Text

Final - Outlines (Change Summaries - Optional)
	ML032690865
Person / Time
Site:	Salem
Issue date:	05/13/2003
From:	Reid J; Public Service Enterprise Group
To:	Conte R; NRC/RGN-I/DRS/OSB
	Conte R
References
	050-272/03-301, 050-311/03-301
	Download: ML032690865 (53)
	v • d • e

Mr. Todd Fish USNRC 475 Allendale Road King of Prussia, PA 19406 May 5,2003

Dear Mr. Fish,

Enclosed please find the corrections and enhancements to the SRO-U exam submitted on April 14,2003.

Questions included for your review are designated Record Numbers 1, 5, 11, 19,22,23, 32, 45,48, 52, 64, 70,79,94, and 98. Also included is an updated Exam Outline Form ES-401-3, and Written Exam Quality Checklist Form ES-401-7.

1. Inserted "to 174 steps withdrawn" in stem.

5. Removed 55.43(b) reference, made question Both.

1 1. Changed WA to AA2.01

19. Changed WA to AK1.O1. ***This is a 2.4 WA, but it is a Plant Specific Priority due to Salem's past and recent history regarding Circulator, steam dump, and MS-10 operations.

22. Added 55.43(b) reference

23. Added "to verify 2A VIB has transferred to the AC LINE REGULATOR" for Distractor C, and "to verify 2A VIB has transferred to the DC POWER SUPPLY" to distractor B.

32. Changed WA to 074 EK3.11

45. Changed to NEW question, same WA., not SRO only.

48. Reworded question into 2 conditions, changed to BOTH, removed 55.43(b) reference

52. Deleted "Enter Tech Spec 3.0.3" from beginning of answer a.

64. 'Changed to NEW question. 55.43(b)7 now instead of 4

70. Capitalized REQUIRED in stem.

79. Capitalized CAN in distracters c and d.

94. Changed to BOTH from 55.43(b)

98. Changed to NEW question.

Please contact me at 1-856-339-1554 if you have any questions.

pyCenJJJ%

Gerald S. Gauding

Printed: 05/05/2003 ES-401 PWR SRO Examination Outline I Total

' I 2 1 l I 2 1 l9 Note: I. Ensure that at least two topics from every WA category are sampled within each teir (i.e., the "Tier Totals" in each K/A category shall not be less than two).

2. Actual point totals must match those specified in the table.

3. Select topics from many systems; avoid selecting more than two or three K/A topics from a given system unless

4. Systems/evolutions within each group are identified on the associated outline.

5. The shaded areas are not applicable to the categoryltier.

6. Thegeneric K/As in Tiers 1 and 2 shall be selected from Section 2 of the K/A Catalog, but the topics must be relevant to the applicable evolution or system.

7. On the following pages, enter the K/A numbers, a brief description of each topic, the topics' importance ratings for the RO license level, and the point totals for each system and category. K/As below 2.5 should be justified on the basis of plant-specific priorites. Enter the tier totals for each category in the table above.

they relate to plant-specific priorities.

1

Facility:

Salem ES - 401 Emei VAPE ##

00 1 005 01 1 015 017 024 026 029 040 EIAPE Name / Safety Function Continuous Rod Withdrawal / I Inoperable/Stuck Control Rod / 1 Large Break LOCA 1 3 Reactor Coolant Pump (RCP) Malfunctions / 4 Reactor Coolant Pump (RCP) Malfunctions (Loss of RC Flow) / 4 Emergency Boration / 1 Loss of Component Cooling Water (CCW) 1 8 Anticipated Transient Without Scram (ATWS) I) I Steam Line Rupture / 4 Printed:

05/05/2003 PWR SRO Examination Outline and Abnormal Plant Evolutions - Tier 1 I Group 1 KA Topic AK3.01 - Manually driving rods into position that existed before start of casualty 2.1.33 - Ability to recognize indications for system operating parameters which are entry-level conditions for technical specifications.

2.2.22 - Knowledge of limiting conditions for operations and safety limits.

AK3.02 - CCW lineup and flow paths to RCP oil coolers AK2.07 - RCP seals AA2.04 - Availability of BWST AA2.01 - Location of a leak in the CCWS EAl.03 - Charging pump suction valves from VCT operating switch AKI.OS - Reactivity effects of cooldown Form ES-401-3

[mp.

3.6 -

4.0 4.1 3.1 2.9 4.2 3.5 3.2 4.4 Points I

1

Facility:

Salem ES - 401 EK3.02 - Actions contained in EOP for loss of offsite and onsite power Emer 4.6 1

SIAPE #

05 1 2.1.32 - Ability to explain and apply all system limits and precautions.

055 3.8 1

057 AA1.07 - Flow rates to the components and systems that are serviced by the SWS; interactions among the components AA2.09 - That a failed fire alarm detector exists AAl.08 - Local boric acid flow EK3.11 - Guidance contained in EOP for Inadequate 059 3.0 1

2.7 1

4.2*

1 4.4 1

062 AKl.06 - Chemical shock and crud burst 067 2.6 1

068 074 076 EIAPE Name I Safety Function Loss of Condenser Vacuum I 4 Loss of Offsite and Onsite Power (Station Blackout) /

6 Loss of Vital AC Electrical Instrument Bus 1 6 Accidental Liquid Radwaste Release 1 9 Loss of Nuclear Service Water 14 Plant Fire on Site 1 9 Control Room Evacuation / 8 Inadequate Core Cooling / 4 High Reactor Coolant Activity / 9 PWR SRO Examination Outline ind Abnormal Plant Evolutions - Tier 1 1 Grour, 1 Printed:

05/05/2003 Form ES-401-3 KA Topic Imp.

IPoints 1

1 AKI.01 - Relationship of condenser vacuum to I 2.4* I 1

circulating water, flow rate, and temperature AK2.0 1 - Radioactive-liquid monitors t 2

Facility:

Salem K3 ES - 401 A1 X

</APE ##

E02 E04 E06 E07 E09 E14 Emet E/APE Name / Safety Function SI Termination 13 LOCA Outside Containment 1 3 Degraded Core Cooling / 4 Saturated Core Cooling 14 Natural Circulation Operations / 4 High Containment Pressure / 5 PWR SRO Examination Outline encv and Abnormal Plant Evolutions - Tier 1 / Group 1 K1 X -

WA Category Totals:

5 Printed:

05/05/2003 KA Topic EK 1.2 - Normal, abnormal and emergency operating procedures associated with SI Termination EA2.1 - Facility conditions and selection of appropriate procedures during abnonnal and emergency operations EA2.1 - Facility conditions and selection of appropriate procedures during abnormal and emergency operations EA 1.3 - Desired operating results during abnormal and emergency situations EK2.2 - Facilitys heat removal systems, including primary coolant, emergency coolant, the decay heat removal systems, and relations between the proper operation of these systems to the operation of the facility EK 1.2 - Normal, abnormal and emergency operating procedures associated with High Containment Pressure Form ES-401-3 mP*

3.9 4.3 4.2 3.9 3.9 3.7 3

Group Point Total:

Points 1

1 1

1 24 3

PWR SRO Examination Outline K1 Printed:

05/05/2003 K2 X

X Facility:

Salem ES - 401 KA Topic AK2.02 - Sensors and detectors EK2.03 - SIGs

</APE #

008 Imp.

Points 2.7 1

3.3*

1 009 2.1.33 - Ability to recognize indications for system operating parameters which are entry-level conditions for technical specifications.

AA2.04 - Location and isolability of leaks 022 4.0 1

3.6 1

02 5 AK3.10 - Automatic actions associated with high radioactivity in S,G sample lines 037 037 I

3.7* I I

03 8 2.1.32 - Ability to explain and apply all system limits and precautions.

EK3.01 - Equalizing pressure on primary and secondary sides of ruptured SIG AK3.03 - Manual control of AFW flow control valves AA2.03 - DC loads lost; impact on to operate and monitor plant systems 054 3.8 1

4.3 1

4.1 1

3.9 1

058 Emei EIAPE Name I Safety Function Pressurizer (PZR) Vapor Space Accident (Relief Valve Stuck Open) I 3 Small Break LOCA 1 3 Loss of Reactor Coolant Makeup I 2 Loss of Residual Heat Removal System (RHRS) 1 4 Steam Generator (SIG) Tube Leak I 3 Steam Generator (SIG) Tube Leak / 3 Steam Generator Tube Rupture (SGTR) 1 3 Loss of Main Feedwater (MFW) 14 Loss of DC Power 1 6 ency and Abnormal Plant Evolutions - Tier 1 / Group 2 Form ES-401-3

Printed:

05/05/2003 PWR SRO Examination Outline

ncy K1 X

X X

Facility:

Salem ES - 401 an(

K2 X

Emei

/APE #

060 06 1 065 E03 E05 El 1 E16 EIAPE Name I Safety Function Accidental Gaseous Radwaste Release 1 9 Area Radiation Monitoring (ARM) System Alarms I 7

Loss of Instrument Air 1 8 LOCA Cooldown and Depressurization / 4 Loss of Secondary Heat Sink 14 Loss of Emergency Coolant Recirculation / 4 High Containment Radiation I 9 K/A Category Totals:

3 3

Lbnormal PI t Evolutions - Tier 1 I Group 2 KA Topic AKI.02 - Biological effects on humans of the various types of radiation, exposure levels that are acceptable for personnel in a nuclear reactor power plant; the units used for radiation intensity measurements and for radiation exposure levels AKI.01 - Detector limitations AA I.02 - Components served by instrument air to minimize drain on system EA 1.3 - Desired operating results during abnormal and emergency situations EA 1.1 - Components, and functions of control and safety systems, including instrumentation, signals, interlocks, failure modes, and automatic and manual features EK2.1 - Components, and functions of control and safety systems, including instrumentation, signals, interlocks, failure modes, and automatic and manual features EKI.2 - Normal, abnormal and emergency operating procedures associated with High Containment Radiation Form ES-401-3

.mp.

3.1*

2.9?

2.8 4.1 4.0 3.9 3.2 Group Point Total:

2 3oints 1

1 1

16 2

Facility:

Salem ES - 401 UAPE #

028 036 Emei E/APE Name / Safety Function Pressurizer (PZR) Level Control Malfunction / 2 Fuel Handling Incidents / 8 A K I.O 1 - PZR reference leak abnormalities 3.1*

WA Category Totals:

1 AA2.03 - Magnitude of potential radioactive release PWR SRO Examination Outline ind Abnormal Plant Evolutions - Tier 1 / Grow 3 4.2*

Printed:

05/05/2003 Form ES-401-3 056 G I KA Topic Loss of Offsite Power I 6 X 2.4.6 - Knowledge symptom based EOP mitigation strategies.

4.0 1

Group Point Total:

Points 1

1

PWR SRO Examination Outline Printed:

05/05/2003 K6 X

I Plant Sysf A1 A2 X

X Facility:

3.2 3.9 3.7 3.8 3.3 4.0 3.2 4.1 2.8*

ES - 401 Sys/Ev #

00 1 I

1 1

003 004 004 013 014 015 015 026 056 Salem System I Evolution Name Control Rod Drive System / I Reactor Coolant Pump System (RCPS) / 4 Chemical and Volume Control System (CVCS) / 1 (CVCS)/ 1 Chemical and Volume Control System Engineered Safety Features Actuation System (ESFAS) 12 Rod Position Indication System (RPIS) / 1 Nuclear Instrumentation System I 7 Nuclear Instrumentation System / 7 Containment Spray System (CSS) / 5 Condensate System I 4 ns - Tie A3.01 - Seal injection flow I A3. I O - PZR level and pressure A4.15 - Boron concentration A 1.OS - Containment sump level K5.02 - RPIS independent of demand position X 2.4.6 - Knowledge symptom based EOP mitigation strategies.

K6.04 - Bistables and logic circuits K3.01 - CCS A2.04 - Loss of condensate pumps Form ES-401-:

1

PWR SRO Examination Outline rorm Imp.

4.3 3.7 3.6 3.0*

2.9 2.8*

3.0 2.8

3.5 Printed

05/05/2003 1x3-4ui-3 Points 1

1 1

rier

$4 I 1 9 2 I G

X K3 X

KIA Category Totals:

1 K4 X

X

S - 401 y s / ~ v 059 06 1 061 063 068 068 07 1 07 1 2

1 System / Evolution Name Main Feedwater (MFW) System 1 4 Auxiliary / Emergency Feedwater (AFW) System 1 4 Auxiliary / Emergency Feedwater (AFW) System / 4 D.C. Electrical Distribution System / 6 Liquid Radwaste System (LRS) 1 9 Liquid Radwaste System (LRS) / 9 Waste Gas Disposal System (WGDS)

/ 9 Waste Gas Disposal System (WGDS) 072 KA Topic 2.4.4 - Ability to recognize abnormal indications for system operating parameters which are entry-level conditions for emergency and abnormal operating procedures.

K2.02 - AFW electric driven pumps Area Radiation Monitoring (ARM)

System / 7 K5.02 - Decay heat sources and magnitude K4.0 I - ManuaVautomatic transfers of control K1.07 - Sources of liquid wastes for LRS A2.02 - Lack of tank recirculation prior to release K4.05 - Point of release A 1.06 - Ventilation system K3.02 - Fuel handling operations Group Point Total:

19 1

2 2

PWR SRO Examination Outline Printed:

05/05/2003 Form Imp.

4.6 3.9 2.9 3.7 3.3 2.8 3.7 3.7*

Facility:

ES-401-2 Points 1

1 1

1

S - 401

,ys/Ev #

002 002 (4

006 K5 X

X 010 System / Evolution Name K1 Reactor Coolant System (RCS) / 2 Reactor Coolant System (RCS) / 2 Emergency Core Cooling System (ECCS) / 2 Pressurizer Pressure Control System 01 1 01 1 K2 K3 X

012 Reactor Protection System 1 7 016 028 029 X

Salem (PZR PCS) / 3 I l l I

Pressurizer Level Control System (PZR LCS) / 2 Pressurizer Level Control System (PZR LCS) / 2 I

I I

Non-Nuclear Instrumentation System 1 X I I

("IS)

I 7 I l l Hydrogen Recombiner and Purge Control System (HRPS) 1 5 Containment Purge System (CPS) / 8

roup 2 KA Topic K3.03 - Containment K5.13 - Causes of circulation K5.02 - Relationship between accumulator volume and pressure 2.2.25 - Knowledge of bases in technical specifications for limiting conditions for operations and safety limits.

K6.03 - Relationship between PZR level and PZR heater control circuit A2.08 - Loss of level compensation K2.01 - RPS channels, components, and interconnections K 1.07 - ECCS A4.03 - Location and operation of hydrogen sampling and analysis of containment atmosphere, including alarms and indications A4.04 - Containment evacuation signal 1 9 I 1

PWR SRO Examination Outline Printed:

05/05/2003

roup 2 KA Topic A 1.O 1 - Spent fuel pool water level A2.0 I - Dropped fuel element K3.02 - ECCS 2.2.22 - Knowledge of limiting conditions for operations and safety limits.

A3.04 - Number of starts available with an air compressor Facility:

Form ES-401-2 Imp.

Points 3.3 I

4.4 1

4.3 1

4.1 1

3.5 1

CS - 401 SysIEv #

033 K2 034 K3 X

035 ns -

43 X

064 064 Tiel A4 086 K6.04 - Fire, smoke, and heat detectors 103 2.9 1

Salem K4.04 - Personnel access hatch and emergency access hatch System I Evolution Name Spent Fuel Pool Cooling System (SFPCS) / 8 3.2 1

Fuel Handling Equipment System (FHES) / 8 Steam Generator System (S/GS) / 4 Emergency Diesel Generator (ED/G)

System I 6 Emergency Diesel Generator (ED/G)

System I 6 Fire Protection System (FPS) / 8 Containment System / 5 KIA Category Totals:

2

Facility:

C4 PWR SRO Examination Outline Printed:

05/05/2003 K5 K6 X

Salem 3s - 401 3ysIEv ##

005 008 04 1 045 (RHRS) / 4 (CCWS) / 8 Turbine Bypass Control / 4 Svstem 14 K/A Category Totals:

0 0

0 1

0 0

1 Group Point Total:

4 1

Generic Knowledge and Abilities Outline (Tier 3)

Printed: 05l0512003 PWR SRO Examination Outline Form ES-401-5 Knowledge of conditions and limitations in the facility license.

Ability to make accurate, clear and concise logs, records, status boards, and reports.

Ability to use plant computer to obtain and evaluate parametric information on system or Ability to execute procedure steps.

3.9 3.O 3.0 4.2 component status.

Facility:

Salem 1

1 1

1 Generic Category KA Conduct of Operations 2.1.10 2.1.18 2.1.19 2.1.20 Ability to perform pre-startup procedures for the facility, including operating those Knowledge of the process for making changes in procedures as described in the safety Knowledge of pre-and post-maintenance operability requirements.

Knowledge of bases in technical specifications for limiting conditions for operations and controls associated with plant equipment that could affect reactivity.

analysis report.

safety limits, 3.6 1

3.3 1

3.5 1

3.7 1

2.2.6 2.2.21 2.2.25 Equipment Control Radiation Control 2.3.1 2.2.1 2.3.2 2.3.3 2.3.8 Knowledge of 10 CFR: 20 and related facility radiation control requirements.

Knowledge of facility ALARA program.

Knowledge of SRO responsibilities for auxiliary systems that are outside the control Knowledge of the process for performing a planned gaseous radioactive release.

room (e.g., waste disposal and handling systems).

KA Topic Imp.

Points 3.0 1

2.9 1

3.2 1

1

Facility:

Salem Generic Category Emergency Procedures/Plan 2.4.8 2.4.12 2.4.25 2.4.27 2.4.28 Generic Knowledge and Abilities Outline (Tier 3)

PWR SRO Examination Outline Knowledge of how the event-based emergency/abnormal operating procedures are used in conjunction with the symptom-based EOPs.

Knowledge of general operating crew responsibilities during emergency operations.

Knowledge of fire protection procedures.

Knowledge of fire in the plant procedure.

Knowledge of procedures relating to emergency response to sabotage.

Printed: 05/05/2003 Form ES-401-5 KA KA Topic Imp. -

3.7 3.9 3.4 3.5 3.3 -

'oints 1

1 1

Category Total:

5 Generic Total:

17 2

PRIORITY ITEMS Facility:

Salem E/APE #

05 1 PWR SRO Examination Outline Printed:

05/05/2003 E/APE Name / Safety Function KA KA Topic Comment Loss of Condenser Vacuum t 4 AKl.01 Relationship of condenser vacuum to circulating water, flow rate, and temperature This is a 2.4 K/A, but is a Plant Specific Priority due to the challenges to plant operation from circulator operationlnon-operation, the effects on condensor vacuum and the operation of the steam dumps.

PRIORITY ITEMS

ALL ACTIVE ON-THE-SPOT CHANGES MUST BE ATTACHED FOR FIELD USE 200304 11 s2. OP-ST.

cvc-ooi O(Q)

Parameter ATTACHMENT 2 (Page 1 of 1)

Data BORATED WATER SOURCES DATA MODES 1-4 RWST Conc 21 BAST Vol AND/OR ppm (2LI106)

RWST Level 2LT960 -

2LT961 -

2LT963 -

ft 2 LT962 -

21 BASTTemp AND/OR 22 BAST Temp "F

RWST Temp T0650A O F '

(2TI 107)

"F TI I 03) 22 BAST Vol I (2tI102) 21 BAST Conc ppm 1

(21 BAST)

AND/OR I

Test Results Acceptance Criteria I

SAT I SAT I Date 364,500 to 400,000 gals (240.5 ft 541.9 ft)

(Note 2)

~

22,300 and 52,500 PPm IAW Tech Spec 3.1.2.6.a and 3.1.2.6.b Figure 3.1-2 (1)

If one BAST is the borated water source, then level and concentration requirements must be maintained in acceptable operation region of figure 3.1-2.

If two BASTS are the borated water source, then combine volumes are used to satisfy Tech Spec 3.1.2.6.a.

(2)

Refer to S2.OP-TM.ZZ-O002(Q), Tank Capacity Data.

I Rev. 7 Salem 2 Page 8 of 11

ALL ACTIVE ON-THE-SPOT CHANGES MUST BE ATTACHED FOR FIELD USE 200304 11 s2.OP-AB. CN-OOol(Q)

ATTACHMENT 2 (Page 1 of 3)

PROGRAMS 1.0 STEAM GENERATOR LEVEL PROGRAM:

STEAM GENERATOR LEVEL ( O h )

o i o 20 30 40 50 sa 70 eo so 100 PERCENT POWER 2.0 STEAM GENERATOR FEEDWATER - AP VS %STEAM FLOW:

FW SG D/P (psidl PA 14932 5 1015 20253035404550556065707580859095100 Z STEAM FLOW (Use any Chonrlet I or II K Steam Flow Indicator for any Steam Generator)

Salem 2 Page 10 of 15 Rev. 12

ALL ACTIVE ON-THE-SPOT CHANGES MUST BE ATTACHED FOR FIELD USE 20030411 S 2.OP-AB.CN-0001(Q)

ATTACHMENT 2 (Page 2 of 3)

PROGRAMS 3.0 LvG PROGRAM VS % IREACTOR POWER:

Salem 2 Page 11 of 15 Rev. 12

ALL ACTIVE ON-THE-SPOT CHANGES MUST BE ATTACHED FOR FIELD USE 20030411 S2.0P-AB. CN-0001 (Q)

ATTACHMENT (Page 3 of 3) 2 PROGRAMS 4.0 MAXIMUM RX POWER LEVEL WITH EOUIPNENT OUT OF SERVICE CN or HTR DRN Salem 2 Page 12 of 15 Rev. 12

~

3.1.2.6 Am a minimum, t h e following borated w a t e r a8 roquirod by Specification8 3.1.2.1 and 3.1.2.2:

a-A boric:8ci.d 8torage symtr w i t h r

1.

A contain& volumo of borated water 3-1-2,

2.

A Boron concentration i n accordancm 8ourcr(m) shall be OPXRABLE I

i n accordance with figure with F i g u r e 3.1-2, and

3.

A minimum solution t a p o r a t w e of 63.F.

The r r t u e l i n g water mtor&gm tank with:

b.

-Xi--

A contained volume ort.between 364,500 and 400,000 gallon. of 2.

A boron concentration of between 2,300 and 2,500 p p, and

3.

A minFmum aolution t-rature of 35.P.

w a t e r,

MPLICABILITY:

MODtS 1, 2, 3 and 4.

hCTlON:

a.

With t h e boric acid s t o t a p rymtem inoperable and being used am one of th* above required borated water sourcem, remtote tho storage nyrtrm t o OPERABLE s t a t u s within 72 hour8 or be in a t h a r t HOT STANDBY within t h e next 6 hour8 and borated t o a SHUTDOWN -GIN equivalent t o a t least 1% d e l t a F/k a t ZOOOF; restore t h e boric acid storage mystem t o OPERABLE ataturn within t h e next 7 day.

or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

b.

With thm refueling watar storage tank inapetablm, terntore t h e tank t o OPERABLE mtatui within one hour or be i n a t least HOT STANDBY within t h e next 6 hour8 and in COLD SHUTDOWN within tho following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

4.1.2.6 Each borated watar source aha11 be demonatrated OPERABLE:

a.

For t h e boric acid rtoragcl rrystem, when it i r t h e source of borated w a t e r a t l r a u t once par 7 days bya

1.

Verifying t h e boron concentration i n each water source.

2.

Verifying t h e water level of each water source, and

3.

Verifying t h e boric acid etorage system s o l u t i o n temperature.

b.

For t h o r e f u e l i n g water storage tank by:

A.

2.

3.

Verifying the boron concentration at l e a s t once par 7 days, Verifying t h e borated water volume at l e a a t once per 7 day.,

and Verifying t h e aolution temperature a t Leaet once per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when the o u t s i d r d r temperature is less than 35'F.

I Amendment NO. 151 314 1-12 SALEM - UNIT 2

BORIC ACID TANK CONTENTS BASED ON RWST CONCENTRATION I

I f 00%

98%

95%

92%

90%

87%

85%

I I

t I

I I

0990 ppm (rnaximurn1'4 7,800' -

',200

(

I i,800 I

1,600 '

6,600 6,700 6,800

~

-~

6,900 7,000 CONCENTRATION IN BAT - ppm BORON SALEM - UNIT 2 Figure 3.1-2 3/4 f-12Ia)

Amendment No. 133

ACT":

8.

. b.

C.

J

A reevaluation of each sccident analysis of Table 3.1-1 is performed within 5 days: this reevalurtion shall confirm that che previously analyzed result8 of these accidents remain valid for cha durarioii of operation under there conditions.

The SHUTDOWN MARGIN requirement of Specification 3.1.1.1 i s determined at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

A core power distribution meaaurcmcnt is obtained and PQ(Z) and PNm are verified t o be within chcii limits within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

I The T H E W POWER level is reduced to less than or equal to 759 of RATED THERMAL POWER within one hour and within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the high neutron f l u x trip fetpoint is reduced to leos chan or equal to 6 5 %

of RATED THERMAL POWER. THERMAL POWER shall be maintained lesa than or equal to 7 5 t of RATED T H E W POWER until compliance with ACTIONS 3.1.3.l.c.3.a and 3.1.3.l.c.3.c above are demonstrated.

SURVEILLANCE REUUIREHENTS

~

~-

~

4.1.3.1.1 The position of each f u l l length rod shall be determined to be within the l i m i t s astablished in the limicing condition for operation ut least once pur 12 hourE (allowing for one hour chcrmsl cosk after rod motion) exctpt during t i m e intervals when the Rod Position Deviation Monitor i s inoperable, then verify the group poriciona at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 4.1.3.1.2 Each full length rod not f u l l y inserted an the core shall be determined to be OPERABLE by movement of a t least 10 steps i n any one direction at least once per 31 days.

SALEM - UNXT 2 314 1-14 Amendment Ne. 216

TABLE 3.1-1 ACCIDENT ANALYSES RE QJIR:NG REEVALUATION I N m m m K N I N O P t R A B L E FULL LE-0 Rod C1 uster Control Assembly Insertion Characteri sttcs Rod C1 uster Control Assembly Mis-a1 i gnment l o s s Of Reactor Coolant From Ruptured Pipes Or From Cracks I n Large PIpes WIfch Actuates The Emrgency Core Coollng System Sfnglc Rod Cluster Control Assembly Hthdrawal A t Full bwer Major Reactor Coolant System Pipa Ruptures (loss Of Coolant Accident)

Major Secondary System Pfpe Rupture Rupture o f a Control Rod Drlve Mechanism b u s i n g (Rod Cluster Control Assembly Ejection)

SALE!! - UNIT 2 3/4 1-15 Amendment No. 48

REACTIVITY CONTROL SYSTEMS POSZTION INDICATXON SYSTEMS - OPERATING LZMITING CONDITION FOR OPERATION 3. 1. 3. 2. 1 The shutdown and control rod position indication systems shall be OPEZABLE and Capable o f determining the a c t u a l and demanded rad positions as follows :

a.

Analog rod position indicators, within one hour after rod motion (allowance for thermal eoak);

All Shutdown Banks: f LB rtcps at 585% reuctot power or if reactor power is D 859 RATED THERMAL POWER t 12 stepE of the group demand counters for withdrawal ranges of 0-30 stmps urd 200-226 steps.

Control Bank A : t IS steps at 9 5 % reactor power or i f reactor power is 85% RATED THERMAL POWER

12 steps o t the group demand counters for withdrawal ranges of 0-30 steps and 200-228 steps.

Control &ink B: t 18 steps at $859 reuctor power or if reactor power is

> 85% RATED THERMAL POWER t 12 steps of t h e group demand counters for withdrawal ranges of 0-30 Stope and 160-228 Stops.

Control Banks C and D: i 18 steps ut 9 5 0 reector power or i f reactor power is > 859 RATED THERMAL POWER

12 steps of the group demand counters for withdrawal range of 0-228 steps.

b.

Group demmd countef~: f 2 steps of tho pulsed output of tho Slave Cycler Circuit over rho withdrawal range of 0-228 steps.

APPLICABILITY: NODES 1 and 2.

ACTION :

a.

With a maximum of one analog rod position indicator per bank inoperable either:

1.

Determine the pornition of the non-indicating rod(s) indirectly using the power distribution monitoring aystem

( i f power is above 25% RTP) or using the movable incore detectors (if power is less than 25% RIP or the power distribution monitoring system is inoperable) at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and within one hour after any motion of the non-indicating rod which exceeds 2 4 steps in one direction since the Last dctrrmanation of the rod's position. or 2.

Reduce THERMAL POWER to loss than SUB of RATED T H E W L POWER within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

b.

With two or mote anslog rod position indicator6 per bank inoperable. within hour restore the inoperable rod position indicator(#) to OPERRBLE starus or be 3n HOT STANDBY within tho next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

A mximum of one rod position indicator per bank may remain inoperable following the hour, w i t h Action (a) above being applicable from the original entry time into tho K O.

SALEM - UNIT 2 314 1-15 Amendment No. 210

c.

Xith a maximum of one group demand position indicator per bank

'inoperable either:

1

'u'erify that all analog rod position indicators or the affected bank are OPERABLE and that the most withdrawn r ~ 2 and

he least #withdrawn rod of the bank are within a rnaxzmum sf la S

C P

~

when reactor power is s 8 5 % RATED THERMAL PCWER or if reactor power is > 8 5 % RATED T H E W A L TOWER, 1 2 steps ~f each other at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , o r 2.

Reduce T H E R W POWER to less chan 50% of W T E D T H E W L 30XER within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

- 1. 1. 3. z. 1. 1 Each analog rod position indicator shall be determined to be OTERABSE by *ier;fying that the demand position indication system and the rod position indication system agree within 18 steps when reactor power is s 5 5 %

FWTEC TXEPflAL. POWER or i f reactor power is > 859 RATED T H E W POWER, 12 steps

[allowing :or one hour thermal soak after rod motion) at least once per 12 hcurs excepc during time intervals when the Rod Position Deviation Monitor is incperable, chen compare the demand position indication system and the rod

~ c 5 i t ~ 0 2

~zdrcation system at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

I 1. 1 3 1. 1. 2 Each a :he above required rod position indicator ( s ) shall be determined tc be O P E R U L E by performance of a CHANNEL calibration at least

.3r.CY p e r 1 9 mci?::?s.

3 / 4 1-16a Amendment NO. 163 I

3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT CONTAINMENT INTEGRITY LIMITING CONDITION FOR OPERATION 3.6.1.1 Primary CONTAINMENT INTEGRITY shall be maintained.

APPLICABILITY: MODES 1, 2, 3 and 4 ACTION :

Without primary CONTAINMENT INTEGRITY, restore CONTAINMENT INTEGRITY within one hour or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.6.1.1 Primary CONTAINMENT INTEGRITY shall be demonstrated:

al.At least once per 31 days by verifying that each containment manual valve or blind flange that is located outside containment and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls. Valves and blind flanges in high radiation areas may be verified by use of administrative controls.

a2.Prior to entering Mode 4 from Mode 5 if not performed within the last 92 days

b.

C.

d.

e.

by verifying that each containment manual valve or blind flange that is located inside containment and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls. Valves and blind flanges in high radiation areas may be verified by use of administrative controls.

By verifying that each containment air lock is OPERABLE per Specification 3.6.1.3.

Afcer each closing of a penetration subject to Type B testing, except containment air locks, i f opened following a Type A or B test, by leak rate testing in accordance with the Containment Leakage R a t e Testing Program.

At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the surveillance requirements of 4.6.2.3.a are met for penetrations associated with the containment fan coil units.

At least once per 18 months by verifying that the surveillance requirements of 4.6.2.3.d are met for penetrations associated with the containment fan coil units.

SALEX - UNIT 2 314 6-1

CONTAINMENT SYSTEMS CONTAINMENT AIR LOCKS LIMITING CONDITION FOR OPERATION 3.6.1.3 Each containment air lock shall be OPEFSBLE with:

a. Both doors closed except when the air lock is being used for normal transit entry and exit through the containment, then a t least one air lock door shall be closed, and:

b. A n overall air lock leakage rate in accordance with the Containment Leakage Rate Testing Program.

APPLLCABILXTY: MODES 1, 2, 3, and 4 ACTION :

Notes (1) Entry and exit is permissible to perform repairs on the affected air lock components.

( 2 ) Separate condition entry is allowed for each air lock.

( 3 ) Required ACTIONS a.1, a.2, and a.3 are not applicable if both doors in the same air lock are inoperable and condition c. is entered.

( 4 ) Required ACTIONS b.1, b.2, and b.3 are not applicable if both doors in the same air lock are inoperable and condition c. is entered.

( 5 ) Enter applicable Conditions and required Actions of LCO 3.6.1, Primary Containment, when air lock leakage results in exceeding the overall containment leakage rate.

a. One or more containment air locks with one containment airlock door inoperable :

1. Verify the OPERABLE door is closed in the affected air l o c k within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and:

2.

Lock the OPERABLE door closed in the affected air lock within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , and :

3. Verify the OPERABLE door is locked closed in the affected air lock once per 31 days. Entry and exit is permissible for 7 days (from initial LCO entry) under administrative controls if one door is inoperable in each air lock. Air lock doors in high radiation areas may be verified locked closed by administrative means.

b. One or more containment air locks with only the containment air lock interlock mechanism inoperable.

1. Verify an OPERABLE door is closed in the affected air lock within I 2.

Lock an OPERABLE door closed in the affected air lock within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , hour, and:

and :

3.

Verify an OPERABLE door is locked closed in the affected air lock once per 31 days.

control of a dedicated individual for the duration of the entry to ensure only one door is open at a time. Air lock doors in high radiation areas may be verified locked closed by administrative means.

Entry and exit of containment is permissible under the SALEM - UNIT 2 314 6-4 Amendment NO

~ 195

CONTAINMENT SYSTEMS CONTAINMENT AIR LOCKS LIMITING CONDITION FOR OPERATIONS (Continuedl

c. One or more containment air locks inoperable for reasons other than condition a. or b.

1. Immediately initiate action to evaluate overall containment leakage per LCO 3.6.1, and:

2. Verify that at least one door is closed in the affected air lock within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and:

3. Restore the air lock to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

d. If the ACTIONS and associated completion times of a., b., Or c. cannot be met, be in Hot Standby within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in Cold Shutdown within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.6.1.3 Each containment air lock shall be demonstrated OPERABLE:

a. By verifying seal leakage rate in accordance with the Containment Leakage Rate Testing program.

b. By conducting an overall a i r lock leakage test in accordance with the Containment Leakage Rate Testing Program.

c. At least once per 6 months by verifying that only one door in each air lock can be opened at a time.

SALEM - UNIT 2 3 1 4 6-5 Amendment NO. 195

3 / 4. 8 ELECTRICAL POWER SYSTEMS 314.8.1 A.C. SOURCES OPERATING LIMITING CONDITION FOR OPERATION 3.8.1.1 A s a'minimum, the following A.C, electrical power sources shall be OPERABLE:

a.

Two physically independent A.C. circuits between the offsite transmission network and the onsite Class 1E distribution system (vital bus system), and

b.

Three separate and independent diesel generators with:

1. Separate day tanks containing a minimum volume of 130 gallons of fuel, and

2. A common fuel storage system consisting of two storage tanks, each containing a.minimum volume of 23,000 gallons of fuel, and two fuel transfer pumps.

APPLICABILITY: MODES 1, 2, 3 and 4 ACTION:

a.

b.

With an independent A.C. circuit of the above required A.C.

electrical power sources inoperable:

1.

Demonstrate the OPERABILITY of the remaining independent A.C. circuit by performing Surveillance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and 2.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , declare required systems or components with no offsite power available inoperable when a redundant required system or component is inoperable, 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 ; and

3.

Restore the inoperable independent A.C. circuit to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

With one diesel generator of the above required A. C. electrical power sources inoperable:

1.

Demonstrate the OPERABILITY of the independent A.C. cir by performing Surveillance Requirement 4.8.1.1.1.a with hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and

2.

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , declare required systems or components supported by the inoperable diesel generator inoperable a required redundant system or component is inoperable, 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 COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and SALEM - UNIT 2 314 8-1 Amendment No.

uits n l when or n

234

ELECTRICAL POWER SYSTEMS ACT I ON (Continued

)

3.

Determine the two remaining OPERABLE diesel generators are not inoperable due to common cause failure or perform Surveillance Requirement 4.8.1.1.2.a.2 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . If the diesel generator is inoperable for preventive maintenance, the two remaining OPERABLE diesel generators need not be tested nor the OPERABILITY evaluated: and

4.

In any case, restore the inoperable diesel generator to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

c. With one independent A.C. circuit and one diesel generator of the above required A. C. electrical power sources inoperable, demonstrate the OPERABILITY of the remaining independent A. C. circuit by performing Surveillance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; demonstrate the OPEXABILITY of the remaining OPERABLE diesel generators by performing Surveillance Requirement 4.8.1.1.2.a.2 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ; restore at least one of the inoperable sources to OPERABLE status within 1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 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 . Restore at least two independent A.C.

circuits and three diesel generators to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the time of initial loss 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 .

d. With two of the above required independent A.C. circuits inoperable:

1.

2.

3.

4.

Demonstrate the OPERABILITY of three diesel generators by performing Surveillance Requirement 4.8.1.1.2.a.2 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , unless the diesel generators are already operating; and Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , declare required systems or components supported by the inoperable offsite circuits inoperable when a required redundant system or component is inoperable, or be in at least HOT STANDBY within Che next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; and Restore at least one of the inoperable independent A.C. circuits 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 With only one of the independent A. C. circuits OPERABLE, restore the other independent A. C. circuit to OPERABLE status within 7 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months from time of initial loss 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 .

SALEM - UNIT 2 314 a-2 0

Amendment No. 234

ELECTRICAL POWER SYSTEMS ACTION (Continued)

e. With two or more of the above required diesel generators inoperable, demonstrate the OPERABILITY of two independent A. C. circuits by performing Surveillance Requirement 4.8.1.1.1.a within one hour and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; restore at least two of the inoperable diesel generators to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 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 3 0 hours0 days 0 hours 0 weeks 0 months . Restore three diesel. generators to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from time of initial loss ox be i n 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 Che following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

f.

With one of t h e above required fuel transeer pumps inoperable, either restore i t to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

g. With one of the above required fuel storage tanks inoperable, either restore it to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SALEM - UNIT 2 314 8-2a Amendment No. 234

THIS PAGE INTENTIONALLY LEFT BLANK SALEM - W I T 2 3/4 a-2b Amendment No. 234

4.8.1.1.1 Two physically independent A.C. circuits between the offsite transmission network and the onsite Class 1E distribution system (vital bus system) shall be:

a.

Determined OPERABLE a t least once per 7 days by verifying correct breaker alignments, power availability, and transferring {manually and automatically) vital bus supply from one 13/4 kv transformer to the other 13/4 kv transformer.

4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE:

a.

At least once per 31 days on a STAGGERED TEST BASIS by:

b.

Demonstrated OPERABLE at least once per 18 months during shutdown by

1.

2.

Verifying the diesel generator starts from standby conditions* and Verifying the fuel level in its day tank.

achieves 2 3910 volts and 1 5 8. 8 Hz in 5 13 seconds, and subsequently achieves steady state voltage of 1 3 9 1 0 and 5 4400 volts and requency of 60 f 1.2 Hz.

Subsequently, verifying the generator is synchronized with voltage maintained 2 3910 and 5 4580 volts, gradually loaded to 2340-2600 kw**, and operates at a load of 2340-2600 kw for greater than or equal to 60 minutes.

to the associated vital bus.

3.

Verifying the diesel generator is aligned to provide standby power

b.

At least once per 31 days and after each operation of the diesel where the period of operation was greater than or equal to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months by checking f o r and removing accumulated water from the day tanks.

c.

At least once per 6 months by verifying the diesel generator starts from standby conditions* and achieves 1. 3910 volts and 2 58.8 Hz in 5 13 seconds, and subsequently achieves steady state voltage of 2 3910 and

< 4400 volts and frequency of 60 i 1.2 Hz.

The generator shall be synchronized to its emergency bus with voltage maintained 2 3910 and 4580 volts, loaded to 2340-2600** kw in less than or equal to 60 seconds, and operate at a load of 2340-2600 kw for at least 60 minutes.

This test, i f it is performed so it coincides with the testing required by Surveillance Requirement 4.8.1.1.2.a.2, may also serve to concurrently meet those requirements.

SALEM - UNIT 2 314 8-3 Amendment No. 223 1

1.

2.

3.

4.

J.

6.

DZLt TED Qrrirrg tM.0 -at.

ELECTRICAL POWER SYSTEMS c)

Verifying that all nonessential automatic diesel generator trips (i.e., other than engine overspeed, lube oil pressure low, 4 KV Bus differential and generator differential) are automatically bypassed upon loss of voltage on the vital bus.

concurrent with a safety injection actuation signal.

7. Deleted

8. Verifying that the auto-connected loads to each diesel generator do not exceed the two hour rating of 2860 kw.

9. Verifying that with the diesel generator operating in a test mode (connected t o its bus), a simulated safety injection signal overrides the test mode by (1) returning the diesel generator to standby operation and ( 2 ) automatically energizing the emergency loads with offsite power.

e.

f.

9.

At least once per 10 years or after any modifications which could affect diesel generator interdependence by starting all diesel generators simultaneously", during shutdown, and verifying that all diesel generators accelerate to at least 5 8. 8 Hz in less than ox equal to 13 seconds.

I At least once per 18 months, the following test shall be performed within 5 minutes of diesel shutdown after the diesel has operated or a t least two h o u r s at 2340-2600 kw**:

Verifying the diesel generator starts'and achieves Z 3910 volts and 2 58.8 Hz in S 13 seconds, and subsequently achieves steady state voltage of 2 3910 and 5 4 4 0 0 volts and frequency of 60 f 1. 2 Hz.

At least once per 18 months verifying the diesel generator operates for at least 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s*. During the first 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test, the diesel generators shall be loaded to 2760-2860 Kw**. During the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of this test, the diesel generator shall be loaded to 2500-2600 Kw**. The steady state voltage and frequency shall be maintained at 1 3910 and S 4580 volts and 60 f 1.2 Hz during this test.

4. 8. 1. 1. 3 The diesel fuel oil storage and transfer system shall be demonstrated OPERABLE:

a.

At least once per 31 days by:

1.Verifying the level in each of the above required fuel storage tanks 2.Verifying that both fuel transfer pumps can be started and transfer fuel from the fuel storage tanks to the day tanks.

SALEM - UNIT 2 3/4 8-5 Amendment No. 223 I

4.

SALEM - WIT 2 TABLE 4.8-1 DXESEL QENERATOR TEST SCHEDULE NOT USED 314 e-7 Amendment No. 185

e I

THIS PAGE INTENTIONALLY LEFT BLANK I

1

ELECTRICAL POWER SYSTEMS SHUTDOWN LIMITING CONDITION FOR OPERATION 3.8.1.2 As a minimum, the following A.C. electrical power sources shall be OPERABLE :

a. One circuit between the offsite transmission network and the onsite Class 1E distribution system (vital bus system), and

b.

Two separate and independent diesel generators with:

1.

Separate day tanks containing a minimum volume of 130 gallons of fuel, and

2. A common fuel storage system containing a minimum volume of 3.

A fuel transfer pump.

23,000 gallons of fuel, and APPLICABILITY: MODES 5 and 6.

ACTION :

With less than the above minimum required A.C. electrical power sources OPERABLE, suspend all operations involving CORE ALTERATIONS or positive reactivity changes until the minimum required A.C. electrical power sources are restored to OPERABLE status.

SURVEILLANCE REQUIREMENTS

_----------^---I_____l__ll______

NOTE-----------------------------------

The following surveillances are not required to be performed to maintain operability during Modes 5 and 6. These surveillances are: 4.8.l.l,l.b, 4.8.1.1.2.d.2, 4.8.1.1.2.d.3, 4.8.1.1.2.d.4, 4.8.1.1.2.d.6,'4.8.1.1.2.d.9, 4.8.1.1.2.e, 4.8.1.1.2.f, and 4.8.1.1.2g.

4.8.1.2 The above required A.C. electrical power sources shall be demonstiated OPERABLE by tha performance of each of the Surveillance Requirements of 4.8.1.1.1, 4.8.1.1.2, 4.8.1.1.3 (except for requirement 4.8.1.1.3.a.2) and 4. 8. 1. 1. 4.

I.

e SALEM - UNIT 2 3/4 8-7a

ELECTRICAL POWER SYSTEM8 3/4.8.2 ONSITS POWRR DISTRIBUTION SYS-A.C. DISTRIBUTlON - OPERATZNG LIMITING CONDITION FOR OPERATZON 4 kvolt 4 kvolt 4 kvolt 460 volt 460 volt 230 volt 230 volt 230 volt 115 volt 115 vole 115 volt 115 volt 460 volt APPLICABILITY:

mDES 1, 2, 3 aad 4.

ACTION:

0 '

3.8.2.2 As a minimum, two A.C. electrical bus trains shall be OPERABLE and energized from sources of power other than a diesel generator but aligned to an OPERABLE diesel generator with each train conaieting of:

1 -

4 kvolt Vital Bus 1 -

460 volt Vital Bus and associated control centers 1 -

230 volt Vital Bue and associated control centers 1 -

115 volt Instrument BUS energized from i t a respective inverter:

connected to it8 rwpective D.C. Bus Train.

BEpLICABILITy: MODES 5 and 6.

During movement of irradiated fuel asaemblims.

ACTION:

I With lase than the above complement of A.C. bus868 and inverters OPETU\\Bm and energized, suspend all operations involving CORE ALTERATIONS, positive reactivity changes, and movement of irradiated fuel aeeembliaa until the minimum required A.C. electrical power sources are restored to OPERABLE statua.

I 4. 8. 2. 2 The specified A.C. busses and inverters shall be determined OPBRRBLE and Qnergizcd from A.C. source6 other than the diesel generators at least once per 7 days by verffying correct breaJcer alignment and indicated voltage on the busses.

SALEM - UNIT 2 3/4 8-9 Amendment NO. 201

9.0 Hazards - InternaVExternal Refer to Attachment 2 Refer to Attachment 3 SITE AREA EMERGENCY Refer to Attachment 4 GENERAL EMERGENCY Refer to Attachment 24 UNUSUAL EVENT (Common Site)

I 9.1 Security Threats Security Event in a Plant Vital Area Protected Area Security 13vent in a Plant Confirmed Secitrity Event Which Indicates a Potential Degradation in the Level of Safety of the Plant Initiating Condition MODE EAL #

1 I

M I

I R

I I

E l

I E

l E

l G

I N

I Y

I A

I T

I 0

1 c

I I

I 1

I I

I N

l 1,

I E

l V

I L

I I

S I

I Action Required (Ti2 9.1.I IF Confirmed security threat directed toward the station as evidenced by ANY one of the following:

Credible threat of malicious acts or destructive device within the Protected Area resulting in SCP-5 iniplenientation Credible intrusion or assault threat to the Protected Area resulting in SCP-5

. implementation Attempted intrusion or assault to the Protected Area resulting in SCP-7 or SCP-11 implementation Malicious acts attempted or discovered within the Protected Area resulting in SCP-10 implementation normal plant operations resulting in SCP-8 implementation Protected Area resulting in SCP-10 implementation Hostage/Extortion situation that threatens Destructive Device discovered within the THEN ciii-3 9.1.2 IF Confirmed hostile intrusion or malicious acts as evidenced by ANY one of the following:

Discovery of an intruder(s), armed and violent, within the Protected Area resulting in SCP-6 implementation Hostage held on-site in a non-vital area resulting in SCP-8 implementation Malicious acts attempted or discovered within a Vital Area (which is in the Protected Area) resulting in SCP-10 implementation that does not meet criteria of 9. I.3 I THEN Confirmed hostile intrusion or nlalicious acts in Plant Vital Areas that involve actual or likely major failures of dant functions needed for the protection of the public as evidenced by any one of the following:

Discovery of an intruder(s), armed and violent, within the Vital Area resulting in SCP-6 implementation Destructive device discovered in a Vital Area resulting in SCP-10 implementation SGS ECG Rev. 01 Page 1 of 1 Ability to Reach and Maintain Cold (TJ 9.1.4 IF Security event resulting in the actual loss of physical control of EITHER one of the following:

Control Room Remote Shutdown Panel 2 I3 THEN Malicious act(s) attempted or discovered in a Vital Area resulting in SCP-10 implementation AND the malicious act(s) is of a magnitude that it SPECIFICALLY results in Damage to ANY one of the following:

TWO OR MORE Trains of a Safety System MORE THAN ONE Safety System

.Any Plant Vital Structure which renders the structure AND I

incapable of performing its Design Function Damaged Safety System(s) or Plant Vital Structure is required for the present MODE of Operation 1

1

9.0 Hazards - InternaVExternal Valid Fire AIann is received in the Control Room 9.2 Fire Report of a fire from personnel at the scene - __

sos ECCi Rev. OU Pagelor I Initiating Condition MODE EAL # -

E I

M E

R G

E N

C Y

A C

T I

0 N

L E

V E

L S

I I

I 1

I I

1 I

I I

1 Action Required

~

Fire Within the Pratected Area Boundary Not Extingwsbed Within 15 Minutes of Detection Fire Affecting the Operability of Plant

(, -

Safety Systems Required to Establish or Maintain safe S h u t d o 3

)

9.2.1 IF 9.2.1 IF

-. 9

m 9.2.2 IF Fire within ANY one of the following Plant ViIal SLructures:

Auxiliary Building B Scrvice Water Intake Structure Control Point Area

' lnner/Outer Penetration Areas Coiminment Fuel Handling Building Selvice Building

. RWST, PWST, and AFWST Area I AND The Fire is of a magnitude (hat it SPECIFICALLY results in Damage to one of the following:

TWO OR MORE Trains of a Safety System MORE THAN ONE Safety System Any Plant Vital Structure which renders the structure I.

incapable of performing its Design Function AND Dainaged Safety Systenr(s) or Plant Vilal Slructure is required for the present ' MODE -1 of operation c-Refer to Attachment 2 I

ALERT

9.0 Hazards - InternaUExternal 9.3 Explosion

,.SI..

SGS ECG Rtv. uu Page I uf I THEN t

Initiating Condition The Explosion is of a magnitude that it SPECIFICALLY results in Damage to ANy one of the following:

1 MODE FAL #

I I

I E

l I

V I

Action Required Phenomena Affecting the Protected Area 9.3.1 -

CaaCirncd Erplo~ioa within the hotccled Area Report of visible damage to Plant equipment or to Protected Area Permanent Plant Structures 9. A Explosion Affecting the Operability of Plant Safety Systems Required to Establish or Maintain safe Shutdown c!!!!.J 9.3.2 IF Confirmed Explosion within ANy one of the following Plant Vital Structures:

Auxiliary Building Sefvice Water Intake Svudure Control Point Area Inner/Outer Penetration Areas Containment Fuel Handling Building Sefvlce Building RWST, PWST, and AFWST Area I AND TWO OR MORE Trains ofa Safety System MORE THAN ONE Safety System Any Plant Vital Structure which renders lhe structure incapable of performing its Design Function I

-1 AND I -

I Dariraged Safety System(s) or Plant Vital Structure

. is ____

required for the present MODE of operation

- I

pGr I

I I

I Refer to Attachment 2 I I

ALERT I

I

Initiating Condition MODE EAL #

I I -

E l

G I

N I

Y I

I I

A I

I T

I M I I

R I

C t

C I

Action Required 9.0 Hazards - InternaUExternal 9.4 ToxidFlammable Gases SGS ECG Rev. OU P q e lof 2 Release of Toxic or Flammable Gases Deemed Detrimental to Safe Operation of the Plant 9 4 1 a IF Notification by Local, County, or State Officials for the potential need to EVACUATE non-essential personnel due to an Offsite Toxic Gas release I-AND SNSS deems evacuation of non-essential personnel is required I-THEN 9.4.1.b 9.4.1.c IF IF 1 I I

Uircoritrolled Toxic Cas release within the Protected Area in ANY area which does not normally require an atmospheric survey or Respiratory Protection for entry Uncontrolled Flammable Gas release within the Protected Area that RESULTS in Flammable Gas concentrations EXCEEDING 25% of the LEL Routine Plant Operations are IMPEDED based on EITHER one of the following:

Access restrictions caused by the uncontrolled release Personnel injuries have occurred as a result of the release 1

I THEN UNUSUAL EVENT (Common Site)

-I___--_

1 Refer to Attachment 1 UNUSUAL EVENT __-

Initiating Condition MODE EAL #

I I

I E

M I I

E l

R I

I G

I E

l I

N I

Y I

A I

T I

0 1

c l

C I

I I

I N

l L

1 V

I L

r E

l I

S I

I Action Required SGS ECG 9.0 Hazards - InternaVExternal 9.4 Toxic/Flammable Gases Rev 00 P.gc1oTl Release of Toxic or Flammable Gases Within a Facility Structure Which Jeopardizes Operation of Systems Required to Maintain Safe Operations or to Establish or Maintain Cold Shutdown Conditions 0

9.4.2.a IF Uncontrolled Toric Gas release within ANY one of the following Plant Vital Structures Auxilary Building Service Water Intake Structure Control Point Area Inner/Outer Penetration Area Containment Fuel Handling Building RWST, PWST, and AFWST Area AND

.. a L > -

Service Building

a.

..V.,.,.

I..\\..

~

Toxic,Gasconcentrations result in AtNY.ona of the-following:.

1 An IDLH atmosphere Plant personnel report severe adverse health reactions, The Threshold Limit Value (TLV) being EXCEEDED including burning eyes, nose, throat, dizziness 9.4.2.b IF Uncontrolled Flammable Gas release within ANY one of the following Plant Vital Structures:

Auxilary Building Service Water Intake Structure Control Point Area Inner/Outer Penetration Area Containment Fuel Handling Building Service Building RWST, PWST, and AFWST Area

. -... I..

I AND

. I >.

Flammable Gas concentrations EXCEED 500/. O f the LEL

Initiating Condition AND pp.---p_--

MODE EAL#

Valid Actuation of the Hope Creek Seismic Switch (> 0.lg) has occurred as verified by The Hope Creek SNSS I

R I

I G

I N

I Y

I I

I A

I I

C I

T I

I I

0 1

I N

I I

I L

I E

l C

I V

I

- S I

L I

Action Required 9.5.l.a Seismic Event felt by personnel within the Protected Area 9.0 Hazards - InternaVExternal 9.5 Seismic Event Natural and Destructive Phenomena Mating the Protected Area --

E) 9 5 1 b

Valid Actuation of the Seismic Trigger (> 0.01s) has occurred as verified by the SMA-3 Event Indicator (flag)

I

' 1 Natural and Destructive Phenomena Mecting the Plant Vital Area SGS ECG Rev. 00 P q c l d l being WHITE on Seismic Monitor System cabinet in the #1 CR Equipment Room

~

.........I- ".

9.5.2 I

I A

- -. -..- - __ 4 UNUSUAL EVENT (Common Site)

/

I THEN

+

Refer to Attachment 2 ALERT

Initiating Condition MODE EAL#

1 I

I I

1 I

I I

1 I

I I

1 I

I I

E M

E R

G E

N C

Y A

C T

I 0

N L

E V

E L

S Action Required 9.0 Hazards - InternaVExternal 9.6 High Winds SOS ECO Rev. 00 P q C I d l 1

)

(

Natuml and DesUuctive Phenomena Affixling the Plan1 Vital Area J

~

Report of a Tornado TOUCHING DOWN within the Protected Area I

All -

9.6.1.b IF Sustained wind speeds

> 75 MPH for 15 minutes, from ANY elevation of the Met Tower UNUSUAL EVENT (Common Site) 9.6.2 The Wind Speed is of a magnitude that it SPECIFICALLY results in Damage to ANY of the following:

TWO OR MORE Trains of a Safety System MORE THAN ONE Safety System Rendering ANY of the following structures incapable of performing its Design Function:

- * 'a. '* Auxiliary Building 4

q

..'. -*, Service Water Intake Structure

Control Point Area

Inner/Outer Penetration Areas

Containment

Fuel Handling Building

Service Building

RWST, PWST,and AFWST Area I AND S

I Damaged Safety System(s) or Plant Vital Structure is required for the present MODE of operation 1

- -~

THEN Refer to Attachment 2

Initiating Condition MODE EAL #

R I

C f

C I

G I

N I

Y I

I I

A I

T I

I 0

1 I

I 1

E l

I N

I L

I V

I L

I S

I I

Action Required 9.0 Hazards - InternaVExternal Internal Flooding in Excess of Sump Handling Capability Alidng Safety 8.7.1 IF Severe Flooding of Safety System Areas S ENDANGERED safety related equipment per OP-AB.zz-0002 THEN

', 4,

Refer to Attachment 1 UNUSUAL EVENT 9.1 Flooding SGS ECG Rev. 00 P. g e 1 6 1 Internal Flooding Afiating the Operability of Plant Safety Systems Required to Establish or Mainrain safe Shutdown Visual Observation of Flooding within ANY one of the following Plant Vital Structures:

Auxiliary Building Service Water Intake Structure Fuel Handling Building Service Building Containment The Flooding is of a magnitude that it SPECIFICALLY results in Damage to ANY one of the following:

TWO OR MORE Trains of a Safety Syetem MORE THAN ONE Safety System Any of the above listed Plant Vital Structures which renders the structure incapable of performing its Design Function is required for the present MODE of operation Refer to Attachment 2

Initiating Condition MODE EAL #

I I

M I I

R I

I E

l E

l G

I N

I Y

r I

I A

I T

I I

0 1 I

I I

E l

C I

1 N

I L

I V

I S

t L

I Action Required 9.0 Hazards - InternaVExternal 9.8 Turbine Failure / Vehicle Crash / Missile Impact SGS EC(i Rev. 00 PqCIofI Natural and Destructive Phenomena Afiiiling Cerlain Structures Wilhin the Prolected Area w

9.8.1.a IF Catastrophic damage to the Main Turbine as evidenced by EITHER one of the following:

Main Turbine casing penetration Main TurbindGenerator Damage potentially releasing Lube Oil or Hydrogen Gas to the Turbine Building 9.8.1.b IF Vehicle Crash / Missile Impact with or within ANY one of the following Plant Vital Structures:

1 Auxiliary Building Service Water Intake Structure Inner/Outer Penetration Areas Containment Fuel Handling Building 1

Refer to Attachment I UNUSUAL EVENT 0

9.8.2

?

The Vehicle Crash / Missile Impact is of a

'magnitude that it SPEClFICALLY results in Damage to ANY one of the following:

".,,,T.WO OR MORE Trains of a Safety System MORE THAN ONE Safety System Any of the above Plant Vital Structures which renders the structure incapable of performing its Design Function AND Damaged Safety System(s) or Plant Vital Structure is required for the present MODE of operation THEN Refer to Attachment 2 ALERT

Initiating Condition MODE PAL # I I

I E

M I I

I E

l I

I E

l Y

I N

I c

l I

I A

I C

I T

I I

0 1 I

N I

I I

I L

I V

I L

I I

I S

I 1

Action Required 9.0 Hazards - InternaVExternal 9.9 River Level Natural and Destructive Phenomena Mwting the Protected Area (37)

CKI 9.9.1.a IF I

I River Level > 99.5' t

9.9.1.b IF River Level < 80.0' THEN SOS ECG Rev. 00 PwId I i

i 0

Refer to Attachment 24 UNUSUAL EVENT

- - - -..- __

ML032690865

Text

Dear Mr. Fish,

3.5 Printed

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