ML22143B003

RO and SRO Exam Reference Handouts

ML22143B003
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Site:	Duane Arnold
Issue date:	04/08/2019
From:	Randy Baker NRC/RGN-III/DRS/OLB
To:	NextEra Energy Duane Arnold
Baker R
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ML17214A863	List: ML22143A999 ML22143B000 ML22143B001 ML22143B002 ML22143B003
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Text

RO

Reference

Handouts

FIGURE #17: EHC LOGIC CONTROL SYSTEM

Rev. 7 SD-693.2a SD-693-2a.docx EHC Logic System SRO

Reference

Handouts MCPR 3.2.2

3.2 POWER DISTRIBUTION LIMITS

3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY: THERMAL POWER 21.7% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Any MCPR not within A.1 Restore MCPR(s) to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limits. within limits.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to 21.7%

Time not met. RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

SR 3.2.2.1 Verify all MCPRs are greater than or equal toOnce within the limits specified in the COLR. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after 21.7% RTP

AND

In accordance with the Surveillance Frequency Control Program

(continued)

DAEC 3.2-2 Amendment 280 Main Turbine Bypass System 3.7.7

3.7 PLANT SYSTEMS 3.7.7 The Main Turbine Bypass System

LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE.

OR

LCO 3.2.2, MINIMUM CRITICALPOWER RATIO (MCPR), limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.

APPLICABILITY: THERMAL POWER 21.7% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> LCO not met. requirements of the LCO.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to 21.7%

Time not met. RTP.

DAEC 3.7-16 Amendment 243 Reactor Steam Dome Pressure 3.4.10

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.10 Reactor Steam Dome Pressure

LCO 3.4.10 The reactor steam dome pressure shall be 1025 psig.

APPLICABILITY: MODES 1 and 2.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Reactor steam dome A.1 Restore reactor steam15 minutes pressure not within limit. dome pressure to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.10.1 Verify reactor steam dome pressure is 1025In accordance with the psig. Surveillance Frequency Control Program

DAEC 3.4-25 Amendment 280 ECCS Operating 3.5.1

3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM

3.5.1 ECCS Operating

LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of four safety/relief valves shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3, except High Pressure Coolant Injection (HPCI) is not required to be OPERABLE with reactor steam dome pressure 150 psig and ADS valves are not required to be OPERABLE with reactor steam dome pressure 100 psig.

ACTIONS

---

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

LCO 3.0.4.b is not applicable to HPCI.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One Residual Heat A.1 Restore RHR pump to 30 Days Removal (RHR) pump OPERABLE status.

inoperable.

B. One low pressure ECCS B.1 Restore low pressure 7 days subsystem inoperable for ECCS subsystem to reasons other than OPERABLE status.

Condition A.

C. One Core Spray C.1 Restore Core Spray 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> subsystem inoperable. subsystem to AND OPERABLE status.

One or two RHR OR pump(s) inoperable. C.2 Restore RHR pump(s) 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to OPERABLE status.

D. Both Core Spray D.1 Restore one Core 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> subsystems inoperable. Spray subsystem to OPERABLE status.

(continued)

DAEC 3.5-1 Amendment 305 ECCS Operating 3.5.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, B,AND C, or D not met. E.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />

F. HPCI System F.1 Verify by Immediately inoperable. administrative means RCIC System is OPERABLE.

AND F.2 Restore HPCI 14 days System to OPERABLE status.

G. HPCI System G.1 Restore HPCI 7 days inoperable. System to OPERABLE status.

AND OR One RHR pump inoperable. G.2 Restore RHR pump 7 days to OPERABLE status.

H. HPCI System H.1 Restore HPCI 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. System to AND OPERABLE status.

One low pressure OR ECCS subsystem is H.2 Restore low pressure 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable for reasons ECCS subsystem to other than Condition A. OPERABLE status.

I. HPCI System I.1 Restore HPCI 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. System to AND OPERABLE status.

One ADS valve OR inoperable. I.2 Restore ADS valve to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

(continued)

DAEC 3.5-2 Amendment 223 ECCS Operating 3.5.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

J. Required Action and J.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition F, G,AND H, or I not met. J.2 Reduce reactor steam 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> dome pressure to 150 psig.

K. One ADS valve K.1 Restore ADS valve to 30 days inoperable. OPERABLE status.

L. One ADS valve L.1 Restore ADS valve to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. OPERABLE status.

AND OR

One low pressure L.2 Restore low pressure 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> ECCS subsystem ECCS subsystem to inoperable for reasons OPERABLE status.

other than Condition A.

M. Two or more ADS M.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> valves inoperable.

OR AND Required Action and M.2 Reduce reactor steam 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> associated Completion dome pressure to Time of Condition K or L 100 psig.

not met.

(continued)

DAEC 3.5-3 Amendment 223 ECCS Operating 3.5.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

N. Two or more low N.1 Enter LCO 3.0.3. Immediately pressure ECCS subsystems inoperable for reasons other than Condition C or D.

OR HPCI System and two or more ADS valves inoperable.

OR HPCI System and two or more low pressure ECCS subsystems inoperable.

OR One ADS valve and two or more low pressure ECCS subsystems inoperable.

OR One ADS valve and HPCI System and one low pressure ECCS subsystem inoperable.

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.5.1.1 Verify, for each ECCS injection/spray In accordance with the subsystem, locations susceptible to gasSurveillance accumulation are sufficiently filled withFrequency Control water. Program

(continued)

DAEC 3.5-4 Amendment 290 Drywell Spray System T 3.5.1

T 3.5 DRYWELL SPRAY SYSTEM AND ES COMPARTMENT COOLING AND VENTILATION

T 3.5.1 Drywell Spray System

TLCO 3.5.1 Two Residual Heat Removal (RHR) drywell spray subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2 and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One RHR drywell spray A.1 Restore RHR drywell 30 days subsystem inoperable. spray subsystem to OPERABLE status.

B. Both RHR drywell spray B.1 Restore at least one 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> subsystems inoperable. RHR drywell spray subsystem to OPERABLE status.

C. Required Action and C.1 Initiate a Corrective Immediately associated Completion Action Program (CAP)

Time of Condition A or document to determine B not met. cause(s) and corrective action(s).

AND

C.2 Obtain Plant Manager 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or designee approval for plans to restore RHR drywell spray subsystem(s) to OPERABLE status.

DAEC 3.5-1 TRMCR-026 Drywell Spray System T 3.5.1

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

TSR 3.5.1.1 Verify the drywell spray spargers are 60 months unobstructed by performing an air test on the drywell spray headers and nozzles.

DAEC 3.5-2 Revision 0 ESW System 3.7.3

3.7 PLANT SYSTEMS 3.7.3 Emergency Service Water (ESW) System

LCO 3.7.3 Two ESW subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME A. One ESW -------------NOTES--------------

subsystem 1. Enter applicable Conditions inoperable. and Required Actions of LCO 3.8.1, AC Sources-Operating, for diesel generator made inoperable by ESW System.

2. Enter applicable Conditions and Required Actions of LCO 3.4.7, Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown, for RHR shutdown cooling made inoperable by ESW System.

A.1 Restore the ESW 7 days subsystem to OPERABLE status.

B. Required Action B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and Associated Completion Time AND of Condition A not met. B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR

Both ESW subsystems inoperable.

DAEC 3.7-5 Amendment 223 ESW System 3.7.3

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.3.1 -------------------------NOTE--------------------------

Isolation of flow to individual components does not render ESW System inoperable.

Verify each ESW subsystem power operated In accordance with and automatic valve in the flow paths the Surveillance servicing safety related systems or Frequency Control components, that is not locked, sealed, or Program otherwise secured in position, is in the correct position.

SR 3.7.3.2 Verify each ESW subsystem actuates on an In accordance with actual or simulated initiation signal. the Surveillance Frequency Control Program

DAEC 3.7-6 Amendment 280 Main Turbine Bypass System 3.7.7

3.7 PLANT SYSTEMS 3.7.7 The Main Turbine Bypass System

LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE.

OR

LCO 3.2.2, MINIMUM CRITICAL POWER RATIO (MCPR), limits for an inoperable Main Turbine Bypass System, as specified in the COLR, are made applicable.

APPLICABILITY: THERMAL POWER 21.7% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the A.1 Satisfy the 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> LCO not met. requirements of the LCO.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> associated Completion POWER to < 21.7%

Time not met. RTP.

DAEC 3.7-16 Amendment 243 Main Turbine Bypass System 3.7.7

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.7.1 Verify one complete cycle of each main In accordance with turbine bypass valve. the Surveillance Frequency Control Program

SR 3.7.7.2 Perform a system functional test. In accordance with the Surveillance Frequency Control Program

SR 3.7.7.3 Verify the TURBINE BYPASS SYSTEM In accordance with RESPONSE TIME is within limits. the Surveillance Frequency Control Program

DAEC 3.7-17 Amendment 280 AC Sources Operating 3.8.1

3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources Operating

LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System; and

b. Two diesel generators (DGs).

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

---

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

LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One offsite circuit A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. OPERABLE offsite circuit. AND

Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter AND

A.2 Restore offsite circuit Prior to entering to OPERABLE status. MODE 2 from MODE 3 or 4 (continued)

DAEC 3.8-1 AMD 255 AC Sources Operating 3.8.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. One DG inoperable. B.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OPERABLE offsite circuit(s). AND

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND

B.2 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from feature(s), supported discovery of by the inoperable DG, Condition B inoperable when the concurrent with redundant required inoperability of feature(s) are redundant required inoperable. feature(s)

AND (continued)

DAEC 3.8-2 Amendment 223 AC Sources Operating 3.8.1

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

B. (continued) B.3 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG is not inoperable due to common cause failure.

AND

---

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

Not required to be performed when the cause of the inoperable DG is pre-planned, preventive maintenance and testing.

B.4 Perform SR 3.8.1.2 for OPERABLE DG. Once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND

B.5 Restore DG to OPERABLE status. 7 days

AND

8 days from discovery of failure to meet LCO expect for Condition A

C. Two offsite circuits C.1 Declare required 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from inoperable. feature(s) inoperable discovery of Condition when the redundant C concurrent with required feature(s) are inoperability of inoperable. redundant required feature(s)

(continued)

DAEC 3.8-3 Amendment 270 AC Sources Operating 3.8.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

AND

C. (continued) C.2 Restore one offsite 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> circuit to OPERABLE status. AND

8 days from discovery of failure to meet LCO except for Condition A

D. Two DGs inoperable. D.1 Restore one DG to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Associated Completion Time of AND Condition A, B, C, or D not met. E.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />

F. Three or more AC F.1 Enter LCO 3.0.3. Immediately sources inoperable.

DAEC 3.8-4 Amendment 270 AC Sources Operating 3.8.1

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.1.1 Verify correct breaker alignment and indicated In accordance with power availability for each offsite circuit. the Surveillance Frequency Control Program

SR 3.8.1.2 ------------------------NOTES-----------------------------

1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

3. When a DG is placed in an inoperable status solely for the performance of testing required by Required Actions B.3 or B.4, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

Verify each DG starts from standby conditions In accordance with and achieves steady state voltage 3744v the Surveillance and 4576v and frequency 59.5Hz and Frequency Control 60.5Hz. Program

(continued)

DAEC 3.8-5 Amendment 280 AC Sources Operating 3.8.1

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.1.3 -------------------------NOTES----------------------------

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded In accordance with and operates for 60 minutes at a load the Surveillance 2750kw and 2950kw. Frequency Control Program

SR 3.8.1.4 Verify each tank contains 220 gal of fuel oil. In accordance with the Surveillance Frequency Control Program

SR 3.8.1.5 Check for the presence of water in the fuel oil in In accordance with each day tank and remove water as necessary. the Surveillance Frequency Control Program

(continued)

DAEC 3.8-6 Amendment 280 AC Sources Operating 3.8.1

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.1.6 Verify the fuel oil transfer system operates to In accordance with transfer fuel oil from storage tank to the day the Surveillance tank. Frequency Control Program

SR 3.8.1.7 -------------------------NOTE------------------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby condition In accordance with and achieves: the Surveillance Frequency Control

a. in 10 seconds, voltage 3744V and Program frequency 59.5Hz; and

b. steady state, voltage 3744V and 4576V and frequency 59.5Hz and 60.5Hz.

SR 3.8.1.8 ----------------------------NOTE----------------------------

The Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify automatic slow transfer of AC power In accordance with supply from the Startup Transformer to the the Surveillance Standby Transformer. Frequency Control Program

(continued)

DAEC 3.8-7 Amendment 280 AC Sources Operating 3.8.1

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.1.9 ----------------------------NOTE---------------------------

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG rejects a load greater than or In accordance equal to its associated single largest post-with the accident load, and: Surveillance

a. Following load rejection, the frequency is Frequency 64.5Hz. Control Program

b. Within 1.3 seconds following load rejection, the voltage is 3744V and 4576V.

c. Within 3.9 seconds following load rejection, the frequency is 59.5Hz and 60.5Hz.

SR 3.8.1.10 ----------------------------NOTE---------------------------

This Surveillance shall not be performed in MODE 1, 2 or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DGs automatic trips are bypassed In accordance on an actual or simulated Loss of Offsite Power with the (LOOP) signal or on an actual or simulated Surveillance ECCS initiation signal except: Frequency

a. Engine overspeed; and Control Program

b. Generator lockout.

(continued)

DAEC 3.8-8 Amendment 280 AC Sources Operating 3.8.1

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.1.11 -----------------------------NOTE--------------------------------

This Surveillance shall not be performed in MODE 1, 2 or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify under manual control each DG: In accordance

a. Synchronizes with offsite power source with the while loaded with emergency loads upon a Surveillance simulated restoration of offsite power; Frequency Control Program

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

SR 3.8.1.12 -----------------------NOTE-----------------------------------

This Surveillance shall not be performed in MODE 1, 2 or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced load In accordance block is 2 seconds. with the Surveillance Frequency Control Program

(continued)

DAEC 3.8-9 Amendment 280 AC Sources Operating 3.8.1

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.1.13 -------------------------NOTES---------------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify, on an actual or simulated loss of offsite In accordance with power signal in conjunction with an actual or the Surveillance simulated ECCS initiation signal: Frequency Control

a. De-energization of essential buses; Program

b. Load shedding from essential buses; and

c. DG auto-start from standby condition and:

1. energizes permanently connected loads in 10 seconds,

2. energizes auto-connected emergency loads in the proper timed sequence,

3. achieves steady state voltage 3744V and 4576V,

4. achieves steady state frequency 59.5Hz and 60.5Hz, and

5. supplies permanently connected and auto-connected emergency loads for 5 minutes.

DAEC 3.8-10 Amendment 280 DC Sources Operating 3.8.4

3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources Operating

LCO 3.8.4 Both Division 1 and Division 2 125 VDC electrical power subsystems and the 250 VDC electrical power subsystem shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One 125 VDC electrical A.1 Restore 125 VDC 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> power subsystem electrical power inoperable. subsystem to OPERABLE status.

OR NOTE: May be used on a A.2.1 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of one-time-only basis for feature(s), supported by Condition A concurrent with each batter y division. the inoperable 125 VDC inoperability of redundant source, inoperable required feature(s).

when the redundant required feature(s) are inoperable.

AND

A.2.2 Restore 125 VDC 10 days electrical power subsystem to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> Associated Completion Time of Condition A not AND met.

B.2. Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />

C. 250 VDC electrical power C.1 Declare associated Immediately subsystem inoperable. supported features inoperable.

D. Two or more DC electrical D.1 Enter LCO 3.0.3. Immediately power subsystems inoperable.

DAEC 3.8-17 Amendment No. 247 DC Sources Operating 3.8.4

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.4.1 Verify battery terminal voltage is 130.5 V on In accordance with float charge for the 125 VDC battery and the Surveillance 252 V for the 250 VDC battery. Frequency Control Program

SR 3.8.4.2 Verify no visible corrosion at battery terminals In accordance with and connectors. the Surveillance Frequency Control OR Program

Verify battery connection resistance within limits.

SR 3.8.4.3 Verify battery cells, cell plates, and racks show In accordance with no visual indication of physical damage or the Surveillance abnormal deterioration that could degrade Frequency Control battery performance. Program

SR 3.8.4.4 Remove visible corrosion and verify battery cell to In accordance with cell and terminal connections are coated with the Surveillance anti-corrosion material. Frequency Control Program

SR 3.8.4.5 Verify battery connection resistance wi thin limits. In accordance with the Surveillance Frequency Control Program

(continued)

DAEC 3.8-18 Amendment 289 DC Sources Operating 3.8.4

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

---

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

This Surveillance shall not be performed on the required battery chargers in MODE 1, 2 or 3.

However, credit may be taken for unplanned events that satisfy this SR.

SR 3.8.4.6 Verify each required battery charger supplies In accordance with 293 amps at 132.5 V for the 125 VDC the Surveillance subsystem and 200 amps at 258 V for the Frequency Control 250 VDC subsystem. Program

SR 3.8.4.7 --------------------------NOTES -----------------------------

1. The modified performance discharge t est in SR 3.8.4.8 may be performed in lieu of the service test in SR 3.8.4.7.

2. This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, In accordance with and maintain in OPERABLE status, the Surveillance the required emergency loads for the design Frequency Control duty cycle when subjected to a battery service Program test.

(continued)

DAEC 3.8-19 Amendment 289 DC Sources Operating 3.8.4

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.4.8 ---------------------------NOTE ----------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is 80% of the In accordance with manufacturers rating when subjected to a the Surveillance performance discharge test or a modified Frequency Control performance discharge test. Program

AND

12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturers rating

AND

24 months when battery has reached 85% of the expected lif e with capacity 100% of manufacturers rating

DAEC 3.8-20 Amendment 280 Distribution Systems Operating 3.8.7

3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Distribution Systems Operating

LCO 3.8.7 The following AC and DC electrical power distribution subsystems shall be OPERABLE:

a. Division 1 and Division 2 AC electrical power distribution subsystems;

b. Division 1 and Division 2 125 VDC electrical power distribution subsystems;

c. 250 VDC electrical power distribution subsystem;

d. Intake structure electrical power distribution subsystems; and

e. 125 VDC RCIC Motor Control Center (MCC).

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more AC A.1 Restore AC electrical 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> electrical power power distribution distribution subsystems to AND subsystems OPERABLE status.

inoperable, except for 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from the intake structure discovery of electrical power failure to meet distribution LCO 3.8.7.a or b subsystems.

B. One or more essential B.1 Restore the 125 VDC 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 125 VDC electrical electrical power power distribution distribution AND subsystems inoperable subsystems to except for the RCIC OPERABLE status. 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from MCC. discovery of failure to meet LCO 3.8.7.a or b

(continued)

DAEC 3.8-27 Amendment 223 Distribution Systems Operating 3.8.7

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of AND Condition A or B not met. C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />

D. One or both intake D.1 Declare the Immediately structure electrical associated River power distribution Water Supply subsystem(s) subsystem(s) inoperable. inoperable.

E. 250 VDC electrical E.1 Declare associated Immediately power distribution supported features subsystem inoperable. inoperable.

F. 125 VDC RCIC MCC F.1 Declare associated Immediately inoperable. supported features inoperable.

G. Two or more electrical G.1 Enter LCO 3.0.3. Immediately power distribution subsystems inoperable that result in a loss of function, for reasons other than Condition D.

DAEC 3.8-28 Amendment 223 Distribution Systems Operating 3.8.7

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.7.1 Verify correct breaker alignments and In accordance with indicated power availability to required AC the Surveillance and DC electrical power distribution Frequency Control subsystems. Program

SR 3.8.7.2 Verify proper coordination of the LPCI Swing In accordance with Bus circuit breakers. the Surveillance Frequency Control Program

DAEC 3.8-29 Amendment 280 DAEC EOP BASES DOCUMENT BASES-EOP 2 Rev. 16 EOP 2 -PRIMARY CONTAINMENT CONTROL Page 41 of69 GUIDELINE

Drywell Spray InitiationLimit 400

350 Donotinitiatedrywell spraysinshadedarea

300

250

200

150

100

50

0 0 2 4 6 8 10 12 14 16 18 20 Drywell Pressure (psig)

DAEC EOP BASES DOCUMENT BASES-ATWS Rev. 19 ATWS -RPV CONTROL Page 62 of96

DISCUSSION - 2nd CRS

The Heat Capacity Limit (See Graph 4) is defined to be the highest torus temperature at which initiation of RPV depressurization will not result in exceeding the Primary Containment Pressure Limit (the PCPL is 53 psig at the DAEC) before the rate of energy transfer from the RPV to the primary containment is within the capacity of the containment vent. Refer to the Curves & Limits EOP Bases Document for a detailed discussion of the Heat Capacity Limit.

Heat Capacity Limit 240

230

220 Action is required

210

200

190

180

170

160

150 Bounding curve for torus levels 140 between8ft and13ft

130

120 0 100200300400 500600700800 90010001100 RPV Pressure(psig)

Control of torus temperature relative to the Heat Capacity Limit is directed in the Primary Containment Control Guideline, EOP 2. If the actions being taken in EOP 2 to preserve torus heat capacity are inadequate or not effective, RPV pressure may be reduced to provide additional margin to the Heat Capacity Limit. Full depressurization, however, may result in loss of steam-driven injection systems. RPV depressurization to mitigate primary containment challenges must therefore be coordinated with core cooling strategies.Full depressurization is appropriate only if adequate core cooling will not be sacrificed as a result.Loss of adequate core cooling would compound containment challenges and increase any resulting radioactivity release. Core cooling is thus prioritized over other EOP objectives.If, at any time during RPV depressurization, it is anticipated that continued pressure reduction will result in loss of injection flow required for adequate core cooling, the depressurization should be terminated. Pressure should be reduced as low as possible to minimize containment challenges but maintained above the maximum value at which the required injection flow can be sustained.

DAEC EOP BASES DOCUMENT BASES-EOP 3 Rev. 13 EOP 3 - SECONDARY CONTAINMENT CONTROL Page 6 of 29 GUIDELINE

Table 6 Secondary Containment Limits

Max Normal Max Safe Parameter and Areas Operating Operating Value/Trend Limit Limit Area/Location Indicator °F °F

A RHR SE Corner Room Area RHR SE CORNER ROOM AMBIENT TR/TDR 2000A Ch 1 130 140 RHR SE CORNER ROOM DIFFERENTIAL TR/TDR 2000A Ch 2 50 N/A

B RHR NW Corner Room Area RHR NW CORNER ROOM AMBIENT TR/TDR 2000B Ch 1 130 140 RHR NW CORNER ROOM DIFFERENTIAL TR/TDR 2000B Ch 2 50 N/A

HPCI Room Area HPCI EMER COOLER AMBIENT TR/TDR 2225A[B] Ch 1 175 310 HPCI ROOM AMBIENT TR/TDR 2225A Ch 2 175 310 HPCI ROOMDIFFERENTIAL TR/TDR 2225A[B] Ch 4[3] 50 N/A

RCIC Room Area RCIC EMER COOLER AMBIENT TR/TDR 2425A[B] Ch 1 175 300 RCIC ROOM AMBIENT TR/TDR 2425A Ch 2 175 300 RCIC ROOM DIFFERENTIAL TR/TDR 2425A[B] Ch 4 50 N/A

Torus Area TORUS CATWALK NORTH AMBIENT TR/TDR 2425A Ch 3 150 165 TORUS CATWALK WEST AMBIENT TR/TDR 2425B Ch 2 150 165 TORUS CATWALK SOUTH AMBIENT TR/TDR 2225A Ch 3 150 165 TORUS CATWALK EAST AMBIENT TR/TDR 2225B Ch 2 150 165 TORUS CATWALK EAST DIFF TR/TDR 2425A Ch 5 50 N/A TORUS CATWALK WEST DIFF TR/TDR 2425B Ch 5 50 N/A TORUS CATWALK SOUTHWEST DIFF TR/TDR 2225A Ch 5 50 N/A TORUS CATWALK SOUTH DIFF TR/TDR 2225B Ch 4 50 N/A

RWCU PUMP ROOM AMBIENT TR/TDR 2700A[B] Ch 1 130 212 RWCU HX ROOM AMBIENT TR/TDR 2700A[B] Ch 2,3 130 212

RWCU ABOVE TIP ROOM AMBIENT TR/TDR 2700A[B] Ch 4,5 111.5 150

Steam Tunnel Area STEAM TUNNEL AMBIENT TR/TDR 2425BCh 3 160 300 STEAM TUNNEL DIFFERENTIAL TR/TDR 2225B Ch 5 70 N/A

Area/Location Indicator mR/hr mR/hr

RB RAILROAD ACCESS AREA RI 9167 10 100 SOUTH CRD MODULE AREA RI 9169 10 100 TIP ROOM RI 9176 60 600

NORTH CRD MODULE RI 9168 10 100 CRD REPAIR ROOM RI 9170 15 150

RWCU SPENT RESIN ROOM RI 9173 100 103 RWCU PHASE SEP TANK RI 9177 20 200

3 4 RWCU PUMP ROOM RI 9156 10 10 3 4 RWCU HX ROOM RI 9157 10 10

Area MAIN PLANT EXHAUST FAN ROOM RI 9171 60 600 JUNGLE ROOM RI 9155 60 600

Refuel Floor AreaNEW FUEL VAULT AREA RI 9153 10 100

NORTH REFUEL FLOOR RI 9163 10 100 SOUTH REFUEL FLOOR RI 9164 10 100 3

SPENT FUEL POOL AREA RI 9178 100 10

Area/Location Indicator inches inches

HPCI ROOM LI 3768 2 6

RCIC ROOM LI 3769 3 6

LI 3770 2 10

LI 3771 2 10

TORUS AREA LI 3772 2 12 DAEC EOP BASES DOCUMENT BASES-CURVES Rev. 16

EOP CURVES AND LIMITS Page 60of80

Figure19: RHR NPSH Limit DAEC EOP BASES DOCUMENT BASES-CURVES Rev. 16

EOP CURVES AND LIMITS Page 66of80

Figure23: RHR Vortex Limit