Text

Initial Exam 2009-301 Final SRO Written Exam (as Given) with References and Answer Key
	ML092290946
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Site:	Summer
Issue date:	07/09/2009
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To:	;
References
	50-395/09-301
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FACILITY NAME: Summer Section 9 REPORT NUMBER: 05000395/2009301 FINAL SRO WRITTEN EXAM CONTENTS:

rgj Final SRO Written Exam (100 'as given' questions with changes made during administration annotated)

@iJ Reference Handouts Provided To Applicants IKI Answer Key Location of Electronic Files:

As given SRO Written:

Attached

References:

Attached Answer Key:

Attached Submitted By: _-----"'~=_-"--------="'==>o=_ __

Verified

Name: __________________________ __

2009 V.C. Summer SRO NRC Exam - As Given Fann:O Version: 0

1. Given the following plant conditions:

8% power CCW flow to the RCP Bearing Oil Coolers is lost.

The crew is addressing the appropriate Annunciator Response Procedures.

During the recovery, the following RCP parameters are observed EIGHT (8) minutes after the loss of flow:

Highest Motor Bearing Temperature Lower Seal Water Bearing Temperature Seal Water Outlet Temperature A

189°F 105°F 100°F B

194°F 105°F 104°F C

196°F 103°F 102°F Which ONE (1) of the following identifies the RCP(s) that have met their trip criteria AND the specific procedure(s) that are REQUIRED to be addressed in accordance with SOP-1 01, Reactor Coolant System?

A. ONLY RCP C; GOP-4B, Power Operation (Mode 1 Descending); and GOP-5, Reactor Shutdown from Startup to Hot Standby (Mode 2 to Mode 3).

B. ONLY RCPs Band C; GOP-4B, Power Operation (Mode 1 Descending); and GOP-5, Reactor Shutdown from Startup to Hot Standby (Mode 2 to Mode 3)

C. ONLY RCP C; EOP-1.0, Reactor Trip/Safety Injection Actuation D. ONLY RCPs Band C; EOP-1.0, Reactor Trip/Safety Injection Actuation Thursday. July 09, 2009 8:39:51 AM 1

2009 V.C. Summer SRO NRC Exam - As Given

2. Given the following plant conditions:

Following a Refueling Outage, the crew is performing a power ascension from 80% power.

Control rods began moving OUT at 72 SPM.

Control rods were placed in MAN, and rod motion is stopped.

Control bank '0' rods stepped out 14 steps.

Tavg is 580°F and continues to rise.

Which ONE (1) of the following statements identifies the FIRST condition that will occur and the action required by AOP-403.3, Continuous Control Rod Motion?

A. A reduction in the OTt,. T trip setpoint will occur, Adjust Control Rods to maintain Tavg within 5°F of Tref.

B. A reduction in the OTt,. T trip setpoint will occur, Adjust Control Rods to maintain Tavg within 1°F of Tref.

C. The Technical Specification 3.2.5 DNB Parameter for Tavg will be exceeded; Adjust Control Rods to maintain Tavg within 5°F of Tref.

D. The Technical Specification 3.2.5 DNB Parameter for Tavg will be exceeded; Ad'ust Control Rods to maintain Tavg within 1°F of Tref.

Thursday, July 09,20098:39:51 AM 2

2009 V.C. Summer SRO NRC Exam - As Given

3. Given the following plant conditions:

100% power AOP-600.1, Control Room Evacuation, has been entered.

Because of the immediate nature of the evacuation, NO operator actions were taken prior to leaving the Control Room.

The NROATC reports to the CRS that he is unable to trip the Reactor from the MG set room and is proceeding to the local switchgear.

The CRS has lined up both CREPs and is determining how long to Emergency Borate.

Reactor power is NOT decreasing.

Based on these conditions, Emergency Boration from the CREPs must continue until A. the Control Room can be re-entered B. RCPs have been run for GREATER THAN 15 minutes C. natural circulation has been established D. Either NI-32A or NI-33 indicates 1000 cps or less Thursday. July 09. 2009 8:39:51 AM 3

2009 V.C. Summer SRO NRC Exam - As Given

4. Given the following plant conditions:

A Waste Monitor Tank #2 release is in progress.

The following annunciators have actuated:

LlQ WST DISCH RM-L9 HI RAD (XCP-644, 2-5)

LlQ WST DISCH RM-L9 TRBL (XCP-644, 2-6)

Release flow rate remains at 55 gpm.

Which ONE (1) of the following completes the statement below?

The operator must close as required by ARP XCP-644. Failure to take this action may result in the dose commitment to an individual (general public) at the

.,---,,---_,....,-,-- from radioactive materials in liquid effluents to exceed the ODCM limit to the total body during any calendar quarter.

A. RCV-018, Liquid Waste Control Valve; Site Boundary B. RCV-018, Liquid Waste Control Valve; Low Population Zone Boundary C. PVD-6910, Liquid Effluents to Fairfield Penstocks; Site Boundary D. PVD-6910, Liquid Effluents to Fairfield Penstocks; Low Population Zone Boundary Thursday. July 09,20098:39:51 AM 4

2009 V.C. Summer SRO NRC Exam - As Given

5. Given the following plant conditions:

85% power.

Power Range channel N-41 is failed and has been removed from service.

One Control Bank 'C' rod bottom light energized and Control Bank '0' moved out 10 steps.

A Quadrant Power Tilt Ratio (QPTR) indicates a QPTR of 1.06.

Which ONE(1) of the following completes the statement below?

Reactor Engineering must confirm the QPTR using ______ within hours in accordance with Technical Specification 3.2.4.

A. BEACON ONLY; TWO (2)

B. BEACON ONLY; TWELVE (12)

C. BEACON or In-Core moveable detectors; TWO (2)

D. BEACON or In-Core moveable detectors; TWELVE (12)

Thursday, July 09.20098:39:51 AM 5

2009 V.C. Summer SRO NRC Exam - As Given

6. Given the following plant conditions:

o 100% power o Following a plant transient, a PZR Code Safety Valve lifts and remains stuck in the FULL OPEN position.

o An automatic Reactor Trip and Safety Injection occur.

o The crew has entered EOP-2.1, Post-LOGA Goo/down and Depressurization, and taken the proper actions.

o The crew has just verified that SG Narrow Range levels are >40%.

o The NROATC notes the following conditions:

oRCS subcooling is 20°F.

The PZR is water-solid.

o PZR pressure is 1000 psig.

lAW EOP-2.1, which ONE (1) of the following identifies what actions are required to be taken next AND the basis for this decision?

A. Initiate an RCS cooldown first Then start RCP 'A' to mix the reactor coolant to a uniform temperature.

B. Initiate an RCS cooldown first Then start RCP 'A' to ensure that PZR Spray is available for RCS pressure control.

C. Start RCP 'A' to mix the reactor coolant to a uniform temperature first.

Then initiate an RCS cool down D. Start RCP 'A' to ensure that PZR Spray is available for RCS pressure control first.

Then initiate an RCS cooldown

~----~~~

~~~~~~----------------

Thursday, July09, 2009 8:39:51 AM 6

2009 V.C. Summer SRO NRC Exam - As Given

7. Given the following plant conditions:

100% power RM-A4, Reactor Building Purge Exhaust Monitor, is Out-of-Service.

Which ONE (1) of the following identifies.illl of the Technical Specification and/or ODCM Specification of Controls which will prevent placing the Altemate Purge Exhaust System in operation?

REFERENCES PROVIDED A. LCO 3.3.2, ESFAS Instrumentation; AND LCO 3.3.3.1, Radiation Monitoring Instrumentation.

B. LCO 3.3.2, ESFAS Instrumentation; AND ODCM 1.2.1, Radioactive Gaseous Effluent Monitoring Instrumentation.

C. LCO 3.3.3.1, Radiation Monitoring Instrumentation; AND ODCM 1.2.1, Radioactive Gaseous Effluent Monitoring Instrumentation.

D. ODCM 1.2.1, Radioactive Gaseous Effluent Monitoring Instrumentation ONLY.

Thursday, July 09, 2009 8:39:51 AM 7

fJ INSTRUMENTATION 3/4.3.3 MONITORING I~STRUHENTATION RADIATION MONITORING INSTRUMENTATION LIMITING CONOITION FOR OPERATION 3.3.3. 1 Th~_.radiation monitoring instrumentation chanl1els shown in Table 3.3-6 shall-be"'6PERABlE with*their.alam/trip setpojnts within the specified limits.

APPLICABILITY:

As shown in Table 3.3-6.

ACTION:

a.

With a radiation monitoring channel alarm/trip setpoint exceeding the value shown in Table 3.3-6, adjust the setpoint to within the limit within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels inoperable, take the ACTION shown in Table 3.3-6.

C.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.1 Each radiation monitoring instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and ANALOG CHANNEL OPERATIONAL TEST operations for the MODES and at the frequencies shown in Table 4.3-3.

SUI+IER - UNIT 1 3/4 3-41

~~

~

TABLE ;I.~-§ RADIATIOH MONITORING INSTRUMENTATION c::

~

MINIMUM

0 INSTRUMENT CHANNELS APPLICABLE ALARH/TRIP

~~~iT OPERABLE MOOE~

SETPOIHI ACTIQ~

c::

1.

AREA MONITORS 1"

a. Spent Fuel Pool Area (RM-G8) 1 s 15 IIR/hr 10-l - 104 IIR/hr 25

b. Reactor Building Manipulator Crane Area (RM-GI7A or AM-GI7B) 1 6

s 1 R/hr 1 ~ 105 IIIR/hr 28 I

2.

PROCESS MONITORS

a. Spent Fuel Pool Exhaust -

Ventilation System (RN-A6)

V.J Six iO-5~CI/cC

1. Gaseous Activity 1

10 - 106 cplll 27 N

(Kr..aS

11. Particulate Activity 1

NIA 10 - 106 cpm 27

b. Containment

1. Gaseous Activity - purxe &

,i10', - 106cpm

§'

Exhaust Isolation (RM-4) 1 6

s 2 ~ background***

28 no "

11. Particulate and Gaseous

~

Activity (RM-A2) -

1 I, 2, 3 & 4 MIA 10 - 106cplll 26

=>....

ReS Leakage Detection 2:

0 10 - lo6cpm

c. 'Control Room Isolation (AM-AI) 1 ALL MOOES s 2 x background Z9

With fuel In the storage ~Ol or building ex>

- With Irradiated fuel In t stora~e pool

- - Alarm/trip setpolnt will be per t e Operational Dose Calculation Manual when purge exhaust operations are In progre~s.

~.

,~,

,~

V>

TABLE 3.3-6 (Continued) c: I

'j m

RADIATION MONITORING INSTRUMENTATION c:

MINIMUM M~ASUREMENT z

ClfAHNELS APPLICABLE ALARM/TRIP

-t INSTRUMENT

!!P~IWILE MODES SETPOINT

RANGE ACTION PROCESS MONITORS (Continued)

d.

Noble Gas Effluent Monltora (H1gh Range)

I. Haln Plant Vent 0.1 - 101 IIIR/hr (RM-AU) 1 I, 2, 3 & 4 N/A 30 iI. Hain Stealll line 6.1 - 107 mR/hr w

(RM-G19A, B, C l/StelllD 1, 2, 3 & 4 HlA 30 Una

.po w,

HI

Reactor Building Purge

.po w

Supply & Exhaust System (RM-A14).

1 1, 2, 3 & 4 HlA (1.1 - 107 mR/hr 30 i

1

(

[

NSTRUMENTATIOH TABLE 3.3-6 (Continued)

ACTION STAT9IENTS ACTIOI!"25 - With the nlllllber of channels OPERABLE leu than required by the M1".1_ Channels OPERABLE requireMnt, perfo~*a,... surveys of ttie*_Mtol'8d area. -wfth portable IIOnitor.ing lnstrumentation at 1 east once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 26 - W1th the nlllllber of channels OPERABLE 1e$$ than required by the M1ni_ CMnnels OPERABLE requ1re.nt, COlllPly with the ACTION requi~ of Sper;:i f'ieation-3-. 4*. 6,* 1.

ACTION 27 - With the IlUllber of channels OPERABLE less than required by the Minilllllll Ctlannels OPERABLE r.equireant, c:oGIply with the ACTION requirements of Specification 3.9.11.

ACTION 28 - ltith the nUliber of channels OPERABLE less than required by the Mini_ Channels OPERABLE requiY'ellellt, COIIPly with the ACTION requiNlDents of Specification 3.9.S.

ACTION 2.9 - With the ",_ber of channels OPERABLE less than required by the Mini.La Chlnnels OPERABLE requinMnt, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months initiate and Mintain opention of the control J'ODIII sergency ventilation systelt in the _rgancy lIDde of operati on.

ACTION 30 - With the nUlilber of OPERABLE cllannels less than NqUfred by the Minim... Channels OPERABLE requ1re.nt, either restore the inoperable Channel (s) to OPERABLE Status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or:

1}

Initiate the preplanned alte!'Mte _thad of.nitoring the appropriate paraeter($), and

2)

Prepare and subiJft II Special Report to the Ccamission pursuant to Specification 6.9.2 within 14 days following the event outl inin; the action taken, the calISe of the inoperabi1ity and the plans and schedula for restoring the system to OPERABLE status.

JlllER - UNIT 1 3/4 3-44

(

1.2 GASEOUS EFFLUENTS 1.2.1 Radioactive Gaseous Effluent Monitoring Instrumentation CONTROLS 1.2.1.1 The radioactive gaseous effluent monitoring instrumentation channels shown in Table 1.2.-1 shall be OPERABLE with their alann/trip setpoints set to ensure that the limits of ODCM Specification 1.2.2.1 are not exceeded. The alarmltrip setpoints of these channels shall be determined in accordance with ODCM Section 3.1.

APPLICABLE:

As shown in Table 1.2-1 ACTION:

a.

With a radioactive gaseous effluent monitoring instrumentation channel alarm/trip setpoint less conservative than required by the above ODCM Specification, immediately suspend the release of radioactive gaseous effluents monitored by the affected channel or declare the channel inoperable.

b.

With less than the minimum number of radioactive gaseous effluent monitoring instrumentation channels OPERABLE, take the ACTION shown in Table 1.2-1. Additionally if this condition prevails for more than 30 days, in the next Annual Radioactive Effluent Release Report, explain why this condition was not corrected in a timely manner.

c.

The provisions of Technical Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 1.2.1.2 Each radioactive gaseous effluent monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, SOURCE CHECK, CHANNEL CALIBRATION and an ANALOG CHANNEL OPERATIONAL TEST operations at the frequencies shown in Table 1.2-2.

ODCM, V. C. Summer, SCE&G: Revision 24 (May 2006) 1.0-17

Table 1.2-1

(

RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION MINIMUM CHANNELS APPLICA*

INSTRUMENT OPERABLE BILITY ACTION

1.

WASTE GAS HOLDUP SYSTEM

a.

Noble Gas Activity Monitor* Providing 1

7 Alann and Automatic Tennination of Release (RM*A 10 or RM*A3)

2.

MAIN PLANT VENT EXHAUST SYSTEM

a.

Noble Gas Activity Monitor* Providing 1

9 Alann and Automatic Tennination of Release from Waste Gas Holdup System (RM*A3)

b.

Iodine Sampler 1

11

c.

Particulate Sampler 1

11

d.

Flow Rate Measuring Device 1

8

e.

Sampler Flow Rate Measuring Device 1

8

/'-

3.

REACTOR BUILDING PURGE SYSTEM

(

Noble Gas Activity Monitor Providing 1

10

a.

Alann & Automatic Tennination of Release (RM*A4)

b.

Iodine Sampler 1

11

c.

Particulate Sampler 1

11

d.

Flow Rate Measuring Device

1. For 36" Purge (IFT09287) 1 8

2. For 6" Purge (IFT08252) 1 8

e.

Sampler Flow Rate Measuring Device 1

8 ODCM, V. C. Summer, SCE&G: Revision 24 (May 2006)

(

1.0-18

(

Table 1.2-1 (Continued)

TABLE NOTATION At all times during releases via this pathway.

ACTION 7 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, the contents of the tank(s) may be released to the environment for up to 14 days provided that prior to initiating the release:

a.

At least two independent samples of the tank's contents are analyzed.

b.

At least two technically qualified members of the Facility Staff independently verify the release rate calculations and discharge valve lineup.

Otherwise, suspend release of radioactive effluents via this pathway.

ACTION 8 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue for up to 30 days provided the flow rate is estimated at least once per4 hours.

ACTION 9 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue for up to 30 days provided grab samples are taken at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and these samples are analyzed for gross activity within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 10- With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, immediately suspend PURGING of radioactive effluents via this pathway.

ACTION 11 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via the affected pathway may continue for up to 30 days provided samples, as specified in Table 1.2-3, are continuously collected with auxiliary sampling equipment.

a.

With the monitor taken out of service, by a condition other than a planned action, the action statement is considered met if a conscious, concerted and continuous effort is being made to initiate the collection of the required sample(s) with auxiliary sampling equipment.

b.

A planned removal of the monitor from service requires that the auxiliary sampling eqUipment be staged in the area to reduce the amount of time for the change over from sampling by the installed monitor to the auxiliary sampling equipment.

ODCM, V. C. Summer, SCE&G: Revision 24 (May 2006) 1.0-19

(~

(

INSTRUMENTA nON 3143.2 ENGINEERED SAFETY EEATIJRE ACTUATION SYSTEM INSTRUMENTATION ClMmNG CONomON FOR OPERATION 3.3.2 The Engineered Safety Feature ActuaIion System {ESFASj Instrurnentatio cIlanneI!it:;w.t;I inIet10cks shown In Table 3.3-3 shell be OPERABLE wiIh llleir trip setpoints set cOlIsistentWiiJ'i tile valueS soow,nri the Trip Se1j:iOIntcolumA of Table 3.3-4 and with RESPONSE TIMES as shown in Table 3.3-5.

APPUCABILITY: As shaNn in Table 3.3.3.

ACTION:

a.

Wrth an ESFAS Instnmentation or IntGrtock Trip Setpoint trip less conservative than the value shown in the Trip Setpoint Column but more conservative than the value shown in the Allowable Value Column of Table 3.3-4, a~

the Setpoint conslst'ent with the Trip Se!point value.

b.

WIth an ESFAS Instrumentation or Intertock T~ SeIpaint less conservative than the value shown in the AJJowabIe Value Column of Table 3.3-4, declare the channel inoperable and apply the appDcabIe ACTION statement requlnlmBnts of Table 3.3-3 until the channel is restored to its OPERABLE stetus with Its selpcJnt adjusted COIlSistellt with the T~ Setpoint value.

c.

WIIh an ESFAS lnsInmenJation channel or interlock inoperable take the ACTION shown in Table 3.3-3.

SURVElUANCE REQUIREMENTS 4.3.2.1 Each ESFAS instrumentation channel and interlock and the automatic actuation lOgIc and relays shall be demon&IJated OPERABLE by perionnanc:e of the engineered safely feature actuation sys1am insIrumentelion survellance requitemenls speclied in Table 4.3-2.

4.3.2.2 The ENGINEERED SAFETY FEATIJRES RESPONSE TIME of NCh ESFAS function shall be verified to be within the limit at least once per 18 months. Each wriIicaIIon I

shalinclude at least one train such that both InIIns are verified at least once per 36 months and one channel per function such that an channels are vertlied at least once per N times 18 months where N Is the total number of redWldant channels In a specIIIc ESFAS function as shown in the "Total No. of Channels" Column of Table 3.3-3.

SUMMER - UNIT 1 3/43-15 Amendment No. ~

78" 1Q'i 1a9, 146

~~,

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I TABLE 3.3-3 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION c

MINIMUM

z TOTAL NO.

CHANNELS CHAIiHElS APPLICABLE "j

~ FUNCTIONAL UNIT Of CHANNELS TO TRIP OPERABLE MODES Blli9N

1.

SAFETY INJECTION,.R£ACTOfl TRIP, FEEDWATER ISOLATION, CONTROL ROOM ISOLATION, START DIESEL GENERATORS, CONTAINMENT COOLING FANS AND ESSEtlTIAl SERVICE WATER.

8.

Manual Initiation 2

1 2

I, 2, 3, 4 18

b.

Automatic Actuation 2

1 2

I, 2, 3, 4 14 lot Logic and Actuation

~

't' Relays In

c.

Reactor Building 3

2

2 1, 2, 3 24*

Pressure

High-l

d.

Pre$Surlzer 3

2 2

1, 2, 31 24*

Pressure

Low

a.

Oi fferent i a 1 3/stlall 11 ne 2/5tellll line

'2/stNm lina I, 2, 3 21*

Pressure Between twfce Ind 1/3 Stelm Lines - High stl!JII 111\\1'

,I

~

,.. Ii

r r+

z 0

0....

<~

.'~'

~

i TABlE~.~-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION "I

c MINIMWI "J.'

z TOTAL NO.

CHANNELS CHANNELS APP~.I CABLE

~ FUlfCTIOHAl UlfIT OF ClU\\NNElS TO TRIP OPERABLE MODES

~"

~

f.

Steam Line Pressure-Low 1 pressurel 1 pressure 1 pressure I, t2, -!'

24'"

loop and 2 loops and 2 loops

2.

REACTOR BUILDING SPRAY

a.

Manual 2 sets - 2 1 set 2 sets I, ~2, 3, 4 18 switches/set

b.

Automatic Actuation 2

1 2

1,:2, 3,4 14 u'

logic and Actuation

~

w Relays

~

c.

Reactor Building 4

2 3

1, 2. 3 16 Pressure--High-3 (Pha&e 'A' ilolation aligns 'prey

.y&tem discharge va 1 ve. and MaoH tank i

suction valves)

I

~.

!}..

rt

z 0

0....

~,

"~

~

TABLE 3.]-3 (Continued) m ENGINEERED SAfETY FEATURE ACTUATION SYSTEM INSTRUMENTATION

~

w 4>

w I

f

> 'I

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FUNCTIONAL IlIIlT

3.

CDNTAINItENT ISOLATION

a.

PhiSe "An holation

1)

Manual

2)

Safety InJectIon"

3)

Autolatlc ACtuatIon logic and ActuatIon Relays

b.

Phase "B" IsollUon

1)

Automatic Actuation logIc and ActuatIon Relays

2)

Reactor Building Pressure--HIgh-3

c.

Purge and Exhilus t isolation

1)

Sifety Injection 2}

Contltnsent Rildlo-acUvlty-HIgh

])

~.tlc ActuatIon logIc Ind Actuation Relays TOTAL NO.

OF CHANNElS CHANNELS TO TRIP "INIHUII CHANNELS OPERABLE APPLICABLE HODES

~ "

"1 ACTION 2 "

1 2

1 2, 3, 4 18 See 1 above for all safety Injection InitIating functions and requlre~nts.

2 i I, 2, 3, 4 14 1

2 2

I 2

I, 2, 3. 4 14 4

2 3

I, 2, 3 16 See 1 above for III sifety Ini.ctlon Initiating 'unctions and requlre.ents.

2"'

1" "

Zl 1, 2, 3~ 4!

17 2

1 2

L I, 2, 3, 4 11 z

o

"'Purge exhaust monitor not required when purge exhaust 15 closed.

w

~

en c

s::

m

n c z

=i

~

w,...

U)

§'

(II

J Q.

i a z

? ;

e l~

~

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION

'1 TOTAL NO, MINIMUM

(

OF CHANNELS CHANNELS AP~LlCABLE FUNCTIONAL UNIT QtlAN~EbS TO TRIP OEsBAeLE MQDES ACTION 4, STEAM LINE ISOLATION a, Manual

i.

One Switch/line l/steam line l/steam line l/operating

~,2, 3UN 23 steam line Ii, One Switch/all lines 1

1 1

1,2,3NII 23 b, Automatic Actuation Logic 2

1 2

1,2,3u,

21 and Actuation Relays

c. Reactor Building Pressure-3 2

2 1,2,3u, 24" High-2 d, Steam Flow In Two Steam 21steam line 1/steam line 1/steam Hoe

\\2,ani 24" Llnes-*High any 2 steam lines

./

COINCIDENT WITH T.,g-*Low-Low 1 T.,g/loop 1 T.vg any 1 Tavg any l,2,3,n 24" 2 loops 2 loops

~,

(f)

TABLE 3.3-3 (Conlinued\\

c s::

s::

ENGlNEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATJON m

JJ C

Z

-I'

~

w

~

w,

I\\)

0 3

(1)

J Q.

3 (1)

~

z o l

0'>

TOTAL NO.

OF FUNCTIONAL UNIT CHANNELS

e. Steam Line Pressure-Low 1 pressure/

loop

5. TURBINE TRIP & FEEDWATER ISOLATION a, Steam Generator Water Level--

3/loop High-High

b. Automatic Actuation Logic and 2

Actuation Relay MINIMUM CHANNELS CHANNELS APPLICABLE TO TRIP OPERABLE MODES 1 pressure 1 pressure 1, 2, 311#*#'"

any 2 loops any 2 loops 21loop in any 2Iloop in 1,2 operating each oper-loop ating loop 1

2 1,2

~

ACTION 24' 24' 25

r.

e

,~

TABLE 3.3-3 (Continued)

VI

~

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM "I

c TOTAL NO.

CHANNELS CHANNELS APPLICABLE z....

FUNCTIONAL UNIT OF, CHANNELS TO TRIP OPERABLE MODES ACTION

-I 6.

EMERGENCY FEEDWATER

a.

Manual Initiation 1 per pump 1 per pump 1 per pump I, 2, 3:

22

b.

Automatic Actuation Logie and Actuation Relays 2

1 2

1, 2, 3 21

c.

Stili. Gen. Water Leve 1-LoW'" Low

i. Start Motor-

~

Driven Pumps 3/stm. gen.

2/stm. gen.

2Istm. gen.

1, 2, 3 24*

any stm gen.

w Ii. Start Turblne-Driven Pump 3/stlll. gen.

2/stm. gen.

21stm. gen I, 2, 3 24~

any 2 stm. gen.

d.

undervo'ta~-both ESF Busses Start Turb ne-1, 2, 3 Driven Pump 2-l/bu5 2

2 19 S.1.

e. Start Motor-I f

Driven Pumps See 1 above (all 5.1. Initiating functions and reqbfr~ments) i

f. Undervoltage-one ESF bus Start Motor-Driven Pumps.

2-l/bus 1

2 I, 2 22

s....

z

g. Trip of Main 0.

Feedwater Pumps

~

Start Motor-Driven Pumps a-l/pump 3-l/purap 3-l/pull1p I, 2 19

h.

Suction Transfer on co Low Pressure 4

2 3

I, 2,,3 16

~

.~.

(f) c TABLE 3.3.=.3 _(Contin..lH'ldl

~

m ENGIt:l!i!iBED SAFETY FEAI!,!RE ACT!,!ATION SYSTEM INSTRUME~TAIION JJ c z

=i

~

TOTAL NO.

MINIMUM OF CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT QI:l8~NELS IQTAIP Q~EBABLE MODES 8QIION

7. LOSS OF POWER

a. 7.2 kv Emergency Bus Undervoltage (Loss of Voltage) 2-11bus 1

2 1,2,3,4 18

~

b. 7.2 kv Emergency Bus Undervoltage (Degraded Voltage) 2-11bus 1

2 1,2,3,4 18 Ci),

e. AUTOMATIC SWITCHOVER N

N TO CONTAINMENT SUMP

a. RWST level low-low 4

2 3

1,2,3 16 b.. Automatlo Actuation Logic and Actuation Relays 2

1 2

U~,3 21

9. ENGINEERED SAFETY FEATURE ACTUATION SYSTEM i

INTERLOCKS

§'

s. Pressurizer Pressure, P-ll 3

2 2

1,2,3 20 ro

J c.

b. Low-Low T.vg, P-12 3

2 2

1,2,3i1 20 r

3 (l)

t

c. Reactor Trip, P-4 2

2 2

1,2,3 22 z

9 :

~

e:

TSR 1029 REVJSIONO Page3/43-22a TECHNICALSPEQFICATION INFORMATION/RELOCATION FORM

'ibis information is provided as -REfERENCE ONL va.and 15 NOT part of the formal. NRC approved Teclmical Speciflcatlqns.

.-~ ~"-~..

I.

The Technical Specification was deleted by Amendment No *....:.;:NiLl/A::l.... __

TIS Number:

TItle:

Reference Ooc:ument to which requintments were relocated:

Document 10:

,:,Nt.::'A;:...... _________________ _

Trtle:

S~on: ____________________________ ___

II.

A Regulatory Interpretation or other reference document provides amplifying information relative to this Technical Specification.

TIS Number:

3/4.3.2 E5FAS Instrumentation

REFERENCES:

TSR 1028* inserted between pages 3/4 3-8 and 3/43*9 Approval:

Manager. NUdear Licensing & Operatlng Experience Issue Date:

03117/95

15R 1029 REVISION 0 Page 3/4 3*22b Document Affected:

V. C. SUMMER NUCLEAR STATION REGULATORY INTERPRETATION Technical Specification 3/4.3.2 - Engineered Safety

--._,....::F..::eatu=!!!r~es=A~ctu=at=ion~S<.Jyst~em~l~nstrui!.!;.~m~'!;;Il~~I!::on~ ____ _

INTERPRETATION:

The fo/lowino interpretation refers to 15 Table 3.3*3. action statement 14.

This interpretation is identical to that of TSR 1028 (instrted between TS oages 3/43-8 and 3/43*9) related to SSPS surveillance testing on both the Reactor Trip Breaker and the Automatic Actua1ion Logic and Actuation Relays.

BASIS: Non'

REFERENCES:

""N""o... n... e"'-___________________ _

Recommended Approval:

~....

Supervsor;tJt!aiensng I Operating EXperll!'nce Approval:

~~

Genera anager.uear Plant Operations Issue Date:_-,0,..3... 1...

17~/..:::9S=-__

,fit

(

TABLE 3.3-3 (Continued)

TABLE NOTATION Trip function may be blocked in this MODE below the P-11 (Pressurizer Pressure Interlock) setpoint.

1. Trip function may be blocked in this MODE below the P-12 (Low-Low Ta"" Interlock) setpoint.

1#1#

Except when below P-12 with all MSIVs and bypasses closed and disabled.

The provisions of SpeCification 3.0.4 are not applicable.

ACTION STATEMENTS ACTION 14 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 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 ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

ACTION 15 -

DELETED ACTION 16 -

With the number of OPERABLE channels one less than the Total Number of Channels, operation may continue provided the inoperable channel is placed in bypass and the Minimum Channels OPERABLE requirement is met. Restore the inoperable channel to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months otherwise; 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 .

One additional channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing per Specification 4.3.2.1.

ACTION 17 -

With less than the Minimum Channels OPERABLE requirement, operation may continue provided the containment purge supply and exhaust valves are maintained closed.

ACTION 18 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-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 .

ACTION 19 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of other channels per Specification 4.3.2.1.

SUMMER - UNIT 1 3/43-23 Amendment No. 1(l1, Hie, 1e7, 177

(

TABLE 3.3-3 (Continued)

ACTION STATEMENTS (Continued)

ACTION 20 -

With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window(s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

ACTION 21 -

With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 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 at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per SpeCification 4.3.2.1 provided the other channel is OPERABLE.

ACTION 22 -

With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or 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 at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 23 -

With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

ACTION 24 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels per Specification 4.3.2.1.

ACTION 25 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable Channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 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 ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

SUMMER - UNIT 1 3/43-24 Amendment No. 1Q1, 197, 177

2009 V.C. Summer SRO NRC Exam - As Given

8. Given the following plant conditions:

Mode 1 B2 Maintenance Week is in progress Annunciator CCW SRG TK L VL HI/LO/LO-LO (XCP-601, 1-1) has just actuated.

The NROATC has determined that it is a LOW level.

CCW Surge Tank 'A' level is decreasing slowly.

Given the following equipment nomenclature:

LCV-7088, MU TO SRG TK (B SIDE)

LCV-7090, MU TO SRG TK (A SIDE)

PVG-9627 A, SW TO CC LOOP A Based on the existing conditions, which ONE (1) of the following describes the response of the CCW System makeup valves and the actions that must be taken in accordance with XCP-601, 1-1?

A. ONLY LCV-7088 and LCV-7090 are open; Swap the running charging pump per SOP-102 and apply actions for T.S. 3.1.2.2, Flow Paths - Operating B. ONLY LCV-7088 and LCV-7090 are open; Swap CCW active loops per SOP-118 and apply actions for T.S. 3.7.3, Component Cooling Water System C. LCV-7088, LCV-7090, and PVG-9627A are all open; Swap the running charging pump per SOP-102 and apply actions for T.S. 3.1.2.2, Flow Paths - Operating D. LCV-7088, LCV-7090, and PVG-9627A are all open; Swap CCW active loops per SOP-118 and apply actions forT.S. 3.7.3, Component L-____ ~C~o=ol~ing~at_e_r_Sy~st=e~m~ ________________________________________ ~

Thursday, July 09.20098:39:51 AM 8

2009 V.C. Summer SRO NRC Exam - As Given

9. Which ONE (1) of the choices below completes the following statement?

To ensure that a fuel assembly has not been mispositioned during core reload, REP-1 07.013, Core Reload, requires the Refueling SROs to check that the fuel assembly reference hole in the top nozzle is oriented toward the and the Refueling SROs are required to sign the permanent copy of the Material Transfer Form _____ _

A. Northeast after each fuel assembly movement B. Northeast prior to the end of their shift C. East-Southeast after each fuel assembly movement D. East-Southeast prior to the end of their shift Thursday. July 09,20098:39:51 AM 9

2009 V.C. Summer SRO NRC Exam - As Given

10. Given the following plant conditions:

100% power The crew has implemented AOP-112.2, Steam Generator Tube Leak NOT Requiring SI.

A plant shutdown has been initiated.

Due to the S/G tube leak, a Reactor Trip is initiated.

The crew has transitioned to EOP-1.1, Reactor Trip Recovery, checked Feedwater status, and checked RCS Tavg trending to SSrF (Step 3).

Which ONE (1) of the following describes the procedure flowpath?

A. Remain in EOP-1.1, complete the EOP, then GO TO AOP-112.2.

B. GO TO AOP-112.2, complete the AOP, then GO TO EOP-1.1, Step 4.

C. Remain in EOP-1.1 and REFER TO AOP-112.2 and perform actions of AOP-112.2 as time allows.

D. GO TO AOP-112.2 and REFER TO EOP-1.1 and perform actions of EOP-1.1 as time allows.

Thursday. July 09. 2009 8:39:51 AM 10

2009 V.C. Summer SRO NRC Exam - As Given

11. Given the following plant conditions:

100% power A loss of ALL Main Feedwater occurs.

A manual Reactor Trip was initiated and the crew is implementing EOP-1.1, Reactor Trip Recovery.

MDEFP 'A' and 'B' fail during the recovery.

Instrument Air Compressor (lAC) 'A' trips and lAC 'B' cannot be started.

The Supplemental Air Compressor is aligned for nonmal operations.

NR Level in all SGs is 67% and rising.

The CRS directs SG levels to be controlled between 60% and 65%.

Given the current conditions, which ONE (1) of the following identifies how the level in all SGs will be controlled AND the proper procedure to be used?

A. MCB throttling of TDEFP FCVs; EOP-15.2, Response to Steam Generator High Level.

B. MCB throttling of TDEFP FCVs; EOP-1.1, Reactor Trip Recovery.

C. Local throttling of TDEFP FCVs; EOP-15.2, Response to Steam Generator High Level.

D. Local throttling of TDEFP FCVs; EOP-1.1, Reactor Trip Recovery.

Thursday, July 09, 2009 8:39:51 AM 11

2009 V.C. Summer SRO NRC Exam - As Given

12. Given the following plant conditions:

100% power During a routine surveillance, it is revealed that Train 'B' of SSPS will NOT automatically actuate RB Spray.

Train 'B' of ESFAS Instrumentation, Functional Unit (Item) 2.b, Reactor Building Spray - Automatic Actuation Logic and Associated Relays, is declared INOPERABLE.

LCO 3.3.2, ACTION 14, is entered, placing the plant in a shutdown LCO.

Which ONE (1) of the following planned activities must be rescheduled until the operability of SSPS Train 'B' has been restored?

A. Swap Charging Pump 'c' to Charging Pump 'B'.

B. Swap Service Water Pump 'A' to Service Water Pump 'C'.

C. Perform the quarterly surveillance on Residual Heat Removal Pump 'B'.

D. Replace the breaker for MVG-8801 B, HI HEAD TO COLD LEG INJ.

Thursday. July 09.20098:39:51 AM 12

2009 V.C. Summer SRO NRC Exam - As Given

13. Given the following plant conditions:

100% power A sustained total loss of offsite power has occurred.

Both ESF Diesel Generators have failed to start automatically and manually.

The crew has implemented EOP-6.0, Loss of All ESF AC Power.

ESF equipment has been placed in PULL-TO-LOCK.

Continued attempts to start the DGs have been unsuccessful.

Subsequently, at Step 11 of EOP-6.0, the crew successfully energizes Bus 1 DA via XTF-5052, ALTERNATE AC POWER SUPPLY TRANSFORMER.

Which ONE (1) of the following identifies the breaker that, when closed, will restore power to bus 1 DA, AND identifies the action required in accordance with EOP-6.0, when the Bus is restored?

A. The 1 DA NORM Feed Breaker; GO TO Step 30 and stabilize SG pressure.

B. The 1 DA AL T Feed Breaker; GO TO Step 30 and stabilize SG pressure.

C. The 1 DA NORM Feed Breaker; GO TO EOP-1.0, Reactor Trip/Safety Injection Actuation, Step 1.

D. The 1 DA AL T Feed Breaker; GO TO EOP-1.0, Reactor Trip/Safety Injection Actuation, Step 1.

Thursday, July 09, 2009 8:39:51 AM 13

2009 V.C. Summer SRO NRC Exam - As Given

14. Given the following plant conditions:

100% power A routine surveillance of Diesel Generator 'A' is in progress.

Diesel Generator 'A' is operating in parallel with offsite power.

Service Water Pump 'C' is aligned to Train 'A' but not running.

Subsequently, the feeder breaker for Bus 1 EA trips OPEN.

The following DG 'A' conditions are observed:

The DG 'A' lube oil temperature is 160"F and rising at 1.0"F/minute.

The DG 'A' coolant temperature is 178"F and rising at 1.5"F/minute.

Which ONE (1) of the following identifies the approximate time frame, within which, Diesel Generator 'A' will trip if NO action is taken, AND the actions that are required be taken within AOP-117.1, Loss of Service Water?

A. 4-8 minutes; Transfer Service Water System loads to Train 'B' in accordance with ARP-001, XCP-604.

B. 4-8 minutes; Start SWP 'C' and open PVG-3105A, FS TO DG A, in accordance with SOP-117.

C. 10-12 minutes; Transfer Service Water System loads to Train 'B' in accordance with ARP-001, XCP-604.

D. 10-12 minutes; Start SWP 'C' and open PVG-3105A, FS TO DG A, in accordance with SOP-117.

Thursday. July 09, 2009 8:39:51 AM 14

2009 V.C. Summer SRO NRC Exam - As Given

15. Given the following plant conditions:

o A Reactor Trip occurs due to a locked rotor on RCP 'B'.

o The crew has just transitioned to EOP-1.1, Reactor Trip Recovery.

o Annunciators RC L TON HI RNG RM-L 1 HI RAD (XCP-642, 1-5) and RC L TON LO RNG RM-L 1 HI RAD (XCP-642, 4-3) both actuate.

o A Chemistry sample indicates that Dose Equivalent 1-131 activity is 1.0 microcuriesfgm.

Assuming RCS activity remains at this level for another 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , which ONE (1) of the following identifies the ARP and Technical Specification actions that must be taken?

A. Increase letdown to 120 gpm lAW the ARP and be in COLD SHUTDOWN within an additional 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

B. Increase letdown to 120 gpm lAW the ARP and reduce Tavg to less than 500°F within an additional 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

C. Isolate letdown lAW the ARP and reduce Tavg to less than 500°F within an additional 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

D. Isolate letdown lAW the ARP and be in COLD SHUTDOWN within an additional 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

Thursday, July 09,20098:39:51 AM 15

2009 V.C. Summer SRO NRC Exam - As Given

16. Given the following plant conditions:

100% power Instrument Air Compressor XAC-3B is in operation.

Instrument Air Compressor XAC-3A is in standby.

The Supplemental Breathing Air Compressor XAC-12 is aligned to provide Breathing Air to support on-going maintenance activities in the Aux Building.

The Instrument Air Dryer fails, causing desiccant to clog the after filters.

Instrument Air header pressure decreases rapidly to 35 psig.

The crew has just entered AOP-220.1, Loss of Instrument Air.

Which ONE (1) of the following describes the action(s) that must be taken to restore Instrument Air header pressure AND what is the consequence of I.A. header pressure dropping below 40 psig prior to manually tripping the reactor?

A. Suspend maintenance activities, open XVB-2633, IA BACKUP SYSTEM SUP HDR ISOLATION VLV, and ensure the Supplemental Breathing Air Compressor is running; Reactor power will increase.

B. Suspend maintenance activities, open XVB-2633, and ensure the Supplemental Breathing Air Compressor is running; Turbine blade erosion will increase.

C. Locally start the Diesel Driven Air Compressor; Turbine blade erosion will increase.

D. Locally start the Diesel Driven Air Compressor; Reactor power will increase.

Thursday. July 09. 2009 8:39:51 AM 16

2009 V.C. Summer SRO NRC Exam - As Given

17. When implementing EOP-16.0, Response to Imminent Pressurized Thermal Shock, which ONE (1) of the following identifies the required soak time and the bases for the soak?

A. ONE (1) hour; prevent flaw growth in the Reactor Vessel wall B. ONE (1) hour; relieve compressive stress on the inner wall of the Reactor Vessel C. EIGHT (8) hours; prevent flaw growth in the Reactor Vessel wall D. EIGHT (8) hours; relieve compressive stress on the inner wall of the Reactor Vessel Thursday. July 09.20098:39:51 AM 17

2009 V.C. Summer SRO NRC Exam - As Given

18. Given the following plant conditions:

100% power A QA Audit has determined that an ECCS valve lineup was not properly documented and may be incorrect.

A Reactor Building entry has been approved to verify the position of the valves in question.

Which ONE (1) of the choices below completes the following statements?

The team will normally enter the Reactor Building through the Airlock. At the completion of this entry, per OAP-1 08.1, Control of Reactor Building Entry, the operating crew must generate an R&R to ensure that is conducted.

A. ESCAPE; STP-1 09.001, Reactor Building Closeout Inspection, B. ESCAPE; STP-215.001 B, Reactor Building Personnel Escape Airlock Test, C. PERSONNEL; STP-1 09.001, Reactor Building Closeout Inspection, D. PERSONNEL; STP-215.001A, Reactor Building Personnel Airlock Test, Thursday. July 09,20098:39:51 AM 18

2009 V.C. Summer SRO NRC Exam - As Given

19. Given the following plant conditions:

A Reactor Trip and SI have occurred due to a LOCA.

The crew has implemented EOP-2.0, Loss of Reactor or Secondary Coolant.

Which ONE (1) of the choices below completes the following statement?

Control Room Emergency Ventilation must be reduced to one train in operation within

_____ to limit the dose to Control Room personnel to a maximum of

_____ whole body?

A. TWO (2) hours; 5.0 rem B. TWO (2) hours; 1.0 rem C. THIRTY (30) minutes; 5.0 rem D. THIRTY (30) minutes 1.0 rem Thursday, July 09,20098:39:51 AM 19

2009 V.C. Summer SRO NRC Exam - As Given

20. Given the following plant conditions:

Component Cooling Water is in a nonnal alignment with the following exception:

(CCW) Pump 'C' is not available.

CCW Loop 'A' is the Active Loop.

A large break LOCA has occurred.

The operating crew is perfonning EOP-2.0, Loss of Reactor or Secondary Coolant, Step 16 - Verify equipment is available for Cold Leg Recirculation.

Which ONE (1) of the following is the REQUIRED action with respect to shifting CCW to FAST speed?

A. Shift CCW Pump 'A' to FAST and continue in EOP-2.0.

S. Leave CCW Pump 'A' in SLOW and continue in EOP-2.0.

C. Shift CCW Pump'S' to FAST speed, swap active loops per SOP-118, Component Cooling Water System, THEN continue in EOP-2.0.

D. Reduce CCW loads per EOP-2.2, Transfer to Cold Leg Recirculation, THEN continue in EOP-2.0.

Thursday, July 09,20098:39:51 AM 20

2009 V.C. Summer SRO NRC Exam - As Given

21. Which ONE (1) of the following would REQUIRE a declaration of a Site Area Emergency per EPP-001, Activation and Implementation of the Emergency Plan?

The event has been in progress for TWENTY (20) minutes.

A. loss of ONLY the following:

1) AC power capability to 7.2 KV ESF buses iDA and 1 DB reduced to a single power source

2) < 108 VDC on both Train A and Train B vital 125VDC systems B. loss of ONLY the following:

1) 115 KV power to XTF-4 and XTF-5

2) 230 KV power to XTF-31

3) Parr Hydro Plant 13.8 KV power to ESF Bus iDA or 1 DB C. ALL of the following:

1) AC power capability to 7.2 KV ESF buses iDA and 1 DB reduced to a single power source

2) Any additional single power source failure will result in loss of all AC power to both 7.2 KV ESF buses.

D. loss of ALL of the following:

1) 115 KV power to XTF-4 and XTF-5

2) 230 KV power to XTF-31

3) Parr Hydro Plant 13.8 KV power to ESF Bus iDA or 1 DB

4) Diesel Generator A 5 Diesel Generator B Thursday. July 09, 2009 8:39:51 AM 21

2009 V.C. Summer SRO NRC Exam - As Given

22. Given the following plant conditions:

A Reactor Trip and SI have occured.

The crew has entered EOP-1.0, Reactor Trip/Safety Injection Actuation, and has reached the diagnostic steps (Steps 12-14).

RCS pressure is 1700 psig and DECREASING slowly.

RB conditions are as follows:

RM-G7 and RM-G18, CNTMT HI RNG GAMMA, are NORMAL.

RB Sump levels are NORMAL.

RB pressure is 0.8 psig and STABLE.

Annunciators XCP-606 (607) 2-2, RBCU 1A!2A (1 B/2B) DRN FLO HI, are NOT lit.

ALL SG pressures and levels are stable.

Auxiliary Building Area Radiation Monitors are in alarm, including the following:

AB VENT DUCTS RM-A11 HI RAD (XCP-645, 2-1)

PLANT VENT GAS RM-A3 TRBL (XCP-644, 3-4)

NO other abnormal radiation monitoring indications exist.

Which ONE (1) of the following describes the appropriate procedure flowpath?

A. Continue in EOP-1.0, Reactor Trip/Safety Injection Actuation; Transition to EOP-2.4, Loss of Emergency Coolant Recirculation.

B. Continue in EOP-1.0, Reactor Trip/Safety Injection Actuation; Transition to EOP-2.5, LOCA Outside Containment.

C. Go to to EOP-2.0, Loss of Reactor or Secondary Coolant; Transition to EOP-2.5, LOCA Outside Containment.

D. Go to EOP-2.0, Loss of Reactor or Secondary Coolant; Transition to EOP-2.4, Loss of Emerg!Jnc}' Coolant Recirculatio:.:.n'-.. ______

Thursday, July 09,20098:39:51 AM 22

2009 V.C. Summer SRO NRC Exam - As Given

23. Which ONE (1) of the following describes the basis for OPERABILITY limits on accumulator volume and boron to ensure that assumptions used for accumulator injection in the safety analysis are met?

ONLY accumulator(s) is(are) required to provide the initial core cooling for a postulated Loss of Coolant Accident and limit the maximum power that may be reached during __ _

A. ONE large secondary pipe ruptures B. TWO an over feeding event as a result of a feedwater malfunction C. ONE an over feeding event as a result of a feedwater malfunction D. TWO large secondary pipe ruptures Thursday. July09, 2009 8:39:51 AM 23

2009 V.C. Summer SRO NRC Exam - As Given

24. Which ONE (1) of the choices below completes the following statement?

In accordance with GOP-2, Plant Startup and Heatup (Mode 5 to Mode 3), Dissolved Oxygen must be within limits prior to exceeding __

The basis for this limit, per Technical Specification 3.4.7, is to prevent ___ _

corrosion.

A. 200°F; stress B. 200°F; crevice C. 350°F; stress D. 350°F; crevice Thursday, July 09,20098:39:51 AM 24

2009 V.C. Summer SRO NRC Exam - As Given

25. Given the following plant conditions:

The unit was at 100% power when a high pressure feedwater heater bypass valve failure caused Reactor power to peak at 2910 MWt on U9002.

The failed valve has been closed and Reactor power is at 100%.

Which ONE (1) of the choices below completes the following statement regarding follow-up actions for these conditions?

In accordance with OAP-100.6, the Reactor power limit of 100% is based on __ _

Notify the NRC within __ _

REFERENCE PROVIDED A. a five-minute rolling average power; 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

B. a five-minute rolling average power; 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

C. an integrated shift average power; 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

D. an integrated shift average power; 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

You have completed the testl Thursday. July 09,20098:39:52 AM 25

NL-122 ENCLOSURE A PAGE 1 OF 35 REVISION 4 MASTER LIST OF REPORTING REQUIREMENTS This Attachment consists of a Master List of Reporting Requirements, which is cataloged by the urgency of the reporting response time as follows:

F E

P S

T NP 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months telephone notifications are required.

4-hour telephone notifications are required.

a-hour telephone notifications are required.

24-hour telephone notifications are required.

72-hour telephone notifications are required.

Written reports. Written reports addressed in Sections I, E, F, and P are not repeated in this section.

Non-periodic reports of a less urgent nature.

Oil Spill. Refer to SAP-0203 and Best Management Practices Plan.

Hazardous Waste Spill. Refer to Best Management Practices Plan and EPP-014.

Key words/phrases in the REPORT/SUBJECT column have been highlighted BOLD to provide rapid identification of the condition or event requirements within the MLRR.

NRC CONTACT NOTE:

If the Emergency Notification System is inoperable, the licensee shall make the required notifications via commercial telephone service, other dedicated telephone system, or any other method which will ensure that a report is made as soon as practical to the NRC Operations Center.

Commercial telephone numbers of the NRC Operations Center:

(301) 816-5100 Primary (301) 951-0550 Backup (301) 816-5151 Fax

MASTER LIST OF REPORTING REQUIREMENTS ID # I REFERENCE REPORT I SUBJECT CONTENT REPORT TIME I METHOD 1-1 Declaration of any of the Emergency Emergency Classes are NUE, Alert, Site Telephone notification:

C...... specifted in the Emergency Plan.

Area Emergency, and General NUE:

1 OCFR50. 72(a)(l )(i)

Emergency.

Within 15 minutes If It Is detennlned that an event or Alert, Site Area Emergency, &

NUREG 0654 condition had existed, which met the NOTE: Refer to the Radiation G.neral Emergency:

emergency plan criteria, but that no Emergency Plan, EP-100, Table 6-2 for Wrthin 15 minutes & updates emergency had been declared and the an other required notlflcatlons.

hourty & as conditions ba.l. for the emergency class no

change, longer exists at the time of discovery, NOTE: Activate the Emergency the NRC does not con.lder actual Response Data System (EROS) as soon As soon as pOSSible, not greater declaration of the emergency cl... to as possible but not later than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

be necessary in these circumstances.

An ENS notlflcatlon (or an ENS update if the event was previously reported but As soon as possible.

mis-classified) wllhln 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of the discovery of the undeclared Written Summary required:

(or mis-cla ** ifled).vent will provide NUE Close out within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

an acceptable allemative.

Alert, SAE, & GE Close out or Reduction within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

1-2 Non... mergency events spacifed in This notification captures those evenls As soon as possible, not greater paragraph (b) of this section that that were not previously identified as than 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

1 OCFR50. 72(a)(l )(ii) occurred wllhln three y.ars of the date requiring a 1, 4, or 8-hour notification of discovery.

under 10CFR50.72 paragraph (b). An LER will probably be required par the applicable section of 10CFR50.73.

Note: This reporting criteria captures missed reports during a roiling three year window that should have been reported by telephone within 1, 4, or 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months of the event occurrence.

1-3 Any deviation from Technical Initial notification follows implementation Telephone notification within 1 Sp.clflcatlon. authorized pursuant to of actions needed to protect the public hour of occurrence.

10CFR50.72(b)(1 )

10CFR50.54(X).

heaHh and safety and that departs from a license condition or TS.

1 OCFR50.73(a)(2)(i)(C)

LER within 60 days.

NL-122 ENCLOSURE A PAGE20F35 REVISION 4 RECIPIENT SCEPD & Counties (ESSX)

NRC - ENS or Operations Ctr.

(301) 816-5100, ANI- (860) 682-1301 DHEC, SCEPD, Counties, & ANI NRC - ENS or Operations Ctr.

(301) 816-5100, SCEPD & Counties (ESSX)

NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD I

MASTER LIST OF REPORTING REQUIREMENTS 10 III REFERENCE REPORT I SUBJECT CONTENT REPORT TIME I METHOD 1-4 Exceeding any Technical Speclflcation Critical operation of the plant shall not be Telephone notification within 1 Safety Umlt.

resumed until authorized by the NRC.

hour.

Tech. Spec. 6.7.1

'Written report to be reviewed by VPNPO, PSRC, and NSRC.

Safety Lim" Violation Report to be submitted within 14 days.

1-5 Any event where the following exposurea Telephone notification within 1 occurred:

hour of event.

10CFR20.2202(a)

1. Exposure of the whole body of ~ 25 10CFR20.2203(a)(1 )

rems of radiation, eye equivalent dose LER within 30 days.

of ~ 75 rems, shallow dose to skin or (A copy of the LER submitted to extremities of an individual of ~ 250 the NRC reporting personal rads; or, exposure shall be provided to eech individual involved per the

2. Release of radioactive material, Inside requirements of 10CFR20.2205) or outside of a restricted area, so that.

had an individual been present for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , the individual could have received an intake 5 times the annual lim" on intake.

1-<5 Theft or Unlawful diversion of special Reportable Safeguard Evenl Telephone notification within one nuclear material.

Security Team Leader to substantiate hour.

10CFR73.71 (b)(1) event, Initiate response and address reportability with Operations Shift App. G l(a)(1)

Supervisor in accordance with LER within 60 days SPP-118. Sacfton 5.3.3 A.

Any event in which there is reason to believe that a person has committed or caused, or attempted to commit or cause, or has made a credible threat to commit or cause.

NL-122 ENCLOSURE A PAGE 3 OF 35 REVISION 4 RECIPIENT NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD o

MASTER LIST OF REPORTING REQUIREMENTS 10 III REFERENCE REPORT I SUBJECT CONTENT REPORT TIME I METHOD 1-7 Radioactive malarial package received Reference 10CFR71.B7(i).

Immediately notify:

with removable betallamma emitting

1. Final delivery carrier, and 10CFR20.1906(d)(1 )

radionucllde contamination on extemal surfaces in excess of 0.01 jlCilcm' (2,200 DPM/100cm'). 220 DPMl100cm' for all

2. NRC Region II by telephone other alpha emitters.

and telegram, mailgram, or facsimile.

1-8 Radioactive material package received Reference 10CFR71.47.

Immediately notify:

with radiation at the external surface in

1. Final delivery carrier, and 1 OCFR20.1906(d)(2) excess of 200 mRemlhr, or at 2 meters from external surface in excess of 10

2. NRC Region II by telephone mRemlhr.

and telegram, mailgram, or facsimile.

1-9 Significant physical damage to a power Security Team Leader to substantiate Telephone notification within 1 reactor or any facility possessing Special event, Initiate response and address hour of discovery.

10CFR73.71 Nuclear Material (SNM) or its equipment reporlabijity with Operations Shift or carrier eqUipment transporting nuclear Supervisor in accordance with Appendix G l(a)(2) fuel or spent nuclear fuel, or to the SPP-118, Section 5.3.3 A.

LER within 60 days.

nuclear fuel or spent nuclear fuel a facility or carrier possesses.

These Incidents shall also be reported if an afiempt or credible threat to commit or cause these events has been made.

Fitness for Duty events shall be reported under 10CFR26.73 (Sec. P-8).

1-10 Interruption of nonnal operation of a Security Team Leader to SUbstantiate Telephone notification within 1 licensed nuclear power reactor through event, initiate response and address hour of discovery.

10CFR73.71 the unauthorized use of or tampering reportability with Operations Shift with its machinery, components, or Supervisor in accordance with Appendix G l(a)(3) controls including the security system.

SPP-118, Section 5.3.3 A.

LER within 60 days.

These incidents shall also be reported if an attempt or credible threat to commit or cause these events has been made.

NL-122 ENCLOSURE A PAGE 4 OF 35 REVISION 4 RECIPIENT Reference receipt paperwork.

NRC - Region II

1. Reference receipt paperwork

2. NRC - Region II NRC -ENS or Operations Ctr.

(301) 816-5100 NRC-DCD NRC-ENS or OperafiCns Ctr.

(301) 816-5100 NRC-DCD I B o

o

MASTER LIST OF REPORTING REQUIREMENTS 10 # / REFERENCE REPORT/SUBJECT CONTENT REPORT TIME / METHOD 1-11 An actual entry of an unauthorized Security Team Leader to substantiate Telephone notification within 1 penlon Into a protected area, material event, in~late response and address hour of discovery.

10CFR73.71 access area, controlled access area, vital reportability with Operations Shift area, or transport.

Supervisor In accordance with Appendix G I(b)

SPP-118, Section 5.3.3 A.

LER within 60 days.

1-12 Any failure, degradation, or the Security Team Leader to substantiate Telephone notification within 1 discovered vulnerability in a safeguand event, initiate response and address hour of discovery.

10CFR73.71 sYltem that could allow unauthorized or reportability wi1h Operations Shift undetected access to a protected area, Supervisor in accordance wi1h Appendix G I(c) material access ares, control access SPP-118, Section 5.3.3 A.

LER within 60 days.

area, vital area, or transport for which compensatory measures have not been employed.

1-13 The actual or attempted Introduction of Security Team Leader to substantiate Telephone notification within 1 contraband into a protected area, event, in~late response and address hour of discovery.

10CFR73.71 material access area, vital area, or reportabllity with Operations Shift Appendix G I(d) transport.

Supervisor in accordance with SPP-118, Section 5.3.3 A.

LER within 60 days.

NUREG-1304 Contraband includes fireanms, explosives, or incendiary devices.

1-14 Any environmental release (I.e., air, Chemistry SuperviSion should be Telephone notification to be ground, stonm drain, lake) of a hazandous contacted to assess event and In~iate made Immediately on 40CFR302.4 subltance that exceeds the Reportable response and telephone notifications per identification.

Quantities In a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period.

guidance In EPP-<l14, NPDES Penm~

40CFR355 SC0030856 and Best Management 4OCFR117.3 Practices plan.

NPDES Penmlt No.

SC0030856 NRC notification is addressed under section F-3.

Written report wi1hin 5 days.

NL-122 ENCLOSURE A PAGE 5 OF35 REVISION 4 RECIPIENT NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD NRC-ENS or Operations Ctr.

(301) 816-5100 NRC - DCD NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD EPA National Response Ctr.

(800) 424-8802 DHEC 896-0620 Day hours 253-0488 After hours Local Planning Committee (Mike Kirkland) 6354444 DHEC o

o o

o I

I J

10 # 1 REFERENCE 1-15 10CFR70.52(a) 1-16 10CFR75.44(c) 1-17 10CFR110.50(a)(7) 10CFR71.95 1-18 Westinghouse Position on Core Tilt (1/15/92) 1-19 FSAR Section 2.5.2.6.4 1-20 DHEC Regulation R.61-58.8(C)(1 )

MASTER LIST OF REPORTING REQUIREMENTS REPORT 1 SUBJECT CONTENT REPORT TIME 1 METHOD Accidental Critlcellty Telephone notification within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months of discovery.

Delay In receipt or shipment of nuclear New dates end times should be Telephone notification as soon material for which advance notification is provided.

as possible (not necessarily 1 required.

hour)

Packaging of nuclear materials for Notify the NRC promptly if the packaging Telephone notification as soon export or import.

requirements of Part 71 have not been as possible.

met. This reporting criteria includes any instance in which there is significant reduction in the effectiveness of any Wrltien report within 30 days.

authorized packaging during or after use.

Beginning of cycle Incore tilts of 2%-

Westinghouse believes that for measured Telephone notification in a ~

4% and> 4%. Core designer to be low power incore tilts > 4% power manner:

notified for safety analysis Input and core escalation is acceptable to the lower of modeling review along with impact 75% RTP or the maximum power

1) Incore tilt> 2%

evaluation.

permitted by Technical Specification limits. These notifications are

2) Incore tilt> 4%

recommended but not required.

Reservoir Induced seismicity that is Notification to provide the location, depth Telephone notification as soon unusual:

and magn~ude of any unusual activ~.

as possible after event.

1. Earthquake larger than magnitude 2.5.

2. > 100 seismic events/\\Wek.

3. Any plans to change water level to

< 415' or> 430' Drinking water distribution system Chemistry Supervision to make Telephone notification as soon pressure drop to,; 10 psi.

assessment and detennine corrective as possible after the event actions. Protection of public health shall take priority over any notification reauirement to DHEC.

NL-122 ENCLOSURE A PAGE 6 OF 35 REVISION 4 RECIPIENT NRC -ENS or Operations Ctr.

(301) 816-5100 NRC - Region II NRC - ENS or Operations CIr.

(301) 816-5100 NRC - Director, Office of Nuclear Material Safety and Safeguards.

Core Designer Core DeSigner &

NRC - ENS or Operations CIr.

(301) 816-5100 NRC Project Manager.

(301) 415-1497 DHEC 896-0620 Day hours 253-6488 After hours D

ID # I REFERENCE 1-21 SC State & Local GoV!.

Commitment 1-22 FAA Standard AC 70n 460-1 K 1-23 NRC Letter August 9, 2002 (CER 02-2843) 1-24 FSAR 13.5.1.3.4 MASTER LIST OF REPORTING REQUIREMENTS REPORT I SUBJECT CONTENT REPORT TIME I METHOD LOIS of >25% of the EWSS State and local county notification Telephone notification within 1 required for implementation of pre-plans hour.

that put Route Alerting in place unfil the sirens are restored.

Meteorological Tower Warning Light VCSNS tower is 67.6 meters above Immediate telephone notification ground level (201.1 meters above mean to nearest Flight Service Station Failure or malfunction that lasts for thirty sea level) and exceeds 200' maximum (FSS) SO a Notice to Airmen can (30) minutes and affects a top light or height for towers not requiring warning be issued.

flashing obstruction light, regardless of its lights. Locetion is: Latitude 34 17 59, posrtlon.

Longrtude 81 19 11. The tower Note: Addrtional calls placed if registration number Is 1246445.

repairs not complete in 15 days (reference FAA Advisory AC 70n460-1K).

and following repairs.

Storage of Classified Material Notification if NRC security container in Telephone notification SAS is found unlocked and unattended.

immediately upon discovery.

Security Container In SAS.

Contents to be guardad until NRC personnel are present.

Reporting Safely and RoUef Valve The reporting of pressurizer safety and Telephone notification as soon Fallurel relief valve failures and challenges is as possible after the event.

based on the guidance in NUREG-0694, Any failure of a pressurizer PORV or "TMI-Retated Requirements for New safety valve to ciose will be reported to Operating Licensees.'

Annual Operating Report the NRC promptly. Challenges to these submitted under TS 6.9.1.5.

valves will be documented in the annual report.

NL-122 ENCLOSURE A PAGE 7 OF35 REVISION 4 RECIPIENT SCEPD & Counties (ESSX)

Anderson Flight Center (800) 443-9287 NRC Resident Inspector or NRC Operations Center (301) 816-5100 NRC - ENS or Operations Ctr.

(301) 816-5100 NRR I

I A

B A

10 # / REFERENCE F-1 10CFR50.72(b)(2)(i) 1 OCFR50.73(a)(2)(I)(A) 10CFR50A F-2 1 OCFR50. 72(b)(2)(iv)

(A) &(8) 10CFR50.73(a)(2)(iv)

F-3 10CFR50.72(b)(2)(xi) 29CFR1904.8 OSHA STD.

MASTER LIST OF REPORTING REQUIREMENTS REPORT/SUBJECT CONTENT REPORT TIME / METHOD Initiation of any nuclear plant.hutdown For 1 OCFR50. 72 reporting purposes a Telephone notification within 4 required by the plant'. Technical telephone notification is required when the hours.

Specifications.

plant takes action to reduce power, J.e.,

adding negative reactivity to achieve a plant shutdoWn requirad by TS. If equipment is LER within 60 days.

restored to service prior to initiating a shutdown then a report is not required.

For 1 OCFR50. 73 reporting, the plant must complete the shutdown before an LER is required. If the Inoperable condition, that initiated the shutdown, is corrected prior to completing the LCO an LER Is not required.

(A) Any event that results or should have Actuations or conditions that result from and Telephone notification within 4 resulted in emergency core cooling are part of a pre-planned sequence during hours.

system (ECeS) discharge Into the testing or reactor operation are not RCS as a resuH of a valid signal.

reportable.

(8) Any event or condition that results in LER within 60 days.

actuation of the reactor protection (Ref. MLRR E-2) system (RPS) whsn the reactor Is critical.

Any event or situation, relaled to the This paragraph pertains to those significant Telephone notification within 4 health and safety of the public or onsite situations that receive or are anticipated to hours.

personnel, or protection of the receive media attention. Where a state or environment, for which. news release other government entity has a requirement Is planned or notification to other or agreement with the NRC licensee for SC DOL to be notified within 8 government agencleo has been or will routine reporting of other matters, the NRC hours.

be made. Such an event may include an only requires a report when the matter is onsite fatality or inadvertent release of escalated to a "news release situation."

radioactively contaminated materials.

The report on personnel injuries shall relate The OSHA Std addresses incidents that the circumstances, number of fatalities, Involve a fatal accident of 1 or more injuries, and the exlent thereof. Indusmal employees, or which results in Safety Is to investigate and prepare the hospitalization of 3 or more employees.

incident report, which will be provided to the Shift Supervisor for required notificalions.

Written follow-up notifications will be prepared and submitted by the Corporate Safety Dept.

NL-122 ENCLOSURE A PAGES OF35 REVISION 4 RECIPIENT NRC - ENS or Operations CIr.

(301) 816-5100 NRC - OCD NRC-ENS or Operations Ctr.

(301) 816-5100 NRC-DCD NRC - ENS or Operations CIr.

(301) 816-5100 South Carolina Department of Labor-OSHA (803) 734-9600 I

I

10 # I REFERENCE F-4 ANI Information Bulletin 97-<11 F-5 10CFR20.2201(a)(1 )

10CFR20.2201 (b)(I)

F-6 DHEC Radioactive Material License No. 325 SC Regulation 61-63 RHA3.44 MASTER LIST OF REPORTING REQUIREMENTS REPORT I SUBJECT CONTENT I REPORT TIME I METHOD Any nuclear emergency if H is believed During normal office hours (8 a.m. to Telephone notification at earliest the emergency may affect offslte 4 p.m.) the call will be directed to an time possible.

person., and financial aasi.tance may appropriate individual. Outside normal be required.

office hours the call will be transferred to a mailbox. Leave a message with a Always In the event of an Alert, Site name and telephone number where the Area Emergency, or General Insurer can call the statlon for follow-up Emergency declaration.

infonnation.

Applicant must include description of accident, prognosis, magnnude; and disposition of off-sHe releases, injuries, fatatHies, evacuation, etc.

Thall or lou of licensed material in an Reference 1 OCFR20.2201 (b) for Telephone notification aggregate quantity" 1 000 times the information, which Is to be contained in immediately after occurrence quantity specified in Appendix C to the written report.

becomes known.

10CFR20.1001 -.2401, under circumstances where n appears that an Note: Guidance from NRC RIS 2005-21 Telephone follow-up within 30 exposure could result to persons in states that Immediate notification is days if quantity of licensed unrestricted areas.

desired within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

material still miSSing is > 10 times quantlty in Appendix C.

LER within 30 days.

Any actual or attempted theft, The information to be provided to DHEC Telephone notification sabotage, or diversion of radiography in the written report is in Section 3.44 of immediately upon discovery.

source.

SC Regulation 61-63. This report Is to DHEC since SC is an agreement state Radioactive Material License 325 and specifically controls this type of Written report within 30 days.

authorizes SCE&G to use an IR-192 radiography source.

source for radiography. This source is greater than the 22 Ci quantHy of concern Note: Guidance from NRC RIS 2005-21 for the reporting criteria.

states that immediate notificetion is desired within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

NL-122 ENCLOSURE A PAGE 9 OF35 REVISION 4 RECIPIENT ANI (American Nuclear Insurers)

(860) 682-1301 NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD DHEC 545-4400 Day hours 253-6488 After hours DHEC - Bureau of Radiological HeaHh

MASTER LIST OF REPORTING REQUIREMENTS 10 # I REFERENCE REPORT I SUBJECT CONTENT REPORT TIME I METHOD E-1 Any event or condition that results in:

(A) this criterion applies to material Telephone notification within 8 (e.g., metallurgical or chemical)

hours, 10CFR50.72 (A) The condition of the nuclear power problems that cause abnormal plant, including its principal safely degradation of or stress upon the (b)(3)(ii)(A) & (8) barrie", being seriously plincipal safety bamers (i.e., the fuel LER within 60 days.

10CFR50.73 degraded; or cladding, RCS pressure boundary, or (a)(2)(II)(A) & (8) the containment).

(8) The nuclear power plant being in an (1) Fuel cladding failures in the unanalyzed condition that reactor, or in the storage pool, significantly degrades plant that exceed expected values, or safely.

that are unique or 'Widespread, or that are caused by unexpected factors.

(2) Welding or matelial defects in the primary coolant system, which cannot be found acceptable under ASME Section XI, JWB-3600 or IWB-3410-1.

(3) Serious steam generator tube degradation. Tube degradatlon is considered serious if the tubing fails to meet performance criteria for structural integrity or primary to secondary accident induced leakage rate for the limiting design basis accident (Ref. NUREG 1022 page 40)

(B) Enginaering judgment and experience can be used to detennine whether an unanalyzed condition existed. It is not intended that this paragraph apply to minor variations In individual parameters, or to problems concerning slngla pieces of equipment Reference Page 40 to NUREG 1022 for additional guidance. The level of significance of the discussed cases generally corresponds to the Inability to perform a reqUired safety function.

NL-122 ENCLOSURE A PAGE 10 OF35 REVISION 4 RECIPIENT NRC-ENS or Operations Ctr.

(301) 816-5100 NRC-OeD i

I I

ID # I REFERENCE E-2 10CFR50.72(b)(3)(lv)(A) 1 OCFR50. 73(a)(2)(iv)

Note: Reference MLRR F-2 for possible 4-hour telephone notifications on ECCS and RPS actuations.

E-3 1 OCFR50. 72(b)(3)(v) 1 OCFR50. 72(b )(3 )(vl) 1 OCFR50. 73(a)(2)(v)

IOCFR50.73(a)(2)(vi)

MASTER LIST OF REPORTING REQUIREMENTS REPORT I SUBJECT CONTENT REPORT TIME I METHOD Any evenl or cond~ion that results In valid System actuations under this part are Telephone notification within 8 actuation of any of the following not reportable when:

haulS. (Note: Telephone systems:

notification for ReporllSubject (1) The actuation resulted from and item (7) is not required under (1) Reactor protection system (RPS) was a part of a pre-planned 1 OCFR50. 72. The actuation including: Reactor scram and reactor trip.

sequence during testing or would still require a written (2) General conlalnment laolatlon signals reactor operation; or report within 60 days.)

affecting containment Isolation valves in (2) The actuation was invalid and; more than one system or muhiple MSNs.

(I)

Occunred while the system LER within 60 days.

(3) Emergency core cooling systems (ECCS) was properly removed from including: High-head injection systems service; or and the low pressure injection function of (Ii) OCCUnred after the safety residual (decay) heat removal systems.

function had been already (4) Emergency or auxiliary feedwater system completed.

(EFW).

(5) Conlalnment heat removal and Note: In the case of an invalid depressurization systemB, including actuation, other than actuation of the containment spray and fan cooler RPS when the reactor is critical, the systems.

NRC allows a telephone notification (6) Emergency diesel GeneratolS (EDG).

within 60 days In lieu of an LER.

(7) Emergency.ervlce water systema fuat Reference 10CFR50.73(a)(I).

do not nonmally run and that serve as ultimate heat sinks.

Any event or condition that at the time of Events may include one or more Telephone notification within 8 discovery could have prevented fu.

procedural enrolS, equipment failures, haulS.

fuHlllment of the.atety function of andlor discovery of design, analysis, structure. or systems that are needed to:

fabrication, construction, andlor (A) Shutdown the reactor and maintain ~ in a procedural Inadequacies. However, LER within 60 days.

safe shutdown condhion; individual component failures need not (6) Remove residual heat; be reported if redundant equipment in (C) Control the release of radioactive the same system was operable and material; or available to perform the required (D) M~igate the consequences of an safely function.

accident.

Note: Event is reportable In LER if it occunred The level of judgment for reporting an at any time within 3 yealS of the date of event or condition under this criterion discovery.

is a reasonable expectatlon of preventing fulfillment of a safety function, regardless of whether there was an actual demand.

NL-122 ENCLOSURE A PAGE 11 OF 35 REVISION 4 RECIPIENT NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - DCD I

I

ID # I REFERENCE E-4 1 OCFR50. 72(b)(3)(xll)

E-5 1 OCFR50. 72(b)(3)(xiii)

MASTER LIST OF REPORTING REQUIREMENTS REPORT I SUBJECT CONTENT REPORT TIME I METHOD Any evenl requiring the transport of a Treatment may be for an illness or an Telephone notification within 8 radioactively contaminated p.",on to inJury.

hours.

an otlslte medical facility for treatment Any event that resulls in a major loss of Impacls to emergency assessment Telephone notification within 8 emergency... essment capability, capability Include loss of ons~e or hours.

olfalte reaponse capability, or offslte unavailability of otlsite meteorological communlcatlona capability (e.g.,

information and loss of> 75% of Main Note: Under VCS Radiation significant portion of control room Control Board annunciators. Otlsite Emergency Plan requiremenls, indication, Emergency Notification response capability would be impacted by loss of >75% of annunciators System, or otls~e notification system).

loss of >25% of the EWSS, an ENS would be an Alert condijion and phone, or all telephone communications loss of ali onsite/otls~e (including Bell South and communications capability would MicrowavelFiber Optic System). Reports be an NUE. Therefore, these are not required for ENS outages of which cond~ions would be reportable we receive NRC notification, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per MLRR condition 1-1.

NL-122 ENCLOSURE A PAGE 12 OF 35 REVISION 4 RECIPIENT NRC - ENS or Operations Ctr.

(301) 816-5100 NRC - ENS or Operations CIr.

(301) 816-5100

ID II/ REFERENCE P-l IEB 80-24 P-2 10CFR20.2202b 10CFR20.2203 CO2....

P-3 SCE&G Ltr. to NRC Dated SI8183 P-4 NPDES Permit No.

SC0030856 V. C. Summer Operating License NPF-12, App. B Section 3.2 MASTER LIST OF REPORTING REQUIREMENTS REPORT/SUBJECT CONTENT REPORT TIME / METHOD Service Water SYll8m leaks Inside the Leakage is considered to be a Telephone, telegraph, mailgram, Reactor Building during Modes 1, 2, 3, degradation of containment boundary.

or facsimile notification within 24 and 4. Minor valve packing leaks will be hours.

evaluated for potential reportabllity on a case basis.

Special written report within 14 days.

Any event involving licenoed material Telephone notification within 24 possessed by the licensee that may have hours.

caused or threatens to cause:

1) In a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period, deep exposure to the whole body of any Individual of" 5 LER within 30 days.

rems of radiation; an eye dose (A copy of the LER submitted to equivalent> 15 rems; or a shallow the NRC reporting personal dose equivalent to the skin or exposure shall be provided to extremitIes> 50 rerns; or each individual involved per the requirements of 10CFR20.2205)

2) The release of radioactive material inside or outside of a restricted area, so that had an individual been present for 24 hou"" the individual could have received an intake in excess of one occupational annual limit on Intake.

Any failure of Reactor Trip or Bypass This notification only applies to the trip Telephone notification within first Breakers, either in service or during function of the breake",.

normal working day after failure.

testing.

Any violation or noncompliance with Chemistry to determine reportabllity for Telephone notificatlon within 24 provisions specified In the NPDES permit releases which exceed limits (chemical &

hou", of becoming aware of where a plant discharge may endanger temperature) and any unanticipated condition.

public heaijh or the environment.

bypasses or upset in NPDES permit.

Wrltlen report within five (5)

"Any 011 spill, which is not contained, is Note: Any release which exceeds working days of becoming aware reportable. Contained spins will be limitations but does not endanger public of condition. The NRC is to be evaluated for needed reports within 4 health or the environment is to be provided a copy of these reports.

hours by Nl.

reported in the next monthly Discharge Monitoring Report Telephone and 5 day wrltIen report is not required.

NL-122 ENCLOSURE A PAGE 13 OF 35 REVISION 4 RECIPIENT NRC-ENS or Operatlons Ctr.

(301) 81S-5100 NRC - DCD (Copy to Region II)

NRC - ENS or Operations Ctr.

(301) 81S-5100 NRC-OeD NRC - Ucensing Project Manager DHEC 89S'{)620 Day hours 25~88 After hours DHEC - Enforcement Section D

MASTER LIST OF REPORTING REQUIREMENTS ID # / REFERENCE REPORT/SUBJECT CONTENT REPORT TIME / METHOD P-5 Unusual or Important Environmental SCE&G Environmental Services may Telephone notification within 24 Events that could resuH in significant need to be contacted to perform hours.

V. C. Summer environmental impact causally related to assessment.

Operating Licanse facility operation.

Examples of events: excessive bird Written report within 30 days NPF-12. App. B impaction events; onsHe plant or animal describing event, probable Section 4.1 disease outbreaks; mortality or unusual cause, action taken, and any occurrence of any species protected by agencies notified along with their the Endangered Species Act of 1973; preliminary responses.

unusual fish kills; increase in nuisanca organisms or conditions; and unanticipated or emergency discharge of waste water or chemical substance.

P-6 This license applies to the Otd Steam HeaHh Physics is responsible for Telephone notification within 24 Generator Recycle Facility (OSGRF).

assessment of this reporting requirement hours.

SCDHEC Radioactive Any unusual evants or entry into this Material License facility by unauthorized persons shall ba Radioactiive Material License No. 517 No. 517 reported.

requires notification to the Manager, Written report wi1hln 10 days.

Radioactiive Waste Management Section, Division of Waste Management at DHEC.

P-7 Any occurrence of an unusual or Chemistry and SCE&G Environmental Telephone notification within 24 important event that Indicates or could Services have responsibility for hours.

V. C. Summer resuH in algnlflcant environmental assessment and reportability Operating License impact causally related to facility determination under this part.

operation.

NPF-12, App. B Occurrences (such as fish kills) under this Section 4.1 part which are similar in nature to those under P-4 and P-5 of this part will be reported per the requirements of the NPDES permtt with a copy of reports provided to tha NRC.

Written report to ba submitted wi1hin 30 days unless reported under P-4 or P-5.

NL-122 ENCLOSURE A PAGE 140F35 REVISION 4 RECIPIENT NRC - ENS or Operations Ctr.

(301) 816-5100 NRC-DCD DHEC 896-4240 Day hours 253-6488 After hours DHEC - Manager, Radioactive Waste Management Section, Division of Waste Manae!'ment NRC-ENS or Operations Ctr.

(301) 816-5100 DHEC - Central Midlands ER Group 935-7015 Day hours 253-6488 After hours DNR - District Biologist (Fish Kills) 366-7024 Days hours 273-9099 After hours NRC - DCD D

10 # / REFERENCE P-8 SCDHEC TrtleA Regulation 61-63 RHA 2.32.2.2 RHA5.22 P-9 V. C. Summer Operating License NPF-12, Section 2 MASTER LIST OF REPORTING REQUIREMENTS REPORT/SUBJECT CONTENT REPORT TIME / METHOD Radiography License 325-01 is Issued by QC Radiographer to determine reportability.

Telephone notification within 24 DHEC to V. C. Summer for radiography hours.

testing. Equipment problems involving The reports shall contain: (1) a deScription unintentional disconnection of the source of the equipment problem; (2) cause of assembly from the control cable or the each incident, if known; (3) manufacturer Written raport within 10 days.

inability 10 retract the source assembly to and model number of equipment involved in its fully shielded and secured position the incident; (4) place, time, and date of the shall be reported.

incident, (5) comectlve actions taken or planned to prevent recumence; and (6) qualifications of personnel involved in the incident.

Any violation of the Operating License Telephone notification within 24 programmatic requirements:

hours of any violation. Confirm by telegram, mailgram, or

1) Maximym Pg~r Lev~l-SCE&G is facsimile transmission to authorized to operate the facility at NRC Region II, reactor core power levels not in excess Regional Administrator.

of 2900 megawatts thermal. Reference Item C(1).

Written follow-up report within 14

2) Sll!!lilili: Q! th~ ~st Em!lankm~ot aog working days.

its Eff~£!l; QO lhe Imilke Structu~

(Section 2.5.4.

SSER 3). Reference Item C(5).

3) Envi!Qomeo!l!1 Q~alifica!lgD of M~haDi~1 ang Electdcal EgMil;!m~l.1t Se£!!gD 3.11, S§E!Hl. Reference Item C(8).

4) Fire Prgtection §~stem §ectiQn 9.5.1,

§SER 41 Reference Item C(1B).

5) Pb~sical ilecuilli, GUilrQ Trnloing ilOd Q!.I!!lifica~QO, ang §afeg~ards Contingency Plan Reference Item E.

6) §j9Difl9:!Dl adv~~ en~i[Qnm~!]ml

6) Obtain prior NRC approval.

iml2ag 9rea~r Ulan 5!§§um(;!tion in Final !;o~lrnnm~otal §li!~m~ot.

Reference Item 2F.

NL-122 ENCLOSURE A PAGE 15 OF35 REVISION 4 RECIPIENT DHEC 545-4400 Day hours 253-6488 After hours DHEC - Bureau of Radiological Health NRC - Region II I

D

MASTER LIST OF REPORTING REQUIREMENTS 10 # I REFERENCE REPORT I SUBJECT CONTENT REPORT TIME I METHOD P-10 Any malfunction of air pollution control The following limits are established in this Telephone notification within 24 eqUipment or system process upset or permit:

hours after beginning of SCDHEC other equipment failure which resulta In Diesel Generators:

occurrence.

Air Quality Permit discharges of air contaminants lasting Opacity,; 20% (Method 9) for" 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and which are greater than Auxiliary BaUer:

Written report within 30 days.

1000-0012 those discharges described for normal OpacHy,; 20% (Method 9)

Reference Regulation 61-62 for operation in the permit are reportable.

Particulate Malter (PM) specific information that must be

,; 0.6 Ib/10' BTU & 67.0 Ibslhr In report (Method 5)

Sulfur Dioxide (SO,)

,; 3.5 Ibsl10' BTU & 392 Ibslhr (Method 6-6B)

Waste Oillncjnerator:

OpacHy,; 20% (Method 9)

Particulate Malter (PM)

,; 0.5 Ib/10' BTU & 0.4 Ib/hr (Method 6-6B)

P-11 The follOwing significant f1tness-for-The 5 specific items are not meant to be Telephone notification within 24 duty events shall be reported to the all inclusive. Reviewers should address hours of discovery.

10CFR26.73 NRC:

each fitness-for-<luty event based on the

1) Sale, use, or possession of illegal significance of the issue.

drugs within the protected area and,

2) Any acts by any peroon licensed under 10 CFR Part 55 to operate a power reactor or by any supervisory personnel assigned to perform duties within the scope of this Part:

(I)

Involving the sale, use, or possession of a controlled substance, (ii) Resuttlng in confirmed positive tests on such persons, (III) Invoiving use of alcohol within the protected area, or (iv) Resulting in a determination of unfitness for scheduled work due to the consumption of alcohol.

NL-122 ENCLOSURE A PAGE 16 OF35 REVISION 4 RECIPIENT DHEC 896-0620 Day hours 253-0488 After hours DHEC - Bureau of Air Quality NRC - ENS or Operations Ctr.

(301) 816-5100 I D

MASTER LIST OF REPORTING REQUIREMENTS 10 # I REFERENCE REPORT I SUBJECT CONTENT REPORT TIME I METHOD P-12 Loss with claim A ioss is an event In which covered property Telephone, Fax or E-Mail damage exceeds the policy deductible.

notification as soon as N.E.I.L. Manual NEIL must be consulted before any action Is possible.

taken to remove, repair, or dispose of damaged property.

Further reports as information becomes available.

P-13 Incident Telephone, Fax or E-Mail (A) Any fire Involving activation or notification as soon as N.E.I.L. Manual malfunctlon of a fixed fire possible.

extinguishing or detection system.

Further reports as (8) Any phYSical damage los. In Information becomes excess of $100,000.00.

available.

P-14 Adverse Condition. Report any Reportable conditions in the following Telephone, Fax or E-Mail condition which if allowed to continue categories ~

be reported:

notification as soan as N.E.I.L. Manual uncorrected, could result in a possible.

Significant property damage (A) Known or suspected damage to Insured Incident or loss.

plant equlpmen~ causing or resulting

Further reports as from an unplanned shutdown, which If infonnatlon becomes allowed to continue unconrected could available.

result in; (1) Physical damage> $500,000, including consequential damage, (2) An outage> 10 weeks.

(8) At rated speed and stable conditions, vibration levels that enter or exceed the Adverse Condition Alert Range, Rotating Equipment Vibration Guidelines.

(C) Test results of transfonner insulating oils outside the acceptable limits by 110% of IEEE values.

,"ContinUed on next page" NL-122 ENCLOSURE A PAGE 17 OF35 REVISION 4 RECIPIENT N.E.I.L -

Phone: (302) 888-3000 Fax: (302) 888-3095 Nuclear Electric Insurance LimIted sune 1100, 1201 Mar1<et Street Vvllmlngton, DE 19801 N.E.I.L -

Phone: (302) 888-3000 Fax: (302) 888-3095 Nudear EJectric Insurance Limited sune 1100, 1201 Mar1<etStreet Vvllmlngton, DE 19801 N.E.I.L-Phone: (302) 888-3000 Fax: (302) 888-3095 I

Nucle.r ElectrIc Insurance Limited I sun. 1100, 1201 Market Street Vvllmlngton, DE 19801 I

I I

I B

B B

10 # / REFERENCE P-14 (cont.)

N.E.I.L. Manual P-15 N.E.I.L. Manual P-16 Fitness For Duty FFD-106 10CFR26 Appendix A 2.8(e)(5)

MASTER LIST OF REPORTING REQUIREMENTS REPORT/SUBJECT CONTENT REPORT TIME / METHOD (0) Continued operation following discovery of crack indications Involving turbine-generator components, the magnITude and growth rate of which may require equipment replacement in ~ years.

(E) Continued operation with failed or defeated safety devices (except those undergoing routine maintenance or calib.) which could lead to a turbine water induction Incident or turbine oversoeed Impalnment (Fire Service System) -

The fire protection supervisor §M!! be Telephone, Fax or E-Mail An impainment to a fire system occurs notified of each impainment. NEIL 'should' notiflcation as 8aon as when the system is prevented from be notified of each impainment, when the possible if impainment to perfunmlng its intended function, duration is expected to exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

last >48 hours.

regardless of the reason.

Further reports as information becomes available.

False poslttve error occurs on a The laboratory shall be required to take Telephone notification blind porfonmance test spoclmen.

corrective action to minimize the occurrence within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of of the particular error In the Mure; and, ~

discovery.

If the error is detenmined to be an there Is reason to believe the error could administrative error (clerical, sample have been systematic, the licensee may mixup, etc.), the licensee shall also require review and reanalysis of promptly notify the NRC.

previously run specimens.

NL-122 ENCLOSURE A PAGE 18 OF 35 REVISION 4 RECIPIENT N.E.I.L-Phone: (302) 888-3000 Fax: (302) 888-3095 NucJear EJectric Insurance LImited Suite 1100, 1201 Market Street

'Mlmlngton, DE 19801 NRC - ENS or Operations Ctr.

(301) 816-5100 B

MASTER LIST OF REPORTING REQUIREMENTS ID # / REFERENCE REPORT/SUBJECT CONTENT REPORT TIME / METHOD P-l?

Radioactive spill or leakage that HP is responsible for idenlifying and Telephone notificalion by could contaminate groundwater.

quantifying leakage of radioactive materials next business day for local NEI07-(l?

that exceed levels in ODCM Table 1.4-2.

and state officials.

Industry Ground Water I) Spill or leak >100 gallons or if not Groundwater impact Is based on Protection Inrtiative -

quantifiable.

engineering assessment of site Final Guidance

2)

Any leak or spill, regardless of the geo-hydrology. Reporting is voluntary and Document volume or activrty, deemed by approved by industry CNOs and the NRC.

August 200?

station management to warrant Telephone notification per voluntary communication.

NRC callis discretionary and based on I OCFR50. 72(b)(2)(xl)

ODCM

3)

Water sample (oflsHe or onsHe) whether statellocal regulations require within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after state from groundwater or surface notifications or when the event is likely to be and local notification.

water.

of media Interest. Ref. NL Guideline 117, Guideline for Potential Public Interest Written report within 30 Events.

days.

L_

DHEC NL-122 ENCLOSURE A PAGE 190F35 REVISION 4 RECIPIENT (803) 896-4240 (day)

(803) 253-6488 (after hours)

NEI - E-mail to:

GW_Notice@nel.org NRC - ENS or Operations Ctr.

(301) 816-5100 DHEC - Bureau of Radiological Heallh NRC - DCD I

A I

D I

B A

ID # I REFERENCE S-1 SCDHEC Underground Storage Tank (UST) Regulation R.61-92, Section 280.61 MASTER LIST OF REPORTING REQUIREMENTS REPORT I SUBJECT CONTENT REPORT TIME I METHOD Turbine Lube 011 Tank - Upon Leakage DetectJon Limits:

ActJons to be laken within confirmation of a releale or after a Daily Inventory. Monthly - confinn release 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s:

release from the UST system Is of less than 1.0% flow-!hrough plus 130

a. Telephone notmcation Iden~fied in any manner. Specific gallons.

b. Take immediate actJons and no~ficatlon of SCDHEC action to prevent are required.

Monthly - Verify < 0.2 gallon per hour leak further release.

rate.

c. Idenfify and mitigate fire, explosion, and vapor hazards.

W~en report within 20 days.

DHEC NL-122 ENCLOSURE A PAGE 20 OF 35 REVISION 4 RECIPIENT 896-7957 Day hours DHEC - Bureau of Underground Storage Tank Management D

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