ML22143B003

RO and SRO Exam Reference Handouts

ML22143B003
Person / Time
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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Download: ML22143B003 (42)

Text

RO Reference Handouts

Rev. 7 SD-693.2a SD-693-2a.docx EHC Logic System FIGURE #17: EHC LOGIC CONTROL SYSTEM

SRO Reference Handouts

MCPR 3.2.2 DAEC 3.2-2 Amendment 280 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 limits.

A.1 Restore MCPR(s) to within limits.

2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> B.

Required Action and associated Completion Time not met.

B.1 Reduce THERMAL POWER to 21.7%

RTP.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to the limits specified in the COLR.

Once within 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)

Main Turbine Bypass System 3.7.7 DAEC 3.7-16 Amendment 243 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 LCO not met.

A.1 Satisfy the requirements of the LCO.

2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> B.

Required Action and associated Completion Time not met.

B.1 Reduce THERMAL POWER to 21.7%

RTP.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />

Reactor Steam Dome Pressure 3.4.10 DAEC 3.4-25 Amendment 280 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 pressure not within limit.

A.1 Restore reactor steam dome pressure to within limit.

15 minutes B.

Required Action and associated Completion Time not met.

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 /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify reactor steam dome pressure is 1025 psig.

In accordance with the Surveillance Frequency Control Program

ECCS Operating 3.5.1 DAEC 3.5-1 Amendment 305 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 Removal (RHR) pump inoperable.

A.1 Restore RHR pump to OPERABLE status.

30 Days B.

One low pressure ECCS subsystem inoperable for reasons other than Condition A.

B.1 Restore low pressure ECCS subsystem to OPERABLE status.

7 days C.

One Core Spray subsystem inoperable.

AND One or two RHR pump(s) inoperable.

C.1 Restore Core Spray subsystem to OPERABLE status.

OR C.2 Restore RHR pump(s) to OPERABLE status.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours D.

Both Core Spray subsystems inoperable.

D.1 Restore one Core Spray subsystem to OPERABLE status.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (continued)

ECCS Operating 3.5.1 DAEC 3.5-2 Amendment 223 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

Required Action and associated Completion Time of Condition A, B, C, or D not met.

E.1 Be in MODE 3.

AND E.2 Be in MODE 4.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours F.

HPCI System inoperable.

F.1 Verify by administrative means RCIC System is OPERABLE.

AND F.2 Restore HPCI System to OPERABLE status.

Immediately 14 days G.

HPCI System inoperable.

AND One RHR pump inoperable.

G.1 Restore HPCI System to OPERABLE status.

OR G.2 Restore RHR pump to OPERABLE status.

7 days 7 days H.

HPCI System inoperable.

AND One low pressure ECCS subsystem is inoperable for reasons other than Condition A.

H.1 Restore HPCI System to OPERABLE status.

OR H.2 Restore low pressure ECCS subsystem to OPERABLE status.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours I.

HPCI System inoperable.

AND One ADS valve inoperable.

I.1 Restore HPCI System to OPERABLE status.

OR I.2 Restore ADS valve to OPERABLE status.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours (continued)

ECCS Operating 3.5.1 DAEC 3.5-3 Amendment 223 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J.

Required Action and associated Completion Time of Condition F, G, H, or I not met.

J.1 Be in MODE 3.

AND J.2 Reduce reactor steam dome pressure to 150 psig.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours K.

One ADS valve inoperable.

K.1 Restore ADS valve to OPERABLE status.

30 days L.

One ADS valve inoperable.

AND One low pressure ECCS subsystem inoperable for reasons other than Condition A.

L.1 Restore ADS valve to OPERABLE status.

OR L.2 Restore low pressure ECCS subsystem to OPERABLE status.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 72 hours M.

Two or more ADS valves inoperable.

OR Required Action and associated Completion Time of Condition K or L not met.

M.1 Be in MODE 3.

AND M.2 Reduce reactor steam dome pressure to 100 psig.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours (continued)

ECCS Operating 3.5.1 DAEC 3.5-4 Amendment 290 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME N.

Two or more low 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.

N.1 Enter LCO 3.0.3.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program (continued)

Drywell Spray System T 3.5.1 DAEC 3.5-1 TRMCR-026 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 subsystem inoperable.

A.1 Restore RHR drywell spray subsystem to OPERABLE status.

30 days B.

Both RHR drywell spray subsystems inoperable.

B.1 Restore at least one RHR drywell spray subsystem to OPERABLE status.

8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> C.

Required Action and associated Completion Time of Condition A or B not met.

C.1 Initiate a Corrective Action Program (CAP) document to determine cause(s) and corrective action(s).

AND C.2 Obtain Plant Manager or designee approval for plans to restore RHR drywell spray subsystem(s) to OPERABLE status.

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

Drywell Spray System T 3.5.1 DAEC 3.5-2 Revision 0 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.5.1.1 Verify the drywell spray spargers are unobstructed by performing an air test on the drywell spray headers and nozzles.

60 months

ESW System 3.7.3 DAEC 3.7-5 Amendment 223 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 subsystem inoperable.

---

NOTES--------------

1.

Enter applicable Conditions 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 subsystem to OPERABLE status.

7 days B.

Required Action and Associated Completion Time of Condition A not met.

OR Both ESW subsystems inoperable.

B.1 Be in MODE 3.

AND B.2 Be in MODE 4.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours

ESW System 3.7.3 DAEC 3.7-6 Amendment 280 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 and automatic valve in the flow paths servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.

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

In accordance with the Surveillance Frequency Control Program

Main Turbine Bypass System 3.7.7 DAEC 3.7-16 Amendment 243 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 LCO not met.

A.1 Satisfy the requirements of the LCO.

2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> B.

Required Action and associated Completion Time not met.

B.1 Reduce THERMAL POWER to < 21.7%

RTP.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />

Main Turbine Bypass System 3.7.7 DAEC 3.7-17 Amendment 280 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify one complete cycle of each main turbine bypass valve.

In accordance with 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 RESPONSE TIME is within limits.

In accordance with the Surveillance Frequency Control Program

AC Sources Operating 3.8.1 DAEC 3.8-1 AMD 255 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 inoperable.

A.1 Perform SR 3.8.1.1 for OPERABLE offsite circuit.

AND A.2 Restore offsite circuit to OPERABLE status.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> thereafter Prior to entering MODE 2 from MODE 3 or 4 (continued)

AC Sources Operating 3.8.1 DAEC 3.8-2 Amendment 223 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

One DG inoperable.

B.1 Perform SR 3.8.1.1 for OPERABLE offsite circuit(s).

AND B.2 Declare required feature(s), supported by the inoperable DG, inoperable when the redundant required feature(s) are inoperable.

AND 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from discovery of Condition B concurrent with inoperability of redundant required feature(s)

(continued)

AC Sources Operating 3.8.1 DAEC 3.8-3 Amendment 270 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.3 Determine OPERABLE 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.

AND B.5 Restore DG to OPERABLE status.

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Once per 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> 7 days AND 8 days from discovery of failure to meet LCO expect for Condition A C.

Two offsite circuits inoperable.

C.1 Declare required feature(s) inoperable when the redundant required feature(s) are inoperable.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from discovery of Condition C concurrent with inoperability of redundant required feature(s)

(continued)

AC Sources Operating 3.8.1 DAEC 3.8-4 Amendment 270 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

(continued)

AND C.2 Restore one offsite circuit to OPERABLE status.

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND 8 days from discovery of failure to meet LCO except for Condition A D.

Two DGs inoperable.

D.1 Restore one DG to OPERABLE status.

2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> E.

Required Action and Associated Completion Time of Condition A, B, C, or D not met.

E.1 Be in MODE 3.

AND E.2 Be in MODE 4.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours F.

Three or more AC sources inoperable.

F.1 Enter LCO 3.0.3.

Immediately

AC Sources Operating 3.8.1 DAEC 3.8-5 Amendment 280 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each offsite circuit.

In accordance with 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 and achieves steady state voltage 3744v and 4576v and frequency 59.5Hz and 60.5Hz.

In accordance with the Surveillance Frequency Control Program (continued)

AC Sources Operating 3.8.1 DAEC 3.8-6 Amendment 280 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 and operates for 60 minutes at a load 2750kw and 2950kw.

In accordance with the Surveillance 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 each day tank and remove water as necessary.

In accordance with the Surveillance Frequency Control Program (continued)

AC Sources Operating 3.8.1 DAEC 3.8-7 Amendment 280 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.6 Verify the fuel oil transfer system operates to transfer fuel oil from storage tank to the day tank.

In accordance with the Surveillance 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 and achieves:

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

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

In accordance with the Surveillance Frequency Control Program 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 supply from the Startup Transformer to the Standby Transformer.

In accordance with the Surveillance Frequency Control Program (continued)

AC Sources Operating 3.8.1 DAEC 3.8-8 Amendment 280 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 equal to its associated single largest post-accident load, and:

a.

Following load rejection, the frequency is 64.5Hz.

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.

In accordance with the Surveillance Frequency Control Program 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 on an actual or simulated Loss of Offsite Power (LOOP) signal or on an actual or simulated ECCS initiation signal except:

a.

Engine overspeed; and

b.

Generator lockout.

In accordance with the Surveillance Frequency Control Program (continued)

AC Sources Operating 3.8.1 DAEC 3.8-9 Amendment 280 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:

a.

Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation.

In accordance with the Surveillance Frequency Control Program 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 block is 2 seconds.

In accordance with the Surveillance Frequency Control Program (continued)

AC Sources Operating 3.8.1 DAEC 3.8-10 Amendment 280 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 power signal in conjunction with an actual or simulated ECCS initiation signal:

a.

De-energization of essential buses;

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.

In accordance with the Surveillance Frequency Control Program

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

OR NOTE: May be used on a one-time-only basis for each battery division.

A.1 Restore 125 VDC electrical power subsystem to OPERABLE status.

A.2.1 Declare required feature(s), supported by the inoperable 125 VDC source, inoperable when the redundant required feature(s) are inoperable.

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

8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 4 hours from discovery of Condition A concurrent with inoperability of redundant required feature(s).

10 days B.

Required Action and Associated Completion Time of Condition A not met.

B.1 Be in MODE 3.

AND B.2.

Be in MODE 4.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours C.

250 VDC electrical power subsystem inoperable.

C.1 Declare associated supported features inoperable.

Immediately D.

Two or more DC electrical power subsystems inoperable.

D.1 Enter LCO 3.0.3.

Immediately

DC Sources Operating 3.8.4 DAEC 3.8-18 Amendment 289 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is 130.5 V on float charge for the 125 VDC battery and 252 V for the 250 VDC battery.

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

OR Verify battery connection resistance within limits.

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

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

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

In accordance with the Surveillance Frequency Control Program (continued)

DC Sources Operating 3.8.4 DAEC 3.8-19 Amendment 289 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 293 amps at 132.5 V for the 125 VDC subsystem and 200 amps at 258 V for the 250 VDC subsystem.

In accordance with the Surveillance Frequency Control Program SR 3.8.4.7

---

NOTES-----------------------------

1.

The modified performance discharge test 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, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

In accordance with the Surveillance Frequency Control Program (continued)

DC Sources Operating 3.8.4 DAEC 3.8-20 Amendment 280 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 manufacturers rating when subjected to a performance discharge test or a modified performance discharge test.

In accordance with the Surveillance Frequency Control 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 life with capacity 100% of manufacturers rating

Distribution Systems Operating 3.8.7 DAEC 3.8-27 Amendment 223 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 electrical power distribution subsystems inoperable, except for the intake structure electrical power distribution subsystems.

A.1 Restore AC electrical power distribution subsystems to OPERABLE status.

8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AND 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO 3.8.7.a or b B.

One or more essential 125 VDC electrical power distribution subsystems inoperable except for the RCIC MCC.

B.1 Restore the 125 VDC electrical power distribution subsystems to OPERABLE status.

8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AND 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from discovery of failure to meet LCO 3.8.7.a or b (continued)

Distribution Systems Operating 3.8.7 DAEC 3.8-28 Amendment 223 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Required Action and associated Completion Time of Condition A or B not met.

C.1 Be in MODE 3.

AND C.2 Be in MODE 4.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 36 hours D.

One or both intake structure electrical power distribution subsystem(s) inoperable.

D.1 Declare the associated River Water Supply subsystem(s) inoperable.

Immediately E.

250 VDC electrical power distribution subsystem inoperable.

E.1 Declare associated supported features inoperable.

Immediately F.

125 VDC RCIC MCC inoperable.

F.1 Declare associated supported features inoperable.

Immediately G.

Two or more electrical power distribution subsystems inoperable that result in a loss of function, for reasons other than Condition D.

G.1 Enter LCO 3.0.3.

Immediately

Distribution Systems Operating 3.8.7 DAEC 3.8-29 Amendment 280 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct breaker alignments and indicated power availability to required AC and DC electrical power distribution subsystems.

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

In accordance with the Surveillance Frequency Control Program

DAEC EOP BASES DOCUMENT BASES-EOP 2 Rev. 16 EOP 2 - PRIMARY CONTAINMENT CONTROL GUIDELINE Page 41 of 69 0

50 100 150 200 250 300 350 400 0

2 4

6 8

10 12 14 16 18 20 Drywell Pressure (psig)

Drywell Spray Initiation Limit Do not initiate drywell sprays in shaded area

DAEC EOP BASES DOCUMENT BASES-ATWS Rev. 19 ATWS - RPV CONTROL Page 62 of 96 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.

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.

Heat Capacity Limit 0

120 RPV Pressure (psig) 100 200 300 400 500 600 700 800 900 1000 1100 130 140 150 160 170 180 190 200 210 220 230 240 Action is required Bounding curve for torus levels between 8 ft and 13 ft

DAEC EOP BASES DOCUMENT BASES-EOP 3 Rev. 13 EOP 3 - SECONDARY CONTAINMENT CONTROL GUIDELINE Page 6 of 29 Table 6 Secondary Containment Limits Parameter and Areas Max Normal Operating Limit Max Safe Operating Limit Value/Trend Area/Location Indicator

°F

°F A RHR SE Corner Room Area RHR SE CORNER ROOM AMBIENT RHR SE CORNER ROOM DIFFERENTIAL TR/TDR 2000A Ch 1 TR/TDR 2000A Ch 2 130 50 140 N/A B RHR NW Corner Room Area RHR NW CORNER ROOM AMBIENT RHR NW CORNER ROOM DIFFERENTIAL TR/TDR 2000B Ch 1 TR/TDR 2000B Ch 2 130 50 140 N/A HPCI Room Area HPCI EMER COOLER AMBIENT HPCI ROOM AMBIENT HPCI ROOM DIFFERENTIAL TR/TDR 2225A[B] Ch 1 TR/TDR 2225A Ch 2 TR/TDR 2225A[B] Ch 4[3]

175 175 50 310 310 N/A RCIC Room Area RCIC EMER COOLER AMBIENT RCIC ROOM AMBIENT RCIC ROOM DIFFERENTIAL TR/TDR 2425A[B] Ch 1 TR/TDR 2425A Ch 2 TR/TDR 2425A[B] Ch 4 175 175 50 300 300 N/A Torus Area TORUS CATWALK NORTH AMBIENT TORUS CATWALK WEST AMBIENT TORUS CATWALK SOUTH AMBIENT TORUS CATWALK EAST AMBIENT TORUS CATWALK EAST DIFF TORUS CATWALK WEST DIFF TORUS CATWALK SOUTHWEST DIFF TORUS CATWALK SOUTH DIFF TR/TDR 2425A Ch 3 TR/TDR 2425B Ch 2 TR/TDR 2225A Ch 3 TR/TDR 2225B Ch 2 TR/TDR 2425A Ch 5 TR/TDR 2425B Ch 5 TR/TDR 2225A Ch 5 TR/TDR 2225B Ch 4 150 150 150 150 50 50 50 50 165 165 165 165 N/A N/A N/A N/A RWCU PUMP ROOM AMBIENT RWCU HX ROOM AMBIENT TR/TDR 2700A[B] Ch 1 TR/TDR 2700A[B] Ch 2,3 130 130 212 212 RWCU ABOVE TIP ROOM AMBIENT TR/TDR 2700A[B] Ch 4,5 111.5 150 Steam Tunnel Area STEAM TUNNEL AMBIENT STEAM TUNNEL DIFFERENTIAL TR/TDR 2425B Ch 3 TR/TDR 2225B Ch 5 160 70 300 N/A Area/Location Indicator mR/hr mR/hr RB RAILROAD ACCESS AREA SOUTH CRD MODULE AREA TIP ROOM RI 9167 RI 9169 RI 9176 10 10 60 100 100 600 NORTH CRD MODULE CRD REPAIR ROOM RI 9168 RI 9170 10 15 100 150 RWCU SPENT RESIN ROOM RWCU PHASE SEP TANK RI 9173 RI 9177 100 20 10 3

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

10 3

10 4

10 4

Area MAIN PLANT EXHAUST FAN ROOM JUNGLE ROOM RI 9171 RI 9155 60 60 600 600 Refuel Floor Area NEW FUEL VAULT AREA NORTH REFUEL FLOOR SOUTH REFUEL FLOOR SPENT FUEL POOL AREA RI 9153 RI 9163 RI 9164 RI 9178 10 10 10 100 100 100 100 10 3

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 60 of 80 Figure 19: RHR NPSH Limit

DAEC EOP BASES DOCUMENT BASES-CURVES Rev. 16 EOP CURVES AND LIMITS Page 66 of 80 Figure 23: RHR Vortex Limit