7, 4etrt Saag

^

11002EA Primary Cub F5

acKuo IIC02EB Primary Cub G1 Bacxup IIC02EC Primary Cub G2 Backupe 14 CC.134 X5 11C02EF Primary Cub Al Y

Backup IIC02EE Primary Cub A2 Backup IIC02ED Primary Cub A3 Backup BYROM - UNIT 1

&la :-n

4 so/r/M ffdie

$f TABLE 3.8-1 (Centinued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICc NUMBER AND LOCATION DEVICE 4

480V Molded Case Ckt. Bkts. (MCCB) (Continued) l33W5

)(

MCC 1::-,"

i N

i VH02J Primary Cub G1 Backup

.L g

t IFH03J Primary Cub G2 Backuo 1RC01PB-B Primary Cub Bl Backup 1RE0lPB Primary Cub B3 Backup W

W i?'n %

1RC01PC-A Primary Cub C1 Backup 1RC0lPC-8 Primary Cub C2 Backup IVP05CB Primary Cub J1 Backup 1RC01PB-A Primary Cub C3 Backup Cs 1HC65(-A j

Primary a

Cub 05 Backup IVP02CB Primary Cub F1 Backup 1RC01R-A Primary Cub F2 A j B Backup 1RF02PA Primary Cub G3 Backup 1EW12EA, B, C.

Primary Cub F3 443 Backup

,Y BYROM - UNIT 1 3/4 8-23

s c/o 2ne e /Pf muu e o e TABt.E 3.8-1 (Continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE 4.

480V Molded Case Ckt. Bkts. (MCCB) (Continued)

MCC 134W 5

10 '12:C o 4 s y*_

g Cd "I 9=- M L

1E"12E0

?. ' : y m J

Ca c2 S:&c o

IVPO4CB Primary Cub F4 Backup IVPO4CD Primary Cub F5 Backup s

+ McC 132 x 2. A e

ISI8808C Primary gcc, i32.

Cub A2 Backup cub B2./] ^151B808B 3

F j

Primary Q Cub A3 Backup s

1RH87028 M ary Cub B1 Backup 1RH87018 Primary Cub B3 Backup J

hCC132x2) h ICV 8112 Primary Cub B4 Backup 10G079 Primary Cub C1 Backup IWOOS6A Primary Cub C2 Backup 10G080 Primary Cub C3 Backup BYROM - UNIT 1 3/4 8-24

[

e FINR DRAFT TABLE 3.8-1 (Continuec) as e 0 g C,'

"* p/fY

/o CONTAINMENT PENETRATION CONDUCTOR CVERCURRENT PROTECTIVE CE/:CES PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE 4

480V Molded Case Ckt. Bkts. (MCCB) (Continued)

MCC 132V2 h

1RY80008 Primary Cub C4 Backup C

1R/8003C k

Primary Cu'a Et D5 sactuo D

4*P05E

.A h

^ -

~

C a C1 1RC80038 o imary r

Cub 04 Eackup t

~-

.. e x

e..-

o_

10C8002A o imary l

r Cub G1 Eackco f

1RC8002B Primary Cub G2 Ea %c 1RC8002C Primary Cub G3 Ea:ku:

1RC90020 o ie.a r e Cub G4 S 2 <uo' MCC 131X2A I

15 88080 Primary Backup D

w s

1SI8808A Primary Cub A3

+0 4 C C ^

Backup D

0100 101 m C ' "-

MCC 131X2 3

IRC8001A Primary Cub G1 Backup BYRON - UNIT 1 3/4 8-25

'ET 2 0 = <#d FE R D HFT TABLE 3.8-1 (Continued)

CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE 4.

480V Molded Case Ckt. Bkts. (MCCB) (Continued) 131X2 MCC 122::2?

3 1RCS0018 Cub G2 Primary Backup 1RC8001C Cub G3 Primary Backup 1RC8001D Cub G4 Primary Backup 1RH8701A Cub B1 Primary Backup 1RH8702A Cub B4 Primary Backup ILL42J Cub C1 Primary Backuo IVQ001A Cub C3 Primary Backup IVQ002A Cub F1 Primary Backup 1RC80030 Primary Cub C4 Backup 1RC8003A Primary Cub CS Backup 10G057A Primary Cub 01 Backup 1CC9416 Primary Cub 03 Backup ICC9438 Primary Cub 04 Backup 10G081 Primary Cub E2 Backup 8YRON - UNIT 1 3/4 8-26

t,.

sa/s/rY ane a a -

nu o a w,

TABLE 3.8-1 (Continued) l CONTAINMENT PENETRATION CONOUCTOR OVERCURRENT PROTECTIVE DEVICES PROTECTIVE DEVICE NUMBER AND LOCATION DEVICE 4.

480V Molded Case Ckt. Bkts.'(MCCB) (Continued)

G MCC 133XS Q

1HC01f - Cub B2 Cub B1 Primary Backup 2

ILLO4E - Cub C;V Cub C1 Primary D

Backup IVP03CA Cub A3 Primary Backup IVP03CD Cub C4 Primary Backup "CC 1:24 C-D 1003414 0

F"*

"A erimary p

Cact; o

MCC 134X7 D

ILLOSE - Cub B2.

Cub Bl # y Primary Backup D

IVP03CB Cub A3 Primary Backup IVP03CC Cub B4 Primary Backup MCC 131Y2B R

f IWOO56B q Primary Cub A?

Backup g

1RYB000A Cub AS Primary Backup BYRON - UNIT 1 3/4 8-27

ATTAQ9EDir 39 Byron Station proposes to change Surveillance Requirement 4.8.1.1.2.f 7) (page 3/4 8-5) as indicated on the attached copy.

Justification The maximum loading on the diesel generator has been limited to 6050 W per vendor recommendations. The 6050W (+0,-150W) establishes a bandwidth in order to compensate for grid fluctuations.

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FIiNAI M-eAFT ELECTRICAL POWER SYSTEMS

=

4 SURVEILLANCE REQUIREMENTS (Continued) 5)

verifying that on an ESF Actuation test signal without loss of ESF bus voltages, the diesel generator starts on the auto-start signal and operates on standby for greater than or equal to 5 minutes.

The generator voltage and frequency shall be 4160 + 420 volts and 60 + 1.2 Hz within 10 seconds after the auto-start signal; the generator steaoy state generator voltage and frequency shall be maintained within these limits during this test; 6)

Simulating a loss of ESF. bus voltage in conjunction with an ESF Actuation test signal, and a)

Verifying deenergization of the E5F tusses and load snedding from the ESF busses; b)

Verifying the diesel starts on the auto-start signal, e

energizes the E5F busses witn permanently connected loads within 10 seconds, energizes the auto-connected emerge y (accident) loads through the LOCA sequencer and opera s for greater tnan or equal to 5 minutes while g

its generator is loaded with emergency loads.

After energization, the steacy-state soli. age and frequency of the ESF busses shall De maintained at 4160 : 420 volts and 60 1.2 Hz during this test; and c)

Verifying that all automatic diesel generator trips, except engine overspeed and generator differential, are automatically bypassed upon loss-of voltage on the emergency bus concurrent with a Safety Injection Actuation signal.

O-o,-t so kN 7)

Verifying the diesel generator coerates for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

During the first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test, the diesel ge erator X

shall be loaded to gr::ter th= cr :: d t9 6050 kW and during the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of this test, the diesel generator shall be loaded to greater than or equal to 5500 kW.

The generator voltage and frequency shall be 4160 420 volts and 60 + 1.2 Hz within 10 seconds after the start si:gnal; the steacy-state generator voltage and frequency shall be maintained within these limits during this test. Within 5 minutes after completing this 24-hour test, perfom Specification 4.8.1.1.2f.6)b);*

8)

Verifying that the auto-connected loads to each diesel generator do not exceed the 2000-hour rating of 5935 kW:

If Specification 4.8.1.1.2f.6)b) is not satisfactorily completed, it is not necessary to repeat the preceding 24-hour test.

Instead, the diesel generator may be operated at 5500 kW for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or until operating temperature has stabilized.

BYRON - UNIT 1 3/4 8-5

s ATTACHMENT 41 Byron Station proposes to modify Technical Specification Figure 6.2-2, UNIT ORGANIZATION (pg 6-4), as attached.

Justification This revision to Figure 6.2-2 is to resolve a Byron Station senior resident NRC inspector open item 454/84-42-01; 455/84-29-01. This figure is representative of the unit organization.

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ATTACHMENT 42 Byron Station proposes to modify Table 3.12-1(pg 3/412-4), T.S. 3/4.12.3 (pg 3/412-14), T.S. 6.5.2 b1) (pg 6-12), T.S. 6.9.1.6 (pg 6-19), T.S. 6.9.1.7 (pg 6-21) and T.S. 6.14.2a (pg 6-25) as shown on the attached pages.

Justification These changes are requested based on recent review by Byron Station as part of the Technical Specification certification process.

g 1

fA9 art TABLE 3.12-1 (Continued}

RADIOLOGICAL ENVIRONMENTAL MONITORING PROGRAM h

NUMBER OF REPRESENTATIVE EXPOSURE PATHWAY SAMPLES AND SAMPLING AND TYPE AND FREQUENCY c_$

AND/0R SAMPLE SAMPLE LOCATIONS COLLECTION FREQUENCY OF ANALYSIS

--e

2. Airborne

~

Radioiodine and Samples from five locations:

Continuous sampler Radiciodine Cannister:

Particulates operation with sample I-131 analysis weekly, Three samples from close to collection weekly, or r

1 rmeausa. c. nan, b riu m u f the three SITE BOUNDARY loca-more frequently if Aamaan inacc*d mu--

tions, in different sectors, required by dust Particulate Sampler:

of the highest calculated loading.

Gross beta radioactivity annual average ground level 0/Q; analysisfollogg filter change; and One sample from the vicinity of gamma isotopic analysis a community having the highest of composite (by location) calculated annual average ground-quarterly.

m2 level D/Q; and g

One sample from a control L

location, as for example 10 to 30 km distant and in the least prevalent wind direction.

3. Waterborne

a. Surface ($)

One sample upstream.

Composite samp1 g er Gamma isotopic analysis One sample downstream.

1 month period.

b monthly.

Composite for to(EELg rages SAMPLE

tritium analysis quarterly,

b. Ground Samples from one or d<o sourc Quarterly.

Gamma isotcpic and tritium only if likely to be affected analysis quarterly.

c. Drinking One sample of each community Composite sample I-131 analysis on each

} {

g) drinking water supply over 2 week period composite when the dose c )%

downstream of the plant when I-131 analysis calculated for the constep-e3 0 within 10 kilometers.

is performed, monthly Lion of the water is greater D

i composite otherwise.

than 1 mrem per year.(8) Com-

. qb One sample from a control positeforgrossbetaag

[ t location.

gamma isotopic analyses monthly.

Composite for tritium analysis quarterly.

A Y

,,, 0.

'5

=

/o///8/

RADIOLOGICAL ENVIRONMENTAL MONITORING 3/4.12.3 INTERLABORATORY COMPARISON PROGRAM LIMITING CONDITION FOR OPERATION 3.12.3 Analyses shall be performed on radioactive materials, suppled as part of an Interlaboratory Comparison Program that has been approved by The g

Commission, that correspond to samples required by Table 3.12-1.

s APPLICABILITY:

At all times.

ACTION:

With analyses not being performed as required above, report the a.

corrective actions taken to prevent a recurrence to the Commission in the Annual Radiological Environmental Operating Report pursuant to Specification 6.9.1.6.

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.12.3 The Interlaboratory Comparison Program shall be described in the ODCM.

A summary of the results obtained as part of the above required Interlaboratory Comparison Program shall be included in the Annual Radiological Environmental Operating Report pursuant to Specification 6.9.1.6.

I 8YRON - UNIT 1 3/4 12.14

l?

E E

b o

ADMINISTRATIVE CONTROLS 6.13 PROCESS CONTROL PROGRAM (PCP) 6.13.1 The PCP shall be approved by the Commission prior to implementation.

6.13.2 Licensee-initiated changes to the PCP:

a.

Shall be submitted to the Commission in the Semiannual Radioactive Effluent Release Report for the period in which the change (s) was made.

This submittal shall contain:

1)

Sufficiently detailed information to totally support the rationale for the change wr.hout benefit of additional or supplenental information; 2)

A determination that the change did not reduce the overall conformance of the solidified waste product to existing criteria for solid wastes; and 3)

Documentation of the fact that the change has been reviewed and found acceptable by the Onsite Review and Investigative Function, b.

Shall become effective upon review and acceptance by the Onsite Review and Investigative Function in accordance with Specification 6.5.2.

6.14 0FFSITE DOSE CALCULATION MANUAL (00CM) 6.14.1 The ODCM shall be approved by the Commission prior to implementation.

6.14.2 Licensee-initiated changes to the 00CM:

udth 'n, Ito Q h d M$8"".dk hd4 ShallbesubmittedtotheCommission(3:'a th: hi:rn:1 ";di;;;ti s; *-

a.

K E"'xr.t ";h;;; " ;;rt ';r th: ?:-i d "4r wo,';) c::

d: t

" eti::*- This submittal shall contain:

1)

Sufficiently detailed information to totally support the rationale for the change without benefit of additional or supplemental information.

Information submitted should consist of a package of those pages of the ODCM to be changed with each page numbered, dated and containing the revision number, together with appropriate analyses or evaluations justifying the change (s);

2)

A determination that the change will not reduce the accuracy or reliability of dose calculations or Setpoint determinations; and 3)

Documentation of the fact that the change has been reviewed and found acceptable by the Onsite Review and Investigative Function.

b.

Shall become effective upon review and acceptance by the Onsite Review and Investigative Function in accordance with Specification 6.5.2.

BYRON - UNIT 1 6-25

b

.A u m[t.7 n, n:

t

[

ADMINISTRATIVE CONTROLS OFFSITE (Continued) h)

Instrumentation and Control Engineering graduate or equivalent with at least 5 years of experience in instrumentation and control design and/or operation.

i)

Metallurgy Engineering graduate or equisilent with at least 5 years of experience in the metallurgical field.

3)

The Supervisor of the Offsite Review and Investigative Function shall have experience and training which satisfy ANSI N18.1-1971 requirements for plant managers.

ONSITE 6.5.2 The Onsite Review and Investigative Function shall be supervised by the Station Superintendent.

Onsite Review and Investigative Function a.

The Station Superintendent shall:

(1) provide directionc for the Review and Investigative Function and appoint the Technical Staff Supervisor, or other comparably qualified individual as the senior participant to provide appropriate directions; (2) approve partici-pants for this function; (3) assure that at least two participants who collectively possess background and qualifications in the sub-ject matter under review are selected to provide comprehensive interdisciplinary review coverage under this function; (4) indepen-dently review and approve the findings and recommendations developed by personnel performing the Review and Investigative Function; (5) report all findings of noncompliance with NRC requirements, and provide recommendations to the Division Vice President and General Manager - Nuclear Stations and the Supervisor of the Offsite Review and Investigative Function; and (6) submit to the Offsite Review and Investigative Function for concurrence in a timely manner, those items described in Specification 6.S.la which have been approved by the Onsite Review and Investigative Function.

b.

Responsibility The responsibilities of the personnel performing this function are:

6TNTion sercWK Pos.TsoN5 oF v

1)

Review of:

(1) procedures required by Specification 6.8.1 and changes tnereto, (2) all prograr's required by Specification 6.8.4 and changu thereto, and (3) any other proposed procedures or changes thereto as determined by the '

Superintendent to affect nuclear safety; 2)

Review of all proposed tests and experiments that affect nuclear safety; BYRON - UNIT 1 6-12

2; Ik/hY ADMINISTRATIVE CONTROLS REPORTING REOUIREMENTS (ContinuedJ ANNUAL RADIOLOGICAL ENVIRONMENTAL OPERATING REPORT

6.9.1.6 Routine Annual Radiological Environmental Operating Reports covering the operation of the Unit during the previo 1 calendar year shall be submitted prior to May 1 of each year.

The initial report shall be submitted prior to May 1 of the year following initial criticality.

The Annual Radiological Environmental Operating Reports.shall include summaries, interpretations, and an analysis of trends of the results of the

{

radiological environmental surveillance activites for the report period, including a comparison with preoperational studies, with operational controls as appropriate, and with previous environmental surveillance reports, and an assessment of the observed impacts of the plant operation on the environme,tt.

m

_____._.ms, m

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0 &@ical Env%%.M m w t te b,~ 4^ y % 3.0 2-AQA The Annual Radiolog ironmental Operating Reports shall include the results of analysis of all radiological environmental samples and of all l

environmental radiation measurements taken during the period pursuant to the locations specified in the tables and figures in the 00CM, as well as summarized and tabulated results of these analyses and measurements in the format of the I

table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979.

In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results.

The missing data chall be submitted as soon as possible in a supplementary report.

The reports shall also include the following:

a summary description of the Radiological Environmental Monitoring Program; at least two legible maps **

l covering all sampling locations keyed to a table giving distances and directions from the centerline of one reactor; the results of licensee participation in

(

the Interlaboratory Comparison Program and the corrective actions being taken if the specified program is not being performed as required by' Specification 3.12.3; reasons for not conducting the Radiological Environmental Monitoring program as required by Specification 3.12.1, and discussion of all deviations from the sampling schedule of Table 3.12-1; discussion of environmental sample measure-ments that exceed the reporting levels of Table 3.12-2 but are not the result of plant effluents, pursuant to Specification 3.12.1; and discussion of all analyses in which the LLD required by Table 4.12-1 was not achievable.

"A single submittal may be made for a multiple unit station.

- 0ne map shall cover stations near the SITE BOUNDARY; a second shall include the more distant stations.

BYRON - UNIT 1 6-19

e 4,S ro///#

FINAL DW** T

=

ADMINISTRATIVE CONTROLS REPORTING REQUIREMENTS (Continued)

" Measuring, Evaluating, and Reporting Radioactivity in Solid Wastes and Releases of Radioactive Materials in Liquid and Gaseous Effluents from Light-Water-Cooled Nuclear Power Plants," Revision 1, June 1974, with data summarized on a quarterly basis following the format of Appendix B thereof.

For solid wastes, the format for Table 3 in Appendix B shall be supplemented with three additional categories: class of solid wastes (as defined by 10 CFR Part 61),

type of container (e.g., LSA, Type A, Type B, large Quantity), and SOLIDIFICA-TION agent or absorbent (e.g., cement, urea formaldehyde).

The Semiannual Radioactive Effluent Release Reports shall include a list and description of unplanned releases from the site to UNRESTRICTED AREAS of racioactive materials in gaseous and liquid effluents made during the reporting period.

The Semiannual Radioactive Effluent Release Reports shall include any changes made during the reporting period to the PCP _,. m m.s.., _., pursuant to Specifications 6.13 and 6.14 respectively, as well as any major changes tc w

Liquid, Gaseous or Solid Radwaste Treatment Systems, pursuant to Specifica-tion 6.15.

It M ' :!: A & d: : 'f: ting of c.s. ;ccati = : fr eco alcula-m 5 44t w a-

" m ; ec. n

......m....... a cr it r< ; + -t m e t tu : = : = ~ ~ < - =" %

/rMVAd D tc O x :f L.ti 7 2.12. 2. C pg fo-l*l The Semiannual Radioactive Effluent Release Reports shall also include the following:

an explanation as to why the inoperability of liquid or gaseous effluent monitoring instrumentation was not corrected within the time specified in Specifications 3.3.3.10 or 3.3.3.'.1, respectively; and description of the events leading to liquid holdup tanks or gas storage tanks exceeding the limits of Specification 3.11.1.4 or 3.11.2.6, respectively.

MONTHLY OPERATING REPORT 6.9.1.8 Routine reports of operating statistics and shutdown experience, including documentation of all challenges to the PORVs or RCS safety valves, shall be submitted on a monthly basis to the Director, Office of Resource Management, U.S. Nuclear Regulatory Commission, Washington, D.C.

20555, with a copy to the Regional Administrator of the NRC Regional Office, no later than the 15th of each month following the calendar month covered by the report.

RADIAL PEAKING FACTOR LIMIT REPORT 6.9.1.9 Changes to the F,y limits for Rated Thermal Power (F,TP) shall be R

provided to the NRC Regional Administrator with a copy to Director of Nuclear Reactor Regulation, Attention:

Chief, Core Performance Branch, U. S. Nuclear Regulatory Commission, Washington, D. C. 20555 for all core planes containing Bank "D" control rods and all unrodded core planes and the plot of predicted T

(F

.Pgg ) vs Axial Core Height with the limit envelope at least 60 days prior q

to cycle initial criticality unless otherwise approved by the Commission by letter.

In addition, in the event that the limit should cnange requiring a new BYRON - UNIT 1 6-21

_

ML20093H766

Text

SUBJECT:

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