ML080280348

Nov/Dec 2007 Exam 05000348-07-301 & 05000364/2007301- Post-Exam Comments Ltrs Dtd 12-7-2007 & 1-4-2008

ML080280348
Person / Time
Site:	Farley
Issue date:	01/28/2008
From:	Southern Nuclear Operating Co
To:	NRC/RGN-II
References
50-348/07-301, 50-364/07-301
Download: ML080280348 (94)

Text

POST-EXAM COMMENTS (Green Paper)

Licensee Submitted Post-Exam Comments

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None FARLEY NOVEMBER -DECEMBER 2007 EXAM NOS. 0500U-j4B;~l)500U364t2007301 POST-EXAM COMMENTS

Southern Nuclear Operating Company, Inc.

Post Office Drawer 470 Ashford, Alabama 36312 Tel 334.8995156 Fax 334.814.4661 FNP-2007-0148-TRN 5

12/07/2007 Mr. Frank Ehrhardt United States Nuclear Regulatory Commission Sam Nunn Atlanta Federal Center 61 Forsyth Street SW, Suite 23T85 Atlanta, Georgia 30303-8931

Dear Mr. Ehrhardt,

Energy to Serve lOurWorld sM Concerning the Farley HLT-31 NRC Exam, administered on the weeks of November 5,2007 and November 13, 2007 at Farley Nuclear Plant, attached is a three page document entitled "Post Exam Comments On: A.1.1 Conduct of operations ADMIN G2.1.10 - SRO".

Changes Requested based on supporting document pages 1-3 of 3 attached:

Make element 3 non-critical for consistency with all the other conditions in this task that do NOT preclude Mode 4 entry based on the literal interpretation of our licensing documents Technical Specifications and Bases. This leaves two other critical tasks which must be properly evaluated to determine Mode 4 entry IS prohibited for reasons other than the EDG inoperability.

Element 3 stated that the 1B DG was required to be immediately declared inoperable due to low fuel oil supply. This is incorrect due to the 1B DG not being required in mode 5, and the DG is required to be declared inoperable only in the mode in which it is required. Element 3 should say that "an Admin LeO must be written for the IB DG" (This is required by Farley policy, but not by Technical Specifications, and this is not a critical task due to it not being a mandatory LCO).

This material discusses a part of this exam that has already been administered. If you have any questions, please contact Charles V. (Vince) Richter at (334) 814-4758.

onna M. Christiansen OPS Training Supervisor CVR/DMC:las cc:

FIle o

Attached to letter FNP-2007-0l48-TRN Concerning: Farley NRC Exam 3012007, Week of NOV 5, 2007 Post Exam Comments On: A.l.l Conduct of operations ADMIN G2.l.l0 - SRO POST EXAM COMMENTS ON: A.l.l Conduct of operations ADMIN G2.l.l0 - SRO CHANGE REQUESTED:

Make element 3 non-critical for consistency with all the other conditions in this task that do NOT preclude Mode 4 entry based on the literal interpretation of our licensing documents Technical Specifications and Bases. This leaves two other critical tasks which must be properly evaluated to determine Mode 4 entry IS prohibited for reasons other than the EDG inoperability.

Element 3 stated that the lB DG was required to be immediately declared inoperable due to low fuel oil supply. This is incorrect due to the lB DG not being required in mode 5, and the DG is required to be declared inoperable only in the mode in which it is required.

Element 3 should say that "an Admin LCO must be written for the 1B DG" (This is required by Farley policy, but not by Technical Specifications, and this is not a critical task due to it not being a mandatory LCO).

SUMMARY

This task presented initial conditions for evaluation to determine if Mode 4 entry from Mode 5 was allowed. Several items were evaluated, and three conditions were intended to preclude Mode 4 entry. Identifying these three items correctly were critical tasks. The IPM also required evaluating several other items that would not prevent a Mode 4 entry, and identifying these correctly were not critical tasks.

Element 3 required declaring the lB DG inoperable due to low fuel oil supply, which precluded a mode change from Mode 5 to Mode 4. Two trains of DGs are required in Mode 4 and the lB DG is considered to be one entire train or set. (1-2A and lC DG are considered to be the A Train set This is consistent with Plant Policy and management expectations (which is not written down),

but not with the Technical Specifications and bases as written in Action B (note LCO 3.0.4c).

In Element 3, Plant Policy and management expectations require both trains of DGs to enter Mode 4, but the Technical Specification is written to allow Mode 4 entry as long only one of the 3 DGs is inoperable (including the lB EDG, even though it is one train by itself). The plant policy has been that the clause in Tech Specs allowing mode change with only one of the three DGs inoperable applied only to the two "A" Train DGs which are shared between units. For the A Train DGs, either DG being inoperable does not completely eliminate an entire train to either unit. The B Train DGs are unit specific and treated differently as standalone DG trains. This policy and expectation is not documented in approved plant procedures which precluded providing the applicants with this information for their evaluation. Previous training and knowledge of on-shift plant-practice is required to determine this interpretation. Subsequent to this operating exam, a post exam condition report will be written to include documenting this policy.

The students were provided the Technical Specifications and Bases for TS 3.8.1: AC Sources -

Operating, & T.S. 3.8.3: Diesel Enel Oil, IJJhe OJ], and Starting Air All Technical Specifications and bases were available on request. Based on a literal interpretation of these documents, the applicants would determine Mode 4 entry was NOT precluded by the lB DG being inoperable, as long as lC & l-2A (both A Train DGs) were operable as was the case in this task.

Page 1 of 3

Attached to letter FNP-2007-0148-TRN Concerning: Farley NRC Exam 3012007, Week of NOV 5, 2007 Post Exam Comments On: A.1.1 Conduct of operations ADMIN G2.1.10 - SRO The Technical Specification guidance and Plant procedure are explained below:

The 1B DG is required to be declared inoperable in Mode 4, due to low fuel oil supply, which precludes a mode change from Mode 5 to Mode 4. Two trains of DGs are required in Mode 4 and the 1B DG is one entire train. One of two required trains being inoperable would normally preclude a mode change, and plant management expectations and past practice requires not changing modes without both trains of DGs, even though the Technical Specifications allow it per the following:

o There is a stated allowance for the mode change in a note in the DG Technical Specification 3.8.1, REQUIRED ACTION B: "LCO 3.0.4c is applicable when only one ofthe three DGs is inoperable".

LCO 3.0.4c states: "When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made: (c.) When an allowance is stated in the individual value, parameter, or other Specification [in this case, the allowance is made in the Specification in the note of3.8.1]"

o The 1B DG is the only DG inoperable as presented in the conditions given, so per the note in TS 3.8.1, the mode change may occur.

o STP-35.1, Mode change procedure, Step 4.2, states: Units 1/2 Technical Specifications Amendments 170/163, INCREASING FLEXIBILITY IN MODE RESTRAINTS, issued 02-22-2006, revised LCO 3.0.4 to allow entry into a MODE while relying on the associated ACTIONS, provided that either (a) the ACTIONS to be entered permit continued operation in the MODE for an unlimited period of time, (b) a risk assessment is performed which justifies the use of LCO 3.0.4 (unless there's an exception in the Specification), or (cl an NRC approved allowance is provided in the Specification to be entered..

o The note in TS 3.8.1 REQUIRED ACTION B allows mode change with only one of the 3 required DGs inoperable, and is an NRC approved allowance provided in the Specification [3.8.1] to be entered.

Page 2 of 3

Attached to letter FNP-2007-0148-TRN Concerning: Farley NRC Exam 3012007, Week of NOV 5, 2007 Post Exam Comments On: A.l.l Conduct of operations ADMIN G2.1.10 - SRO The following is from the ADMIN JPM A.I.I SRO ONLY "as administered":

TITLE: Determine if current conditions allow Mode 4 entry TASK STANDARD: Determine while completing a mode change checklist that mode 4 entry is prohibited by two unsat STPs, STP-I0.4 & STP-15, and an inoperable IB DG (due to low Fuel Oil Storage tank content).

CONDITIONS When I tell you to begin, you are to determine if Mode 4 entry is allowed. IF mode 4 entry is prohibited, identify which conditions preclude Mode 4 entry.

a.

Unit 1 is in Mode 5.

b.

You are the Shift Support Supervisor. You are to complete filling out STP-35.1 and determine if Mode 4 entry is allowed. If any conditions preclude Mode 4 entry, then identify all conditions that preclude Mode 4 entry.

c.

Shift turnover and shift brief has just been completed.

1. STP-35.1, step 5.3, is in progress reviewing requirements for Mode 4 entry.

2. STP-l.0 has been performed 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> ago for mode 4.

3. All STPs have been reviewed per FNP-l-STP-35.1E with exceptions noted on coversheet.

4. Taggout review is complete sat.

5. All applicable signatures and initials have been completed in STP-35.1 except on the pages provided.

6. Review for mode 4 LCOs has been completed except for DG which have parameters listed:

1/2A lC IB Diesel Fuel Oil storage 25,500 gals 25,500 gals 20,350 gals tank contents Lube Oil inventory 248 gals 183 gals 255 gals Starting Air receiver 415 psig 240 psig 425 psig pressures Page 3 of 3

HLT-31 ADMIN exam A.1.1 SRO A.I.I Conduct of operations ADMIN G2.1.1 0 - SRO TITLE: Determine if current conditions allow Mode 4 entry Page 1 of 5 TASK STANDARD: Determine while completing a mode change checklist that mode 4 entry is prohibited by two unsat STPs, STP-IO.4 & STP-15, and an inoperable IB DG (due to low Fuel Oil Storage tank content).

PROGRAM APPLICABLE: SOT SOCT OLT ~ LOCT__

ACCEPTABLE EVALUATION METHOD: ~ PERFORM SIMULATE EVALUATION LOCATION:

X CLASS ROOM PROJECTED TIME:

30 MIN SIMULATOR IC NUMBER:

N/A ALTERNATE PATH TIME CRITICAL PRA__

DISCUSS Examinee:

Overall JPM Performance:

Satisfactory 0

Unsatisfactory 0

Evaluator Comments (attach additional sheets if necessary)

EXAMINER:

HLT-31 ADMIN exam A.1.1 SRO Page 2 of 5 CONDITIONS When I tell you to begin, you are to determine if Mode 4 entry is allowed. IF mode 4 entry is prohibited, identify which conditions preclude Mode 4 entry.

eVIew ormo e s

as een comp e e excep or w IC ave parame ers I l/2A lC IB Diesel Fuel Oil 25,500 gals 25,500 gals 20,350 gals storage tank contents Lube Oil inventory 248 gals 183 gals 255 gals Starting Air receiver 415 psig 240 psig 425 psig pressures a.

Unit 1 is in Mode 5.

b.

You are the Shift Support Supervisor. You are to complete filling out STP-35.1 and determine if Mode 4 entry is allowed. If any conditions preclude Mode 4 entry, then identify all conditions that preclude Mode 4 entry.

c.

Shift turnover and shift brief has just been completed.

1. STP-35.1, step 5.3, is in progress reviewing requirements for Mode 4 entry.

2. STP-l.0 has been performed 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> ago for mode 4.

3. All STPs have been reviewed per FNP-I-STP-35.1E with exceptions noted on coversheet.

4. Taggout review is complete sat.

5. All applicable signatures and initials have been completed in STP-35.1 except on the pages provided.

6 R

£ d 4 LCO h bIt d t £ DG h* h h t

l*sted:

EVALUATION CHECKLIST ELEMENTS:

STANDARDS:

RESULTS:

(CIRCLE)

START TIME

• 1.

Determines that STP-I0.4, EMERGENCY BORATION CHECK VALVES INSERVICE TEST, is UNSAT due to step 5.8 (IB BAT pump flow low). This precludes Mode 4 entry.

Determines that STP-I0.4, EMERGENCY BORATION S / U CHECK VALVES INSERVICE TEST, is UNSAT due to step 5.8 flow lower than graph of 44 gpm (IB BAT pump flow low). This precludes Mode 4 entry.

• 2.

Determines that STP-15.0, CONTAINMENT AIR LOCK DOOR SEAL OPERABILITY TEST, is unsat due

---

t,-0--,S----:.2,...,.-.2Ol'IDT ~ 2347 sccm. This precludes Mode 4 entry.

Determines that STP-15.0, CONTAINMENT AIR LOCK S / U DOOR SEAL OPERABILITY TEST, is unsat due to 5.2.20 NOT

~ 2347 sccm. This precludes Mode 4 entry.

HLT-31 ADMIN exam A.1.1 SRO EVALUATION CHECKLIST ELEMENTS:

• 3.

Determines that of the 9 given DG parameters, one makes the 1B DG inoperable due to usable Fuel Level. This TS also requires immediately declaring the IB DG inoperable. This precludes Mode 4 entry due to two trains of DGs required in Mode 4. (SEE table on next page for KEY)

(TS 3.8.3 Condo E)

TS 3.8.3:

Page 3 of 5 RESULTS:

STANDARDS:

(CIRCLE)

Determines that of the 9 given DG parameters, one makes the IB DG S I U inoperable due to usable Fuel Level. This TS also requires immediately declaring the IB DG inoperable.

1/2A IC 1B Diesel Fuel Oil 25,500 gals 25,500 gals 20,350 gals storage tank contents Inoperable (TS 3.8.3 Cond F. & TS 3.8.1)

Lube Oil inventory 248 gals 183 gals 255 gals Starting Air receiver 415 psig 240 psig 425 psig pressures STOP TIME Terminate when all initial conditions have been evaluated.

CRITICAL ELEMENTS: Critical Elements are denoted with an asterisk (*) before the element number.

HLT-31 ADMIN exam A.1.1 SRO Page 4 of 5 2.

KIA:

G2.1.10 SRO 3.9 GENERAL TOOLS AND EQUIPMENT:

Provide:

1.

Marked up STP-35.1 2.

Marked up STP-I0.4 3.

Marked up STP-15.0 4.

Technical Specifications & Basis for TS 3.8.1 & 3.8.3 COMMENTS:

HLT-31 ADMIN exam A.1.1 SRO Page 5 of 5 CONDITIONS When I tell you to begin, you are to determine if Mode 4 entry is allowed. IF mode 4 entry is prohibited, identify which conditions preclude Mode 4 entry.

eVIew ormo e s

as een comp.e e excep or w IC ave parame ers I 1/2A 1C 1B Diesel Fuel Oil 25,500 gals 25,500 gals 20,350 gals storage tank contents Lube Oil inventory 248 gals 183 gals 255 gals Starting Air receiver 415 psig 240 psig 425 psig pressures a.

Unit 1 is in Mode 5.

b.

You are the Shift Support Supervisor. You are to complete filling out STP-35.1 and determine if Mode 4 entry is allowed. If any conditions preclude Mode 4 entry, then identify all conditions that preclude Mode 4 entry.

c.

Shift turnover and shift brief has just been completed.

1. STP-35.1, step 5.3, is in progress reviewing requirements for Mode 4 entry.

2. STP-1.0 has been performed 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> ago for mode 4.

3. All STPs have been reviewed per FNP-1-STP-35.1E with exceptions noted on coversheet.

4. Taggout review is complete sat.

5. All applicable signatures and initials have been completed in STP-35.1 except on the pages provided.

6 R

£ d 4 LCO h bit d t £ DG h* h h t

l*sted:

Southern Nuclear Operating Company, Inc.

Post Office Drawer 470 Ashford, Alabama 36312 Tel 334,899.5156 Fax 334,814.4661 1/4/2008 Mr. Frank Ehrhardt United States Nuclear Regulatory Commission Sam Nunn Atlanta Federal Center 61 Forsyth Street SW, Suite 23T85 Atlanta, Georgia 30303-8931

Dear Mr. Ehrhardt,

FNP-2008-002-TRN Energy to Serve lOurWorld slV1 Enclosed is our Post-Written Examination submittal of examination grade sheets, post-exam comments, and other materials. The ES-201 Form, Examination Security Agreement, is in the process of being signed off as personnel become available. The ES-201 Form will be set at a later date as soon as all required signatures are obtained.

Enclosed you will find the following forms and materials for the NRC Written examination administered on 12-21-2007 at Farley Nuclear Plant.

Hard Copy:

1)

Eleven,5 SRO & 6 RO, exam grade sheets for electronic scanning in LXR software (scantron sheets) 2)

Exam cover sheets signed by Applicants 3)

Preliminary grades 4)

ES-403-1, Written Examination Grading Quality Checklist 5)

ES-401-6, Written Examination Quality Checklist (resubmitted original due to some inadvertently omitted initials on previously submitted form) 6)

Written Exam seating chart 7)

List of Questions and replies during exam 8)

Post exam comments for potential Key changes Question 95, G2.1.6, is security related and must be withheld from public disclosure. The remainder of this material should be withheld from public disclosure until after the examination grading is complete.

If you have any questions, please contact Charles V. (Vince) Richter at (334) 814-4758.

nmn onna M. Christiansen OPS Training Supervisor Enclosure CVR/DMC cc:

File

Farley NRC Written exam Applicant questions and answers during exam, 12-21-2007 Examination proctors: Vince Richter & Gary Ohmstede NRC chief examiner available by telephone: Frank J. Ehrhardt

[bracketed text indicates post exam comments NOT communicated by or to any applicants during the exam]

LJ Applicant I Question/comment I Answer I

17 Newell Does "the BKR Panel" mean the lA 120V Yes Vital panel?

17 Pickens Can I assume that RCP BKR ind is lost?

[After phone call with chief examiner]:

Assume all systems are aligned per normal actual plant conditions 16 Rose LT-459 Failed low, how low did it fail?

As low as it can fail.

36 Newell R-15A is at midscale, is it stable at mid scale Take the statement at to start with?

face value 25 Rose Valves are stated to be closed, can I assume Take statements at face the SI signal to the valves has been disabled?

value. Everything that has been done is stated or implied in the question 77 Payne Desire documentation of comment for this We'll document your question because Payne thought that A was comment.

most correct and was going to choose it, but thought the 2nd part of A was not correct. The

[There was no A choice stated that subcooling being too low problem found with was the reason, but the real reason should be this question or choice that a LOCA is in progress.

A]

86 Payne Assuming MSIV Auto closure has occurred, We'll document your since an assumption must be made to assumption.

distinguish between A & D

[This assumption was not necessary. Stem conditions indicated that an auto MSIV closure had occurred on low steam pressure]

89 Payne Can I assume that "Releases can continue" Yes.

means only future releases but not the current release?

Page 10f2

Farley NRC Written exam Applicant questions and answers during exam, 12-21-2007 Examination proctors: Vince Richter & Gary Ohmstede NRC chief examiner available by telephone: Frank J. Ehrhardt

[bracketed text indicates post exam comments NOT communicated by or to any applicants during the exam]

17 NaIl Does this question ask the BKR Position Answer the question as between the two times 1000 & 1010?

written.

[The time of the question was clearly stated in the stem].

90 Carrol Does placing B TRN of SW on service mean The statement means placing C SW Pump on B train?

what it says.

87 Szollosi The high alarm light is stated to be NOT lit.

Answer based on Was the high alarm light ever lit just previous conditions given.

to these conditions?

55 Prichett Is the loss of A train SW just U-2, or is it a Unit 2 only.

total loss of SW?

82 Taylor What time is the 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> in choice "C" Answer the question as referenced to of the several times in the stem?

written.

22 Carrol Confused about what A and B choices

[No response actually meant.

required]

[Ended up without asking a question or making a comment. Applicant talked through it while trying to explain his confusion and said: "I guess 1 answered my own question"]

36 Prichett Does this mean SJAE Filtration is on service It means what it says.

when the Rx Trips?

32 Carrol What is RCS Press? Did Letdown operate?

This is as expected during an ATWT event.

74 Wilhoit Is the location in Choice "B" really what it It means what it says.

means?

Page 2 of2

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Courtney Rose Mike Wilhoit Rob Szollosy Josh Pritchett Jash Carroll Matt NaIl Tracey Newell Taylor Joseph Matt Pickens Brannon Payne Steve Lee

Farley NRC Written Exam 12-21-2007 comments Question 32, 029 EKl.Ol

References:

FRP-S.l Given the following:

An ATWT has occurred on Unit 2 during coastdown prior to entering a refueling outage.

The crew is performing actions of FRP-S.1, Response to Nuclear Power Generation/ATWT.

An operator has been dispatched to trip the reactor locally.

Attempts to establish Emergency Boration have been unsuccessful.

Reactor power indicates 6%.

Intermediate Range Startup rate is slightly positive.

The RCS temperature is slowly rising.

Which ONE of the following describes the actions required lAW FRP-S.1?

A. [Originally identified as Correct] Allow the RCS to heat up, and continue attempts to place the reactor in a subcritical condition.

B. [Also Correct] Allow the RCS to heat up, and open one PORV as necessary to maintain pressurizer pressure less than 2135 psig to increase charging flow.

c. & D [Incorrect, no change to C & 0]

Comment: Both 'B' and 'A' should be accepted as correct, since the first parts of both are the same, and the second part of B is a subset of A. FRP-S.1 has procedure steps for continuing attempts to place the reactor in a subcritical condition which include, during establishing emergency boration, step 4.5 RNO "open one PORV as necessary to maintain pressurizer pressure less than 2135 psig to increase charging flow." The words "as necessary" in the second part of 'B' make it correct. Even though there is no reason to believe that the PORVs would not open and control pressure automatically, in which case it would not be necessary to open the PORVs manually, it is still true that "opening PORVs as necessary" is required.

Page 1 of 3

Farley NRC Written Exam 12-21-2007 comments Question 90, 076 G2.1.2

References:

SOP-24.0, AOP-IO.O, ARP-l.l Window AE4 Given the following:

Unit 2 is at 100% power withlA" Train on service.

At 1200 on 11/7/2007, 2E Service Water pump tripped and "B" Train SW was declared INOPERABLE.

Which ONE of the following describes the Technical Specification REQUIRED ACTION lAW 3.7.8, Service Water System, and the action required to make "B" Train Service Water OPERABLE?

A. [Originally identified as Correct]- Immediately declare the DG supported by Train "B" Service Water INOPERABLE.

- Place "B" Train of SW on service and align 2C SW pump to auto start for 2E SW pump lAW SOP-24.0, Service Water System.

B. [Also Correct]- Immediately declare the OG supported by Train "B" Service Water INOPERABLE.

- Align 2C SW pump to auto start for 2E SW pump lAW AOP-1 0.0, Loss of Service Water.

c. & D [Incorrect, no change to C & 0]

Comment: Both 'B' and 'A' should be accepted as correct, since the first parts of both are the same, and the second parts of both provide procedurally correct paths to obtain the same result. They would both result in the B Train Service Water Operable as the question asks.

The differences between choices 'A' & 'B' are:

1) 'A' states a more complete description ofthe action of "placing C SW pump on the B Train and then aligning it to auto start for E", but the shortened description in 'B' "Align 2C SW pump to auto start for 2E" includes all the actions to perform this by the procedure: SOP-24.0. IF both trains of SW were >60 psig after AOP-10.0 directed starting the 2C SW pump, the ARP would direct SOP-24.0 and 'A'- is the' correct choice.

2) 'A' states the alignment is performed per SOP-24 which is correct. Even though, per 'B' choice, AOP-10.0 does not directly provide guidance for aligning the 2C SW Pump for E, AOP-10 does direct swapping per AOP-24.0 later in the procedure. AOP-10.0 is entered and performed, and if SW pressure is not> 60 psig in both Trains, AOP-10.0 will be continued to the point of directing 2C SW Pump swap and alignment to auto start for 2E per SOP-24.0. SW Pressure is not given in the question stem, so knowledge of the procedure led some to choose 'B' because the stem did not preclude AOP-10 directing the alignment. The simulator is modeled for SW pressure being>

60 psig after starting 2C SW pump, but in tile plant, it may be < 60 psig in otlleI plant COllditiolIS than the simulator modeling (e.g. heat of the summer with all SW cooling valves throttled max open).

Page 20f3

Farley NRC Written Exam 12-21-2007 comments Question 100, G2.4.44

References:

EIP-9.0 A Site Area Emergency was declared 35 minutes ago. Subsequently, conditions have degraded and a General Emergency classification needs to be declared.

When upgrading to the General Emergency classification, which one of the following contains ONLY required actions lAW FNP-O-EIP-9.0, Emergency Actions?

A. &D. [Incorrect, No change]

B. [Previously inadvertently identified in LXR as correct]

• Sounding of the plant emergency alarm.

• Notify Alabama and Georgia of the status of the unaffected Unit.

c. [Should have been identified in LXR as correct]

• Notify Alabama and Georgia of Protective Action Recommendations.

• Announce needed evacuation instructions to plant personnel.

Comment: 'B' is incorrect because the plant emergency alarm has already been actuated for the Site Area Emergency. The alarm is not directed to be sounded again for the General Emergency. Also, the second part is incorrect because the unaffected Unit status is not required for the initial General Emergency notification.

'C' is correct, and should be accepted as the only correct answer, since the PARs are required for both Alabama and Georgia for the General Emergency, and the procedure requires the announcement of needed evacuation instructions to plant personnel.

Page 3 of3

Farley Nuclear Plant 2006-301 SRO Inital Exam

32. 029 EKl.Ol 001 Given the following:

An ATWT has occurred on Unit 2 during coastdown prior to entering a refueling outage.

The crew is performing actions of FRP-S.1, Response to Nuclear Power Generation!ATWT.

An operator has been dispatched to trip the reactor locally.

Attempts to establish Emergency Boration have been unsuccessful.

Reactor power indicates 6%.

Intermediate Range Startup rate is slightly positive.

The RCS temperature is slowly rising.

Which ONE of the following describes the actions required lAW FRP-S.1?

A~ Allow the ReS to heat up, and continue attempts to place the reactor in a subcritical condition.

B. Allow the RCS to heat up, and open one PORV as necessary to maintain pressurizer pressure less than 2135 psig to increase charging flow.

C. Stop the RCS heatup by increasing AFW flow to greater than 700 gpm, and verify dilution paths isolated.

D. Stop the RCS heatup by dumping steam to the main condenser, and continue attempts to place the reactor in a subcritical condition.

FRP-S.1 version 25 17 Continue emergency boration. 17 Perform the following.

17.1 Determine if moderator temperature coefficient positive or negative.

[] Core Physics Curve 5 17.2 IF moderator temperature coefficient negative, THEN allow ReS to heat up.

A. correct. During coastdown at EOl, MTC is negative under all conditions. Do not leave FRP-S.1 until power below 5°A>. IF power was to be >%5 or a positive SUR on the IR, then in addition to continuing the emergency boration, if the MTC is negative, then the RCS would be allowed to HU to add positive reactivity to the core and help shut it down.

B. incorrect The RCS is allowed to heatup, but the PORvs are not cycled to maintain pressure less than 2135 psig unless pressure is > 2335 psig.

C. incorrect because S.1 does not have the AFW flow to be >700 gpm for this reason, but does have an RNO step to increase AFW flow to 700 gpm if SGWls are not >31 %

D. incorrect RCS temperature is not stabilized, it is allowed to rise.

Farley Nuclear Plant 2006-301 SRO Inital Exam 029 Anticipated Transient Without Scram (ATWS)

EK1.01 Knowledge of the operational implications of the following concepts as they apply to theATW8:

Reactor nucleonics and thermo-hydraulics behavior Question Number:

46 Tier 1 Group 1 Importance Rating:

R02.8 Technical

Reference:

FRP-S.1 Proposed references to be provided to applicants during examination:

None Learning Objective:

10 CFR Part 55 Content:

41.1 0 Comments:

This meets the KA in that this tests the operational implications during an ATWT and the effects that we would take if the reactor was still critical after emergency boration and rods going in what would happen temperature wise, ie. thermo-hydralic behavior.

FNP-I-FRP-S.l 4-20-2007 Revision 25 FARLEY NUCLEAR PLANT FUNCTION RESTORATION PROCEDURE FNP-I-FRP-S.l RESPONSE TO NUCLEAR POWER GENERATION/ATWT PROCEDURE USAGE REQUIREMENTS-per FNP-O-AP-6 SECTIONS Continuous Use Remainder of Procedure Reference Use Steps 1-2 Information Use S

A F

E T

Y R

E L

A T

E D

Approved:

Jim L.

Hunter (for)

Operations Manager Date Issued:

04/23/07

FNP-1-FRP-S.1

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.~L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Table of Contents Revision 25 Procedure Contains Number of Pages Body 19 8

Attachment 2

8 Page 1 of 1

FNP-1-FRP-S.1 A.

Purpose

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 This procedure provides actions to add negative reactivity to a core which is observed to be critical when expected to be shutdown.

B.

Symptoms or Entry Conditions I.

This procedure is entered when reactor trip is not verified and manual trip is not effective; from the following:

a.

FNP-1-EEP-O, REACTOR TRIP OR SAFETY INJECTION, step 1 II.

This procedure is entered from the Subcriticality Critical Safety Function Status Tree on either a Red or Orange condition.

Page 1 of 19

FNP-I-FRP-S.l

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JL RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained CAUTION:

rCA]

RCPs should NOT be tripped with reactor power GREATER THAN 5%.

NOTE:

Steps 1 and 2 are IMMEDIATE ACTION steps.

1 Verify reactor - TRIPPED.

RX TRIP ACTUATION

[]

AB to TRIP 1

Perform the following.

1.1 Trip CRDM MG set supply breakers.

lA(IB)

MG SET SUPP BKR

[J NICIIE005A

[J NICIIE005B 1.2 IF reactor still NOT tripped, THEN perform the following.

• Insert control rods in manual control.

OR

• Verify rods insert in AUTO at greater than 48 steps per minute.

1.2.1 Dispatch an operator to locally trip the reactor trip and bypass breakers.

___Page Completed Page 2 of 19

FNP-1-FRP-S.1

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..:it RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained NOTE:

The DEB Valve Test Display may be used for alternate indication of turbine stop valve and governor valve position.

-- 2 Check turbine - TRIPPED.

[ ]

TSLB2 14-1 lit

[ ]

TSLB2 14-2 lit

[]

TSLB2 14-3 lit

[ ]

TSLB2 14-4 lit 2

Perform the following.

2.1 Place MAIN TURB EMERG TRIP switch to TRIP for at least 5 seconds.

2.2 IF turbine NOT tripped, THEN close GVs.

2.2.1 Reduce GV position demand signal to zero from DEH panel.

[J TURBINE MANUAL depressed

[J GV CLOSE depressed

[J FAST ACTION depressed Step 2 continued on next page.

___Page Completed Page 3 of 19

FNP-I-FRP-S.l

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Action/Expected Response II I

I

-- 3 Verify AFW pumps - RUNNING.

3.1 MDAFWPs - RUNNING

[J lA amps > 0

[J IB amps > 0 3.2 TDAFWP - RUNNING IF NECESSARY TDAFWP STM SUPP FROM IB(IC)

SG

[]

MLB-4 1-3 lit

[]

MLB-4 2-3 lit

[]

MLB-4 3-3 lit TDAFWP SPEED

[]

SI 3411A > 3900 rpm TDAFWP SPEED CONT

[]

SIC 3405 at 100%

Response NOT Obtained NOTE:

• 2500 gallons of emergency boration is required for each control rod not fully inserted, up to a maximum of 17,309 gallons.

[CA]

Emergency boration should continue until an adequate shutdown margin is established.

4 4.1 Initiate Emergency Boration of

~

the Res.

Verify at least one CRG PUMP -

RUNNING.

Step 4 continued on next page.

___Page Completed Page 5 of 19

FNP-I-FRP-S.l

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j.t RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained 4.2 Start a boric acid transfer pump.

BATP

[J lA

[J 1B 4.3 Align normal emergency boration.

EMERG BORATE TO CRG PUMP SUCT

[J Q1E21MOV8104 open 4.2 Perform the following.

4.2.1 Align charging pump suction to RWST.

RWST TO CRG PUMP

[ ] QIE21LCVl15B open

[J Q1E21LCVl15D open VCT OUTLET ISO

[J Q1E21LCVl15C closed

[ ] Q1E21LCVl15E closed 4.2.2 Proceed to step 4.4.

4.3 Perform the following.

• Align charging pump suction to RWST.

RWST TO CRG PUMP

[ ] Q1E21LCVl15B open

[J Q1E21LCVl15D open VCT OUTLET ISO

[J QIE21LCVl15C closed

[J Q1E21LCV115E closed

• Align manual emergency boration flow path.

BORIC ACID TO BLENDER

[J QIE21FCVl13A open MAN EMERG BORATION

[J Q1E21V185 open (100 ft, AUX BLDG rad side chemical mixing tank area)

Step 4 continued on next page.

___Page Completed Page 6 of 19

FNP-1-FRP-S.l

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Jt RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained 4.4 Establish adequate letdown.

4.4.1 Verify 45 GPM letdown orifice - IN SERVICE.

LTDN ORIF ISO 45 GPM

[J Q1E21HV8149A open 4.4.2 Verify one 60 GPM letdown orifice - IN SERVICE.

LTDN ORIF ISO 60 GPM

[J Q1E21HV8149B open

[J Q1E21HV8149C open 4.5 Check pressurizer pressure LESS THAN 2335 psig.

4.6 Establish adequate charging flow.

• IF boration is from boric acid storage tank, THEN verify charging flow -

GREATER THAN 40 GPM.

• IF boration is from the

RWST, THEN verify charging flow -

GREATER THAN 92 GPM.

4.5 Verify PRZR PORVs and PRZR PORV ISOs - OPEN.

IF NOT,.

THEN open PRZR PORVs and PORV ISOs as necessary until pressurizer pressure less than 2135 psig.

e-1I5-~':> e-H~

C ~;:;J

~ aJetVd'-([f:

~ ~,

~P1""6- ~I\\ 0)'\\

~

Step 4 continued on next page.

___Page Completed Page 7 of 19

FNP-1-FRP-S.1

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JiL RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained 4.7 Verify emergency boration flow adequate.

4.7.1 IF normal emergency boration flow path aligned, THEN check emergency boration flow greater than 30 GPM.

BORIC ACID EMERG BORATE

[J FI 110 4.7.2 IF manual emergency boration flow path aligned, THEN check boric acid flow greater than 30 GPM.

MAKEUP FLOW TO CHG/VCT

[J BA FI 113 4.7.3 IF boration is from the

RWST, THEN verify charging flow -

GREATER THAN 92 GPM.

___Page Completed Page 8 of 19

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Jt RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 5

Action/Expected Response Verify containment ventilation isolation.

Response NOT Obtained 5.1 Verify containment purge dampers - CLOSED.

[]

3197

[]

3198D

[]

3198C

[]

3196

[]

3198A

[]

3198B 5.2 Verify containment mini purge dampers - CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[]

2866C

[]

2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[]

2866D

[]

2867D 5.3 Stop MINI PURGE SUPP/EXH FAN.

6 Check SI actuated.

6.1 Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[]

ACTUATED status light lit

[] MLB-l 1-1 lit

[]

MLB - 1 11 - 1 lit 6.2 Initiate ATTACHMENT 1, AUTUMATiC

~Ar'~'1'Y INJECTIUN VERIFICATION.

___Page Completed 6

5.1 Manually close dampers.

5.2 Manually close dampers.

[CA]

IF an SI signal is actuated during this procedure, THEN initiate ATTACHMENT 1, AUTOMATIC SAFETY INJECTION VERIFICATION.

Page 9 of 19

FNP-I-FRP-S.l

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J!L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Il 7

Action/Expected Response Check the following trips.

Response NOT Obtained 7.1 Verify all reactor trip and reactor trip bypass breakers -

OPEN.

7.2 Check turbine - TRIPPED.

[ ]

TSLB2 14-1 lit

[ ]

TSLB2 14-2 lit

[ ]

TSLB2 14-3 lit

[ ]

TSLB2 14-4 lit

___Page Completed Page 10 of 19 7.1 Locally open the reactor trip and reactor trip bypass breakers.

7.2 Locally place turbine overspeed lever to TRIP for at least 5 seconds.

(189 ft, TURB BLDG)

FNP-I-FRP-S.l

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jlL RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step II Action/Expected Response Response NOT Obtained CAUTION:

Emergency boration should be continued until adequate shutdown margin is established.

NOTE:

Step 8 is a continuing action step.

8

[CAl Check if reactor still critical.

• Check power range indication

- GREATER THAN OR EQUAL TO 5%.

PRl(2,3,4)

PERCENT FULL POWER

[J NI 41B

[J NI 42B

[J NI 43B

[J NI 44B

• Check any intermediate range startup rate - POSITIVE.

IRl(2) siu RATE

[J NI 35D

[J NI 36D 8

Go to procedure and step in effect.

___Page Completed Page 11 of 19

FNP-1-FRP-S.1

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..!IL RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained 9

Monitor CST level.

9.1

[CA]

Check CST level greater than 5.3 ft.

CST LVL

[]

LI 4132A

[]

LI 4132B 9.2 Align makeup to the CST from water treatment plant OR demin water system using FNP-1-S0P-5.0, DEMINERALIZED MAKEUP WATER SYSTEM, as necessary.

10 Check SG levels.

10.1 Check at least one SG narrow range level - GREATER THAN 31%{48%}.

9.1 Align AFW pumps suction to SW using FNP-1-S0P-22.0, AUXILIARY FEEDWATER SYSTEM.

10.1 Perform the following.

10.1.1 Verify total AFW flow greater than 700 gpm.

AFW FLOW TO 1A(lB,lC)

SG

[] FI 3229A

[ ] FI 3229B

[ ] FI 3229C AFW TOTAL FLOW

[ ] FI 3229 Step 10 continued on next page.

___Page Completed Page 12 of 19

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained I

I 10.1.2 Verify AFW valves open.

MDAFWP TO 1A(lB,lC)

SG FLOW CONT

[ ] HIC 3227AA

[ ] HIC 3227BA

[ ] HIC 3227CA TDAFWP TO 1A(lB,lC)

SG FLOW CONT

[ ] HIC 3228AA

[ ] HIC 3228BA

[ ] HIC 3228CA AFW TO 1A(lB,lC)

SG STOP VLV

[ ] 'Q1N23MOV3350A

[ ]

Q1N23MOV3350B

[ ] Q1N23MOV3350C MDAFWP TO 1A(lB,lC)

SG ISO (BOP)

[J Q1N23MOV3764A

[ ]

Q1N23MOV3764D

[ ]

Q1N23MOV3764F

[ ]

Q1N23MOV3764E

[ ]

Q1N23MOV3764B

[ ] Q1N23MOV3764C Step 10 continued on next page.

___Page Completed Page 13 of 19

FNP-1-FRP-S.1

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.....L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained 10.2

[CA]

WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

10.2.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[]

FCV 3227 in MOD SG 1A 1B 1C MDAFWP TO 1A(lB,lC)

SG Q1N23HV

[] 3227A

[] 3227B

[] 3227C in MOD in MOD in MOD MDAFWP TO 1A(lB,lC)

SG FLOW CONT HIC

[]3227AA []3227BA []3227CA adjusted adjusted adjusted Step 10 continued on next page.

___Page Completed Page 14 of 19

FNP-1-FRP-S.1

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J'L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Action/Expected Response Response NOT Obtained 11 I

I I

10.2.2 Control TDAFWP flow.

TDAFWP FCV 3228

[]

RESET reset TDAFWP SPEED CONT

[ ]

SIC 3405 adjusted SG TDAFWP TO 1A(lB,lC)

SG Q1N23HV 1A

[] 322 8A in MOD 1B

[] 3228B in MOD 1C

[] 3228C in MOD TDAFWP TO 1A(lB,lC)

SG FLOW CONT HIC

[]3228AA []3228BA []3228CA adjusted adjusted adjusted

_11 Verify dilution paths isolated.

11.1 Isolate RMW to boric acid blender.

RMW TO BLENDER

[]

Q1E21FCVl14B closed 11.2 Notify Chemistry to secure the zinc addition system (ZAS).

11.3 Verify RMW supp iso to CHG pump suction locked closed (key # Z-58).

[]

Q1E21V212 locked closed (100' elev.

AUX BLDG BIT area at suction of CRG pumps)

___Page Completed Page 15 of 19 11.1 Locally isolate RMW to CVCS.

RMW TO CVCS ISO

[]

Q1E21V233 closed (100' elev.

AUX BLDG above hydro test pump)

FNP-I-FRP-S.l

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j*L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 12 Action/Expected Response Check for reactivity addition from UNCONTROLLED RCS cooldown:

12 Response NOT Obtained Perform the following:

• Check RCS cold leg temperature - DECREASING IN AN UNCONTROLLED MANNER.

RCS COLD LEG TEMP

[J TR 410

• Check any SG pressure -

FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

12.1 Stop any CONTROLLED cooldown.

12.2 Proceed to step 15.

_13

_14 Check main steam line isolation and bypass valves - CLOSED.

Check SGs not faulted.

14.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

13 Close the main steam line isolation and bypass valves.

lA(IB,IC)

SG MSIV - TRIP

[J QINIIHV3369A

[J QINIIHV3369B

[J QINIIHV3369C

[J QINIIHV3370A

[J QINIIHV3370B

[J QINIIHV3370C lA(IB,IC)

SG MSIV - BYPASS

[J QINIIHV3368A

[J QINIIHV3368B

[J QINIIHV3368C

[J QINIIHV3976A

[J QINIIHV3976B

[J QINIIHV3976C 14.1 Isolate faulted SG(s) using ATTACHMENT 2.

_15 Check core exit TiCs - LESS THAN 1200°F.

___Page Completed 15 IF fifth hottest core exit Tic greater than 1200°F AND rising, rT1T.,.,...,

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.L, SEVERE ACCIDENT CONTROL ROOM GUIDELINE INITIAL RESPONSE.

Page 16 of 19

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response Response NOT Obtained CAUTION:

Emergency boration should be continued until adequate shutdown margin is established.

_16 17 Check if reactor still critical.

• Check power range indication

- GREATER THAN OR EQUAL TO 5%.

PRl(2,3,4)

PERCENT FULL POWER

[J NI 41B

[J NI 42B

[J NI 43B

[J NI 44B

• Check any intermediate range startup rate - POSITIVE.

IRl(2) siu RATE

[J NI 35D

[J NI 36D Continue emergency boration.

16 17 Go to procedure and step in effect.

Perform the following.

17.1 Determine if moderator temperature coefficient positive or negative.

[J Core Physics Curve 5 17.2 IF moderator temperature coefficient negative, THEN allow RCS to heat up.

___Page Completed Page 17 of 19

FNP-I-FRP-S.l

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Il Action/Expected Response Response NOT Obtained NOTE:

18 Actions of other Function Restoration Procedures in effect which will not add positive reactivity to the core may be performed while efforts to return the core to a subcritical condition continue.

Return to step 4.

-END-Page 18 of 19

FNP-1-FRP-S.1 START STEP

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..ilL RESPONSE TO NUCLEAR POWER GENERATION/ATWT CONTINUOUS ACTION Revision 25 D

D 1

CAUTION

[CA]

RCPs should NOT be tripped with reactor power GREATER THAN 5%.

4 NOTE

[CA] Emergency boration should continue until an adequate shutdown margin is established.

D 6

6 [R]

[CA]

IF an SI signal is actuated during this procedure, THEN initiate ATTACHMENT 1, AUTOMATIC SAFETY INJECTION VERIFICATION.

D D

D 8

[CA]

Check if reactor still critical.

9 9.1

[CA]

Check CST level greater than 5.3 ft.

10 10.2

[CA]

WHEN SG narrow range level greater than 31%{48%},

THEN maintain SG narrow range level 31%-65%{48%-65%}.

Page 19 of 19

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Il Action/Expected Response ATTACHMENT 1 Response NOT Obtained AUTOMATIC SAFETY INJECTION VERIFICATION CAUTION:

Diesel generator damage may occur if all running diesels are not supplied with service water within three minutes.

1 Check power to 4160 V ESF busses.

1.1 4160 V ESF busses - AT LEAST ONE ENERGIZED

• A Train (F & K) power available lights lit

• B Train (G & L) power available lights lit 1.2 4160 V ESF busses - BOTH ENERGIZED

[J A Train (F & K) power available lights lit

[J B Train (G & L) power available lights lit 1.3 Verify operating diesel generators are being supplied from at least one SW pump.

1.2 Try to restore power to deenergized 4160 V ESF bus as time permits while continuing with the remainder of this procedure.

1.3 IF service water flow cannot be readily restored to a running diesel generator THEN secure the diesel generator using operator aid located on EPB.

___Page Completed Page 1 of 8

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 1 Response NOT Obtained 2

Check SI Status.

2.1 Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[J ACTUATED status light lit

[J MLB-l 1-1 lit

[J MLB-l 11-1 lit 2.2 Verify both trains of SI-ACTUATED.

[J MLBI 1-1 AND MLBI 11-1 lit 3

Verify main feedwater status.

3.1 Verify main feedwater flow control and bypass valves -

CLOSED.

lA(IB,IC)

SG FW FLOW

[J FCV 478

[]

FCV 488

[J FCV 498 lA(IB,IC)

SG FW BYP FLOW

[J FCV 479

[]

FCV 489

[J FCV 499 3.2 Verify both steam generator feed pumps - TRIPPED.

3.3 Verify SG blowdown - ISOLATED.

lA (IB, lC)

SGBD ISO

[]

QIG24HV7614A closed r 1

(\\ 1 ("' ') /. U1 T7 h 1 /I"R n 1 r.. rc r.. ~

LJ

\\.)(..L'J~

'-J

.L.LJ

-~

~~

[J QIG24HV7614C closed 2.2 Manually actuate SI.

3.1 Verify main feedwater stop valves closed.

MAIN FW TO lA(IB,IC)

SG STOP VLV

[J QIN21MOV3232A

[J QIN21MOV3232B

[J QIN21MOV3232C 3.2 Stop both EH PUMPs.

Step 3 continued on next page.

___Page Completed Page 2 of 8

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 1 Response NOT Obtained 3.4 Verify SG blowdown sample ISOLATED MLB lights lit.

1A(lB,lC)

SGBD SAMPLE ISO

[ ]

MLB4 6-4 lit Q1P15HV3328 closed

[J MLB4 7-4 lit Q1P15HV3329 closed

[ ]

MLB4 8-4 lit Q1P15HV3330 closed 3.4 Locally verify SGBD sample -

isolated (BOP).

STEAM GEN 1A(lB,lC)

SAMPLE ISO

[J Q1P15HV3328 closed

[J Q1P15HV3329 closed

[J Q1P15HV3330 closed OR Locally verify SGBD sample-isolated (PRIP).

STEAM GEN 1A(lB,lC)SAMPLE ISO 4

Verify PHASE A CTMT ISO.

4.1 Verify PHASE A CTMT ISO -

ACTUATED.

[J MLB-2 1-1 lit

[J MLB-2 11-1 lit

[J Q1P15HV3179C

[J Q1P15HV3180C

[J Q1P15HV3181C closed closed closed NOTE:

The turbine building SW isolation valves Q1P16V515, 517, 514 and 516 will take approximately two minutes to fully stroke closed.

4.2 Check all MLB-2 lights - LIT.

5 Verify one CRG PUMP in each train - STARTED.

[ ] A train (lA or 1B) amps > 0

[ ] B train (lC or 1B) amps > 0 4.2 Verify proper PHASE A CTMT ISO alignment.

___Page Completed Page 3 of 8

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 6

7 Action/Expected Response ATTACHMENT 1 Verify RHR PUMPs - STARTED.

RHR PUMP

[J lA amps > 0

[J IB amps > 0 Verify each train of CCW -

STARTED.

Response NOT Obtained

_8 7.1 Verify one CCW PUMP in each train-STARTED.

A train HX lC or IB CCW FLOW

[J FI 3043CA > 0 gpm OR

[J FI 3043BA > 0 gpm B train HX lA or IB CCW FLOW

[J FI 3043AA > 0 gpm OR

[J FI 3043BA > 0 gpm 7.2 Verify SW flow to associated CCW HX's.

SW FROM lA(IB, Ie)

CCW HX

[J QIP16FI3009AA > 0 gpm

[J QIP16FI3009BA > 0 gpm

[J QIP16FI3009CA > 0 gpm Verify each SW train - HAS TWO SW PUMPs STARTED.

[J A train (IA,IB or lC)

[J B train (ID,IE or lC) 7.2 Modulate open SW to the associated CCW HX's.

[J QIP16FV3009A

[J QIP16FV3009B

[J QIP16FV3009C

___Page Completed Page 4 of 8

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J:L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Il 9

Action/Expected Response ATTACHMENT 1 Verify containment fan cooler alignment.

Response NOT Obtained 9.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED

• A train

[J 1A

[J 1B

• B train

[J 1C

[J 1D 9.2 Verify associated emergency service water outlet valves -

OPEN.

EMERG SW FROM 1A(lB,lC,lD)

CTMT CLR

[J Q1P16MOV3024A

[J Q1P16MOV3024B

[J Q1P16MOV3024C

[J Q1P16MOV3024D

___Page Completed Page 5 of 8

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J,L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 1 Response NOT Obtained 10 Check no main steam line 10 Perform the following.

isolation actuation signal present.

10.1 Verify main steam line isolation and bypass valves closed.

Signal SetDoint Coincidence TSLB TSLB4 lA(IB,IC)

SG LO 19-2 MSIV - TRIP SG PRESS < 585 psig 2/3 19-3

[ ] QINIIHV3369A 19-4

[ ] QINIIHV3369B TSLB4

[ ] QINIIHV3369C HI 1/2 16-3 16-4

[J QINIIHV3370A STEAM

> 40%

ON 17-3 17-4

[ ] QINIIHV3370B FLOW 2/3 18-3 18-4

[ ] QINIIHV3370C AND TSLB2 lA(IB,IC)

SG 10-1 MSIV - BYP LO-LO

< 543 0 F 2/3 10-2

[ ] QINIIHV3368A TAVG 10-3

[ ] QINIIHV3368B TSLBI

[ ] QINIIHV3368C HI-HI 2-2

[ ] QINIIHV3976A CTMT

>16.2 psig 2/3 2-3

[ ] QINIIHV3976B PRESS 2-4

[] QINIIHV3976C 10.2 IF any main steam isolation valve open, THEN place the associated test switch in the TEST position.

SG lA IB lC lA(IB,IC)

SG MSIV - TEST QINIIHV

[J 3369AI

[J 3369BI

[J 3369CI 70A 70B 70C

___Page Completed Page 6 of 8

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Il Action/Expected Response ATTACHMENT 1 Response NOT Obtained CAUTION:

RCPs should NOT be tripped with reactor power GREATER THAN 5%.

NOTE:

Step 11 is a continuing action step while in this procedure.

11 Check containment pressure -

HAS REMAINED LESS THAN 27 psig.

CTMT PRESS

[J PR 950 11 Perform the following.

11.1 Verify PHASE B CTMT ISO -

ACTUATED.

[] MLB-3 1-1 lit

[ ]

MLB-3 6-1 lit 11.2 Stop all RCPs.

RCP

[ ]

1A

[J 1B

[ ]

1C 11.3 Verify PHASE B CTMT ISO alignment.

11.3.1 Check All MLB-3 lights lit.

11.3.2 IF any MLB-3 light NOT lit, THEN verify proper PHASE B CTMT ISO alignment.

___Page Completed Step 11 continued on next page.

Page 7 of 8

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 1 Response NOT Obtained 11.4 Check containment spray.

11.4.1 Check containment spray flow in both trains greater than 0 gpm.

CS FLOW

[J FI 958A

[J FI 958B 11.4.2 IF containment spray flow in both trains NOT greater than 0 gpm, THEN verify containment spray pump suction valves open.

RWST TO 1A(lB)

CS PUMP

[J Q1E13MOV8817A

[J Q1E13MOV8817B

-END-Page 8 of 8

FNP-1-FRP-S.1

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J't, RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 2 FAULTED SG ISOLATION Response NOT Obtained CAUTION:

A loss of secondary heat sink will result from failure to maintain at least one SG available for RCS cooldown.

1 Isolate all faulted SGs.

1.1 Verify all faulted SG atmospheric reliefs - MANUALLY CLOSED.

Faulted SG 1A 1B 1C 1.1 Locally unlock and close one isolation valve for any failed atmospheric relief.

(127 ft, AUX BLDG main steam valve room) 1A(lB,lC)

MS ATMOS REL VLV PC

[J 3371A [J 3371B

[J 3371C Faulted SG Q1N11V 1A 1B 1C

[J 004A [J 004C

[J 004E

[J 004B

[J 004D

[J 004F Key Z-131 Z-126 Z-125 Z-124 Z-123 Z-122 1.2 Verify all faulted SG main feed stop valves - CLOSED.

Faulted SG 1A 1B 1C 1.2 Locally close all faulted SG main feed stop valves.

(127 ft, AUX BLDG main steam valve room)

MAIN FW TO 1A(lB,lC)

SG STOP VLV Q1N21MOV

[]

3232A

[]

3232B

[]

3232C Step 1 continued on next page.

___Page Completed Page 1 of 8

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 2 Response NOT Obtained 1.3 Verify blowdown from all faulted SGs - ISOLATED.

1.3 Locally isolate blowdown.

(121 ft, AUX BLDG rad side at PRIP)

[J 7697A

[J 7698A

[J 7699A stopped stopped stopped

[J 7697B

[J 7698B

[J 7699B stopped stopped stopped Faulted SG 1A(lB,lC)

SGBD ISO Q1G24HV 1A

[J 7614A closed 1B

[J 7614B closed 1C

[J 7614C closed Faulted SG 1A(lB,lC)

SGBD PENE RM ISO Q1G24HV 1A 1B 1C CAUTION:

The TDAFWP will not be available if both steam supplies are isolated.

At least one steam supply should remain aligned if TDAFWP required.

1.4 IF 1C SG faulted, THEN isolate TDAFWP steam supply from 1C SG.

1.4.1 Isolate TDAFWP steam supply from 1C SG at hot shutdown panel.

TDAFWP STM SUPP FROM 1C SG

[J Q1N12HV3235B in LOCAL (HSDP-F)

TDAFWP STM SUPP FROM 1C SG

[J Q1N12HV3235B to STOP (HSDP-D) 1.4 Proceed to step 1.5.

1.4.1 Locally unlock and close STM LINE 1C TO TDAFWP ISO VLV Q1N12V005B.

(Key Z-132)

(127 ft, AUX BLDG main steam valve room)

Step 1 continued on next page.

___Page Completed Page 2 of 8

FNP-1-FRP-S.1

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 2 Response NOT Obtained 1.5 IF 1B SG faulted, THEN isolate TDAFWP steam supply from 1B SG.

1.5.1 IF TDAFWP NOT required, THEN isolate TDAFWP steam supply from 1B SG at hot shutdown panel.

TDAFWP STM SUPP FROM 1B SG

[J Q1N12HV3235A/26 in LOCAL (HSDP-F)

TDAFWP STM SUPP FROM 1B SG

[J Q1N12HV3235A/26 to STOP (HSDP-D) 1.5 Proceed to step 2.

Step 1 continued on next page.

___Page Completed Page 3 of 8

FNP-1-FRP-S.l

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step Il Action/Expected Response ATTACHMENT 2 Response NOT Obtained CAUTION:

Failing open TDAFWP STM SUPP ISO Q1N12HV3226 will cause the RGSC to ramp to maximum output. Admitting steam to the TDAFWP with TDAFWP SPEED CONT SIC-3405 NOT set to 0% could cause a TDAFWP overspeed trip.

1.5.2 IF TDAFWP required, THEN perform one of the following.

• Perform the following:

a)

Close TDAFWP STM SUPP WARMUP ISO valves (BOP)

[J Q1N12HV3234A Closed

[J Q1N12HV3234B Closed b)

IF the TDAFWP is NOT in operation, THEN adjust TDAFWP SPEED CONT to 0%

[J SIC 3405 adjusted to 0%

c)

Open TDAFWP STM SUPP ISO QlN12HV3226 by failing air supply.

(100 ft, AUX BLDG TDAFWP room)

Step 1 continued on next page.

___Page Completed Page 4 of 8

FNP-I-FRP-S.l

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j~L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step II Action/Expected Response ATTACHMENT 2 d)

Isolate TDAFWP steam supply from IB SG at hot shutdown panel.

TDAFWP STM SUPP FROM IB SG

[J QIN12HV3235A/26 in LOCAL (HSDP-F)

TDAFWP STM SUPP FROM IB SG

[J QIN12HV3235A/26 to STOP (HSDP-D) e)

Adjust TDAFWP SPEED CONT SIC 3405 as required when starting or stopping TDAFWP.

• Locally unlock and close STM LINE IB TO TDAFWP ISO VLV QINI2V006A.

(Key Z-13 0)

(127ft, AUX BLDG main steam valve room)

Response NOT Obtained

___Page Completed Page 5 of 8

FNP-l-FRP-S.l

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RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 2 Response NOT Obtained 2

IF all SGs faulted, THEN maintain 20 gpm AFW flow to each SG.

2.1 Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO lA/lB/lC SG B TRN

[]

FCV 3227 in MOD 2

Proceed to step 3.

SG lA lB lC MDAFWP TO lA(lB,lC)

SG QIN23HV

[] 3227A

[] 3227B

[] 3227C in MOD in MOD in MOD MDAFWP TO lA(lB,lC)

SG FLOW CONT HIC

[] 3227AA []3227BA [] 322 7CA adjusted adjusted adjusted Step 2 continued on next page.

___Page Completed Page 6 of 8

FNP-I-FRP-S.l

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..!it RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 2 Response NOT Obtained 2.2 Control TDAFWP flow.

TDAFWP FCV 3228

[J RESET reset TDAFWP SPEED CONT

[J SIC 3405 adjusted SG lA IB lC

[] 3228AA

[] 3228BA [] 3228CA adjusted adjusted adjusted TDAFWP TO lA(lB,lC)

SG QIN23HV

[J3228A in MOD TDAFWP TO lA(IB,lC)

SG FLOW CONT HIC

[] 3228B in MOD

[J 3228C in MOD 2.3 Proceed to step 4.

3 Isolate AFW flow to all faulted SGs.

3.1 Close MDAFWP isolation valves to all faulted SGs.

(BOP) 3.1 Close MDAFWP flow control valves to all faulted SGs.

Faulted SG lA IB lC Faulted SG lA IB lC MDAFWP TO MDAFWP TO lA (IB, lC) lA(IB,IC)

SG SG ISO QIN23HV

[J3227A

[J 3227B

[J 3227C QIN23MOV

[J 37 64A

[J 3764B

[J 3764C in MOD in MOD in MOD

[J 3764E

[J 37 64D

[J 3764F MDAFWP TO lA(IB,IC)

SG FLOW CONT HIC

[J 3227AA

[J 322 7BA

[J 3227 CA Step 3 continued on next page.

___Page Completed Page 7 of 8

FNP-I-FRP-S.I

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.*L RESPONSE TO NUCLEAR POWER GENERATION/ATWT Revision 25 Step 11 Action/Expected Response ATTACHMENT 2 Response NOT Obtained 3.2 Close TDAFWP flow control valves to all faulted SGs.

Faulted SG TDAFWP TO IA(IB,IC)

SG QIN23HV IA

[] 3228A in MOD IB

[] 3228B in MOD IC

[] 3228C in MOD TDAFWP TO IA(IB,lC)

SG FLOW CONT HIC

[]3228AA []3228BA []3228CA 3.3 Locally unlock and close flow control valve inlet isolation to all faulted SGs.

(100 ft, AUX BLDG above AFW pump rooms)

Faulted SG IA IB IC QlN23V

[]

017A []

017B

[J 017C Key Z-139 Z-170 Z-14I 4

Notify control room of SG isolation status.

-END-Page 8 of 8

Farley Nuclear Plant 2006-301 SRO Inital Exam

90. 076 G2.1.2 001 Given the following:

Unit 2 is at 100% power with"A" Train on service.

At 1200 on 11/7/2007, 2E Service Water pump tripped and "B" Train SW was declared INOPERABLE.

Which ONE of the following describes the Technical Specification REQUIRED ACTION lAW 3.7.8, Service Water System, and the action required to make "B" Train Service Water OPERABLE?

A'!

• Immediately declare the DG supported by Train "B" Service Water INOPERABLE.

• Place "B" Train of SW on service and align 2C SW pump to auto start for 2E SW pump lAW SOP-24.0, Service Water System.

B.

• Immediately declare the DG supported by Train "B" Service Water INOPERABLE.

• Align 2C SW pump to auto start for 2E SW pump lAW AOP-1 0.0, Loss of Service Water.

c.

• Declare the DG supported by Train "B" Service Water INOPERABLE no later than 1600 on 11/7/2007 (4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> later).

• Align 2C SW pump to auto start for 2E SW pump lAW AOP-10.0, Loss of Service Water.

D.

• Declare the DG supported by Train "B" Service Water INOPERABLE no later than 1600 on 11/7/2007 (4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> later).

• Place B Train of SW on service and align 2C SW pump to auto start for 2E SW pump lAW SOP-24.0, Service Water System.

Meets 10 CFR 55.43 (b) 2 and 5 requirements for SRO level question A. Correct. This TS immediately entered from 3.7.8 and the DG is declared INOP.

Then the 2C SW pump is aligned to auto start for 2E. The trains are swapped to do this. This will allow both trains to be operable.

AOP-10 CAUTION: Based on plant needs, shifting electrical trains in FNP-1-S0P-24.0, SERVICE WATER SYSTEMS, may be delayed. Subsequent shifting of electrical trains is required for train separation.

19 IF affected train NOT leaking, THEN evaluate aligning 1C SW pump to affected train using FNP-2-S0P-24.0, SERVICE WATER SYSTEM.

Bases 3.7.8 Leo Two SWS trains are required to be OPERABLE to provide the required redundancy to

Farley Nuclear Plant 2006-301 SRO Inital Exam ensure that the system functions to remove post accident heat loads, assuming that the worst case single active failure occurs coincident with the loss of oftsite power.

An SWS train is considered OPERABLE during MODES 1, 2, 3, and 4 when:

a. Two pumps are OPERABLE; and

b. The associated piping, valves, and instrumentation and controls required to perform the safety related function are OPERABLE.

Note from A.1 The first Note indicates that the applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources-Operating," should be entered if an inoperable SWS train results in an inoperable emergency diesel generator.

FSD 181001 3.1.5.1 The Service Water pumps shall be automatically started by a signal from the LOSP or ESS sequencer. The Service Water swing pump shall be automatically started by a signal from the LOSP or ESS sequencer when in service replacing one ofthe train oriented pumps. (References 6.7.039 and 6.1.009)

SOP-24 P&L 3.3 Service Water pump lC may be selected for auto-start from the ESS or the LOSP sequencers, instead ofan A Train or B Train pump, by using key-interlocked selector switches at the SW local control panels. Normal position ofboth the A Train and B Train selector switches will be the lC position and lC SW pump will not autostart.

B. Incorrect.

This TS is immediately entered from 3.7.8 and the DG is declared INOP.

The second part is in part correct but B Train would be however AOP-1 0 sends the operator to SOP-24 to select the 2C SWP to autostart and if this was done wlo swapping trains it would be in an incorrect alignment. This has to be done in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (3 days later) lAW TS 3.7.8. NOT 7 days.

C. incorrect.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> would NOT be allowed to declare inop if DG was OOS.

The second part is in NOT correct. See above.

D. incorrect.

4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> would NOT be allowed to declare inop if DG was OOS.

Second part of this is correct.

Farley Nuclear Plant 2006-301 SRO Inital Exam 076 Service Water System G2.1.2 Conduct of Operations: Knowledge of operator responsibilities during all modes of plant operation.

Question Number:

90 Tier 2 Group 1 Importance Rating:

4.0 Technical

Reference:

TS 3.7.8, 3.8.1, AOP-10, SOP-24 Proposed references to be provided to applicants during examination:

None Learning Objective:

10 CFR Part 55 Content:

43.2 Comments:

fixed per FJE comments and added how to restore B train to operable status.

1/3/2008 14:27 FNP-2-AOP-I0.0 01-24-2005 Revision 15 FARLEY NUCLEAR P~ANT ABNORMAL OPERATING PROCEDURE FNP-2-AOP-I0.0 LOSS OF SERVICE WATER PROCEDURE USAGE REQUIREMENTS SECTIONS CONTINUOUS USE - Each step of the procedure is to be read prior to performing that step.

Each step is to be performed in the sequence given.

Where required, each-step is to be signed off as complete before proceeding to the next step.

ALL S

A F

E T

Y REFERENCE USE - The procedure is to be referred to periodically to confirm that all required parts of a work activity have been performed.

Where required, steps are to be signed off to show that procedure requirements have been met.

R E

L A

T E

D INFORMATION USE - An activity may be performed from memory, but the procedure should be available for use as needed and for training.

Approved:

Ray Martin Operations Manager 01/31/2005 Date Issued:

~

.. FNP-2-AOP-I0.0 LOSS OF SERVICE WATER Revision 15 Table of Contents Procedure Contains Number of Pages Body...................................

14............................

1 Page 1 of 1

'FNP-2-AOP-I0.0 A.

Purpose

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LOSS OF SERVICE WATER Revision 15 This procedure provides actions for response to a loss of one or both trains of service water.

This procedure is applicable at all times.

B.

Symptoms or Entry Conditions I.

This procedure is entered when a loss of either train of service water is indicated by any of the following:

a.

Actuation of SW PRESS A TRN LO annunciator AD4 or SW PRESS B TRN LO annunciator ADS (60 psig) b.

Actuation of SW PUMP TRIPPED annunciator AE4 c.

Actuation of SW TO AUX BLDG HDR PRESS A OR B TRN LO annunciator AE5 (50 psig) d.

Trip of any operating SW PUMP e.

Rising temperatures on components supplied by service water f.

Loss of power to one or both SW 4160 V busses 2K or 2L Page 1 of 14

FNP-2-AOP-I0.0 i?,'t::,t,:,:,

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LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response Response NOT Obtained NOTE:

SW TO TURB BLDG ISO ACB)

TRN valves will automatically close if SW flow in either train is greater than 17,600 gpm.

-- I Verify affected SW 4160 V supply breakers closed.

[]

BKR DF02 closed

[]

BKR DG02 closed

-- 2 IF a SW PUMP trips.

THEN verify standby SW PUMP started.

-- 3 IF SW pressure in both trains greater than 60 psig.

THEN go to procedure and step in effect.

CAUTION:

A running diesel generator will overheat if adequate SW flow is not provided.

Steps 4.2.1 through 4.2.6 must be performed immediately to verify adequate SW flow to a running diesel generator.

4 Check diesel generators.

4.1 Check any diesel generator in affected train - STARTED.

4.1 Proceed to step 5.

Step 4 continued on next page.

___Page Completed Page 2 of 14

I/pr2uuo. i'-t.27 FNP-2-AOP-I0.0

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LOSS OF SERVICE WATER Revision 15 Step rJ Action/Expected Response Response NOT Obtained NOTE:

The loss of Service Water to the Turbine Building could be unisolable and would affect both trains of Service Water.

The intent of Step 4.2 RNO is to allow isolation of an affected train if possible.

If both trains are affected then the Turbine Building must be isolated and the turbine generator removed from service.

4.2 IF diesel generator NOT

required, THEN secure diesel generator using ATTACHMENT 1.

4.2 Perform the following SW isolations.

4.2.1 Isolate SW on the affected train(s) to the turbine building.

Close A TRN SW TO TURB BLDG ISO valves.

[]

Q2P16V515

[]

Q2P16V516 (B trn elect)

Close B TRN SW TO TURB BLDG ISO valves.

[]

Q2P16V514

[]

Q2P16V517 (A trn elect)

Close A TRN SW FROM TURB BLDG HDR ISO valves.

[]

Q2P16V540

[]

Q2P16V542 VOLIAN Close B TRN SW FROM TURB BLDG HDR ISO valves.

[]

Q2P16V541

[]

Q2P16V543 Step 4 continued on next page.

___Page Completed Page 3 of 14

FNP-2-AOP-I0.0 i:::

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...IL.*"\\i\\',.1.Jlt.....!IIt..<::;;:::::,f LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response Response NOT Obtained 4.2.2 IF both trains of service water have been isolated to the turbine building,.

THEN perform the following:

4.2.2.1 IF Rx power is less than 35%,

THEN trip the turbine and refer to FNP-2-AOP-3.0, TURBINE TRIP BELOW THE P9 SET POINT.

4.2.2.2 IF Rx power is greater than 35%,

THEN trip the reactor and refer to FNP-2-EEP-O.O, REACTOR TRIP 4.2.3 Perform FNP-2-AOP-7.0, LOSS OF TURBINE BUILDING SERVICE WATER in conjunction with this procedure.

4.2.4 Close SW TO RCP MTR AIR CLRS Q2P16MOV313S and SW TO BLDN HX & BTRS CHLR Q2P16MOV3149.

4.2.S Verify diesel bUilding SW header valves open.

SW TO/FROM DG BLDG HDR A

[]

Q2P16V519/S37 open SW TO/FROM DG BLDG HDR B

[]

Q2P16V518/S36 open Step 4 continued on next page.

___Page Completed Page 4 of 14

'FNP AOP -1 0. 0

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LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response Response NOT Obtained 4.2.6 IF unable to maintain running diesel generator(s) lube oil temperature below the alarm(155' DG BLDG local control panel)

THEN perform the following.

4.2.6.1 For shared diesel generators verify Unit 1 Service Water aligned.

NOTE:

5 No evaluation has been performed to demonstrate that the Unit 1

'B' Train Service Water System is capable of supplying the cooling requirements for IB and 2B diesel at the same time.

4.2.6.2 IF Unit 1 SW is available for 2B diesel generator,.

THEN align Unit 1 SW supply to 2B diesel generators.

2B DIESEL GENERATOR SW SUPP TO/FROM UNIT 1 (UNIT 2)

[]

QIP16V592/s93 open

[]

Q2P16V592/s93 closed 4.2.7 IF unable to maintain running diesel generator(s) lube oil temperature alarm clear (155' DG BLDG local control panel)

THEN stop affected diesel generator.using ATTACHMENT 1.

Verify all available SW PUMPs STARTED.

___Page Completed Page 5 of 14

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LOSS OF SERVICE WATER Revision 15 Step 11 6

Action/Expected Response Check pressure in a SW train GREATER THAN 60 psig.

6 Response NOT Obtained IF, one train of Service Water cannot be immediately restored to the Turbine Building,.

THEN.perform the following:

6.1 Isolate SW to the turbine bUilding.

Close SW TO TURB BLDG ISO A TRN ISO valves.

[]

Q2P16V515

[]

Q2P16V516 (B Trn Electrical)

Close SW TO TURB BLDG ISO A TRN ISO valves.

[]

Q2P16V514

[]

Q2P16V517 (A Trn Electrical)

Close SW FROM TURB BLDG A HDR ISO valves

[]

Q2P16V540

[]

Q2P16V542 Close SW FROM TURB BLDG B HDR ISO valves

[]

Q2P16V541

[]

Q2P16V543 6.2 IF Rx power is less than 35%,

THEN trip the turbine and refer to FNP-2-AOP-3.0, TURBINE TRIP BELOW THE P9 SET POINT.

6.3 IF Rx power is greater than 35%,.

THEN trip the reactor and refer to FNP-2-EEP-O.O, REACTOR TRIP 6.4 Close SW TO RCP MTR AIR CLRS Q2P16MOV3135 and SW TO BLDN HX

& BTRS CHLR Q2P16MOV3149.

6.5 Perform FNP-2-AOP-7.0, LOSS OF TURBINE BUILDING SERVICE WATER in conjunction with this proceaure.

Step 6 continued on next page.

___Page Completed Page 6 of 14

FNP-2-AOP-I0.0

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LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response Response NOT Obtained 6.6 Verify SW isolated to standby CCW heat exchanger.

Standby CCW HX SW TO 2C(2B,2A)

CCW HX Q2P16MOV 2C

[] 3130C closed 2B

[] 3130B closed 2A

[] 3130A closed 6.7 Maintain SW flow to in service CCW heat exchanger 3500-4000 gpm.

In Service CCW HX 2C 2B 2A 2C(2B,2A)

CCW HX DISCH FCV HIC

[]

3009C

[]

3009B

[]

3009A adjusted adjusted adjusted 7

8 9

Check operating CCW train -

SUPPLIED FROM AFFECTED SW TRAIN.

Verify CCW PUMP in non affected train - STARTED.

Verify CRG PUMP in non affected train - STARTED.

7 Proceed to step 14.

CAUTION:

Steps 8 and 9 must be complete before step 10 is performed to ensure seal injection is maintained to the RCPs.

_10

_11 Verify all CRG PUMPs in affected train - STOPPED.

Perform FNP-2-AOP-9.0, LOSS OF 1M...,

IN K RJ

('()()T Tun Wf...rrER in conjunction with this procedure.

___Page Completed Page 7 of 14

'FNP-2-AOP-I0.0

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LOSS OF SERVICE WATER Revision 15 12.1 IF reactor critical, THEN perform the following.

Step Il 12 Action/Expected Response Monitor Rep motor bearing temperatures - LESS THAN 195°F.

12 Response NOT Obtained Perform the following.

NOTE:

The remainder of this procedure should be performed in conjunction with FNP-2-ESP-O.l, REACTOR TRIP RESPONSE if sufficient personnel are available.

12.1.1 Trip the reactor.

12.1.2 IF reactor tripped, THEN stop all RCPs.

RCP

[]

2A

[]

2B

[]

2C 12.1.3 Proceed to step 13.

12.2 IF reactor NOT critical, THEN perform the following.

12.2.1 Verify all reactor trip and reactor trip bypass breakers open.

[] Reactor trip breaker A

[] Reactor trip breaker B

[] Reactor trip bypass breaker A

[] Reactor trip bypass breaker B 12.2.2 Stop all RCPs.

RCP

[]

2A

[]

2B

[]

2C 12.2.3 IF unit in Mode 3 or 4, T.t1~l\\J perIorm l:!-Nt' LAUP 7I.0, LOSS OF REACTOR COOLANT FLOW in conjunction with this procedure.

___Page Completed Page 8 of 14

IP/LVVtD l"t.LI FNP-2-AOP-I0.0

'\\:::.:::,,,:,,:::.JL **:tt::::.:.:ll::::.

..j::.t.;:;:(,:.:::::::/

LOSS OF SERVICE WATER Revision 15 Step 11

_13 Action/Expected Response Minimize CCW loads in affected train.

Response NOT Obtained 13.1 Check on service SFP HX -

SUPPLIED FROM NON AFFECTED SW TRAIN.

13.2 IF RHR system in operation, THEN check operating RHR train supplied from non affected SW train.

13.1 Place non affected SFP HX in service using FNP-2-S0P-S4.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

13.2 IF RHR system in operation, THEN perform the following.

13.2.1 Place non affected RHR train in service using FNP-2-S0P-7.0, RESIDUAL HEAT REMOVAL SYSTEM.

13.2.2 Secure affected RHR train using FNP-2-S0P-7.0, RESIDUAL HEAT REMOVAL SYSTEM.

NOTE:

The CCW Pump Room Coolers are not considered to be attendant equipment; however, the room cooler fan must be tagged out of service when SW is lost to the affected cooler(s)

(Ref. NEL-96-0101; REA 95-0873).

13.3 Check on service CCW train -

SUPPLIED FROM NON AFFECTED SW TRAIN.

___Page Completed Page 9 of 14 13.3 Align non affected CCW train as on service train using FNP-2-S0P-23.0, COMPONENT COOLING WATER SYSTEM.

FNP-2-AOP-I0.0 LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response Response NOT Obtained 14 Minimize SW loads in affected train.

14.1 If required, secure BTRS using FNP-2-S0P-3.0, BORON THERMAL REGENERATION SYSTEM.

14.2 Minimize A TRAIN SW LOADS as required.

14.2.1 Secure SGBD using FNP-2-S0P-16.1, STEAM GENERATOR BLOWDOWN PROCESSING SYSTEM.

14.2.2 Close SW TO BLDN HX & BTRS CHLR Q2P16MOV3149 14.2.3 Stop A TRAIN CTMT CLRS

[] A Ctmt Cooler Q2EI2HOOIA-A

[] B Ctmt Cooler Q2EI2HOOIB-A 14.3 Minimize B TRAIN SW LOADS as required.

14.3.1 Close SW TO RCP MTR AIR CLRS Q2P16MOV3135.

14.3.2 Stop B TRAIN CTMT CLRS

[]

C Ctmt Cooler Q2EI2HOOIC-B

[] D Ctmt Cooler Q2EI2HOOID-B 14.4 Verify CTMT CLRS in non-affected train - STARTED.

A TRAIN CTMT CLRS

[] A Ctmt Cooler Q2EI2HOOIA-A

[] B Ctmt Cooler Q2EI2HOOIB-A B TRAIN CTMT CLRS

[]

C Ctmt Cooler Q2EI2HOOIC-B

[] D Ctmt Cooler Q2EI2HOOID-B 15 Evaluate event classification and notification requirements

___Page Completed Page 10 of 14

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LOSS OF SERVICE WATER Revision 15 Step Il

_16 Action/Expected Response Check pressure in both SW trains - GREATER THAN 60 psig.

16 Response NOT Obtained Perform the following.

16.1 Verify affected train SW PUMP MINI FLOW valves closed.

(SWIS) 16.2 Dispatch personnel to inspect SW system for leakage.

16.3 WHEN SW system leakage source is identified, THEN isolate leakage.

16.4 Close affected train dilution bypass line isolation valve.

Affected train DILUTION BYPASS ISOLATION VALVE Q2P16V A

[]

558 155 AUX bldg RADSIDE HALL B

[]

557 155 AUX bldg RADSIDE HALL

_17 Go to procedure and step in effect.

16.5 IF pressure in both SW trains greater than 60 psig, THEN go to procedure and step in effect IF NOT, proceed to step 18.

___Page Completed Page 11 of 14

1~~

~

J~\\>T~ ~o 1..... L. I t FNP-2-AOP-I0. 0 1!:[\\,:".".,.,}.Jt.*"'t::::;1.j!:ll.......l!:!t...,,(;;:.::::,,{,

LOSS OF SERVICE WATER Revision IS Step Action/Expected Response 11 I

I I

--18 Verify SW alignment to diesel generators based on affected train:

18.1 IF affected train has a Shared diesel generator running THEN verify Unit 1 SW aligned.

1-2A DIESEL GENERATOR (A TRN)

SW SUPP TO/FROM UNIT 1 (UNIT 2)

[ ]

QIPI6VS26/S34 open

[]

QIPI6VS27/S3S closed lC DIESEL GENERATOR (A TRN)

SW SUPP TO/FROM UNIT I(UNIT 2)

[]

QIPI6VS24/S32 open

[]

QIPI6VS2S/S33 closed 2C DIESEL GENERATOR (B TRN)

SW SUPP TO/FROM UNIT I(UNIT 2)

[]

QIPI6VS21/S29 open

[]

QIPI6VS20/S28 closed Response NOT Obtained NOTE:

No evaluation has been performed to demonstrate that the Unit 1

'B' Train Service Water System is capable of supplying the cooling requirements for IB and 2B diesel at the same time.

18.2 IF Unit 1 SW is available for 2B diesel generator,.

THEN align Unit 1 SW supply to 2B diesel generators.

2B DIESEL GENERATOR SW SUPP TO/FROM UNIT I(UNIT 2)

[]

QIPI6VS92/S93 open

[]

Q2P16VS92/S93 closed

___Page Completed Page 12 of 14

• • FNP AOP - 10. 0 m

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LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response Response NOT Obtained CAUTION:

To prevent a leak on one train from affecting both trains, 2C SW pump must not be realigned to a train with an unisolated leak.

CAUTION:

Based on plant needs, shifting electrical trains in FNP-I-S0P-24.0, SERVICE WATER SYSTEMS, may be delayed.

Subsequent shifting of electrical trains is required for train separation.

___19 IF affected train NOT leaking.

THEN evaluate aligning lC SW pump to affected train using FNP-2-S0P-24.0.

SERVICE WATER SYSTEM.

___20 Align 2C battery charger room cooler to non affected train using FNP-2-S0P-37.1.

125 V D.

C. AUXILIARY BUILDING DISTRIBUTION SYSTEM.

___21 Align 2B charging pump to non affected train using FNP-2-S0P-2.1.

CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION.

___22 Monitor 600 V load centers cooled by affected train.

22.1 IF load center operation is

degraded, THEN evaluate transferring loads to a non affected load center using FNP-2-S0P-36.3,

600, 480 AND 208/120 VOLT AC ELECTRICAL DISTRIBUTION SYSTEM.

_23 Check pressure in both SW trains - GREATER THAN 60 psig.

23 Return to step 1.

___Page Completed Page 13 of 14

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LOSS OF SERVICE WATER Revision 15 Step 11 Action/Expected Response ATTACHMENT 1 Response NOT Obtained 1

SECURING A DIESEL GENERATOR Secure affected diesel generator from EPB.

1.1 Place the affected diesel generator MODE SELECTOR SWITCH to MODE 2.

1.2 Depress affected diesel generator DIESEL EMERG START RESET pushbutton.

CAUTION:

Failure to perform steps 1.4 and 1.5 immediately following step 1.3 may result in restart of the diesel generator when the low speed relay de-energizes.

1.3 Depress affected diesel generator STOP pushbutton.

[]

DIESEL STOP light lit 1.4 Place affected diesel generator MODE SELECTOR SWITCH to MODE 3.

1.5 Depress affected diesel generator DIESEL EMERG START RESET pushbutton.

1 Secure affected diesel generator from diesel local control panel (15~

ft, DIESEL BLDG).

a)

Place affected diesel generator MODE 4 SELECTOR SWITCH to MODE 4 b)

Depress affected diesel generator local STOP pushbutton.

-END-Page 1 of 1

06/27/07 09:13:27 FNP-2-S0P-24.0 4.5 Aligning Train B (A) SW to charging pump 2B room cooler.

NOTE:

Service water to charging pump 2B room cooler shall be aligned to the same train that charging pump 2B is aligned to in the CVCS. This procedure should be performed by FNP-2-S0P-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION, which aligns charging pump 2B to Train B (A).

4.5.1 Align Train B (A) SW to Charging Pump 2B Room Cooler per FNP-2-S0P-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION.

4.6 Aligning service water pump 2C to A train.

4.6.1 To align service water pump 2C to A train, perform FNP-2-S0P-24.0C.

4.7 Aligning service water pump 2C to B train.

4.7.1 To align service water pump 2C to B train, perform FNP-2-S0P-24.0D.

4.8 Shutdown of service water system train A (B).

NOTE:

Prior to taking any actions that will significantly affect service water dilution flow, notify the shift radiochemist to ensure any chlorination can be adjusted or terminated as needed.

4.8.1 Close SW FROM TURB BLDG A (B) HDR ISO valves:

Q2P16V540 (Q2P16V~41)

Q2P16V542 (Q2P16V543).

4.8.2 Close SW TO TURB BLDG A (B) TRN Q2P16V515 (Q2P16V514)

Q2P16V516 (Q2P16V517).

4.8.3 Secure all but one A(B) train service water pump.

10 Version 51.0

06/27/07 09:13:27 FNP-2-S0P-24.0D SYSTEM CHECKLIST SYSTEM CHECKLIST SOP-24.0D ALIGNING SW PUMP 2C TO B TRAIN Situation Requiring Completion Of Check List:

Performed By:

Verified By:

Reviewed By:

Date/Time Date/Time Date/Time This Check List consists of 6 pages.

Version 51.0

06/27/07 09:13:27 FNP-2-S0P-24.0D SYSTEM CHECKLIST SYSTEM CHECKLIST SOP-24.0D ALIGNING SW PUMP 2C TO B TRAIN 1.0 Electrical Alignment 1.1 1.2 1.3 1.4 1.5

_/_

1.6 CV NOTE:

1.7 1.8 1.9 1.10 The version of this procedure has been verified to be the current version for the task. (OR 1-98-498)

The version of this procedure has been verified to be for the correct unit for the task. (OR 1-98-498)

IF 2C service water pump is to be aligned for auto-start, THEN obtain key

1. LL299 from the Shift Support Supervisor.

Stop or verify stopped 2C service water pump.

IF 2C service water pump is selected to Auto Start on A Train, THEN select 2C position on A Train spare pump selector switch and remove key #LL299.

Open DC control power breaker for DK05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB.

During the performance of the following steps of racking out the breaker and removing it from the cubicle, special consideration should be given to prevent damage to the key or to the interlock. (OR 1-98-009)

Rack out circuit breaker DK05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB, to the DISC (disconnect) position.

Tum key #RE-11579 in the mechanical interlock on the circuit breaker DK05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB, and remove the key.

IF required for seismic consideration, THEN remove circuit breaker DK05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB, from the cubicle and take appropriate actions with the breaker.

Insert key #RE-11579 into mechanical interlock on SERVICE WATER pIIMP 2C 4KV DISC SW 2A, Q2R18A501A-A, and tum key. Key #RE-11579 is now held in place.

Page 1 of 6 Version 51.0

06/27/07 09:13:27 FNP-2-S0P-24.0D SYSTEM CHECKLIST

_/_

1.11 CV 1.12 1.13

_/_

1.14 CV 1.15 NOTE:

1.16 1.17 1.18

_/_

1.19 CV Open SERVICE WATER PUMP 2C 4KV DISC SW 2A, Q2R18A501A-A and verify the position indicator reads SW OPEN.

Turn key #RE-11578 in its mechanical interlock on SERVICE WATER PUMP 2C 4KV DISC SW 2A, Q2R18A501A-A and remove key. Disconnect 2A is now locked open.

Insert key #RE-11578 into its mechanical interlock on SERVICE WATER PUMP 2C 4KV DISC SW 2B, Q2R18A501B-B, and turn key. Key #RE-11578 is now held in place.

Close SERVICE WATER PUMP 2C 4KV DISC SW 2B, Q2R18A501B-B and verify the position indicator reads SW CLOSED.

Tum key #RE-11580 in its mechanical interlock on SERVICE WATER PUMP 2C 4KV DISC SW 2B, Q2R18A501B-B, and remove key. Disconnect switch 2B is now locked closed.

During the performance of the following steps of returning the breaker to the cubicle and racking it in, special consideration should be given to prevent damage to the key or to the interlock. (OR 1-98-008)

Rack or verify racked circuit breaker DL05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB to the DISC (disconnect) position.

Insert key #RE-14253 into the mechanical interlock on circuit breaker DL05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB, and turn key. Key #RE-14253 is now held in place.

Rack circuit breaker DL05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB to the connected position.

Close DC control power breaker for DL05-2, SERVICE WATER PUMP 2C Q2P16M001C-AB and verify breaker spring charges.

Page 2 of6 Version 51.0

06/27/07 09:13:27 2.0 Mechanical Alignment FNP-2-S0P-24.0D SYSTEM CHECKLIST 2.1 On Service Water Pumps cooling header close or verify closed the following valves:

2.1.1 A trn S.W. pump motor clg water header iso valve Q2P16V712 2.1.2 A trn S.W. pump motor clg water header iso valve Q2P16V713 2.2 Open or verify open the following valves:

2.2.1 B trn S.W. pump motor clg water header iso valve Q2P16V714 2.2.2 B trn S.W. pump motor clg water header iso valve Q2P16V715 NOTE:

IF 2C Service Water Pump is already aligned to B Train, THEN step 2.3.1 and 2.3.2 may be marked NtA.

2.3 At the SW structure, close the following breakers (in any order):

2.3.1 FK-L2 SW pmp 2C to SW HDR A Q2P16V507.

2.3.2 FL-L2 SW pmp 2C to SW HDR B Q2P16V506.

NOTE:

Service water pump 2C train A and B header isolation valves Q2P16V506 and Q2P16V507 should not be open or stroking simultaneously to prevent cross connection of trains.

2.4 On the main control board close or verify closed 2C SW PUMP TO A HDR ISO Q2P16V507.

2.5 On the main control board open or verify open 2C SW PUMP TO B HDR ISO Q2P16V506.

2.6 At the SW structure, open the following breakers (in any order):

2.6.1 FL-L2 SW pmp 2C to SW HDR B Q2P16V506.

2.6.2 FK-L2 SW pmp 2C to SW HDR A Q2P16V507.

Page 3 of6 Version 51.0

06/27/07 09:13:27 FNP-2-S0P-24.0D SYSTEM CHECKLIST 2.7 INDEPENDENTLY VERIFY the following at the SW structure:

2.7.1 A trn S.W. pump motor clg water header iso valve Q2P16V712 closed.

IV 2.7.2 A trn S.W. pump motor clg water header iso valve Q2P16V713 closed.

IV 2.7.3 B trn S.W. pump motor clg water header iso valve Q2P16V714 open.

IV 2.7.4 B trn S.W. pump motor clg water header iso valve Q2P16V715 open.

IV 2.7.5 Breaker FL-L2 for SW pmp 2C to SW hdr B Q2P16V506 open.

IV 2.7.6 Breaker FK-L2 for SW pmp 2C to SW hdr A Q2P16V507 open.

IV 2.8 INDEPENDENTLY VERIFY the followi,ng on the MCB (verification may be performed locally if desired).

2.8.1 2C SW PUMP TO A HDR ISO Q2P16V507 closed.

IV 2.8.2 2C SW PUMP TO B HDR ISO Q2P16V506 open.

IV NOTE:

2.9 The next step preferred action is to start the 2C SW pump and place it on-service. If extenuating circumstances preclude placing the pump on-service, then bumping the pump is allowed with the shift supervisor's permission.

Perform one of the following:

2.9.1 IF desired, THEN place the 2C service water pump on-service..

2.9.2 IF desired, THEN bump service water pump 2C 2.10 IF NOT needed in section 3.0, THEN return key #LL299 to the Shift Support Supervisor.

Page 4 of 6 Version 51.0

06/27/07 09:13:27 FNP-2-S0P-24.0D SYSTEM CHECKLIST 3.0 Selecting 2C SW pump for B Train auto-start NOTES:

The following steps may be performed even if 2C SW pump is already running.

IF 2C SW pump is running on B trn as indicated by a red running light on DLOS handswitch, THEN only section 2.0 of the alignment need be completed.

IF 2C SW pump is selected for auto-start in B Train, THEN the 2D or the 2E SW pump it replaces will NOT sequence on following an SI or LOSP.

3.1 Verify that 2C SW pump is aligned mechanically and electrically to B Train per the above sections 1.0 and 2.0.

NOTE:

The following step is performed to ensure that the 2C SW Pump will start and run normally prior to selecting it for autostart. (OR 2-98-070) IF the 2C SW Pump is already running, THEN step 3.2 may be marked NtA.

3.2 Bump the 2C Service Water Pump to verify that it will start and run normally.

3.3 IF NOT obtained in section 1.0, THEN obtain Key # LL299 from the Shift Support Supervisor.

3.4 Check that the 2C SW pump A Train auto-start selector switch is in the 2C position. IF NOT, THEN stop and notify the Shift Supervisor.

NOTE:

Key may only be inserted or removed if switch is in the 2C position.

3.5 Insert Key # LL299 into the 2C SW pump B Train spare pump selector switch lock. (Directly above spare pump selector switch.)

3.6 Turn Key # LL299 clockwise. The key is now held in place. Select 2D or 2E pump wIth the spare pump selector sWItch. Record posItion selected.

________ Position Page 5 of6 Version 51.0

06/27/07 09: 13:27 FNP-2-S0P-24.0D SYSTEM CHECKLIST 3.7 INDEPENDENTLY VERIFY 2C SW pump B Train spare pump selector switch selected to 2D or 2E pump with Key # LL299 held in place.

3.8 Place a caution tag on the MCB B Train handswitch for SW pump 2C noting the auto-start selector switch position.

4.0 Returning 2C Service Water pump auto-start to normal.

NOTE:

Steps 4.1 and 4.2 are performed to ensure that the de-selected B Train SW Pump will start and run normally prior to selecting it for autostart. (OR 2-98-070) IF the de-selected B Train SW Pump is already running, THEN steps 4.1 and 4.2 may be marked NtA.

4.1 Verify that the pump recorded in step 3.6 of this checklist is aligned per System Checklist FNP-2-S0P-24.0A.

4.2 Bump the B Train pump identified in step 4.1 of this checklist to verify that it will start and run normally.

4.3 Select 2C with the spare pump selector switch.

4.4 Tum key # LL299 counterclockwise and remove key.

4.5 Return key # LL299 to the Shift Support Supervisor.

4.6 Remove the caution tag from the MCB B Train handswitch for 2C SW Pump.

4.7 INDEPENDENTLY VERIFY 2C SW pump B Train spare pump selector switch selected to 2C SW pump.

4.8 INDEPENDENTLY VERIFY2C SW pump B Train spare pump selector switch Key #LL299 removed.

Page 6 of6 Version 51.0

09/28/07 14:02:43 FNP-2-ARP-I.I LOCATION AE4 SETPOINT:

1.

Not Applicable ORIGIN:

52-B Contact on anyone of the following breakers 1.

DK03-2A SW Pump 2.

DK04-2B SW Pump 3.

DK05-2C SW Pump A Train 4.

DL05-2C SW Pump B Train 5.

DL03-2D SW Pump 6.

DL04-2E SW Pump PROBABLE CAUSE SW PUMP TRIPPED 1.

2A, 2B, 2C, 2D, or 2E Service Water Pump tripped due to an overload or an electrical fault.

AUTOMATIC ACTION NONE OPERATOR ACTION J,.. ':). (-e~ I/'- ;V

~ L

--&> k

.at /,'~

1 Ch k

• d**

d d r7.h* h*

&hk-~c4-d $-+-~Y-ed?

ec In lcatlons an etermlne\\~C serVIce water pump as trlppe.

2.

Start another service water pump[n the same traimas the tripped pump.

3.

Refer to FNP-2-AOP-IO.0, LOSS OF SERVICE WATER.

4.

Refer to Technical Specification 3.7.8 for LCO requirements with a loss of train A or B service water.

5.

Notify appropriate personnel to determine and correct the cause of the alarm.

6.

Return the Service Water electrical and component lineup to normal as soon as possible.

References:

A-207IOO, She 74A-C; D-202747; D-202748; D-202749; D-202750; D-20275I; D-202752; Technical Specification 3.7.8 Page 1 of 1 Version 27.0

Farley Nuclear Plant 2006-301 SRO Inital Exam 100. G2.4.44 045 A Site Area Emergency was declared 35 minutes ago. Subsequently, conditions have degraded and a General Emergency classification needs to be declared.

When upgrading to the General Emergency classification, which one of the following contains ONLY required actions lAW FNP-0-EIP-9.0, Emergency Actions?

A.

• Sounding of the plant emergency alarm.

• Announce needed evacuation instructions to plant personnel.

B~

• Sounding of the plant emergency alarm.

• Notify Alabama and Georgia of the status of the unaffected Unit.

C.

• Notify Alabama and Georgia of Protective Action Recommendations.

• Announce needed evacuation instructions to plant personnel.

D.

• Notify Alabama and Georgia of Protective Action Recommendations.

• Notify Alabama and Georgia of the status of the unaffected Unit.

Meets 10 CFR 55.43 (b) requirements for SRO level question since the IR is a 2.1 for an RO and not required knowledge or an action for an RO.

EIP-9.0 A: Incorrect: This action is required by the General Emergency Guideline Procedure only when not already previously performed. The SRO must know that it was required, and was already sounded, for the SAE. Second part correct II. Emergency Director Actions NOTE: THE SHIFT MANAGER SHALL PERFORM THE DUTIES OF THE EMERGENCY DIRECTOR UNTIL HIS ARRIVAL AND ASSUMPTION OF DUTIES.

Initials A. Notify personnel on site

1. If the Plant Emergency alarm has not already been activated, then announce over the public address system "All Plant Personnel Report to Designated Assembly Area," activate the PEA [Plant Emergency alarm] for 30 seconds and repeat the announcement.

2. Announce the classification, and the condition, request setup ofthe TSC and OSC and give needed evacuation instructions over plant public address system.

Farley Nuclear Plant 2006-301 SRO Inital Exam

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B. Correct: Notification of Protective Action Recommendations is required to be completed for the Initial Notification of a General Emergency. (Not required for any other classification including Site Area Emergency). Announcement with evacuation instructions required per step II. A. 2. of Guideline 2, EIP-9.0.

C: Incorrect: First part correct, second part incorrect. For initial notifications the Form "Guideline 1" states: (Unaffected Unit(s) Status Not Required for Initial Notifications)

D: Incorrect: First part correct, second part incorrect.

G2.4,44 Knowledge of emergency plan protective action recommendations.

Question Number:

100 Tier 3 Group 4 Importance Rating:

4.0 Technical

Reference:

EIP-9.0 Proposed references to be provided to applicants during examination: NO Learning Objective:

10 CFR Part 55 Content:

43.5 Comments: Replaced the question with one that does not require reference matenal and IS not a direct lookup. It is more closely related to what an SRO duty is in the emergency plan and required knowledge for an SRO.

09/28/07 13:10:44 GUIDELINE 1 GENERAL EMERGENCY FNP-O-EIP-9.0 GUIDELINE 1 I.

Purpose of Classification The classification of General Emergency applies to those events which are in progress or have occurred which involve actual or imminent substantial core degradation or melting with potential loss ofcontainment integrity or HOSTILE ACTION that results in an actual loss ofphysical control ofthe facility. The potential for release of radioactive material for the General Emergency classification is more than 1000 Ci of1-131 equivalent or more than 106 Ci ofXe-133 equivalent.

The purpose ofthe declaration ofa General Emergency is to:

(a)

Initiate predetermined protective actions for the public.

(b)

Provide continuous assessment of information from licensee and offsite measurement.

(c)

Initiate additional measures as indicated by event releases or potential releases

and, (d)

Provide current information for and consultation with offsite authorities and the public.

A General Emergency would be declared based on FNP-O-EIP-9.2 II.

Emergency Director Actions NOTE: THE SHIFT MANAGER SHALL PERFORM THE DUTIES OF THE EMERGENCY DIRECTOR UNTIL IDS ARRIVAL AND ASSUMPTION OF DUTIES.

Initials A.

1.

2.

Notify personnel on site

@he Plant Emergency alarm ha@lready been activated, then announce over the public address system "All Plant Personnel Report to Designated Assembly Area," ~ivate the PEA for 30 seconds and repeat the announcement;....1 oC~/'I>t.A4IY

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pe-A q I(~V r

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~ R E Announce the classification, and the conoition, request setup ofthe TSC and OSC and give needed evacuation instructions over plant public address system.

Page lof8 Version 59.0

09/28/07 13:10:44

~HAR>*.-'D GUIDELINE 1 GENERAL EMERGENCY FNP-0-EIP-9.0 GUIDELINE 1 B.

Callout the ERO staff 1.

Activate the ERO callout system per FNP-0-EIP-8.3, Table 2. (Located in the Unit 2 SS desk)

NOTE:

IF POSSIBLE AND TIME PERMITTING, DISCUSS WITH ALABAMA RADIATION CONTROL AND GEORGIA EMERGENCY MANAGEMENT AGENCY ABOUT THE PARs PRIOR TO ANNOUNCING THEM OVER THE ENN.

C Complete Notification form 1.

Fill in the General Emergency Initial Notification Form (last pages ofthis guideline),

including developing protective action recommendations per step L. Take into account the zones and evacuation time estimates shown in Figure 1.

NOTE:

INITIAL NOTIFICATIONS WILL NORMALLY BE MADE BY THE OPERATIONS SHIFT COMMUNICATOR, BUT MAY BE MADE BY OPERATIONS STAFF, TSC STAFF OR OTHER QUALIFIED PERSON USING THE INITIAL NOTIFICATION FORM (LAST PAGES OF THIS GUIDELINE).

NOTE:

INITIAL AND UPGRADE CLASSIFICATIONS AND NOTIFICATIONS SHOULD BE PERFORMED BY THE CONTROL ROOM OR THE TSC STAFF, WITH THE EOF INFORMED AS SOON AS POSSIBLE.

D.

Initial Notifications

___1.

Within 15 minutes of declaration, verbally notify the state and local agencies using the General Emergency Initial Notification Form (last pages ofthis guideline).

___2.

Verify notifications complete and documented on the General Emergency Initial Notification Form (last pages ofthis guideline).

___3.

Complete Figure 6, follow-up message. Instructions for completing the form are available as part ofthe figure.

___4.

Within one hour ofthe General Emergency Initial Notification Form (Verbal Notification) transmittal, fax Figure 6, follow-up message to state and local agencies. The goal should be within 30 minutes ofthe verbal notification.

5.

Complete Figure 5, NRC notification message. Instructions for completing the form are available in Figure 5.

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09/28/07 13:10:44 "H'W GUIDELINE 1 GENERAL EMERGENCY FNP-0-EIP-9.0 GUIDELINE 1

___6.

Provide the information on Figure 5, to the NRC as soon as possible, but within one hour ofthe declaration per the instructions on Figure 5.

E.

Emergency Organization Notifications 1.

On-call Emergency Director 2.

On-call EOF Manager 3.

SNC Duty Manager 4.

Notify Security ofEmergency, incoming personnel and access restrictions (4611).

F.

Other Notifications 1.

Have Regulatory ERDS activated to transmit data to the NRC within one hour of the declaration ofthe emergency (EIP-8-3, step 10).

2.

Ifpersonnel injury or fire is involved, refer to FNP-0-EIP-l1.0 and 13.0 respectively for additional actions and EIP-8.0 steps 5.0 and 6.0 for additional notification requirements.

3.

U.S. Army EOD group at Fort Benning, GA, ifnecessary.

4.

Savannah River Operations Office, ifnecessary.

5.

Ifthere is a security event involved ensure appropriate notifications and actions of FNP-0-AOP-49 and FNP-O-SP 37.0 are performed 6.

Ifthere is a security event involved and access to the plant from off site is restricted by local law enforcement (LLE) and it is desired to bring a plant employee to the site or additional off site resources such as fire departments or law enforcement then perform the following:

Contact the Houston County EMA to arrange a route and provide the names of individuals or resources that require access to the plant for relay to LLE.

In conjunction with Houston County EMA determine on site and off site staging areas for off-site resources using Appendix 1 Inform the individuals and resources that are coming to the site ofthe required route to the site. Individuals must have a company picture ID to get through the roadblocks Page 3 of8 Version 59.0

09/28/07 13:10:44 FNP-0-EIP-9.0 GUIDELINE 1 GUIDELINE 1 GENERAL EMERGENCY G.

In Plant Protective Actions 1.

Ensure personnel accountability per EIP-I0.0.

2.

Plan and initiate reentry's per EIP-14.0.

3.

Ensure proper Control Room response.

4.

Assign an individual to provide periodic plant status updates.

5.

Assign an individual to maintain a log of important Emergency Director activities.

6.

Assign an individual to keep a record ofall off-site communications.

___7.

Determine what should be done with a unit that is not affected by the declared emergency. Consider the effect on the emergency unit, manpower utilization, plant and grid stability, and other relevant factors.

___8.

In the event ofmass casualties refer to FNP-0-EIP-l1.0 step 15 to arrange for triage and additional ambulances.

H.

Off-Site Support 1.

Ensure Field Monitoring teams have been dispatched per EIP-4.0.

2.

Provide information to the EOF Manager for use in press releases and recovery planning.

I.

Information to Off Site Authorities 1.

Provide periodic plant status updates, meteorological and dose estimates and release projections based on plant conditions and foreseeable contingencies.

J.

Re-Assess plant conditions 1.

Continue to assess plant and radiological conditions to ensure the correct emergency classification is declared.

2.

Ifplant and radiological conditions no longer require the current emergency classification terminate the emergency class using FNP-0-EIP-28.0.

K.

Long term concerns 1.

Within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, provide for full TSC and OSC reliefs.

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GUIDELINE 1 GENERAL EMERGENCY FNP-0-EIP-9.0 GUIDELINE 1 2.

Within 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />, provide for 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> TSC and OSC coverage.

3.

If an LOSP has occurred evaluate the event to ensure that an adequate supply of fuel oil is available for the Diesel Generators for 7 days. Refer to REA 00-2337 and FNP-0-SOP-42.0 Figure 1.

L.

Protective action recommendation guidance 1.

Make Protective Action Recommendations (PARs) for all General Emergency declarations in accordance with NMP-EP-I09. If an upgrade to PARS is required after making this notification use figure 4 to transmit the new PARS to the state and county agencies.

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FNP-0-EIP-9.0 I

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GUIDELINE 1 GENERAL EMERGENCY RED VERBAL NOTIFICATION FORM 09/28/07 13:10:44 1*1:~_;~,,~

2@INITIALNOTIFICATION:TIME, DATE._---:-_..:.---.:

3. SITE: FARLEY NUCLEAR PLANT

~ U1 __0/0 Power Shutdown at Time Date _/__/__

~ U2 __0/0 Power Shutdown at Time Date _/__/__

D read additional remarks on separate page fQI Under evaluation

§ Above normal operating limits f9 Degrading

.il(II._::~:::-~:.*;::~:*:::> :;*Y~Ii*

Stability Class ~

~ § fQI (§ lEI IQI

~ Not applicable

~ Within normal operating limits

~ Improving

~ Stable ml~~li::::~::

• • • • • ~I;;(iil~:~~:;::~~;;i.~~~;;:;;~:}~1;:~;ilt~?j;*::~~t.l.

Precipitation

8. EVENT PROGNOSIS:

9. METEOROLOGICAL DATA:

7. RELEASE SIGNIFICANCE:

17. APPROVED BY:

Title Emergency Director Time Date

/

/

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GUIDELINE 1 GENERAL EMERGENCY RED VERBAL NOTIFICATION FORM H.__Line 8 Event Prognosis. Mark box A, B or C.

A should be marked ifmitigation efforts appear successful, progressing toward termination/recovery.

B should be marked if escalation to a higher classification is unlikely based on current conditions.

esc;alatlon to a higher emergency classification or PAR change is likely.

Ifstability class is not available it can be calculated from delta temperature from the below table i\\T (200' elev. temp, OF - 35' elev. temp, OF)

Stability Class

<-1.74 A

-1.74 to <-1.56 B

-1.56 to <-1.38 C

-1.38 to <-0.46 D

-0.46 to < 1.38 E

1.38 to 3.60 F

G L.__Line 12 Fill in per cent power or the time for with the event M.__Line 13 Ifadditional remarks are required mark the box for additional remarks and write them on a separate paper and have them read over the ENN, or mark the box for no additional remarks N.__The Emergency Director must sign the form with time and date.

o.

Within 15 minutes ofdeclaration time, using the ENN contact the state and local agencies listed below.

P.__Verify the Southern LINC ENN Radio being used is turned on Q.__Ifthe Southern LINC display does not show "WIDE AREA, FEP ENN" when group is pressed in step R, THEN perform the following:

Press the button with the square until the top line is indicated, then press the arrow buttons until "WIDE AREA" is displayed, then press the button under OK. Press the button with the square until the second line is indicated then press the arrow buttons until "FEP ENN" is displayed, and then press the button under OK.

R__Press group pushbutton, verify display shows WIDE AREA, FEP ENN.

Correct per above step ifnecessary.

Pickup handset or leave in cradle, press to talk (PTT), wait for the chirp and announce "This is name/title at Farley Nuclear Plant. Please obtain a GENERAL EMERGENCY RED initial notification form and monitor the ENN."

Release the PTT.

S.__Contact one state and county agency listed in each ofthe four boxes below.

Indicate the time of initial attempt to contact any Alabama agency. Circle agency actually contacted. Indicate the name ofthe individual contacted. Underlined phone numbers staffed 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> a day PTT and request one Alabama agency in the order listed below acknowledge manning ofthe ENN. State agency name and ask ifthey are on the line. Release the PTT after each request.

ALABAMA State Agencies In preferred order Alabama Radiation Control at Montgomery EOC. ENN (1305), OPX (6628), (334-206-5391), (334-324-0076)

AEMA ENN (1306), OPX(6619), (205-280-2312, 205-280-2310)

Alabama Radiation Control at Alabama Forward EOC, ENN (1307), OPX 6621), (334-793-1565)

HOUSTON COUNTY ENN (1307), OPX (6621), (334-794-9720, 793-9655, 677-4807,48082 Time N.ame

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GUIDELINE 1 GENERAL EMEkGENCY RED VERBAL NOTIFICATION FORM FNP-0-EIP-9.0 Indicate the time of initial attempt to contact any Georgia agency. Circle agency actually contacted. Indicate the name ofthe individual contacted. Underlined phone numbers staffed 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> a day PTT and request one Georgia agency in the order listed below acknowledge manning ofthe ENN. State agency name and ask ifthey are on the line. Release the PTT after each request.

GEORGIA State Agencies In preferred order GEMA at Atlanta EOC, ENN (1304), OPX (6629), (404-635-7200)

GEMA at Georgia Forward EOC, ENN (1308) OPX (6626), (229-723-4826)

EARLY COUNTY, ENN(1308) OPX (6622),(229-723-3577, 3578, 4826)

Time Name

~Acknowledged 0 Indicate the time of initial attempt to contact Houston County. Indicate the name ofthe individual contacted.

Underlined phone numbers staffed 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> a day PTT and request Houston County acknowledge manning ofthe ENN. State agency name and ask ifthey are on the line.

Release the PTT after each request.

HOUSTON COUNTY HOUSTON COUNTY, ENN(1307), OPX (6621), (334-794-9720, 793-9655, 334-677-4807,4808)

Time Name Acknowledged 0 Indicate the time of initial attempt to contact Early County. Indicate the name ofthe individual contacted. Underlined phone numbers staffed 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> a day PTT and request Early County acknowledge manning ofthe ENN. State agency name and ask ifthey are on the line.

Release the PTT after each request.

EARLY COUNTY EARLY COUNTY, ENN(1308) OPX (6622), (229-723-3577, 3578, 4826)

Time

---

.;Name

--.-;Acknowledged 0 T.__Fill in the date and time on line 2 using the time that the fIrst state agency contact ATTEMPT was made U.__PTT and announce on the ENN "Please prepare to receive a GENERAL EMERGENCY, RED initial notification message with acknowledgment", then slowly read the GE initial notification form over the ENN. Release the PTT after reading two or three lines to allow individuals to respond.

V.__Have the agencies contacted above, acknowledge receipt ofthe message and fill in the acknowledge checkbox above when they do.

W.__Ifany required agency could not be contacted on the ENN, then use numbers listed with each agency or in FNP-0-EIP-8.1 to contact them by any available means as soon as possible.

X Fax a copy ofthe previous page GENERAL EMERGENCY RED VERBAL NOTIFICATION FORM to the State ofFlorida, EOF using speed dial #10 Y.__Wait for the Fax report indicating the fax was received then verify the state ofFlorida has received the Fax by caJ1ing (800-320-0519) (850-413 9911)

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