Text

Draft Section B Operating
	ML033100028
Person / Time
Site:	Vermont Yankee File:NorthStar Vermont Yankee icon.png
Issue date:	10/03/2003
From:	Gosekamp M; Entergy Nuclear Vermont Yankee
To:	Conte R; NRC/RGN-I/DRS/OSB
	Conte R
References
	50-271/03-301
	Download: ML033100028 (170)
	v • d • e

JPM-20107F Rev. 4, 08/03 Page 1 of 7 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task ldentification:

Title:

Perform Weeklv Operable Control Rod Check Failure Mode: Stuck Control Rod

Reference:

OP-41 1 1 Control Rod Drive Svstem Surveillance Task Number: 201 0020201 Tack Performance: AO/RO/SRO

- - RO/SRO X SRO Only Sequence Critical: Yes __ No 2 Time Critical: Yes __ No Operator Performing Task:

Examiner:

Date of Evaluation:

Method of Testing: Simulation - Performance X Discuss Setting: Classroom __ Simulator X Plant Performance Expected Completion Time: 1 5 minutes Evaluation Results:

Performance: PASS __ FAIL __ Time Required:

Prepared by:

Date Reviewed by:

SRO Lic&sed/Certified Reviewer Approved by: I - w Operations Training Sbperintendent K ME6 F/ddJ Date

JPM-20107F Rev. 4, 08/03 Page 2 o f 7 Directions: Discuss the information given on this page with the operator being evaluated.

Allow time for him t o ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "Do you understand the task? 'I Read t o the person being evaluated:

-~

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are t o perform the actions.

You are requested t o "talk through" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions: Normal Rx operation, 90% power. The previous crew started the Weekly Operable Control Rod Check.

Init'atinq Cues: The CRS directs you t o complete the Weekly Operable Control Rod Check per OP 41 11.

Task Standards: Rod 06-1 5 and 18-03 satisfactorily cycled.

Reqrrired Materials: OP-41 11 Control Rod Drive System Surveillance VYOPF 41 11.02 ON 3143 Stuck Control Rod Simulator Setup: IC-20 ERFIS Printer ON, Preinsert MALFUNCTION RD021803. Ensure CRD flows are in the Green Band Reduce Reactor power t o 90% with recirc flow RE stated no control rod blocks are expected Drive water pressure adjusted t o 250 psig Mark rods 06-1 5 and 18-03 with asterisks on VYOPF 41 11.02

JPM-20107F Rev. 4, 08/03 Page 3 of 7 Evaluation Performance Steps TIME START:

SAT /U NSAT Step 1: Obtain Procedure OP-4111 and review admin limits, precautions and prerequisites reviewed.

Standard: OP-41 11 obtained section A, admin limits, precautions and prerequisites reviewed.

Interim Cue: Prerequisites are complete.

SAT/UNSAT Step 2: Verify RBM channels.

Standard: No rod blocks, verifies detector bypass lights out when rods are selected.

SATlU NSAT Step 3: Demand and print control rod positions display (CRD) to document initial control rod position.

Standard: Select "CRD" display on ERFIS, ensure printer is on, and print display.

Interim Cue: The operator does not need to wait for printout t o continue surveillance. When asked, no rod sequence exchange is planned.

SATNNSAT *Step 4: Select rod 06-15.

Standard: Energize rod select power, depress rod select pushbutton for 06-15.

SAT i UNSAT Step 5 : Verify rod 06-15 selected.

Standard: Verify rod select pushbutton for rod 06-15 is illuminated.

SAT/UNSAT Step 6: Verify no adjacent control rod to rod 06-15 is presently at position 46.

Standard: Verify rods 06-1 1 , 10-11 , 10-15, 10-19, 06-19, and 02-19 are not at position 46 using full core display or ERFIS printout.

JPM-20107F Rev. 4, 08/03 Page 4 of 7 Eva'uat- ion

- ~ Performance Steps SAT/U NSAT *Step 7: Drive rod 06-15 t o position 46.

Standard: Momentarily place rod movement control switch t o the "Rod in position.

'I SAT/UNSAT *Step 8: Verify rod 06-15 position decreases t o position 46.

Standard: Verify rod 06-1 5 position is at 46 using full core or 4 rod position display on CRP 9-5.

SATNNSAT *Step 9: Withdraw rod 06-15 t o position 48.

Standard: Momentarily place rod movement control switch t o the "rod out notch" position.

SATNNSAT Step I O : Ensure rod 06-15 is at position 48.

Standard: Verify rod 06-1 5 position is at 4 8 using full core or 4 rod display on CRP 9-5.

SAT/U NSAT Step 1I: Performs coupling check when control rod is at position 48.

Standard: Out notch override and notch out 3-5 seconds.

Check alarm typer-cup check SAT SATIUNSAT *Step 12: Initial VYOPF 41 11.02 for rod 06-1 5.

Standard: Initials recorded on form for rod 06-1 5.

SA7 / UNSAT *Step 13: Select rod 18-03 at least 2-3 seconds after settle liwht extinauishes.

Standard: > 2-3 seconds after settle light extinguishes depress rod select pushbutton for 06-15. (OP 41 1 1, Precaution 8)

SATfUNSAT S t e p 14: Verify rod 18-03 selected.

Standard: Verify rod select pushbutton for 18-03-is illuminated.

JPM-20107F Rev. 4, 08/03 Page 5 of 7 SAT/UNSAT Step 15: Verify no adjacent control rod t o rod 18-03 is presently at position 46.

Standard: Verify rods 22-03, 22-07, 18-07, and 14-07 are not at position 46 using full core display or ERFIS printout.

SAT/UNSAT *Step 16: Attempt t o drive rod 18-03 t o position 46.

Standard: Momentarily place rod movement control switch t o "rod in" position.

SAT/UNSAT *Step 17: Recognize failure of rod 18-03 to move t o position 46.

Standard: Observe rod 18-03 a t position 48 on full core or 4 rod display.

SAT/U NSAT Step 18: Inform Control Room Supervisor of 18-03 failure t o move.

Standard: Control Room Supervisor informed.

Interim Cue: CRS directs the operator t o implement ON 3143, stuck control rod, for rod 18-03.

SAT/UNSAT Step 19: Obtain ON 3143 and review symptoms.

Standard: ON 3143 obtained and reviewed.

SAT/U NSAT Step 20: Verify no rod block exists.

Standard: Verify no rod block in by observing annunciators 5-D-2, 5-D-6, 5-D-7, 5-M-7, 5-M-8, 5-N-1, 5-N-2 clear.

SAT/UNSAT *Step 21: Attempt a one notch insert and withdrawal of rod 18-03 observing drive flow, drive pressure and settle in lights.

Standard: Momentarily place rod movement control switch t o "rod in" then "rod out" position and verify on CRP 9-5:

Drive pressure, DPI-3-303, normal (green band)

Drive flow, FI-3-310, normal Settle, drive in, drive out lights sequence normally

JPM-20107F Rev. 4, 08/03 Page 6 of 7 Evaluation Performance Steps SAT/UNSAT *Step 22: Incrementally raise drive water DP t o +350 psig.

Standard: Adjust CRD-PCV-20 t o raise drive DP by 10 t o 50 psig increments.

interim Cue: CRS directs the operator t o increase DP in 10-50 psig increments.

NOTE: REMOVE MALFUNCTION RD020615 AT THIS TIME (PRIOR TO NEXT STEP).

SAT/UNSAT *Step 23: Attempt t o insert rod 18-03 one notch.

Standard: Momentarily place rod movement control switch t o "rod in" position.

Note: If drive water pressure is raised too much the control rod will double or triple notch and the mispositioned control rod procedure will also be entered if required.

SAT/UNSAT Step 24: Verify rod 18-03at position 46.

Standard: Observe rod 18-03 a t position 46 by full core or 4 rod display.

SAT/UNSAT Step 25: Return rod 18-03t o position 48.

Standard: Momentarily place rod movement control switch t o "rod out" position.

SATlUNSAT Step 26: Verifv rod 18-03at position 48.

Standard: Observe rod 06-15 at position 48 by full core or 4 rod display.

SAT/UNSAT -Step 27: Exercise rod 18-03 several times.

Standard: Repeat steps 23, 24, 25, and 26 above as directed by CRS.

Interim Cue: CRS directs rod 18-03 be exercised twice.

JPM-20107F Rev. 4, 08/03 Page 7 of 7 Evaluation

- Performance Steps SAT I U NSAT Step 28: Return drive water DP to normal.

Standard: Adjust CRD-PCV-20 t o return drive water DP t o green band on DPI-3-303.

SATlUNSAT Step 29: Exercise rod 18-03 several times.

Standard: Repeat step 26 above.

Interim Cue: When operator desires to continue surveillance, advise that no further action's required for this JPM.

TIME FINISH:

Terminating Cue: Rod 06-1 5 and 1 8 - 0 3 successfully exercised.

Eva1u ators Commeni 5 :

System: 201C03 K/A's: A2.01 Ability to (a) predict the impacts of the following on the CONTROL ROD AND DRIVE MECHANISM ;and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those abnormal conditions or operations:

(CFR: 41.5 / 45.6)

Stuck rod RO 3.4 SRO 3.6 System Generic K/A's:

JPM-20107F Rev. 3, 01/99 Page 1 of 1 EXAMINEE HANDOUT Initial Conditions:

- Normal Rx operation, 90% power. The previous crew started the Weekly Operable Control Rod Check.

m

a t i n gCues: The CRS directs you t o complete the Weekly Operable Control Rod Check per OP 41 11.

VERMONT YANKEE NUCLEAR POWER STATION OPERATING PROCEDURE OP 4111 REVISION 39 CONTROL ROD DRIVE SYSTEM SURVEILLANCE USE CLASSIFICATION: REFERENCE LPC Effective Affected Pages No. Date 1 05115/03 23 of 43 2 06/24/03 5,6 & 43 of 43 3 07/24/03 4, 5,9, 11, 14, 16,22,25,28, 33, 34, 37,42 & 43 of 43, VYOPF 41 11.01 Pg 2 of 2, VYOPF4111.02Pgl &2of2,VYOPF4111.03Pg1 ofl,VYOPF4111.05Pgl of 1, VYOPF 4111.06 Pg 1 of 1, VYOPF 4111.08 Pg 1 of 1, VYOPF 4111.09 Pg 1 of 1, VYOPF 41 11.11 Pg 1 of 1, VYOPF 41 11.12 Pg 1 of 1, VYOPF 41 11.13 Pgs 1 through 5 of 5, App. B Pg 7 of 7, & App. C. Pg 4 of 5 7 - I I ImDlementation Statement: N/A I Issue Date: 07/25/02 OP 41 11 Rev. 39 Page 1 of 43

TABLE OF CONTENTS PURPOSE .......................................................................................................................................................... 3 DISCUSSION .................................................................................................................................................... 3 ATTACHMENTS ............................................................................................................................................ -4 REFERENCES AND COMMITMENTS......................................................................................................... 5 PRECAUTIONS/LIMITATIONS..................................................................................................................... 6 PREREQUISITES ............................................................................................................................................. 8 PROCEDURE.................................................................................................................................................. 11 A. Operable Control Rod Check ................................................................................................. 11 B. Nuclear Instrument Response and Coupling Integrity Verification .First Withdrawal........15 C. Coupling Integrity Verification .Fully Withdrawn ............................................................... 16 D. Accumulator Pressure, Level Alarm and HCU-112 Valve Check ........................................ 17 E. Swap of the CRD Flow Control Valves ................................................................................. 23 Control Rod Fnction Testing.................................................................................................. 24 F.

G. Settling Test Performed using Tektronix TestLab Equipment .............................................. 25 H. Cycling Speeds and Stall Flows ............................................................................................. 29 I. SDIV Valve Operability Tests ................................................................................................ 32 J. SDIV Valve Position Verification .......................................................................................... 33 K. Leakage Check of CRD-115 Check Valves ........................................................................... 33 L. SDV Vent Check Valve Test .................................................................................................. 34 M. HCU-114 Leak Test ................................................................................................................ 37 ACCEPTANCE CRITERIA ........................................................................................................................... 43 FINAL CONDITIONS .................................................................................................................................... 43 OP 4111 Rev . 39 Page 2 of 43

PURPOSE To provide the steps necessary to perform the required tests on the Control Rod Drive (CRD) system to ensure its operability by Operations Department personnel.

Completion of the following tests satisfy the respective Technical Specification requirements:

Test Technical Specification Operable Control Rod Check 4.3.A.2.4.6.E.2 Nuclear Instrument Response and Coupling Integrity - First Withdrawal 4.3.B.l(a),4.3.B.I(b)

Coupling Integrity Verification - Fully Withdrawn 4.3 .B.1(b)

Cycling Speeds and Stall Flows 4.3.B.l(b)

SDIV Valve Position Verification 4.3.B.7 Accumulator Pressure and Level Alarms 4.3.D CRD-115 Leakage Check 4.6.E.2 SDIV Valve Surveillance 4.6.E.2 IST HCU-114 Leak Check 4.6.E.2 DISCUSSION All surveillance and operability requirements pertaining to the CRD system, under the cognizance of the Operations Department, are delineated in this procedure.

Tests performed following a refuel outage veri@ control rod operability to ensure that control rod stroke times are within acceptable values and that rod binding in the core does not occur. Also, these tests can be used to assess Hydraulic Control Unit (HCU) valve deterioration and filter degradation in the control rod drives. Additional testing is performed if abnormal trends are noted. A coupling integrity test is performed whenever a control rod is first withdrawn after a refueling outage, maintenance, or when at position 48. Another test checks the nuclear instrumentation for a discernible response and, when response is not discernible, subsequent exercising of these control rods is performed after the reactor is critical to verify instrumentation response (within the constraints of the rod worth minimizer).

Friction testing is designed to check proper drive operation and may also be used as a drive troubleshooting aid. During the friction test, several other checks may be performed such as subcritical checks, coupling verification, and control rod functional tests.

Weekly operability surveillance tests performed at power maintain the high degree of reliability that is required for the system as do visual checks of accumulator pressure and seal leakage which are performed on a daily basis.

OP 41 11 Rev. 39 Page 3 of 43

The IST HCU-114 leak test is performed with the CRD pumps secured and the reactor well flooded. The HCU charging water and accumulator water side pressures are bled off by inserting and not resetting a reactor scram. This results in pressurization of the Scram Discharge Volume (SDV) equal to the static head from the level in the reactor well, approximately 40 psig.

The exhaust header return is isolated and a test pressure gauge is installed in place of exhaust header pressure indicator PI-226. On the PI-226 test connection, a clear hose is installed in a loop seal configuration so that static head in the CRD exhaust header will not interfere with observation of leakage past the HCU-114 check valve into a floor drain. A temporary 120 VAC power supply is connected to the selected HCU's 121 valve and the valve is energized open.

Following the stabilization of flow from the temporary loop seal, the 102 valve for the HCU being tested is closed. Since a scram signal is in, the selected HCU's 114 valve closure can be confirmed by observing flow decreasing or stopping altogether when the 102 valve closes. When the test is complete the selected HCU's 121 valve is de-energized and the normal power supply reconnected. The HCU-102 valve for the selected HCU is reopened and the test repeated on the next HCU to be tested.

Testing performed under this procedure satisfies requirements of the Vermont Yankee Inservice Testing (IST) Program.

ATTACHMENTS

1. VYOPF 41 11.01 CRD Hydraulic Control Unit Check

2. VYOPF 41 11.02 Control Rod Operability Check

3. VYOPF 41 11.03 Friction Testing and Control Rod Cycling Data Sheet

4. VYOPF 41 11.04 Deleted

5. VYOPF 41 1 1.05 Nuclear Instrument Response

6. VYOPF 41 11.06 SDIV Valve Surveillance

7. VYOPF 41 11.07 Deleted

8. VYOPF 41 11.08 SDIV Valve Position Verification

9. VYOPF 41 11.09 CRD-115 Leakage Check

10. VYOPF 4111.10 Deleted

11. VYOPF 41 11.11 TestLab Results Acceptance Criteria Checksheet for Notch Out and Continuous In Friction Testing

12. VYOPF 4111.12 SDV Vent Check Valve Test

13. VYOPF 41 11.13 HCU- 1 14 Leak Check Data Sheet

14. Figure I Differential Pressure Plug-In Unit

15. Figure I1 CRD Hydraulic Control Unit

16. Figure 111 Continuous Rod Insertion Trace

17. Figure IV Single Notch Operation Trace

18. Figure V Deleted

19. Appendix A Deleted

20. Appendix B Friction Testing a Control Rod Drive When the Reactor is Shutdown

21. Appendix C Friction Testing a Control Rod Drive When the Reactor is at Power OP 411 1 Rev. 39 Page 4 of 43 LPC #3

22. Table1 CRD HCU Accumulator Required Nitrogen Precharge Pressure Versus Ambient Temperature

23. Table I1 CRD HCU Required Operating Nitrogen Pressure Versus Ambient Temperature REFERENCES AND COMMITMENTS

1. Technical Specifications and Site Documents TS Section 3.3, 3,4, 3.5,4.3, and 4.6

2. Codes, Standards, and Regulations a.

3. Commitments

a. EPC 9509, Evaluate Memo, DAR to RJW, "Implementation Plan for Tech. Spec.

Review Issue", dated 8/1/94, Implement Necessary Actions RE: Adequacy of 10CFR5O App. B Test Program

b. EPC 9510 06, RE TS Review, PCIS Valve Surveillance

c. ER95015902, Failure to Perform IST Evaluation on FWRSW Pump C. Revise Procedures to Include Valve Stroke Times on IST Forms.

d. INS90100P6, Identified Minor Weaknesses in Control Rod Friction Testing

e. OE6410-01, CRD Accumulator Gas Pressures at Monticello. Revise OP 21 11 and OP 4 1 11 as detailed in OE 64 10

f. UND97132-01, Revise Procedures To Remove Steps To Check Operability Of Control Rod Overtravel Prior To Coupling. Include Steps To Address Proposed Change 183. See J.S. Marshall Memo dated 11/7/97. (AMD 149)

g. UND97 132-02, Proceduralize TestingRecording The Overtravel Indication When A Control Rod Is Uncoupled For Maintenance Per Proposed Change 183.

See J.S. Marshall Memo Dated 11/7/97. AMD. 149.

4. Supplemental References

a. General Electric Equipment Manuals GEK-780,9582A, 32424A and 92809

b. Master Surveillance List C. DWG 191170, Control Rod Drive System

d. UND 87-14, Temperature Variability of SDM Demonstration

e. Tektronix TestLab Operator Manual

f. Memo, R.J. Sojka to PORC, Regarding OP 41 11, Rev. 33, Review of OP 41 11 Revision 33 and Associated Safety Evaluation Memo VYE 98/113, ECM to RGJ, Tontrol Rod Drive Scram Discharge Volume Vent and Drain Valves Opening Time," dated 4/20/98

h. AP 0009, Event Reports

1. OP 0105, Reactor Operations

j. OP 0150, Conduct of Operations and Operator Rounds OP 41 11 Rev. 39 Page 5 of 43 LPC #3

k. OP 1411, Core Verification and Strongest Rod Out Test

1. OP 21 11, Control Rod Drive System

m. OP 2403, Control Rod Sequence Exchange with the Reactor On Line

n. OP 2404, Determination and Implementation of Rod Movement Sequences

0. OT 3 110, Positive Reactivity Insertion P. ON 3 144, Control Rod Uncoupled

4. OT 3 166, Mispositioned Control Rod

r. AP 4000, Surveillance Testing Program S. OP 4102, Refuel OutagePuel Movement Periodic Tests

t. OP 4424, Control Rod Scram Testing and Data Reduction U. OP 4450, Rod Worth Minimizer Surveillance V. AP 6807, Collection, Temporary Storage and Retrieval of QA Records W. PP 7013, Inservice Testing Program PRECAUT I0 NS/LIMI TAT I 0 NS

1. Do not start a CRD pump unless its minimum flow bypass valve is fully open.

2. If the minimum flow line is the only pump discharge path, do not run a CRD pump for greater than 15 minutes.

3. Do not exceed the following pump parameters:

e Maximum pressure at suction flange: 250 psig e Suction fluid temperature: 40°F min.;l50"F max.

e Cooling water temperature: 100°F max.

e Cooling water pressure: 150 psig max.

e Oil temperature: 100°F min.; 150°F max.

NOTE High filter D/P will alarm at 18 psid. Normal clean filter D P is 5-6 psid.

4. Do not operate drive water filters when filter D/P exceeds 50 psid.

5. Do not bypass the RWM to perform CRD exercising when reactor power level is less than 20%.

6. If an inadvertent control rod drive-out should occur during normal operation (i.e., the control rod continues to withdraw after the operator terminates the withdraw command),

refer to OT 3 110.

OP 41 11 Rev. 39 Page 6 of 43 LPC #2

7. Prior to withdrawing a control rod for any purpose, ensure reactor water temperature is 268°F. If temperature decreases below 68°F while a control rod is withdrawn, insert it and take appropriate action to prevent control rod withdrawal (Mode switch to SHUTDOWN and/or attaching white tags) until temperature can be maintained above 68°F. (UND87-14)

8. Excessive CRD HCU accumulator pressure (>1400 psig) could result in internal CRD damage in the event of a reactor scram. (OE6410-01)

9. CRD system water is radioactively contaminated. All radiation protection practices must be observed with system leakage, venting and draining operations. Radiation Protection shall be notified of any spills to ensure appropriate surveys are performed.

10. Whenever individual control rods are being withdrawn for test purposes (venting, stall flows, speed adjustment, friction testing, scram testing, S F W response, etc.) while the reactor is in a shutdown condition, the following requirements shall be met (except during RWM testing):

e The mode switch shall be in REFUEL.

e The RWM shutdown margin function shall be operable and in service.

- At the beginning of the refueling outage, prior to initiation of control rod withdrawal, the RWM shutdown margin Eunction shall be proven operable per OP 4450, Rod Worth Minimizer Surveillance.

Prior to each rod withdrawal, RWM will be confirmed to be operable and in service by verifylng the shutdown margin mode is latched with no INOP/RESET lights on.

0 If the RWM shutdown margin function becomes inoperable or is bypassed, the Two Rod Interlock will be tested for each rod prior to its withdrawal per OP 4102.

OP 41 11 Rev. 39 Page 7 of 43

11. With the Reactor Pressure Vessel head not installed:

a. If (1) core verification has not been completed, or (2) if performing the strongest control rod withdrawn subcritical check, then all personnel shall be out of line of sight of the open vessel when withdrawing a control rod from a cell with fuel installed.

b. All personnel shall be clear of the refuel floor when two (2) or more control rods are withdrawn from cells with fuel installed.

These facts must be verified by the Senior Licensed Operator on the refuel floor and transmitted to the Shift Supervisor prior to control rod motion.

The two exceptions to this Admin Limit are:

e Performance of the Functional Test of Refueling Interlocks per OP 4102.

e Performance of the Two Rod Interlock Functional Test per OP 4102.

PREREQUISITES

1. Apparatus required (Procedure Sections F and G):

e Differential Pressure Unit e Tektronix 2505 TestLab and Printer (printer is optional per RE) 0 Plastic vent hose with adapter (2 required) e Stopwatch e Leak Rate Test Rig

2. If available, the RWM SDM option should be latched prior to performing rod testing, friction testing, rod timing, etc.

3. Verifi that proper acceptance criteria has been programmed into TestLab equipment by I/C personnel (Procedure Section F).

4. Reactor Engineering has determined which control rod drives require friction testing and have provided this information to Operations (Procedure Section F).

OP4111 Rev. 39 Page 8 of 43

5. For the HCU-114 Ball Check Valve Leak Test:

a. A test power supply is available for energizing HCU- 121.

b. The reactor cavity is flooded.

c. Pre-job brief covering the following is completed:

1) Termination Criteria:

a) Unexpected leakage.

b) Unexpected pressure transients.

c) Control Room direction.

2) Backout Methodology:

a) Close PI 3-226 Test Connection, confirm cessation of flow.

b) If required to stop flow:

(1) Place test power supply switch in OFF, unplug if necessary.

(2) Close SN-3-101 the PI-226 Instrument Root.

(3) Close the selected HCU-102 Valve.

(4) Close the selected HCU- 105 Valve.

c) Confirm cessation of flow.

d) Notify the Shift Manager.

3) Cautions:

a) The following conditions ensure that there is no potential to drain the vessel during this activity:

a Continuous presence of an operator whenever the drain path is open.

e The requirement that the reactor cavity is flooded.

a The 1/2 inch physical drain path restriction provided by the chemistry sample connection.

b) Use appropriate radiation protection measures.

OP 4111 Rev. 39 Page 9 of 43 LPC #3

d. RWP obtained for long-term work in the HCU Bank areas.

e. Length of clear reinforced hose available to route drains from the PI-226 test connection to a floor drain or appropriate container.

f. 0-100 psig test gauge available, with a maximum tolerance of *2% and a resolution of at least 5 psi.

g. ALARA brief conducted if deemed appropriate by RP.

h. A 25' ladder is available to route the drain hose.

1. Hose clamps available to attach the hose to the PI-226 test connection.

j. No testing or work in progress which prohibits the performance of this test.

k. Confirm all rods fully inserted.

6. OP 1411, Core Verification and Strongest Rod Out Test, has been performed following a fuel shuffle prior to performing Control Friction Testing and Cycling Speed and Stall flows. (SER9513)

OP 41 11 Rev. 39 Page 10 of 43

PROCEDURE A. Operable Control Rod Check (Use VYOPF 41 11.02)

I e NOTES CRD exercise for those control rods designated by Reactor Engineering will be performed at reduced power level. The rods I requiring a power reduction prior to exercising will be annotated with an asterisk (*) in the column to the left of the Rod No.

column on VYOPF 41 11.02.

e If rod exercise is not required and only a coupling check for rods at position 48 is required, steps 5.b.l), 2), and 3), and 11.b.l), 2),

and 3) may be performed independently. If only the coupling check is performed document in Remarks section of VYOPF 41 11.02.

e The coupling check per steps 5.b.l), 2), and 3), and 11.b.l), 2),

and 3) may be deferred with Operations Manager permission. If the coupling check is deferred document in the Remarks section of VYOPF 41 1 1.02.

1. If reactor power is greater than 30%, veri@ both RBM channels are operable.

a. If an RI3M is inoperable, suspend all rod movements and refer to OP 2133.

NOTES e Prior to inserting a control rod one notch for exercising, veri3 that no adjacent control rod is presently at the resulting rod position. If this cannot be accomplished do not move the control rod; consult with Reactor Engineering.

e If rod blocks become an operator distraction during control rod exercising, insert rods per Reactor Engineering instruction.

2. Demand and print Control Rod Positions Display (CRD) to document initial control rod positions.

a. If the computer is inoperable, record the initial positions on VYOPF 41 11.02.

OP 41 11 Rev. 39 Page 11 of 43 LPC #3

3. Select the first control rod shown on VYOPF 41 11.02 without an asterisk and drive it in one notch.

a. Do not insert more than one notch, should this happen:

1) If inserted more than two notches, then enter "Mispositioned Control Rod" procedure, OT 3 166.

2) If inserted two notches, then immediately select the mispositioned rod and attempt to withdraw it to its intended position.

3) Document occurrence on VYOPF 41 11.02.

4. Verify rod position indication decreases to the next even notch.

5. Return the control rod to its original position as follows:

a. Do not withdraw control rod past original position, should this happen:

1) If more than one notch, then enter "Mispositioned Control Rod" procedure, OT 3 166.

2) If only one notch, then immediately select the mispositioned rod and attempt to insert it to its original position using an insert signal.

3) Document occurrence on VYOPF 41 11.02.

b. If the original rod position is 48, perfom a coupling check at position 48 as follows: (UND97132-0 1)

1) Verify the control rod is at position 48.

2) Provide continuous withdraw signal for 3 to 5 seconds by simultaneously going to NOTCH OVERRIDE and ROD OUT Veri@ the following:

a) The display window continues to show 48.

b) The computer printout indicates coupling check SAT c) The ROD OVER TRAVEL (5-D-4) annunciator does not alarm.

OP 41 11 Rev. 39 Page 12 of 43

3) If during the coupling check, the 48 disappears, the rod display window goes dark, and the ROD DRIFT (5-D-5) and ROD OVER TRAVEL (5-D-4) alarms are received, the control rod is uncoupled.

a) If a rod is uncoupled, refer to ON 3 144.

6. Ensure that the previous exercised control rod is at its original position prior to exercising the next control rod.

7. Repeat the above steps for all operable control rods shown on VYOPF 41 11.02 without an asterisk that are not fully inserted.

8. For those control rods shown on VYOPF 41 1 1.02 annotated with asterisks (*) that require a power reduction prior to exercising, reduce reactor power to 90% or that power level specified by Reactor Engineering.

9. Select the first control rod shown on VYOPF 41 11.02 with an asterisk and drive it in one notch.

a. Do not insert more than one notch, should this happen:

1) If inserted more than two notches, then enter "Mispositioned Control Rod" procedure, OT 3 166.

2) If inserted two notches, then immediately select the mispositioned rod and attempt to withdraw it to its intended position.

3) Document occurrence on VYOPF 41 11.02.

10. Verify rod position indication decreases to the next even notch.

11. Return the control rod to its original position as follows:

a. Do not withdraw control rod past original position, should this happen:

1) If more than one notch, then enter "Mispositioned Control Rod" procedure, OT 3 166.

2) If only one notch, then immediately select the mispositioned rod and attempt to insert it to its original position using an insert signal.

3) Document occurrence on VYOPF 41 11.02.

OP 41 11 Rev. 39 Page 13 of 43

b. If the original rod position is 48, perform a coupling check at position 48 as follows: (UND97132-0 1)

1) Verify the control rod is at position 48.

2) Provide continuous withdraw signal for 3 to 5 seconds by simultaneously going to NOTCH OVERRIDE and ROD OUT Verify the following:

a) The display window continues to show 48.

b) The computer printout indicates coupling check SAT c) The ROD OVER TRAVEL (5-D-4) annunciator does not alarm.

3) If during the coupling check, the 48 disappears, the rod display window goes dark, and the ROD DRIFT (5-D-5) and ROD OVER TRAVEL (5-D-4) alarms are received, the control rod is uncoupled.

a) If a rod is uncoupled, refer to ON 3 144.

12. Ensure that the previous exercised control rod is at its original position prior to exercising the next control rod.

13. Repeat the above steps for all operable control rods shown on VYOPF 41 11.02 with an asterisk that are not fully inserted.

14. Record the final control rod position on VYOPF 41 11.02 or demand and print a second Control Rod Positions Display to verify all rods are in their original position.

15. Attach both computer printouts (if available) to VYOPF 41 11.02 and route to the Shift Technical Advisor and Shift Manager for review.

16. Record completion in the Surveillance Log.

17. If applicable, return to the pre-surveillance power level in accordance with Reactor Engineering recommendations.

18. Verify APRM GAFs are less than 1.O.

19. Demand a 3D Monicore case and verify thermal limits are less than the administrative thermal limits posted on CRP 9-5.

OP 41 11 Rev. 39 Page 14 of 43 LPC #3

CONTROL ROD OPERABILITY CHECK Date 0Weekly 0Other-Specify wo # Time NOTE Indicate satisfactory cycling with a check mark and attach control rod positions display printouts. If the computer is unavailable, log the before and after positions in the CYCLED SAT columns for each control rod. Indicate any rod movement problems such as double-notching, failure to move on first drive attempt, etc.

A power reduction is required prior to exercising control rods annotated with an asterisk (*).

Control Rods Requiring Power Reduction: Identified By: Reactor Engineer (Not Applicable if no rods require power reduction for exercising) Reviewed By: Operations Manager Rod No. I Cycled Sat RodNo. I Cycled Sat RodNo. I Cycled Sat 18-43 I 10-27 I 42-19 I I 22-43 I I 06-15 18-27 10-15 14-15 I 18-15 I I I 30-27 I I 22-15 I 22-39 I I 34-27 I I 26-15 I L

26-39 I 38-27 30-39 42-27 34-39 02-23 38-15 I 06-35 06-23 06-11 1 I 10-35 I I 10-23 10-11 I 14-35 14-23 14-11 I 18-35 18-23 18-11 I 22-35 22-23 I 22-11 I 26-35 30-35 34-35 38-35 06-3 1 I

I I

26-23 30-23 34-23 38-23 42-23 I

I I 1 26-1 1 30-1 1 34-1 1 38-11 10-07 I

I I

02-19 06-19 18-31 10-19 22-07 I I 14-19 I I 26-07 I I 18-19 I I I 30-07 I I I 30-31 I I 26-19 18-03 38-31 34-19 I I 26-03 I I I 06-27 I I 38-19 1 W O P F 41 11.02 OP 41 11 Rev. 39 Page 1 of 2 LPC #3

JPM 24507 Rev. 1,05102 Page 1 of 6 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Synchronize Turbine Generator With Output Grid At Min. Load Failure Mode: N/A

Reference:

OP 0 105, Reactor Operations Task Number: 2450050101 Task Performance: AO/RO/SRO __ RO/SRO X SRO Only Sequence Critical: Yes - No Time Critical: Yes - No Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation _ . Performance X Discuss -

Setting: Classroom __ Simulator Plant Performance Expected Completion Time: 15 minutes Evaluation Results:

Performance: PASS - FAIL - Time Required:

Prepared by:

Reviewed by Approved by:

0per"ationsTraining Superintendent

JPM 24507 Rev, 1,05/02 Page 2 of 6 Directions:

Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsatl'. Comments are required for any "Unsatll classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "DOyou understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform the actions.

You are requested to "talk through" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

Plant startup is underway. Turbine is operating at 1800 WM. The generator acceleration relay is reset.

Initiatinz Cues:

CRS directs you to synchronize turbine generator to grid and load it to approximately 20% per OP 0105, Section 3.C.

Task Standards:

Turbine generator is synchronized to grid at minimum load.

Required Materials:

OP 0105, Reactor Operations Completed VYOPF 0105.05 up to and including Phase 3B Simulator Setuw IC-7,reset the Acceleration RelayBcram.

JPM 24507 Rev. 1,05/02 Page 3 of 6 Evaluation Performance Steps TIME START:

NOTE: All actions performed on C W 9-7 unless otherwise indicated.

SATAJNSAT Step 1: Obtain Procedure OP 0105.

Standard: OP 0105 obtained, Phase 3 admin limits and precautions reviewed.

~

Interim Cue: Provide operator with completed VYOPF 0105.05.

SATAJNSAT Step 2: Check OPEN the exciter field breaker.

Standard: Operator observes exciter field breaker green light ON and red light OFF.

SATAJNSAT Step 3: Check voltage regulator transfer control is in MANUAL position.

Standard: Operator observes voltage regulator transfer control is positioned to MANUAL.

SATAJNSAT Step 4: Check that the exciter is in minimum volts position bv lowering DC voltage until the LOWER white light is energized.

Standard: Operator observes LOWER white light ON.

SATAJNSAT *Step 5: Close the exciter field breaker.

Standard: Operator positions exciter field breaker hand switch to CLOSE.

Operator observes exciter field breaker red light on, green light off SATAJNSAT Step 6: With the voltage regulator in MANUAL, bring the Generator Stator voltape from minimum (approximatelv 20,000 volts) to rated value of approximately 22,000 volts by going to Raise with the manual DC control switch on EI-9-7-8.

Standard: Operator verifies voltage regulator in MANUAL and then positions Manual DC Control switch to RAISE until generator stator voltage is approximately 22,000 volts as indicated on EI-9-7-8.

SAT/UNSAT Step 7: Shift the voltaee regulator from MANUAL to AUTO as follows:

a. Use AC Voltage Adiust switch to null the regulator transfer indication.

Standard: Operator positions the AC Voltage Adjust switch to null the regulator transfer indication on EI-9 12.

SATAJNSAT Step 8: b. Switch the Voltage Regulator Transfer switch to AUTO.

Standard: Operator positions the Voltage Regulator Transfer switch to AUTO.

JPM 24507 Rev. 1,05/02 Page 4 of 6 SATAJNSAT Step 9: Null the deviation between the AC and DC regulators using the DC voltage adiust switch and the Voltage Regulator Mismatch meter.

Standard: Operator positions the DC Voltage Adjust switch to null the AC and DC regulators as observed on the Voltage Regulator Mismatch meter EI-9 12.

SATNNSAT Step 10 Prepare to synchronize bv coordinating with VELCO and Derforming the Switching and Tagging Order as follows:.

Standard: Operator contacts VELCO and requests permission to open BKR 81-1T, BKR-lT, close T1-MOD, and place reclosure switches to OFF.

Interim Cue: Inform Operator that switching order has been issued as requested.

SATNNSAT *Step 11 Place reclosure switches to OFF for 81-1T and lT, Open BKR 81-1T Open BKR-1T

. Close T1-MOD Standard: Operator performs the following:

calls the A 0 to position 81-1T and 1T reclosure switches to OFF

- positions BKR 8 1- 1T and BKR- 1T hand switches to OPEN and verifies breaker green lights on and red lights off

- positionsTlMOD handswitch to CLOSE, and verifies MOD green light off and red light on Interim Cue: When asked, inform operator the reclosure switches are OFF. A 0 reports local visual observation of breakers as requested.

SATNNSAT *Step 12: Place breaker switch in synchroscope socket and turn the synchroscope on.

Standard: Operator places breaker switch in synchroscope socket and turns the synchroscope to ON. Verifies the meter begins to rotate slowly.

SATNNSAT *Step 13: Load the generator as follows:

a. Adiust generator output voltage (incoming) to be equal to o r slightly higher than line voltage (running), using the AC voltage adiust switch.

Standard: Operator positions AC Voltage Adjust switch to adjust incoming generator output voltage to be equal to or slightly higher than line voltage by comparing the voltage meters on either side of the synchroscope.

SATNNSAT *Step 14: b. Adiust the turbine generator speed so that the svnchroscope needle is moving slowly in the FAST direction.

Standard: Operator intermittently positions Speed Load Changer to either RAISE or LOWER to maintain the synchroscope needle moving slowly in the FAST direction.

JPM 24507 Rev. 1,05/02 Page 5 of 6 SAT/UNSAT *Step 15: When the synchroscope is between 5 minutes to 12 and 12 oclock, close BKR 81-1T.

Standard: Operator observes synchroscope needle rotating slowly in fast direction and when needle position is between 5 minutes to 12 and 12 oclock, operator positions breaker 8 1- 1T hand switch to CLOSE.

Operator verifies breaker 8 1-1T red light on and green light off.

SAT/UNSAT *Step 16: Immediately pickup 25-50 MWE on the generator bv going; to RAISE on the speed load changer.

Standard: Operator immediately positions Speed Load Changer hand switch to RAISE until megawatts indicates 25 -50 MWE on meter 9-7-7.

SATKJNSAT Step 17: When BKR 81-1T is closed and generator is at desired load, synchronize and close BKR-1T.

Standard: Operator observes synchroscope needle not rotating and positions breaker 1- 1T hand switch to CLOSE and observes breaker red light ON and green light OFF.

SAT/UNSAT Step 18: Turn synchroscope off and remove breaker switch from socket.

Standard: Operator positions synchroscope to OFF and removes breaker switch from socket.

SATIUNSAT Step 19: Per VELCO, place reclosure switch for 1T to INST and 81-1T to SYNC CK.

Standard: Contact A 0 in switchyard to place 1T in INST and 8 1-1T to SYNC CK.

Interim Cue: A 0 reports switches in INST and SYNC CK.

SATNNSAT Step 20: If exhaust hood temperatures are > 125 F, remain at 25 to 50 MWE to allow the exhaust hoods to cool below 125 F (time required may be about 5 minutes).

Standard: Operator maintains load at 25-50 MWE until exhaust hoods temperature drops to below 125°F as indicated on Recorder 110-2 Interim Cue: When operator checks temperature, Inform him that exhaust hoods temperature are below 125°F.

JPM 24507 Rev. 1,05/02 Page 6 of 6

Critical Step TIME FINISH:

Terminating Cue: The Turbine generator is synchronized to grid at approximately 20% load.

Evaluators Comments:

System: 245000 KIA's: A4.02 Ability to manually operate and/or monitor in the control room:

(CFR 41.7 / 45.5 to 45.8)

A4.02 Generator controIs RO 3.1 SRO 2.9 A4.05 Generator megawatt output R02.7 SRO 2.7 A4.06 Turbine speed RO 2.7 SRO 2.6 Generic: KIA's:

JPM 24507 Rev. 1,05/02 Page 1 of 1 EXAMINEE HANDOUT Initial Conditions:

Plant startup is underway. Turbine is operating at 1800 RPM. The generator acceleration relay is reset.

Initiatine Cues:

CRS directs you to synchronize turbine generator to grid and load it to approximately 20% per OP 0105, Section 3.C.

3. PHASE 3 Turbine Startup and Synchronization REFERENCES AND COMMITMENTS

1. Technical Specifications and Site Documents

a. All Tech. Spec. sections apply.

2. Codes, Standards, and Regulations

a. See Phase 1

3. Commitments

a. See Phase 1

4. Supplemental References

a. See Phase 1 PRECAUTIONS/LI MITATlONS

1. The reactor vessel dome pressure shall be maintained 11025 psig. At 100% RTP, the allowable range for reactor vessel dome pressure is 1000 to 1010 psig, with a nominal value of 1005 psig as indicated on recorder R-6-96 red pen, PI-101-22 or computer point C202 (R-6-96 red pen preferred). (ER990094-01) (ER2001-215 1-02)

2. The pressure at the turbine stop valves, as indicated by computer point T006, shall be controlled so that it does not exceed 978.5 psig so long as steam flow does not exceed 6.744 x 106 1bs.h.

3. Rapid load increases are permitted only when the exhaust hood temperature is 125°F or less. An exhaust hood temperature rise is expected whenever the turbine is operated at 40% of rated load and can be minimized with the use of exhaust hood sprays.

4. When the exhaust hood temperature is above 125"F, increase the load slowly until the temperature falls below 125°F.

5. Do not operate the turbine at speeds below 800 rpm for greater than 5 minutes. Vibration detectors are inaccurate below approximately 800 rpm, with accuracy dropping off very rapidly below approximately 600 rpm.

Phase 3 OP 0105 Rev. 10 Page 49 of 137

6. If any of the following conditions exist when <25% RTP, then consider core thermal limits (MCPR and APLHGR) evaluation suspect and do not exceed 25% RTP:

(EDCR 97-422)

a. Less than 4 main steam lines passing steam (except surveillances).

b. MTS-2 tripped or any bypass valve inoperable.

C. Either EPR or MPR out of service.

d. Feedwater heater string bypassed.

7. If any of the following conditions exist when CTP >25% RTP, then consider core thermal limits (MCPR and APLHGR) evaluation suspect: (EDCR 97-422)

a. Less than 4 main steam lines passing steam (except surveillances).

b. MTS-2 tripped or any bypass valve inoperable.

c. Feedwater heater string bypassed.

Then exit the condition within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce CTP to less than 25% RTP within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

8. If either the MPR or EPR is not operable, initiate an ER per AP 0009 and ensure an operability determination, per AP 0167, is completed within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

9. When opening a manual containment isolation valve that is within the primary containment boundary as defined by PP 7006, Primary Containment Leak Rate Testing Program, when primary containment integrity is required, either enter the TS LCO (TS 3.7.A.8) or apply all of the following administrative controls:

Station a dedicated operator with no concurrent duties in the immediate vicinity of the valve controls to rapidly close the valve when directed by the control room.

e Establish communication with the control room that is immediately available using either Gaitronics, sound powered phones, radios, telephones or other means.

These administrative controls will ensure the manual containment isolation valve can be rapidly closed when primary containment isolation is required during accident conditions (NVY99004-02).

10. If the air lock is opened during periods when primary containment integrity is not required, the air lock must be leak-rate tested at the end of the period prior to primary containment integrity being required.

Phase 3 OP 0105 Rev. 10 Page 50 of 137

11. If the air lock is opened when primary containment integrity is required, the airlock must be leak-rate tested within 5 days from the time the outer airlock door is opened. If the airlock is opened more frequently than once every 5 days, then the airlock must be closed and leak-rate tested at least once every 5 days. (Tech. Spec. requires testing within 7 days per PP 7006.)

12. Vacuum should not be broken before speed has decreased to 900 to 1200 rpm range. If an emergency condition should arise that requires the turbine be brought to rest as quickly as possible, then it may be necessary to break vacuum immediately on trip out to minimize overall damage to the unit.

13. For normal startups and shutdowns, the rate of change of first-stage bowl inner metal temperature should be limited to 150°F per hour (ERFIS Point C021).

14. The temperature difference across the first-stage bowl should not exceed 75°F.

15. Avoid heating the exhaust hood above 175°F. Normally, the manual selector valve for the water sprays in the hood will be placed in the AUTO position when the unit is rolled off the turning gear on start-up and will remain in this position until the unit has been returned to the turning gear on shutdown. The exhaust hood spray valve automatically opens when control valves are below their 15% flow position. The motor operated hood spray valve bypass can be used if the automatic valve is out of service.

16. It is undesirable to operate a turbine with auxiliary load or no load at any speed through the admission of steam to the control valves after the unit has been running at or near rated temperature. This may cause quenching of the internal parts and result in cracking or excessive distortion.

17. During starting, when bringing the unit to rated speed, operation near or at the rotor critical speeds should be minimized in order to minimize the possibility of excessive vibration. A continual increase in speed is usually desirable from turning gear to near rated speed. As it is accelerated, it is normal for the generator bearing vibration to increase as the first critical point is approached, approximately 1000 rpm. Less than 6 mils vibration is considered desirable and 10 mils is acceptable.

18. If the turbine is being started and brought to speed from the front standard, observe all precautions that pertain to areas where high radiation levels exist. Contact the Radiation Protection Department for an RWP and updated survey if applicable.

19. To avoid transients on the reactor-turbine system, make adjustments to the system slowly.

20. Operation below 5% load should be held at a minimum because of the increased rates of moisture erosion of the latter stage buckets.

21. When condenser vacuum is broken and steam is present in the headers outside of the isolation valves, the mechanical vacuum pump must be placed in service.

Phase 3 OP 0105 Rev. 10 Page 51 of 137

22. When synchronizing the generator to the grid, ensure the phase angle is small as possible.

Close BKR 8 1- 1T first (preferably), then ATB- 1T.

23. During operation, ensure there is no arcing between the collector ring and the brush holder rigging. If any arcing is observed, contact the Maintenance Manager immediately.

24. Any air in the control oil system for the intercept valves may cause them to operate in an unstable manner. If the lube oil system has been shut down, ensure that any trapped air in the positioning devices is bled out as required.

25. All protective functions associated with generator voltage regulator are bypassed when the manual regulator is controlling generator voltage. Therefore, it is important that the regulator not be in MANUAL except when absolutely necessary.

26. Since there are several conditions which may automatically shift generator voltage control from AUTO to MANUAL, maintain the manual voltage regulator balanced with the auto regulator at all times.

27. Turbine control should be shifted to the MPR if any of the following conditions associated with EPR oil filter system occurs:

a. Replacing filter elements.

b. Low oil tank level alarm.

c. Oil tank temperature increasing to 150°F.

d. Accumulator precharge checks.

e. Problems associated with both filter pumps.

28. To reduce copper particle generation and the probability of field winding problems caused by copper particle accumulation, turning gear operation should be minimized (consistent with other turbine operating instructions).

29. To avoid a "bowed-rotor condition", the turbine generator must be put on the turning gear for a minimum of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months before rolling the unit with steam.

30. If BKR Sl-lT, BKR-lT, and T1-MOD fail to open due to a turbine trip, protective action to prevent turbine overspeed has priority over action to limit generator motoring.

3 1, If a turbine trip occurs, do not attempt to reset the emergency governor before turbine speed has decreased below 1800 rpm; otherwise, extensive damage can occur to the emergency governor trip finger.

32. The BPOJ should not be used at any time when the reactor is critical. (PTR88803OP4)

Phase 3 OP 0105 Rev. 10 Page 52 of 137

C. Generator Synchronization and Loading (Use VYOPF 0105.05)

1. If not previously performed, reset the generator acceleration relay as follows: *

a. Place the scram reset switch to the "Group 2 and 3" position, then to the "Group 1 and 4" position, and again to the "Group 2 and 3" position.

b. Check that annunciator TURB CTRL VLV FAST CLOSURE (5-L-4) on CRP 9-5 clears.

2. Check open the exciter field breaker.

3. Check voltage regulator transfer control is in MANUAL position.

4. Check that the exciter is in minimum volts position by lowering DC voltage until the LOWER white light is energized.

5. Close the exciter field breaker.

NOTE The following step checks that the excitation circuit is functioning properly.

6. With the voltage regulator in MANUAL, bring the Generator Stator voltage from minimum (approximately 20,000 volts) to rated value of approximately 22,000 volts by going to RAISE with the manual DC control switch on EI-9-7-8.

7. Shift the voltage regulator from MANUAL to AUTO as follows:

a. Use AC Voltage Adjust switch to null the regulator transfer indication.

b. Switch the Voltage Regulator Transfer switch to AUTO.

c. Null the deviation between the AC and DC regulators using the DC voltage adjust switch and the Voltage Regulator Mismatch meter.

Phase 3C OP 0105 Rev. 10 Page 62 of 137

8. Prepare to synchronize by coordinating with VELCO and performing the Switching and Tagging Order as follows:

a. Place reclosure switches to OFF for 8 1- 1T and 1T.

b. OpenBKR 81-1T.

c. Open BKR-IT.

d. Close T1-MOD.

9. Place breaker switch in synchroscope socket and turn the synchroscope on.

10. Load the generator as follows:

a. Adjust generator output voltage (incoming) to be equal to or slightly higher than line voltage (running), using the AC voltage adjust switch.

b. Adjust the turbine-generator speed so that the synchroscope needle is moving slowly in the FAST direction.

c. When the synchroscope is between 5 minutes to 12 and 12 o'clock, close BKR 81-1T. *

d. Immediately pickup 25 to 50 MWE on the generator by going to RAISE on the speed load changer.

e. When BKR 81-1T is closed and generator is at desired load, synchronize and close BKR-1T. *

f. Turn synchroscope off and remove breaker switch from socket.

g. Per Velco, place reclosure switch for 1T to INST and 81-1T to SYNC CK.

h. If exhaust hood temperatures are >125"F, remain at 25 to 50 MWE to allow the exhaust hoods to cool below 125°F (time required may be about 5 minutes).

11. If not previously performed, close the following drains (CRP 9-23): *

a. CV above seat drains, MS-SA/B/C/D.

b. HP Steam lead drain, MS-12.

C. Steam line drains, MS-2A/B/C/D.

d. Steam line lead drain, MS-4.

Phase 3C OP 0105 Rev. 10 Page 63 of 137

e. Steam drain level control valves, MS-LCV-38A/B/C/D.

f. Mn Stm Drain Strainer Blowdown, MS-143.

g. Close/check closed the following valves:

e AS-39 AE Press Control Inlet Steam Trap Bypass e AS-40 Air Ejector Inlet Steam Trap Bypass e AS-34 AE Press Reducer Bypass to Main Condenser NOTES e All protective functions associated with the voltage regulator are bypassed when the regulator is in MANUAL. Therefore, it is important that the regulator not be in MANUAL except when absolutely necessary.

e There are several conditions that could automatically shift generator voltage control from AUTO to MANUAL. Therefore, the manual voltage regulator and the auto regulator should be balanced at all times.

e With the regulator in AUTO, the voltage and power factor can be adjusted with the "AC Voltage Adjust" rheostat.

With the regulator in MANUAL: the voltage and power factor can be adjusted with the "DC Voltage Adjust" switch.

12. Adjust voltage to maintain reactive load at minimum.

13. Monitor all generator temperatures immediately following phasing generator to the gnd until the temperatures have stabilized.

14. Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of exceeding 150 psig reactor steam pressure, if required, perform HPCI and RCIC pump operability surveillance per OP 4120 and OP 4121.

a. Verify HPCI and RCIC operable or initiate appropriate LCOs.

1) Record completion of HPCI and RCIC pump surveillance completion, if applicable, in the Shift Managers Log.

b. Verify Drywell to Torus Vacuum Breaker operability test, per OP 41 15, complete.

Phase 3C OP 0105 Rev. 10 Page 64 of 137

JF'M-20205 Rev. 0, 05/02 Page 1 of6 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Reset of Scoop Tube Lockup Failure Mode: N/A

Reference:

OP 2 110, Reactor Recirc System Task Number: 2027050101 Task Performance: AO/RO/SRO - RO/SRO X SRO Only Sequence Critical: Yes - No 3 Time Critical: Yes - No 2 Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation - Performance X Discuss -

Setting: Classroom - Simulator X Plant Performance Expected Completion Time: 20 minutes Evaluation Results:

Performance: PASS - FAIL - Time Required:

Prepared by: -

Date Reviewed by:

SRO Li&&&Vc&ified Reviewer Approved by: G P %?G& 8/43

.I-Opbations Training Superintendent Date

JPM-20205 Rev. 0,05/02 Page 2 of 6 Directions:

Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

ARer providing the initiating cue, ask the operator "DOyou understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform the actions.

You are requested to "talk through" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

1) The A Recirc scoop tube had been manually locked up for IC adjustments and repairs. Local manual control was taken, however speed was not changed.

2) All controller repairs have been made and checked out.

Initiatine Cues:

The CRS has directed you to Reset the A Scoop Tube Lockup and leave control in Manual. When restoring control, you are authorized to make an increase adjustment to speed, as necessary to re-engage the controller.

Task Standards:

Reset the A Recirc Scoop Tube in accordance with OP 21 10.

Required Materials:

OP 21 10, Recirc System System General

References:

None

JPM-20205 Rev. 0,05/02 Page 3 of 6 Simulator Setup:

Any 100% power IC.

Lower power with Recirc to 90%.

Lockup the A recirc scoop tube fi-om CRP 9- 18.

Select Manual on the A Individual speed controller VYOPF 0150.03 page 7 of 27, with numbers that match IC used

JPM-20205 Rev. 0,05102 Page 4 of 6 Evaluation Performance Steps TIME START:

SATAJNSAT Step 1: Obtain Procedure, Review Administrative Limits, Precautions and Prerequisites Standard: OP 2 110, obtained, Administrative Limits, Precautions, and Prerequisites reviewed.

~~

Interim Cue: All prerequisites are complete.

SATKJNSAT Step 2: If 2-184-32A(B) MG A(B) DEM/POS at CRP 9-4 is unavailable or off scale.... Otherwise continue at step 2.

Standard: Operator observes meter is on scale and indicating, proceeds to step 2.

SAT/UNSAT Step 3: At CRP 9-4 vertical section, observe the following indication on meter 2-184-32A(B), MG A B ) DEWPOS.

Controller DEM (Left side, Preen displav)

Scoop tube positioner POS (Right side, red display)

Standard: Operator checks meter 2-284-32A on the vertical section of CRP 9-4.

SATAJNSAT Step 4: If the affected pumps PUMP Am) CONTROLLER 2-184-16A(B) is not in manual, depress the A/M pushbutton. Ensure the MAN red LED is lit.

Standard: Operator verifies red MAN is lit.

SATAJNSAT Step 5: Verify or select the MG-A(B) P display as indicated on the second display.

Standard: The operator uses the D pushbutton to select P as the displayed value.

JPM-20205 Rev. 0,05/02 Page 5 of 6 SAT/UNSAT Step 6: Adjust PUMP A(B) CONTROLLER 2-184-16A03) as follows:

If no recirculation MG speed change has occurred from the time of the last CRO log readings until the time of the SCOOP tube lock up, adiust the PUMP A B ) CONTROLLER 2-184-116A(B) speed demand signal to achieve the value corresponding to the last CRO log reading for 2-184-32AtB) MG A B ) DEM/POS and proceed with step 6 Standard: The operator checks speed and demand and verifies that no change has been made to speed using the provided CRO log sheet.

Interim Cue: Provide a completed VYOPF 0150.03 page 7 of 27 log sheet with numbers that match the present DEJWPOS values.

SATAJNSAT

Step7: If the scoop tube was manually locked, on CRP 9-18, place the A(B) SCOOP TUBE ACTUATOR MANUAL LOCKOUT SW 184-2Am)L to NORMAL and push in the switch Standard: The scoop tube was locked manually, so the operator turns the key and pushes in the switch.

SATAJNSAT

Steps: Depress the A B ) SCOOP TUBE LOCKUP RESET pushbutton Standard: On CRP 9-4, the operator pushes the scoop tube Lock up Reset Pushbutton.

SAT/UNSAT Step 9: Observe that MG SET A(B) SCP TUBE LOCK, 4-B-1(4-F-l) alarm clears Standard: The operator observes and resets alarm 4-B-1.

SAT/UNSAT

Step 10: If recovering from Local Manual Control of Scoop Tube positioner, adiust PUMP A(B) CONTROLLER 2-184-16A(B) output +/- 2% as plant conditions dictate to re-engage the scoop tube positioner Standard: The operator uses the controller to raise or lower the P signal on the controller + or - 2% to re-engage the positioner and verifies speed increaseshforms the CRS that the controller is back in remote manual control.

Interim Cue: CRS directs speed to remain as is for the time being.

JPM-20205 Rev. 0,05/02 Page 6 of 6 TIME FINISH:

Terminating Cue: A Recirc Controller in Remote Manual Control IAW OP 21 10.

Evaluators Comments:

System: 202002 WA's: A2.05 Ability to (a) predict the impacts of the following on the RECIRCULATION FLOW CONTROL SYSTEM ;and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those abnormal conditions or operations:

(CFR: 41.5 / 45.6)

Scoop tube lockup: BWR-2,3,4 RO 3.1 SRO 3.1 A4.01,04,08 Ability to manually operate and/or monitor in the control room:

(CFR 41.7 / 45.5 to 45.8)

MG sets R03.3 SRO 3.1 Reactor power RO 3.8 SRO 3.8 Recirculation system flow RO 3.3 SR03.3 Core flow R03.2 SR03.3

JPM-20205 Rev. 0, 05/02 Page 1 of 1 EXAMINEE HANDOUT Initial Conditions:

1) The A Recirc scoop tube had been manually locked up for IC adjustments and repairs. Local manual control was taken, however speed was not changed.

2) All controller repairs have been made and checked out.

Initiating Cues:

The CRS has directed you to Reset the A Scoop Tube Lockup and leave control in Manual. When restoring control, you are authorized to make an increase adjustment to speed, as necessary to re-engage the controller.

VERMONT YANKEE NUCLEAR POWER STATION OPERATING PROCEDURE OP 2110 REVISION 35 REACTOR RECIRCULATION SYSTEM USE CLASSIFICATION: REFERENCE 1 IL PC No.

1 Effective Date 1 10/01/02 PgS 15-19 of45 Affected Pages 2 10/18/02 4,15,21,23 & 25 of45 3 10/23/02 Pg 14of45 4 12/20/02 34 of 45 I 5 I 06/09/03 1 2,7,45 of 45, ADDED Figure 4 Pg 1 of 1 & Figure 5 Pg 1 of 1 I Implementation Statement: N/A I Issue Date: 07/30/02 OP 2110 Rev. 35 Page 1 of 45

~

TABLE OF CONTENTS PURPOSE .......................................................................................................................................................... 3 DISCUSSION .................................................................................................................................................... 3 ATTACHMENTS.............................................................................................................................................. 7 REFERENCES AND COMMITMENTS ......................................................................................................... 8 PRECAUTIONS/LIMITATIONS................................................................................................................... 10 PREREQUISITES ........................................................................................................................................... 13 PROCEDURE.................................................................................................................................................. 15 A. Startup of a Recirculation Pump(s) With the Reactor Shutdown........................................... 15 B. Shutdown of Recirculation Pumps ......................................................................................... 19 C. Shutdown of One Recirculation Pump ................................................................................... 21 D. Startup of Idle Pump With Other Pump Running While Reactor is at Power ....................... 24 E. Venting Recirculation Pump Seals ......................................................................................... 29 F. Local Manual Control of Scoop Tube Positioner ................................................................... 35 G. Cold Water Stratificationin the Reactor Vessel ..................................................................... 37 H. Reset of Scoop Tube Lockup (UND94034-03 and LER9409-03) ....................................... 38 I. MG Set Lube Oil Pump Trip .................................................................................................. 41 J. Recirc Pump MOV Operation While in Shutdown Cooling.................................................. 41 K. Placing Recirc Pumps In Master Manual Flow Control......................................................... 43 L. Recirc Pump Bias Adjustment While Operating in Master Manual Flow Control ...............44 M. Recirc System Operation With Recirc Pump Speed In or Approaching Critical Speed Zones ............................................................................................................................ 45 FINAL CONDITIONS .................................................................................................................................... 45 OP 21 10 Rev. 35 Page 2 of 45 LPC #5

PURPOSE To ensure proper operation of the Recirculation System by Operations Department personnel.

DISCUSSION The reactor recirculation system consists of two recirculation pump loops external to the reactor vessel which provide the driving flow of water to the reactor vessel jet pumps. Each external loop consists of a downcomer, a motor-operated pump suction valve, a high capacity motor-driven pump, a motor-operated discharge valve with a motor-operated bypass, a discharge riser containing a venturi-type flow meter nozzle and a ring header which supplies five jet pump risers.

The water pumped through the external loops becomes the driving force for 20 jet pumps located in the reactor vessel annulus between the vessel wall and the core shroud. The water in the reactor annulus becomes the driven flow of the jet pumps which is accelerated by and mixed with the driving flow. The 2 flows are discharged below the core and provide core coolant flow up through the cooling channels.

The 4-inch pump discharge valve bypass valve is used to preheat an idle loop by reverse flow and also limits flow during pump starting. After the pump has been started, the main discharge valve is opened (the discharge valve bypass valve remains open).

Each recirculation pump is a single-stage centrifugal pump equipped with mechanical seals. The seals are normally supplied with clean water from the control rod drive system by the seal purge system to reduce the potential of foreign material damaging the seal surfaces. Each recirculation pump seal is supplied by its independent seal purge control system. Should a seal purge flow control station become inoperable, seal flow will be automatically supplied by the original seal leakage system for that recirculation pump.

Each recirculation pump motor is a variable speed AC induction motor which can drive the pump over a speed range of 20% to 102% rated speed. The motor is supplied from a variable frequency motor generator (MG) set. The pump operates over a speed range corresponding to a supply frequency of 11.5 cps to 57.5 cps.

OP 2110 Rev. 35 Page 3 of 45

The reactor recirculation pump speed control system is a digital system consisting of one master speed controller and two auto/manual control stations, one auto/manual control station for each recirc pump. The reactor recirculation pumps are operated over a speed control range of 20-105% speed. The control stations are configured such that a 0% controller output signal corresponds to a 20% pump speed and a 100% controller output signal corresponds to a 105%

pump speed. The minimum output of the master controller is 25%. The master controller is equipped with an adjustment knob and a digital display. The digital display on the master controller has a resolution of 0.1%. The auto manual control stations are equipped with numerous displays and pushbuttons. Refer to Figure 3. The upper display on the auto/manual transfer station displays the percent value of one of the following as selected by the Operator:

a The master controller output, indicated by MG-A(B).S in the second display.

e The individual auto/manual controller output, indicated by MG-A(B).P in the second display.

0 The scoop tube positioner signal, indicated by MG-A(B).V in the second display.

The displayed parameter is accurate to 0.01%. The Operator selects the display desired by depressing the D pushbutton. The D pushbutton allows the operator to alternate between the S, P, and V display. Changing displays has no effect upon controller output and the operator may select any display at any time. Three other displays provide continuous bargraph representation of the S, P, and V values. During the performance of this procedure, when the use of MG-A(B).S, P, or V digital values are specified, if the numerical digital value display is not available, the bargraph values of S, P, and V on PUMP A(B) CONTROLLER 2-184-16A(B), may be used instead. An auto manual select, A / M , alternate action pushbutton allows the Operator to select between master recirc pump speed control, when in auto, and auto/manual transfer station control when in manual. A green LED illuminates when in auto and a red LED illuminates when in manual. Auto/manual transfer station output is adjusted using the adjustment knob. The auto/manual transfer station adjusting knob has no affect upon recirc pump speed when in automatic. Regardless of mode, the auto/manual transfer station adjusting knob has no effect if the master controller output (MG-A(B).S) is selected for display. When depressed the UNITS pushbutton displays PCNT in the second display. Depressing the UNITS pushbutton a second time returns the displays to normal, The remaining pushbuttons are not used. Every 0.1% controller output change results in a core flow change of approximately 0.045 Mlbm/hr (45,000 lbdhr). An access door that opens fi-om the top allows access to controls that allow bias adjustment of the controller signal. If power is lost to the controller, the bias settings are lost. When repowered, the controller will have a zero bias setting. Protection against a master controller failure with increasing signal is provided. When master controller output increases at a rate >l%/sec., the auto manual stations will transfer to manual.

The variable frequency MG set is electrically connected to the pump motor. The MG sets motor is a constant speed 3500 HP machine. The generator speed is varied by adjusting the hydraulic coupling between the motor and generator. The hydraulic coupling is supplied with operating oil and lubricating oil by 2 of 3 AC motor driven oil pumps. The standby AC oil pump can only be started upon loss of one of the operating pumps. It is not possible to operate the three pumps simultaneously. Should a loss of DC control power occur, AC lube oil pumps A&B(D&E) will start if AC power is available. AC lube oil pumps C(F) will trip. Upon a loss of DC control power, to stop an AC lube oil pump, open the pumps AC breaker. When DC control power is restored AC lube oil pumps A&B(D&E) will continue to run. A DC motor-driven small capacity pump will supply the coupling bearings during motor coast down.

OP 2110 Rev. 35 Page 4 of 45 LPC #2

The hydraulic coupling is varied through controllers located on CRP 9-4. These controllers can be operated manually by the operator or automatically by a master flow controller on CRP 9-5. The master flow controller is operated by the operator in the Manual Mode only (the AUTOMATIC position is for use of a signal from the speed-load changer, but is not connected).

An increase in recirculation flow temporarily reduces the steam void volume in the core by removing the steam at a faster rate and replacing it with water. Since voids act as negative reactivity, this increase in removal rate adds positive reactivity to the core, which in turn causes reactor power level to increase. The increased steam generation rate increases the steam void volume in the core with a subsequent negative reactivity effect, and thereby, a new higher power level is established. When recirculation flow is reduced, the power level is reduced in a similar manner.

The transient associated with the trip of one or both recirculation pumps will result in a drop in reactor power. MCPR and thermal limitations are affected during this transient but no reactor scram should occur.

The drive motor trips upon the following conditions:

a. 4KV Bus undervoltage

b. Low lube oil pressure

c. High lube oil temperature

d. Generator lockout

e. Pump suction valve not fully open

f. Both discharge valve and discharge bypass valve not fully open

g. Low-Low Reactor Vessel water level The combined rotating inertia of the recirculation pump and motor, motor-generator set, and the variable speed coupling are chosen to provide a slow coastdown of flow following loss of power to the drive motors so that the core is adequately cooled during a combined loss-of-power and loss-of-coolant transient.

The Recirculation Pump Trip (RPT) Analog logic provides a backup system to the Reactor Protection System (WS)to introduce negative reactivity into the core to combat an Anticipated Transient Without Scram in the event of a malfunction of the RPS. This is accomplished by tripping both of the recirculation MG field breakers upon any one of the following conditions:

a. Reactor vessel water level remains at the low-low level setpoint (82.5 inches) (10 sec.

b. High reactor vessel pressure (1 150 psig), or

c. Manually using pushbuttons on CRP 9-4.

The two TRIP pushbuttons (BX and DX, or AX and CX) associated with a particwlator Alternate Rod Insertion (ARI) valve must be depressed to manually trip both MG set field breakers and initiate Alternate Rod Insertion.

OP 21 10 Rev. 35 Page 5 of45

Reset pushbuttons are located on C W 9-4 to reset the logic, if actuated, once the condition that caused the trip is cleared. The power supply for the RPT circuitry is from two 125 VDC battery systems. One charger per battery maintains them in a fully charged state.

In order to limit thermal shock to the reactor vessel nozzles and the bottom reactor head region on startup of an idle recirculation loop, two temperature limits have been established:

1. The first thermal consideration requires coolant temperature in the idle loop to be within 50°F of the operating loop prior to pump start. If possible, the suction and discharge valves should be left open in the idle loop so that the loop does not cool down. If the loop has cooled down, it should be slowly heated utilizing reverse flow by opening the discharge bypass valve and suction valve followed by the discharge valve. Computer point C274 provides the maximum recirculation inlet differential temperature.

If the reactor is in hot shutdown and both loops are secured with the reactor in natural circulation, coolant temperature in the loop to be started must be within 50°F of saturation temperature for the corresponding reactor pressure. This may be accomplished by allowing the loop to warm up via convective flow.

2. The second thermal consideration requires the bottom drain temperature to be within 145°F of the reactor saturation temperature prior to pump start (GESIL 251). The 145°F differential limit is to minimize fatigue damage of the CRD stub tubes. Adhering to this limit prior to initiating any action that will sweep a cooler bottom head with hot fluid will also conservatively assure the brittle fracture pressureltemperature are maintained. Specific pressure/temperature limits for a bottom head hot sweep transient are provided in VYC-829. This condition can be corrected by either:

a. A decrease of CRD cooling water flow with an increase of bottom drain flow by ensuring CU-99 is open and throttling CU-46.

b. Shutting down and depressurizing to lower reactor bulk coolant temperature.

3. For the cold shutdown condition, saturation temperature should be considered to be 212°F any time that pressure in the vessel is not due to steam pressure. During vessel hydrostatic tests which require pump starts with coolant bulk temperature

<2 12°F but pressurized above atmospheric, the required saturation temperature for calculating A-Ts will be falsely high. Steam tables only recognize saturated steam conditions. This will result in calculated A-TS in excess of maximum allowable; but, which are actually false because bulk coolant temperatures are actually <212"F.

OP 21 10 Rev. 35 Page 6 of 45

The following plant operating conditions are likely to cause thermal stratification in the bottom head region:

1. Operation of the reactor at less than 30% rated power without forced recirculation flow in both loops.

2. During heatup of the reactor with only one recirculation loop in operation.

3. Operation at any power level with only one recirculation loop in operation at less than 40% flow.

4. Reactor scram accompanied by loss of both recirculation pumps. (GESIL 25 1)

5. Shutdown cooling in service, Reactor Cleanup secured and Reactor Water Level less than 185 inches.

6. One recirculation loop in operation and operating at any reactor power with Reactor Cleanup secured.

7. Core flow less than 30% with normal CRD cooling flow and no Reactor Cleanup.

Startup and operation of the reactor is permissible in single loop operation (SLO) even though maximum obtainable reactor power will be greatly reduced. Concern for safe operation is assured by adjustments to restore the normal margin of safety to the APRM flux scram, APRM rod block and rod block monitor setpoint equations. These adjustments are to be initiated within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months and completed within 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months of SLO. For further discussion of the requirements for SLO, refer to OP 2428, Single Loop Operation.

Loss of both recirculation pumps while the reactor is in the RUN mode requires a reactor scram.

Each recirculation pump is equipped with a monitoring system that is designed to give ample warning of shaft degradation that could lead to a catastrophic shaft failure. Each pump has six sensors attached that transmit data to the Data Analysis Acquisition Cabinet (DAAC).

The data consists of pump shaft displacement, acceleration, and speed. This data is processed by the DAAC, and a local readout is provided. If the monitored parameters exceed preset values, an alarm is energized in the Control Room. Operator actions in response to alarms are provided by the applicable alarm response sheet.

ATTACHMENTS

1. Appendix A Valve Lineup

2. VYOPF 21 10.01 Deleted

3. Figure 1 Deleted

4. Figure2 Deleted

5. Figure 3 Recirc Speed Control - Individual M/A Station

6. Figure4 Decreasing Recirc Flow

7. Figure 5 Increasing Recirc Flow OP 2110 Rev. 35 Page 7 of 45 LPC #5

REFERENCES AND COMMITMENTS

1. Technical Specifications and Site Documents

a. TS Sections 3.2,3.7,4.2, 3.6,4.6

b. Core Operating Limits Report Figure 2.4-1 C. UFSAR Sections: 1.6.1.3.3, 1.6.4.1.2, 3.3.5.2, 3.3.5.6, 3.4.5.3.3, 3.7.5.3, 3.7.5.4, 4.1,4.2.4.1,4.3,4.6,5.2,6.3,6.5, 7.1.2, 7.1.3.7, 7.1.4.2,7.3.4.7.1, 7.3.4.7.2, 7.3.4.7.3,7.3.4.7.4, 7.3.4.7.5,7.3.4.7.14, 7.4.3.5.2.3,7.4.3.5.2.6,7.4.3.5.2.7, 7.4.3.5.4,7.5.7.5, 7.5.8.2.4, 7.7.4.3.2.e, 7.7.4.3.2.f, 7.7.4.3.4,7.8.5.2,7.8.5.3, 7.9, 7.16, 7.18, 12.2.1.2, 14.4, 14.5.4.3, 14.6.2.6.2, 14.6.3, 14.6.5, 14.8, A.9.2.2, A.9.2.7, A.9.2.8, A.9.3, A.10.6.B, B.2.2.7, B.3.3.10, B.4.8, B.4.20, B.4.21, C.2.5.3, C.3.1, C.3.2, H.2.1, H.3.3.1.1, Appendix J Tables: 1.2.1, 1.7.1,4.1.1,4.2.1,4.10.1, 5.2.2,6.5.1, 6.5.3, 6.5.4,6.5.5,6.5.6, 6.5.7,6.5.8,7.3.1, 7.5.4, 7.8.1, 14.6.4AYH.2.2,H.3.1

2. Codes, Standards, and Regulations

a. None

3. Commitments

a. SILO5170P1, Single Loop Operation

b. LER9409-03, Revise OP 21 10 as Detailed in Long Term Recommendation 3 (i.e., Speed Demand Adjustment For Scope Tube Reset)

C. UND94034-3, Revise OP 21 10 to Provide Specific Guidance For Resetting Scoop Tube Lock Up

d. UND97039-01, Specify a Recirc Flow Range In Procedures

e. NVY94084-03, RE: BVY 94-90, Encl. A; Thermal Hydraulic Stability -

Develop Procedures to Provide Operators Guidance

f. NVY99004-02, Re Tech Spec Amendment 165, Re Primary Containment Isolation Valves (PCIS). Review all procedures impacted by the amendment and revise as necessary. Ensure that control room communications is (or will be) immediately available.

SILO621-01, Revise OP 21 10 to Provide Instructions for Responding to Valid and Invalid Recirculation Pump Runback Signals with Scoop Tube of One Recirc Pump Locked

h. SIL0628-00, Core Flow Measurement System Summer Calibration

1. ER2000-1448-01 ,Add Note to Procedure Regarding Responsiveness of Recirc Master Controller

j. SER 9604-01, Failure of Reactor Coolant Pump Seal

4. Supplemental References

a. GEK 17436

b. GEK 9609, Reactor Recirculation System

c. GE Document 23A1487, Recirculation System (Single Loop Operation)

d. DWG 191162, Sh. 1, Misc. Systems - Recirc MG Lube Oil OP 21 10 Rev. 35 Page 8 of 45

e. DWG 191165, Sampling System

f. DWG 191 167, Nuclear Boiler 5 DWG 191159, Sh. 5, Recirc Pump Cooling Water

h. GESIL 406, In-Core Instrumentation Protection

i. GE Information Report Allowable Recirculation Flow Rates for In-Core Protection, dated Sept. 1985

j. GESIL 368, Recirc Discharge Isolation Valve Locking

k. SOER 84-07, Pressure Locking and Thermal Binding of Gate Valves

1. SOER 83-09, Valve Inoperability Caused by Motor Operator Failures

m. NRC Bulletin 88-07, Supp. 1, dated Dec. 30, 1988

n. GESIL 25 1, Control of Reactor Pressure Vessel Bottom Head Temperatures

0. Memo, J.S. Chizever to S.R. Miller, "Valve Locking Requirements, SR 91-98",

VYS 302/91, dated 12/31/91 P. SR 91-12, "Service Request 91-12, MOV Maintenance Verification Options",

OPVY 548/91, dated 8/29/91

4. SER9305, Reactor Pressure-Temperature Limits Exceeded

r. BVY 94-91 Response to NRC Generic Letter 94-02, Stability S. GESIL 380 Rev. 1, BWR Core Thermal Hydraulic Stability

t. ER970145, Recirc Loop Response U. Memo, RLS to JKT, OPVY 33/96, "10CFR50.59 Safety Evaluation for Operation With Recirculation Discharge Bypass Valves Open", dated 1/30/96 V. NRC IN 95-16, Vibration Caused By Increased Recirculation Flow in A BWR W. SIL 05 16, Core Flow Indication in the Low Flow Region X. Vermont Yankee Nuclear Power Station SAFEWGESTR-LOCA Loss of Coolant Accident Analysis, NEDC-328 14P, March 1998 Y* Letter from W.H. Hetzel (GE) to David Mannai, "SAFER/GESTR Analysis for Single Loop Operation", WHV:98-058,4/28/98 Z. AP 0009, Event Reports aa. AP 0047, Work Request bb. OP 0105, Reactor Operations cc. AP 0155, Current System Valve and Breaker Lineup and Identification dd. OP 21 11, Control Rod Drive System ee. OP 21 15, Primary Containment ff. OP 2 124, Residual Heat Removal System gg. OP 2182, Reactor Building Closed Cooling Water hh.

OP 2190, Service and Instrument Air 11.

.. OP 2428, Single Loop Operation JJ

OP 4 110, Reactor Recirc System Surveillance kk. AP 6100, Infrequently Performed Tests or Evolutions

11. AP 6807, Collection, Temporary Storage and Retrieval of Quality Assurance Records OP 2110 Rev. 35 Page 9 of 45

PRECAUTIONS/LIMITATIONS

1. To avoid overstressing the CRD stub tube and in-core housing welds, the reactor vessel bottom drain temperature must be within 145°F of the saturation temperature before restarting the reactor recirculation pump(s), increasing recirculation flow, or increasing reactor power level.

2. The pump in an idle recirculation loop shall not be started unless the temperatures of the coolant within the idle and operating loops are within 50°F of each other.

3. To obtain a valid reactor vessel bottom head temperature, there must be sufficient flow through the vessel bottom head drain. (SER9305)

4. When starting a reactor recirculation pump to recover from the natural circulation mode of operation, a pump shall not be started unless the recirculation loop temperature is within 50°F of the saturation temperature for the corresponding reactor pressure. This precaution prevents thermal shock to the recirculation pump and reactor vessel nozzles.

(GEK-9609)

5. The pump discharge valve should be opened within a few minutes of startup to prevent damage to the pump bearings. Do not exceed a maximum of 15 minutes pump operation with the discharge valve closed.

6. Operation of the recirculation pumps at suction pressures below 300 psig should be minimized since such operation can contribute to shortening seal life.

7. Avoid operation of the recirculation pumps with air in the seal cavities by thoroughly venting the seal cavities whenever seal maintenance or pump isolation in combination with seal cavity draining has occurred. It is particularly important to avoid operation with air in the cavities at low reactor pressure.

8. Loss of RBCCW cooling can cause recirculation pump seal failure. If it is lost and seal purge is not in service, seal failure is likely in approximately two minutes. If seal purge is in service, seal damage is not expected but seal temperature should be monitored closely.

9. Prior to isolating a recirculation pump, the seal purge to that pump must be isolated.

Operating seal purge with no discharge path results in lifting the relief valve at the discharge of the seal purge flow control station.

10. Due to the possibility of "wedge binding" in gate valves which remain closed during system cooldown, consider cycling or manually backing them off their seats prior to system cooldown (GESIL 368 and SOER 84-7)

11. During periods when he1 and blade guides have been removed from the reactor vessel, do not operate any recirculation pumps without providing in-core instrumentation protection. (GESIL 406)

OP 21 10 Rev. 35 Page 10 of 45

12. With blade guides installed, do not operate the recirculation system and/or RHR system such that core plate d/p reaches 4 psid. If core d/p exceeds 4 psid the blade guides may lift from the core support (GESIL 406)

13. When operating motor operated valves that are not specifically identified as throttle valves, the control switch should be turned to openhlose just long enough to verify valve movement and then released. If there is doubt that the valve is fully opedclosed, the switch may be operated again, but should not be held in position since motor damage or breaker tripping could result.

14. Electrical seatinghackseating which bypasses the normal controls, or manual engagement of a safety-related motor operated valve will require the valve being declared inoperable unless an evaluation determines that continued valve operability is ensured, or until remote (motor) operation can be demonstrated. (SOER 83-09) (SR 91-12)

15. It is possible, during the single loop recovery to dual loop operations, for the total core flow to briefly indicate below the natural circulation lines on the power and flow map.

This is a result of the timing of the reverse flow summer vs. actual flows in the recirculation loops during the recovery evolutions of starting an idle recirculation pump.

The "false" indication of core flow will continue until both recirculation pumps are operating at minimum speed or greater. A valid "alternate" core flow indication that can be used is computer point BO50 "derived core flow - DP based". (SIL0516W)

16. VY has had a history of recirc speed oscillations/instability in the 92.5-94% (tach based speed M040 & M041) speed range. This is equivalent to approximately 90.5-92%

fiequency speed range as read on the controller displays. Normally recirc speed control maintained within +/- 0.25% (0.4% max.). In the oscillation region, speed control is 1%

(perhaps a shade more at times). These oscillations may be dampened by adjusting the bias on the recirc loop experiencing the oscillations. (ER970145)

17. Planned entry into single reactor recirculation loop operation is an infrequently performed evolution. The requirements of AP 6100, Infrequently Performed Tests or Evolutions, must be performed prior to planned single loop operation.

18. Operation with total core flow >104.3% of rated requires Operations Manager permission.

19. The adjustment knob on the recirc pump speed controllers is connected to a rotary encoder that controls the output current. A micro controller in the front panel reads phase information from the encoder to determine the direction of rotation. Occasionally, the phase angle may initially be misread by the encoder resulting in the output changing in a direction opposite the direction desired. Continued operation will allow proper adjustment of the controller. (ER2000-1448-01)

OP 21 10 Rev. 35 Page 11 of 45

20. Limit reactor vessel pressure/temperature to the right of the curves on Tech. Spec. Figure 3.6.2 or Figure 3.6.3.

a. The following temperature indications may be used when identifying the area to the right of the curves on Tech. Spec. Figures 3.6.2 and 3.6.3:

e For Bottom Fluid Temperature utilize Vessel Bottom Head Drain Temp on the PLC 2-166, RPV/SV/RV screen on CRP 9-21 or ERFIS pt. S026.

e For Bottom Head Surface Temperature utilize Vessel Bottom Head on the PLC 2-166, RPV/SV/RV screen on CRP 9-21 or ERFIS pt. S028.

e For Downcomer Region Fluid Temperature:

e If recirculation loop(s) is in operation utilize Recirc Loop Temp on TR-2-165 CRP 9-4 or e If RCU is in service utilize RWCU Inlet Temperature (B023) or e If RCU is in service and RWCU inlet temperature is not available, utilize Vessel Bottom Drain Temp on the PLC 2-166, RPV/SV/RV screen on CRP 9-21 or ERFIS pt. S026.

e For Flange Region Outside Surface Temperature utilize Rx Vessel Temp Flange on TR-2-3-90 on CRP 9-4 or Vessel Head Flange Temperature on the PLC 2-166 RPV/SV/RV screen on CRP 9-21 or ERFIS pt. S024.

b. The following pressure indications may be used when identifying the area to the right of the curves on Tech. Spec. Figures 3.6.2 and 3.6.3.

e Reactor Pressure-Widemarrow Range on PR-6-96 on CRP 9-5 e Reactor Pressure (B025) e Reactor Pressure 56B on LWR-2-3-68B on CRP 9-3 (B048) e Reactor Pressure 56A on LlUPR-2-3-68A on CRP 9-4 (B049)

21. Normal Starting

a. With the windings at ambient temperature, the motor can be started and brought to speed two times in succession.

b. With the windings at rated temperature, the motor can be started and brought to speed once.

22. Additional Starts

a. Whenever the motor windings are at rated temperature or below, the motor can be started and brought to speed. In the absence of thermal devices that indicate winding temperature, the following rule can be used: The motor windings can be assumed to have returned to rated temperature after 45 minutes de-energized or after 15 minutes running at rated speed.

OP 21 10 Rev. 35 Page 12 of 45

23. During normal operation, MG set speeds are required to be within 5% of each other. This limit does not apply to single loop operations. (INF 95-16)

24. For single loop operation, do not exceed pump motor current of 333 amps, drive motor current of 450 amps, or 70% speed.

25. When the stability monitor is unavailable, the Exclusion Region of the Core Operating Limits Report Figure 2.4- 1, will be expanded by an additional 5% Power/Flow Buffer Region. (BVY94-91)

26. Startup of an idle recirculation pump is prohibited when operating within the Exclusion Region of the Core Operating Report Figure 2.4-1. (NVY94084-03)

27. Limit steady state total core flow to 106.25% of rated. This corresponds to 51 Mlbm/hr.

Operations Manager permission is required to operate with total core flow >104.3%

rated. This corresponds to 50.05 M l b m h . When operating in steady state conditions, momentary fluctuations above and below the flow setpoint will occur. These fluctuations have been found acceptable.

28. When opening a manual containment isolation valve that is within the primary containment boundary as defined by PP 7006, Primary Containment Leak Rate Testing Program, when primary containment integrity is required, either enter the TS LCO (TS 3.7.A.8) or apply all of the following administrative controls:

0 Station a dedicated operator with no concurrent duties in the immediate vicinity of the valve controls to rapidly close the valve when directed by the control room.

e Establish communication with the control room that is immediately available using either Gaitronics, sound powered phones, radios, telephones or other means.

These administrative controls will ensure the manual containment isolation valve can be rapidly closed when primary containment isolation is required during accident conditions (NVY99004-02).

PREREQUBITES

1. 4 KV Buses 1 and 2 energized.

2. 480 V Buses 6A and 7A energized.

3. Reactor Building Closed Cooling Water system in operation.

4. Instrumentation calibrated and in operation.

5. 125 VAC and DC-2A power available.

6. Lockout relay reset.

OP 21 10 Rev. 35 Page 13 of 45

7. Auxiliary lockout relay reset.

8. MG set area ventilation system in operation.

9. Appendix A valve lineup complete.

10. Service water to recirculation unit MG lube oil coolers available.

11. 480V MCC 89A and 89B energized.

12. Lube oil temperature -100°F.

13. Scoop Tube reset.

14. ECCS/RPT 24 VDC power available.

15. RPT logic reset.

16. Ensure the reactor is shutdown and will remain shutdown prior to starting an idle recirculation pump when in the natural circulation mode.

17. If venting recirculation pump seals, a temporary hose free of debris, foreign material and chemical residue and rated for at least 150 psig is available to connect from DW system (elev. 252') to CRD 41 1A(B) (Torus area).

18. Deleted.

19. Scoop Tube Positioner Local Control Switch for MG AE3 positioned to ON.

OP 21 10 Rev. 35 Page 14 of 45 LPC #3

b. If the temperature difference of fluid in bottom head and saturation temperature corresponding to vessel steam pressure becomes greater than 145"F, core flow cannot be increased until this temperature is brought within limits by one or more of the following methods:

1) Decrease CRD cooling water flow.

2) Increase bottom drain flow by throttling reactor outlet, CU-46 and verify vessel head supply to CUW CU-99 open.

3) Shut down and depressurize to lower bulk saturation temperature.

c. When conditions permit, open reactor outlet CU-46 fully if throttled in above step.

H. Reset of Scoop Tube Lockup (UND94034-03 and LER9409-03)

1. If 2- 184-32A(B) MG A(B) DEM/POS at CRP 9-4 is unavailable or off-scale, proceed as follows, otherwise continue at step 2.

a. If the scoop tube was manually locked, on CRP 9-18, place the "A(B)

SCOOP TUBE ACTUATOR MANUAL LOCKOUT SW-2-184-2A(B)L to NORMAL and push in the switch.

b. If the affected pump's PUMP A(B) CONTROLLER 2-184-16A(B) is not in MANUAL, depress the A/M pushbutton. Ensure MAN red LED is lit.

c. On PUMP A(B) CONTROLLER 2-184-16A(B), verify or select the MG-A(B).P display as indicated on the second display.

d. Locally at Scoop Tube Positioner A(B), open the AmplifierRelay Panel door.

e. Locally at Scoop Tube Positioner A(B) in the Amplifier/Relay Panel, observe the values of CMD (command) and POS (position) on the display.

f. Adjust the CMD value to match the POS value using PUMP A(B)

CONTROLLER 2-1 84- 16A(B) to vary the CMD value.

g. When the CMD and POS values are matched, depress the A(B) SCOOP TUBE LOCKUP RESET pushbutton.

h. Observe that MG SET A(B) SCP TUBE LOCK, 4-B-1(4-F-l) alarm clears.

i. If recovering from Local Manual Control of Scoop Tube Positioner, adjust PUMP A(B) CONTROLLER 2-184- 16A(B) output slightly to re-engage the scoop tube positioner actuator.

OP 21 10 Rev. 35 Page 38 of 45

j. Adjust PUMP A(B) CONTROLLER 2- 184-16A(B) output to achieve the desired recirc pump speed.

k. Locally at Scoop Tube Positioner A(B), verify closed or close the Amplifier/Relay Panel door.

1. Continue at step 11.

2. At CRP 9-4 vertical section, observe the following indication on meter 2-184-32A(B), MG A(B) DEMPOS.

a. Controller DEM (Left side, green display)

b. Scoop tube positioner POS (Right side, red display)

3. If the affected pump's PUMP A(B) CONTROLLER 2- 184-16A(B) is not in manual, depress the A/M pushbutton. Ensure MAN red LED is lit.

4. Verify or select the MG-A(B).P display as indicated on the second display.

5. Adjust PUMP A(B) CONTROLLER 2-184-16A(B) as follows:

a. If no recirculation MG speed change has occurred from the time of the last CRO log readings until the time of the scoop tube lockup, adjust the PUMP A(B) CONTROLLER 2- 184-116A(B) speed demand signal to achieve the value corresponding to the last CRO log reading for 2- 184-32A(B) MG A(B) DEM/POS and proceed with step 6.

b. If a recirculation MG speed change has occurred from the time of the last CRO log readings until the time of the scoop tube lockup then:

1) Based on the last CRO log reading determine the difference in MG speed and speed demand based upon the 2-184-32A(B) MG A(B)

DEMPOS values recorded.

2) Adjust the PUMP A(B) CONTROLLER 2-184-16A(B) speed demand signal to achieve the same difference above, below or equal to the MG speed, determined from the previous step.

3) Proceed with step 6.

6. If the scoop tube was manually locked, on CRP 9-18, place the "A"(B) SCOOP TUBE ACTUATOR MANUAL LOCKOUT SW-2-184-2A(B)L to NORMAL and push in the switch.

7. Depress the A(B) SCOOP TUBE LOCKUP RESET pushbutton.

OP 2110 Rev. 35 Page 39 of 45

___ __ ~

8. Observe that MG SET A(B) SCP TUBE LOCK, 4-B-1(4-F-l) alarm clears.

NOTE A +2% change in controller output will cause scoop tube positioner re-engagement in approximately 2-3 minutes. The scoop tube positioner is re-engaged when changes in recirculation flow are observed or the POS value moves toward the DEM value as indicated on 2-184-32A(B) MG A(B) DEMPOS.

9. If recovering from Local Manual Control of Scoop Tube positioner, adjust PUMP A(B) CONTROLLER 2-184-16A(B) output +2% as plant conditions dictate to re-engage the scoop tube positioner actuator.

10. Adjust PUMP A(B) CONTROLLER 2- 184-16A(B) output to achieve the desired recirc pump speed.

11. If desired, place the MG set in master manual control as follows:

a. On PUMP A(B) CONTROLLER 2- 184-16A(B) use the display pushbutton to observe the value of the following:

a MG-A(B).P a MG-A(B).S

b. Using one or both of the following steps as plant conditions dictate, adjust the recirc speed control system so that MG-A(B).P and MG-A(B).S indicate the same value.

1) Adjust PUMP A(B) CONTROLLER 2-184-16A(B).

2) Adjust MASTER RECIRC FLOW CONTROLLER.

c. When MG-A(B).P and MG-A(B).S indicate the same value, on PUMP A(B) CONTROLLER 2- 184-16A(B) depress the A/M pushbutton.

1) On PUMP A(B) CONTROLLER 2-184-16A(B) verify the green auto LED illuminates.

d. Adjust recirc pump speed as desired.

OP 2110 Rev. 35 Page 40 of 45

JPM-20041 Rev. 4, 05/01 Page 1 of 6 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task ldentification:

Title:

Bypassing Reactor Building Non-Rad HVAC Trips

Reference:

OE 3107 Appendix AA, Rev 15 Task Number: N/A Task Performance: AO/RO/SRO __ RO/SRO X SRO Only Sequence Critical: Yes - No 2 Time Critical: Yes - No 2 Operator Performing Task:

Examiner :

Date of Evaluation:

Activity Code:

Method of Testing: Simulation - Performance Discuss __

Setting: Classroom __ Simulator Plant Performance Expected Completion Time: 1 0 minutes Evaluation Results:

Performance: PASS __ FAIL - Time Required:

Prepared by:

Date Reviewed by:

ShO LicensedKertified Reviewer Approved by: WE&

Operations Training Manager Date

J PM-2004 1 Rev. 4, 05/01 Page 2 of 6 Directions: Discuss the information given on this page with the operator being evaluated.

Allow time for him t o ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "Do you understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform the actions.

You are requested t o "talk throuqh" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions: A primary system break has occurred in the Reactor Building and the CRS has entered EOP-4 on high temperature. Reactor Building HVAC has tripped on low Reactor water level.

Initiating Cues: The Control Room Supervisor directs you to bypass RB HVAC trips and restart RB HVAC per OE 3107 Appendix AA.

Task Standards: RB HVAC trips bypassed and RB HVAC running.

Required Materials: OE 3107 Appendix AA Simulator Setup: Works with OE 3107 App F, JPM 20023F

JPM-20041 Rev. 4, 05/01 Page 3 of 6 Evaluation Performance Steps TIME START:

SAT/UNSAT Step 1: Obtain Procedure OE 3107 Appendix AA Standard: OE 3107 Appendix AA, obtained.

Interim Cue: If asked inform the operator that power is available t o RB HVAC. Operator may confirm power available at CR 9-25 SAT/UNSAT Step 2: Obtain Jumpers.

Standard: Operator obtains jumpers from the EOP tool box in the Control Room.

JPM-20041 Rev. 4, 05/01 Page 4 of 6 SAT/UNSAT *Step 3: Place Group 111 Isolation Valves to Close..

Standard: Operator places control switches that are in the open position t o close.

CRP 9-3 CRP 9-26 AC-8, DRYWELL PURGE HVAC-9, RB VENT SUPPLY AC-7A. DRYWELL VENT HVAC-10, RB VENT SUPPLY AC-GA, DRYWELL 3" VENT HVAC-12, RB VENT EXHAUST AC-20, NZMAKE-UP HVAC-11, RB VENT EXHAUST AC-10, TORUS PURGE AC-7B, TORUS VENT CRP 9-47 AC-GB, TORUS 3" VENT VG-26, CAM SUPPLY INBD AC-9, AIR PURGE SUPPLY VG-76A, CAM RETURN INBD AC-22B, DRYWELL MAKE-UP VG-23, CAM SUPPLY OUTBD SGT-6, VENT TO SBGT VG-76B, CAM RETURN OUTBD AC-23, NZPURGE SUPPLY AC-7, VENT TO RTF-5 CAD Panel "A" AC-22A, TORUS MAKE-UP NG I l A , 12A, 13A CA-38A, CTMT COMPR SUCT VG 22A. 9A CA-38B, CTMT COMPR SUCT

JPM-20041 Rev. 4, 05/01 Page 5 of 6 SATlUNSAT Step 4: Ensure the Reset Permissive Lights Are Lit.

Standard: On CRP 9-5, operator checks Group 111 Sys I and Sys 2 red Reset Permissive Lights are ON (lower right section of vertical panel).

Interim Cue: Permissive lights are lit.

SATlU NSAT *Step 5: Install Jumpers.

Standard: Operator installs the following jumpers:

- CRP 9-15: EE6 t o EE9

- CRP 9-17: BBlO t o BB11 SATlUNSAT *Step 6: Reset the PClS Logic When the Signal has CLeared.

Standard: On CRP 9-5 (upper right section of benchboard), operator positions System lsol Reset Switch t o INBD and then OUTBD.

Interim Cue: Reset switch moves t o the INBD position, OUTBD position and then returns t o normal.

SAT/UNSAT *Step 7 : Open Reactor Buildinn Ventilation Isolation Valve.

Standard: On CRP 9-26, operator places the following control switches t o OPEN:

HVAC-9 HVAC-11 HVAC- 1 0 HVAC- 12 SATlUNSAT Step 8: Verify Reactor Building Ventilation Isolation Valves are Open.

Standard: ON CRP 9-26, operator verifies red light ON and Green light OFF for each Reactor Building Ventilation Isolation Valve.

Note: Step 7 and Step 8 actions will likely be done simultaneously.

JPM-20041 Rev. 4, 05/01 Page 6 of 6 SATlUNSAT Step 9: Start Reactor Building HVAC system per OP 2192.

Standard: Direct A 0 to start RB HVAC per OP 2192.

Interim Cue: Direct booth operator to restart Reactor Building ventilation. Inform the operator that the A 0 has started RB HVAC per OP 2192 and Standby Gas Treatment will be secured by another operator.

TIME FINISH:

Terminating Cue: Appendix AA implemented, HVAC trips bypassed HVAC-9, I O , 1 1,12 OPEN, and RB HVAC started.

Evaluators Comments:

System: 295032 EA1.03 Ability to operate and/or monitor the following as they apply to HIGH SECONDARY CONTAINMENT AREA TEMPERATURE :

(CFR 41.7 / 45.6)

Secondary containment ventilation. RO 3.7 SRO 3.7 System Generic K/A's:

JPM-20041 Handout Rev. 4, 05/01 Page 1 of 1 Initial Conditions: A primary system break has occurred in the Reactor Building and the CRS has entered EOP-4 on high temperature. Reactor Building HVAC has tripped on low Reactor water level.

lnitiatinn Cues: The Control Room Supervisor directs you to bypass RB HVAC trips and restart RB HVAC per OE 31 07 Appendix AA.

APPENDIX A A BYPASSING REACTOR BUILDING NON-RAD HVAC TRIPS PURPOSE The purpose of this procedure is to bypass the automatic trip and isolation of the reactor building ventilation system and the auto start of SGTS due to PCIS Group III high drywell pressure and low RPV water level isolation signals.

REFERENCES

1. CWD Sheets 1112 and 1116

2. OP 21 17, Standby Gas Treatment

3. OP 2 192, Heating, Ventilating, and Air Conditioning System PREREQUISITES

1. Power available to reactor building ventilation system supply fans (MCC 7D or MCC 1OA) and exhaust fans (MCC 6 or MCC 10).

2. Two jumpers with banana plugs from the EOP toolbox in the Control Room.

PROCEDURE Initial 1, Place the control switches to CLOSE for the Group 3 valves listed in Appendix B.

2. Ensure the containment isolation reset permissive lights (IOPL) for Group 111are lit (CRP 9-5).

CAUTION The following step will:

e Bypass the PCIS Group 111 high drywell pressure and low RPV water level trip and isolation logic of the reactor building ventilation system.

e Defeat the auto start logic of the SBGT system trains A and B on high drywell pressure and low RPV water level.

3. INSTALL the following jumpers:

e CFW 9-15: EE6 to EE9 (CWD 1112) 0 CRP 9-17: BBlO to BBl1 (CWD 1116)

Appendix AA OE 3107 Rev. 16 Page 1 of 2

APPENDIX AA (Continued)

4. RESET the PCIS logic by placing the System Isolation reset switch on CRP 9-5 to INBD and then OUTBD.

5. START the reactor building ventilation system in accordance with OP 2192.

6. SECURE SGTS trains per OP 21 17.

Satisfactorily completed without, 0with attached exception(s).

Shift Manager: I I Name (PrinUSign) Time Date RESTORATION InitiaWeri fied

1. Verify that both a high drywell pressure and a low reactor water level condition DO NOT EXIST. I

2. Remove the following jumpers:

e CRP 9-15: EE6 to EE9 (CWD 1112) l a CRP 9-17: BBlO to BB11 (CWD 1116) I Satisfactorily completed 0without, with attached exception(s).

Shift Manager: I I Name (PrintISign) Time Date Appendix AA OE 3107 Rev. 16 Page 2 of 2

APPENDIX B (Continued) initiation Signals Group 3 8 Low Rx Water Level 2127 inches Containment Makeup (AC-20, AC-22AY 0 Hi DIW Press 12.5 psig AC-22B) 8 Hi Rad Refueling Floor I 100 mR/hr Containment Inerting (AC-23) 0 Hi Rad Rx Bldg Exh I 14 mR/hr Containment Purge (AC-8, AC-9, AC-10) 8 Low Rad Refueling Floor <1.O mWhr Containment Exhaust (SGT-6, AC-6AY (2 of 2) AC-6BYAC-7, AC-7A, AC-7B) 0 Low Rad Rx Bldg Exh <O. 1 mWhr (2 of 2) Containment Air Monitor (VG-23, VG-26, 109-76A, 109-76B)

Rx Bldg Supply and Vent (HVAC-9, HVAC-10, HVAC-11, HVAC- 12)

Containment Air Suction (CA-38A, CA-3 8B)

SBGT Start Rx Bldg Supply & Exhaust Fans OFF CAD A (NG-11A, NG-l2A, NG-13AY VG-22AYVG-9A)

CAD B (NG- 1 1B, NG- 12B, NG- 13B, VG-22BYVG-9B)

Initiation Signals Group 4 Low Rx Water Level 2127 inches RHR SD Cooling Suction (RHR-17, RHR-18)

Hi DIW Press 12.5 psig Hi Rx Press 1150 psig Initiation Signals Group 5 0 Low Rx Water Level 2127 inches RWCU System (CU-15, CU-18, CU-68) hitiation Signals Group 6 0 Mn Steam Tunnel Hi Temp 5212°F (35 HPCI Steam Supply (HPCI-15, HPCI-16) min TD) 8 RCIC Steam Supply (RCIC-15, RCIC-16) 8 Hi Steam Space Temp 5212°F 0 Hi Flow S300% (RCIC 5 sec TD) 0 HPCI Low Steam Press 270 psig 0 RCIC Low Steam Press 250 psig Appendix B OE 3107 Rev. 16 Page 2 of 2

JPM 26209 Rev. 1,05/01 Page 1 of 5 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Transfer MCC-89A Power From The Maintenance Tie To RUPS Failure Mode: N/A

Reference:

OP 2 143,480 And Lower Voltage AC System ('ExceDt Vital, Inst. AC, And Lighting Panels), Rev 42 Task Number: 2627320101 Task Performance: AO/RO/SRO - RO/SRO X SRO Only Sequence Critical: Yes X No -

Time Critical: Yes- N o 3 Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation - Performance 2Discuss -

Setting: Classroom - Simulator Plant Performance Expected Completion Time: 10 minutes Evaluation Results:

Performance: PASS - FAIL - Time Required:

+

Prepared by:

Date Reviewed by:

Approved by: &&- Date

JPM 26209 Rev. 1,05/01 Page 2 of 5 Directions: Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "DOyou understand the task?"

Read to the person being: evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform the actions.

You are requested to "talk throurrh" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

MCC-89A is powered from the maintenance tie.

Initiating Cues:

The CRS directs you to transfer MCC-89A power from the maintenance tie to RUPS and startup UPS 1A IAW OP 2143 Section K.

Task Standards:

Transfer of MCC-89 power from the maintenance tie to the RUPS is complete.

Required Materials:

OP 2143 Simulator Setur>:

Any IC, MCC-89A, powered from maintenance tie. Check following IDAs:

Place MCC 89A on Main Tie Shutdown UPS EDR 05 CLOSE EDR 07 CLOSE EDR 10 OPEN EDR 11 OPEN

JPM 26209 Rev. 1,05/01 Page 3 of 5 Evaluation Performance Steps TIME START:

SATNNSAT Step 1: Obtain Procedure OP 2143, review Admin Limits and Precautions.

Standard: OP 2143 obtained, admin limits and precautions reviewed.

SATNNSAT *Step 2: At MCC-89A open the FEED From MCC 9B maintenance tie breaker.

Standard: Operator directs an A 0 to open feed from MCC 9B maintenance tie breaker.

Interim Cue: Maintenance Tie breaker at MCC-89A is open (EDR 07 OPEN)

SATNNSAT Step 3: Lock closed control cabinet door.

Standard: Operator directs an A 0 to shut control cabinet door and lock door for feed from MCC 9B.

Interim Cue: MCC-89A control cabinet is shut and locked.

SAT/UNSAT *Step 4: At MCC-89A close the feed from UPS-1A output tie breaker.

Standard: Operator directs an A 0 to position UPS-1A feed switch at MCC-89A to CLOSED

~~~ ~~ ~

Interim Cue: The feed from UPS-1A output tie breaker at MCC-89A is closed. (EDR11 CLOSE)

Note: Completion of task will require transition to Procedure Steps D3 and D4. JPM Steps 2 and 3 were previously completed.

SATPUNSAT Step 5: Position UPS A control switch on CRP 9-3 to OFF for amroximatelv one second then release it.

Standard: Operator positions UPS A control switch to OFF for approximately one second then releases it on CRP 9-3.

JPM 26209 Rev. 1,05/01 Page 4 of 5 Evaluation Performance Steps SATIUNSAT Step 6: If ECCS signal is present, position the UPS feeder trip keylock switch on CRP 9-32 to BLOCK.

Standard: Operator verifies an ECCS signal is NOT PRESENT. No action required.

SATNNSAT *Step 7: At Bus-9 close the UPS-1A supply breaker.

Standard: Operator directs an A 0 at Bus-9 to position the UPS-1A supply breaker hand switch to CLOSE.

Interim Cue: UPS-1A supply breaker is shut (EDR10 CLOSE)

SATIUNSAT Step 8: Verifv UPS 1A local control cabinet breakers closed.

Standard: Operator directs A 0 to verify the following breakers closed on UPS 1A control cabinet:

- Input AC Circuit Breaker

- Output AC Circuit Breaker

- DC Circuit Breaker Interim Cue: All local control cabinet breakers are closed.

SATNNSAT *Step 9: Position UPS-1A control selector switch on CRP 9-3 to ON for approximately one second and then release it.

Standard: Operator positions UPS A control switch to ON for approximately one second and then releases it on CRP 9-3.

Interim Cue: If asked, CRS directs the C W 9-3 switch be used.

JPM 26209 Rev. 1,05/01 Page 5 of 5 Evaluation Performance Steps SAT/UNSAT Step 10: Monitor UPS for unusual conditions, such as excessive noise or vibration, as it starts and comes up to speed.

Standard: Operator directs an A 0 to monitor UPS for unusual conditions as it starts and comes up to speed.

Interim Cue: Inform operator that UPS is running SAT.

SATKJNSAT Step 11: Verify MCC-89A bus voltage 435 to 506 VAC from CRP 9-3.

Standard: Operator verifies MCC-89A bus voltage is approximately 480 VAC by observing MCC-89A volt meter on CRP 9-3.

SATKJNSAT Step 12: Once UPS MG is up to speed and producing rated voltage, locally press the FAILURE RESET pushbutton on the UPS control panel to reset the TFR relay and clear all remaining alarm conditions.

Standard: Operator directs A 0 to press FAILURE RESET pushbutton on local UPS control panel.

TIME FINISH:

Terminating Cue: Transfer of MCC-89 power from the maintenance tie to the RUPS is complete.

Evaluators Comments:

~~

System: 2622002 WA's: A4.01 Ability to manually operate and/or monitor in the control room:

(CFR: 41.7 / 45.5 to 45.8)

Transfer from alternative source to preferred source RO 2.8 SRO 3.1

JPM 26209 Handout Rev. 1,05/01 Page 1 of 1 Student Handout Initial Conditions:

MCC-89A is powered from the maintenance tie.

Initiating Cues:

The CRS directs you to transfer MCC-89A power from the maintenance tie to RUPS and startup UPS 1A IAW OP 2143 Section K.

VERMONT YANKEE NUCLEAR POWER STATION OPERATING PROCEDURE OP 2143 REVISION 44 480 AND LOWER VOLTAGE AC SYSTEM (EXCEPT VITAL, INST. AC, AND LIGHTING PANELS)

USE CLASSIFICATION: REFERENCE I 1 LPC No.

1 Effective Date 1 10/18/02 App. A Pgs 47 & 53 of 55 Affected Pages 2 11/13/02 App. A Pgs 38,39 & 41 of 55 3 12/10/02 App. D Pg 18 of 21 4 01/08/03 8.10 & 12 of 35 5 02/10/03 App A Pg 48 of 55 6 07/08/03 App D Pgs 7 through 21 of 21 Implementation Statement: N/A 1 Issue Date: 10/04/02 OP 2143 Rev. 44 Page 1 of 35

~ ~___

TABLE OF CONTENTS PURPOSE .......................................................................................................................................................... 3 DISCUSSION .................................................................................................................................................... 3 ATTACHMENTS ............................................................................................................................................. 5 REFERENCES AND COMMITMENTS......................................................................................................... 5 PRECAUTIONS/LIMITATIONS ..................................................................................................................... 7 PREREQUISITES ............................................................................................................................................. 9 PROCEDURE.................................................................................................................................................. 10 A. Raclung Out 480 Volt Switchgear Breakers .......................................................................... 10 B. Racking In 480 Volt Switchgear Breakers ............................................................................. 10 C. Normal Energization of 480 VAC Buses and MCCs ............................................................ 13 D. Startup of UPS lA(1B) Units ................................................................................................. 13 E. Shutdown of UPS lA(1B) Units ............................................................................................ 14 F. U P S Operation Upon ECCS Initiation ................................................................................... 14 G. UPS Operation Following ECCS Initiation ........................................................................... 15 H. UPS Transfer to DC Drive...................................................................................................... 15 I. Trip/Shutdown ofUPS ........................................................................................................... 16 J. Transferring MCC-89A(B) Power from UPS to the Maintenance Tie ................................. 16 K. Transferring MCC-89A(B) Power from the Maintenance Tie to U P S Output Breaker Tie to MCC-89A(B).................................................................................................. 17 L. Energizing 480 Volt Bus 7 from Bus 6 .................................................................................. 17 M. Energizing 480 Volt Bus 6 from Bus 7 .................................................................................. 18 N. Energizing 480 VAC Bus 9 from Bus 8 ................................................................................. 19

0. Energizing 480 VAC Bus 8 from Bus 9 ................................................................................. 23 P. Transferring AC-DP-4 Supply Power Between Normal and Alternate Sources...................27 Q. Energizing AC-DP-D 1A from the John Deere Diesel Generator .......................................... 27 R. Restoration of Supplying Bus 9 From Bus 8.......................................................................... 28 S. Restoration of Supplying Bus 8 From Bus 9 .......................................................................... 32 FINAL CONDITIONS .................................................................................................................................... 35 OP 2143 Rev. 44 Page 2 of 35

PURPOSE To provide the information necessary for Operations Department personnel to operate 480 Volt and Lower Voltage AC System, (except Vital, Inst. AC and Lighting Panels).

Instructions for operation of the Unintermptable Power Supply (UPS) system are included.

DISCUSSION The breaker lineup sheets are used to check the status of the 480 volt and lower voltage AC systems (except Vital, Inst. AC and lighting panels) per AP 0155.

The rotating UPS system consists of a battery bank, an AC motor and generator, and a DC machine which can operate as either a motor or generator (battery charger). Controls, alarms and indications necessary for system operation are located on CRP 9-3.

Alternate power (power other than UPS), used to power MCC-89A(B) whenever the respective UPS is found or made inoperable, is supplied to MCC-89A(B) from MCC-9B(8B).

If a loss of U P S occurs and the reactor building becomes inaccessible, control switches on C W 9-3 allow for tripping UPS A(B) output breakers on MCC-89A(B) and closing the maintenance tie breakers on MCC-89A(B), thus supplying power to MCC-89A from MCC-9B and MCC-89B from MCC-8B.

The feed from U P S breakers on MCC-89A(B) and the maintenance tie breakers on MCC-89A(B) are electrically interlocked so that the maintenance tie breakers cannot be shut remotely until the UPS feeder breaker is in the OPEN position. This prevents the possibility of remotely paralleling two AC sources out of phase. There are no interlocks which will prevent an operator from closing both the local U P S and maintenance tie breakers manually at MCC-89A(B), therefore extreme caution must be exercised when manually operating the feed and tie breakers at MCC-89A(B).

All local UPS controls and indications are located on the UPS control panels. The local indications serve to identify the precise nature of any alarms or cause of shutdowns and other data for maintenance. Some alarm conditions which shut down the UPS units also prevent re-energization until their indication as well as the cause are removed. Failure reset pushbuttons on the UPS control panels are provided for this purpose.

Tie breakers, (i.e.: 8T9, 9T8, and 6T7) and main bus feeder breakers (i.e.: 66, 77, 88, 99, 1010, and 1111) are AK-50/AK-75 1600/3000 amp 480V breakers. These breakers differ from the other 480V breakers that are AK-25 600 amp 480V breakers. The AK-50 and AK-75 breakers are equipped with spring charging motors that will charge when the breaker is racked in.

Discharging the springs before racking in these breakers verifies operability of the spring charging motors when the breakers are returned to service. The AK-25 breakers have light indication only of breaker position when racked in. (SOER 82-16)

OP 2 143 Rev. 44 Page 3 of 35

The following table provides a list of breaker styles and sizes.

BREAKER STYLE SIZE

~~

8T9,77 AK-50 1600 amp 9T8,88 6T7,99 66 1010 AK-75 3000 amp 1111 All Other 480V AK-25 600 amp Breakers To close the Bus 8 normal supply BKR 88, its cross-tie BKR 8T9 must be open.

To close the Bus 8 cross-tie, BKR 8T9 EITHER its normal supply, BKR 88 or the normal supply breaker on Bus 9, BKR 99 must be open.

To close the Bus 9 normal supply BKR 99, its cross-tie BKR 9T8 must be open.

To close the Bus 9 cross-tie BKR 9T8, EITHER its normal supply BKR 99 or the normal supply breaker on Bus 8, BKR 88 must be open.

See CWDs: 338,340,341 and 343.

To close the Bus 6(7) normal supply BKR 66(77), the cross-tie BKR 6T7 must be open.

To close the Bus 6 to Bus 7 cross-tie 6T7, EITHER the Bus 6 normal supply BKR 66 OR the Bus 7 normal supply breaker BKR 77 must be open.

See CWDs: 336,337 and 344.

If one of these breakers is racked out the breaker logic will not know its position and will assume it is closed, preventing others from closing, per the above interlocks.

To close one of these breakers with one racked out, the racked out breaker must first be verified open and racked to either the IN or the TEST positions. The breaker logic will then know the breaker is open and allow the others to close.

Appendix ByEnergizing 480 V Bus 9 (Dead Bus) from Bus 8, is intended to be used as an operator aid at CRP 9-8 to provide a check for major actions to crosstie bus 9 from bus 8.

Appendix B only provides immediate actions, immediate verifications and required steps to safely perform this evolution. A review of all actions required by procedure Section N to validate all actions is required at the first available opportunity.

OP 2143 Rev. 44 Page 4 of 35

Appendix C, Energizing 480 V Bus 8 (Dead Bus) from Bus 9, is intended to be used as an operator aid at CRP 9-8 to provide a check for major actions to crosstie bus 8 from bus 9.

Appendix C only provides immediate actions, immediate verifications and required steps to safely perform this evolution. A review of all actions required by procedure Section 0 to validate all actions is required at the first available opportunity.

ATTACHMENTS

1. Table 1 Breaker Lineup Index

2. Appendix A Powerblock Breaker Lineup

3. Appendix B Energizing 480 V Bus 9 (Dead Bus) from Bus 8

4. Appendix C Energizing 480 V Bus 8 (Dead Bus) from Bus 9

5. Appendix D Non-Powerblock Breaker Lineup REFERENCES AND COMMITMENTS

1. Technical Specifications and Site Documents

a. TS Sections 3.5.A, 4.5.A, 3.10,4.10

b. Technical Requirements Manual - None C. UFSAR 8.1 and 8.4

d. VOQAM-None

e. ODCM Sections 3/4.1.2, 314.6

2. Codes, Standards, and Regulations

a. None

3. Commitments

a. LER 9512-02, Stack Radiation Sampling Out of Service Due to Power Interruption, Rev. 1, Perform Assessment of Admin. Controls For Bus De-energization To Ensure Tech. Spec. Requirements

b. ER960820-02, Failure to Notify Chemistry of Loss of Stack Flow Indication

c. ER981120-04, Revise OP 2143 to Add a Note to Any Power Supply that when either Removed or Restored, may Directly Cause a PCIS Isolation

4. Supplemental References

a. DWG G-l91303,48OV

b. DWG G-l91304,48OV C. DWG G-l91370,48OV

d. DWG G-19137lY480V,Essential AC

e. DWG G-l91398,48OV

f. DWG G-l91409,48OVAC and 125VDC

g. DWG G-191352, Lighting Dist.

h. DWG VY-E-40-001

1. DWG G-191341, AUX480V OP 2 143 Rev. 44 Page 5 of 35

j. CWD 364,370 UPS

k. CWD 1248 Elementary DWG

1. CWD Motor Data Sheet Book (for Dist. Panel ckts.)

m. Kato Engineering Pub. No. 352-25000-01, dated July 1990

n. YAEC Report 1205, dated March 17,1980

0. VYC-1688, Transient Voltage on 480 Volt Power System P. SOER 82-16

4. EDCR 75-1

r. EDCR 73-3 1 S. EDCR 86-413 (RCIC-15)

t. Memo, J.W. Durborow to PORC, dated June 21, 1991 with att.

U. Memo, P.B. Corbett to R.P. Lopriore, "UPS Installation Information and Documentation Turnover", dated October 23, 1990 V. Vermont Yankee Safety Manual, Safety Standard 302, Electrical Safety W. One For One Number 93-183, Use of Electrically Operated AK-25 Breakers, 12/8/93 X. ER98-0301, Bus 819 Crosstie Does Not Load Shed During an LNP Y* ER98-0131, Online Recombiner Shift to Standby Z. Tech. Spec. Amendment No. 193, RETS aa. ER200 1- 1391, Two Different Styles of 1600 Amp Breakers Are Being Used Interchangeably Without Proper Labeling bb. Letter From GE Nuclear Energy, PDS-00-0 1, Manual Operation of GE Type AK and AKR Circuit Breakers cc. UND-2001-099-04, Change OP 2143 to Include Steps to Align the Plant for an Anticipated Group 3 Isolation dd. AP 0155, Current System Valve and Breaker Lineup and Identification ee. OP 2124, Residual Heat Removal System ff. OP 2 127, John Deere Diesel Generator System 35 OP 2 134, Reactor Protection System hh.

.. OP 2148, ERFIS UPS 2A

11. OP 2190, Service and Instrument Air

.. OP 2192, Heating, Ventilating and Air Conditioning System JJ kk. OT 3 122, Loss of Normal Power

11. OP 4800, General Safety Surveillance 111111. AP 6807, Collection, Temporary Storage and Retrieval of Quality Assurance Records OP 2143 Rev. 44 Page 6 of 35

PRECAUTIONS/LIMITATlONS

1. Precautions

a. After operation of any breaker, observe indication lights to verify proper operation and check voltage on all three phases where possible.

b. Prior to de-energizing source of power to any lighting panel, (refer to VYOPF 4800.07 for a list of Appendix R lights). Evaluate if Appendix R lights will be affected and provide compensatory lighting to affected area if required unless power can be readily restored. (LER9512-02)

c. Prior to de-energizing source of power to any lighting panel that is powered from safety related bus, verify if any safety related equipment is affected and evaluate if any limiting conditions may pertain. Refer to Lighting Panel Arrangements A 191352 for lighting panels and their power supplies. Upon restoration of power verify that power is restored to the affected safety related equipment.

(LER95 12-02)

d. Do not close the maintenance tie breakers to MCC-89A and 89B unless the respective UPS tie breaker is checked open first (under no circumstances should the U P S unit be paralleled to the maintenance feeder).

e. The use of the alternate power supply (maintenance feeder breaker) provides a means to keep the affected LPCI subsystem in service in the event of the loss of UPS. The use of the maintenance tie, however, does not alter the present Tech.

Specs. requirement of the UPS and LPCI (Le., and LPCI subsystem associated with a failed U P S unit must be considered inoperable even though maintenance tie is in use).

f. The length of time a bus tie breaker (6T7,8T9,9T8, 66,88,99) is removed from service should be minimized since this condition prevents the reclosure of the normal feeder breaker following an LNP condition. These breakers are identified with the following message:

"Removal or testing of this breaker defeats 480V bus interlocks

See the discussion section for an explanation of the above interlocks.

g. Prior to planned cycling of feeder breakers to office areas, inform office personnel of power interruption to minimize computer power outage impact.

h. Exercise due caution when working near energized equipment to prevent contact with high voltage.

1. Personnel protective equipment required by Safety Standard 302 of the VY Safety Manual shall be worn when racking in and out breakers.

OP 2 143 Rev. 44 Page 7 of 35

.i. If a 480 volt MCC molded case breaker trips due to any condition other than thermal overload, do not attempt to reclose it until cleared by Maintenance Dept.,

unless the equipment is urgently needed due to an emergency condition affecting plant safety. If emergency reclosure is required, a face shield, electrical gloves and Nomex coat should be worn.

k. Optimum DC machine performance for the U P S units is achieved after the fixed field and control fields are warmed up. If the UPS units are removed from service for extended periods (machine allowed to cool off to ambient), it is recommended that a 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months warm up to be allowed prior to declaring operational. (Memo, P.B.

Corbett to R.P. Lopriore.)

1. The main turbine auxiliary oil pump does not load shed upon loss of power.

Restoring power to Bus 6 could cause a MHC system control transient if the main turbine auxiliary oil pump is repowered and auto starts.

m. When transferring power supplies from MCC-11C to MCC-IOC, ATS-IP-1 momentarily deenergizes. The deenergization of this transfer switch may cause the on line AOG recombiner to swap from OPERATE to STANDBY. To prevent the unwanted recombiner swap, place the affected recombiner to MANUAL prior to transferring power supplies. (ER 98013 1)

n. When operating a manually operated AK-25 480V breaker, use the pistol grip handle only to reset and close the breaker. To trip the breaker use the Trip push button. (ER 98226)

0. When operating the Admin office building breaker (BUS-11-4C) if can only be closed using the close push button on the front of the breaker.

p. It is important to verify after racking a 480 volt breaker full in (CONNECT), out (DISCONNECT) or TEST that the sliding sleeve jaw slides forward (toward you) and engages the pin.

2. Administrative Limits

a. A U P S unit will not be shut down for any reason except for DC motodgenerator brush maintenance, component failure or recovery from ECCS operation whenever the LPCI system is required to be operable when the reactor is critical.

b. The maintenance tie breaker covers on MCC-89A(B) shall be locked at all times except when manually transferring power from the maintenance tie breaker back to UPS.

c, If the reactor building is accessible, the feed from U P S output breaker on MCC-89A(B) must be locked open when the maintenance tie breaker on MCC-89A(B) is closed.

d. To be considered operable, 480 volt bus voltage must be greater than 435 volts and less than 506 volts (YAEC Report 1205, dated March 17,1980 and VYC-1688, Transient Voltage on 480 Volt Power System).

OP 2 143 Rev. 44 Page 8 of 35 LPC #4

e. Prior to planned power loss to MCC-gA, SWGR-11 or opening the breakers on these buses that are labeled as supplying security power, inform I/C and Security Department.

f. If a breaker trips from other than thermal overload, do not attempt to reclose it until cleared by Maintenance Department, unless the equipment is urgently needed due to an emergency condition affecting plant safety.

g. Tie breakers 8T9 and 9T8 are not load shed by the diesel generator LNP circuitry.

The EDG loading analysis does not account for the loading of the alternate 480 V bus for the first ten minutes if an LNP were to occur with buses 8 and 9 cross-tied.

This additional load could exceed the rated capacity of the diesel generator and thus it is declared inoperable. The EDG without its normal 480 volt bus would be inoperable per the Tech. Spec. definition of Operability. Also, each of the 480V buses would be inoperable due to each EDG being inoperable. Therefore if for any reason, buses 8 and 9 are cross-tied, enter a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months cold shutdown LCO (TS 3.5.H.1). (ER 98-0301).

PREREQUISITES

1. None OP 2 143 Rev. 44 Page 9 of 35

K. Transferring MCC-89A(B) Power from the Maintenance Tie to UPS Output Breaker Tie to MCC-89A(B)

NOTE Reactor building must be accessible.

I. At MCC-89A(B) open the FEED FROM MCC 9B(8B) maintenance tie breaker and lock closed its control cabinet.

2. At MCC-89A(B) close the feed from UPS-lA(1B) output tie breaker.

3. Proceed to the Startup of UPS-lA(1B) Units section as necessary.

L. Energizing 480 Volt Bus 7 from Bus 6

1. Ensure that Bus 6 is energized.

2. As appropriate for plant conditions, perform the following if the transfer is pre-planned:

a. Notify maintenance office, security office, and Aquatec Building personnel of power interruption to computers.

b. Secure "C" station air compressor per OP 2190 Section B if running.

c. Notify Maintenance of temporary power interruption to Reactor Building Crane (MCC-7A) if in use.

d. Refer to Appendix A to secure non-essential loads and shift redundant equipment to minimize loads on Bus 7, MCC-7A7MCC-7BYMCC-7C7 MCC-7D, and MCC-7F.

1) Place 'A' side of Turbine Building and Reactor Building HVAC systems in service.

2) Place Turbine Exhaust Fan TEF-6 in service; secure Turbine Exhaust Fan TEF-7.

3) Verify/place Reactor Cleanup Pump P 1B in service per OP 21 12.

4) Verify/secure Reactor Cleanup Letdown Flowpath.

5) Verify/place Stator Cooling Pump P-75-1A in service per RP-2162 Sect. B.

OP 2143 Rev. 44 Page 17 of 35

C. Normal Energization of 480 VAC Buses and MCCs

1. Observe the applicable voltmeter on CRP 9-8 ,3 ensure that the respective 4KV Buses are energized.

2. Close the applicable power supply breaker on CRP 9-8 to energize the respective station service transformer.

3. Close the applicable station service transformer output breaker from CRP 9-8.

4. Observe voltmeter indication 435 - 506 VAC.

5. Close the power supply breakers to the MCCs at the appropriate bus.

D. Startup of U P S lA(1B) Units

1. Position UPS lA(1B) CONTROL SELECTOR keylock switch on CRP 9-3 to OFF for about one second then release it.

2. If an ECCS signal is present, position the UPS FDR TRIP, 10A-S36A(B)keylock switch on CRP 9-32(33) to BLOCK.

3. At Bus-9(8) close the UPS lA(1B) supply breaker.

4. At MCC-89A(B) check OPEN the maintenance tie breaker and lock closed its control cabinet.

5. At MCC-89A(B) CLOSE the FEED FROM UPS-lA(1B) output breaker.

6. At UPS lA(1B) local control cabinet, verify the following breakers closed:

a. Input AC Circuit Breaker b, Output AC Circuit Breaker C. DC Circuit Breaker NOTE With Shift Manager approval, the STOP/START buttons on UPS control panels may be used in lieu of the UPS control on CRP 9-3.

7. Position UPS lA(1B) CONTROL SELECTOR keylock switch on CRP 9-3 to ON for about one second then release it.

OP 2 143 Rev. 44 Page 13 of 35

~

8. Monitor the UPS as it starts and comes up to speed for unusual conditions, such as excessive noise or vibration.

9. Verify MCC-SBA(B) bus voltage 435 to 506 VAC from CRP 9-3.

10. Once the MG is up to rated speed and is producing rated voltage, locally press the FAILURE RESET pushbutton on the UPS control panel to:

a. Reset the TFR relay.

b. Clear all remaining alarm conditions.

E. Shutdown of UPS lA(1B) Units

1. Position UPS 1A( 1B) CONTROL SELECTOR keylock switch on CRP 9-3 to OFF for about one second then release it.

2. On CRP 9-3, note that MCC-89A(B) voltage is zero.

F. UPS Operation Upon ECCS Initiation NOTES The UPS feeder breakers on Buses 8 and 9 open automatically and the UPS batteries supply power for ECCS valve operation.

Power to open RHR-27A and 27B is delayed for 2 seconds to prevent overloading the UPS units.

Five minutes after ECCS initiates, RHR-27A(B) can be throttled to control the desired reactor water level, providing the UPS FDR TRIP, lOA-S36A(B) keylock switch on CRP 9-32(33) is positioned to BLOCK.

1. Monitor local UPS indications and alarms for proper operation as time and conditions permit:

a. DC MOTOR DRIVE light ON.

b. AC INPUT FAILURE light ON

c. AC GENERATOR light ON.

d. All other indicatiodalann lights OFF.

OP 2143 Rev. 44 Page 14 of 35

JPM- 20901F Rev. 0,06/01 Page 1 of 5 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Perform Core Spray "A" Ouarterly Full Flow Test Failure Mode: Minimum Flow Valve Fails Shut

Reference:

OP 4123, Core Spray System Surveillance, Rev. 34 Task Number: 2090010201 Task Performance: AO/RO/SRO __ RO/SRO Only X SE Only -

Sequence Critical: Yes - No .J Time Critical: Yes - No 2 Individual Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation __ Performance X Discuss -

Setting: Classroom - Simulator X Plant __

Performance Expected Completion Time: 24 minutes Evaluation Results:

Performance: PASS - FAIL - Time Required:

Prepared by:

Date Reviewed by: -

SRO dicensedlcertified Reviewer Date Approved by: M& 42%??5 Gerations Training Superintendent Date

JPM-20901F Rev. 0,06/01 Page 2 of 5 Directions:

Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the individual has failed the Job Performance Measwe.

After providing the initiating cue, ask the individual "DOyou understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform the actions.

You are requested to "talk-through" the procedure, stating the parameters you are verifLing or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

The plant is operating at power during normal operations.

Initiating Cues:

You have been directed by the CRS to perform the Core Spray Quarterly Full Flow Test on the "A" Core Spray Pump.

Task Standards:

"A"Core Spray Quarterly Full Flow Test performed satisfactorily.

Required Materials:

OP 4123, Core Spray System Surveillance (latest revision)

Form VYOPF 4123.01 (latest revision) with Steps 1 & 2 data filled in Simulator Setup:

0 Any at power IC 0 Run Event Trigger CS JPM ET, CS JPM SCN. This event trigger will cause the Minimum Flow Valve (CS-SA) to stroke shut once the Core Spray "A" control switch is taken to START.

Ensure Reactor feed pumps A & C are running

JPM- 20901F Rev. 0,06/01 Page 3 of 5 Evaluation Performance Steps TIME START:

SATKJNSAT Step 1: Obtain Procedure, review administrative limits, precautions and pre-requisites Standard: OP 4123 Section A obtained, administrative limits, precautions, and prerequisites reviewed Interim Cue: If asked, inform operator that prerequisites are done.

SAT/UNSAT Step 2: Notify RP of test gauge installation and core sprav full flow test.

Standard: RP notified SATKJNSAT Step 3: Install safetv class temporary test gauges on A Core Smav suction and discharge piping, fill and vent the svstem, system walkdown and dedicated operator for PCIS valves IAW Step C.2.

Standard: Operator directs that temporary test gauges be installed and verified IAW procedure Step C.2.

Interim Cue: Inform Operator that Step C.2 is completed and:

VY-1 Suction Pressure Test Gauge VY-2 Discharge Pressure Test Gauge The "A" Core Spray System is filled and vented The "A" Core Spray piping and component inspection is complete A dedicated operator is stationed for CS-806A and CS-807A SATKJNSAT Step 4: Prompt CRS to declare Core Sprav Subsystem "A" inoperable, and to enter either LCO 3.5.A.2 or 3.5.A.6 Standard: Operator prompts CRS to declare Core Spray "A" inop, and to enter 3.5.A.2 Interim Cue: As CRS, acknowledge prompt to declare Core Spray "A" inop and to enter 3.5.A.2.

JPM- 20901F Rev. 0,06/01 Page 4 of 5 SATIUNSAT *Step 5: Start Core Spray Pump "A" Standard: Operator places Core Spray Pump "A" hand switch to START on CRP 9-3 horizontal panel, and observes red light On, green light Off above pump start switch.

SATIUNSAT Step 6: Verify Core Spray Pump "A" running Standard: Operator identifies Red light On, Green light Off above Core Spray Pump "A" control switch.

SATIUNSAT Step 7: Verify Minimum Flow Valve CS-SA remains open Standard: Operator identifies CS-SA stroked shut on pump start and reports to CRS.

Interim Cue: If informed as the CRS that the CS-SA valve has failed shut, acknowledge the report.

SATIUNSAT

Step 8: Secure Core Spray Pump A.

Standard: Operator secures pump by taking Core Spray "A" hand switch to STOP.

If the operator has not secured the pump and checks RRU operation, this step in UNSAT.

SATJUNSAT Step 9: Verify Core Spray Pump "A" secured.

Standard: Operator verifies pump secured by observation of green light ON, red light OFF, on CRP 9-3 and/or zero pump amps.

JPM- 20901F Rev. 0,06/01 Page 5 of 5 TIME FINISH:

Terminating Cue: "A"Core Spray Pump secured after starting once it is noted that the Minimum Flow Valve fails shut.

Evaluator Comments:

System:209001 WA's: A2.02 Ability to (a) predict the impacts of the following on the LOW PRESSURE CORE SPRAY SYSTEM ;and @) based on those predictions, use procedures to correct, control, or mitigate the consequences of those abnormal conditions or operations:

(CFR: 41.5 I 45.6)

Valve closures RO 3.2 SRO 3.2 Generic WA's:

JFM- 20901F Rev. 0,06/01 Page 1 of 1 Student Handout Initial Conditions:

The plant is operating at power during normal operations.

Initiating Cues:

You have been directed by the CRS to perform the Core Spray Quarterly Full Flow Test on the "A" Core Spray Pump.

VERMONT YANKEE NUCLEAR POWER STATION OPERGTING PROCEDURE OP 4123 REVISION 36 CORE SPRAY SYSTEM SURVEILLANCE USE CLASSIFICATION: REFERENCE L PC Effective Date Affected Pages No.

Implementation Statement: N/A Issue Date: 07/02/2003 OP 4123 Rev. 36 Page 1 of 27

TABLE OF CONTENTS PURPOSE ................................................................................................................................................... 3 DISCUSSION ............................................................................................................................................. 3 ATTACHMENTS ....................................................................................................................................... 3 REFERENCES AND COMMITMENTS................................................................................................... 4 PRECAUTIONS/LIMITATIONS.............................................................................................................. 5 PREREQUISITES ...................................................................................................................................... 7 PROCEDURE............................................................................................................................................. 8 A. Maintenance of Filled Discharge Pipe (Monthly) .......................................................................... 8 B. Motor Operated Valvehjection Check Valve Closure Test (Quarterly) (IST Rqmt.) ..................8 C. Core Spray Pump Operability Test (Quarterly and Refueling Outage) ........................................ 18 D. Pump Dischargehjection Check Valve Open Operability Test (Refueling Outage) ..................26 ACCEPTANCE CRITERIA..................................................................................................................... 26 FINAL CONDITIONS ............................................................................................................................. 27 OP 4123 Rev. 36 Page 2 of 27

PURPOSE To provide to Operations Department personnel the steps necessary to perform all required tests on the Core Spray (CS) systems to ensure their operability.

Completion of the following tests satisfy the respective Technical Specification requirements:

Technical Specifications/

Technical Requirements Manual Core Spray Pump Operability Test 4.5.A.l.(b),4.5.A.l.(~), 4.6.E.2.6.7.A Motor Operated Valve / Injection Check Valve Closure Test 4.5.A.l.fi). 4.6.E.2 Maintenance of Filled Discharge Pipe 4.5.1.1, 4.5.1.2 Pump Discharge / Injection Check Valve Open Operability Test 4.5.E.2 DISCUSSION This procedure will be performed per the below listed steps depending upon plant conditions.

The operability requirements for pump capacity of 23000 gpm at 120 psig based upon LOCA criteria of a flow path from torus to vessel are met by ensuring 23100 gpm at 2217.5 psid in the torus-to-torus test mode (includes instrument uncertainty per Memo SYSENG 98-136)

Periodic valve stroking is performed during normal plant operation and when in the refueling mode. Observation of stroke times within the prescribed limits established by the IST program aid in determining possible valve operability degradation.

The Pump DischargeAnjection Check Valve Open Operability Test is performed in conjunction with the Reactor Well fill per OP 2 184 Normal Fuel Pool Cooling System and OP 2123 Core Spray.

Testing performed under this procedure satisfies requirements of the Vermont Yankee Inservice Testing Program.

ATTACHMENTS

1. VYOPF 4123.01A CS Pump A (P-46-1A) Full Flow Test Data Sheet

2. VYOPF 4123.01B CS Pump By(P-46-1B) Full Flow Test Data Sheet

3. VYOPF 4123.02A CS Loop A MOV / Check Valve Closure Operability Test

4. VYOPF 4123.02B CS Loop By MOV / Check Valve Closure Operability Test

5. VYOPF 4123.03 Deleted

6. VYOPF 4123.04A Pump A Discharge / Injection Check Valve Open Operability Test

7. VYOPF 4123.04B Pump B Discharge / Injection Check Valve Open Operability Test

8. VYOPF 4123.05 Deleted OP 4123 Rev. 36 Page 3 of 27

9. VYOPF 4123.06 Deleted

10. VYOPF 4123.07A Maintenance of ACore Spray Filled Discharge Piping

11. VYOPF 4123.07B Maintenance of BCore Spray Filled Discharge Piping

12. VYOPF 4123.08 Deleted

13. Figure 1 Deleted REFERENCES AND COMMITMENTS

1. Technical Specifications and Site Documents

a. TS Sections: 3.5,3.7,4.2,4.5,4.6, and 6.7.A

2. Codes, Standards, and Regulations

a. None

3. Commitments

a. EPC-95 10, Tech. Spec. Review Committee Resolution

b. EPC-95 10-06, RE TS Review, PCIS Valve Surveillance C. ER2000 1026, Cycle CS-26A(B) Prior to Closing CS-1 1A(B)

d. ER970137 03, SBFPC Test Data Unsat Due to Procedure Problem

e. ER950159-02: Type A, Failure to Perform IST Evaluation on RHRSW Pump C. Revise all Ops Surveillance Procedures for pumps in the IST Program and Include Hydraulic Parameter Acceptance Range on Test Data Form.

f. ER950159 03: Type B, Failure to Perfom IST Evaluation on RHRSW Pump C, Revise all 6 p s Surveillance Procedures for Valves in the IST Program and Include Stroke Times on the IST Forms.

ER970694-01, RHR and Core Spray (CS) Pump Minimum Flow. Revise Procedure to Include Appropriate Min Flow Rate and Operating Times.

ER970822-03, (IST) For Core Spray (CS) Pump P-46-1B Approaching Lower IST Differential Pressure. Revise OP 4123 to Include Correct Parameter Used for Flow Rate test of the Core Spray Pumps. See L.T.REC.4.

1. NVY99004-02, Re Tech Spec Amendment 165, Re Primary Containment Isolation Valves (PCIS). Review all procedures impacted by the amendment and revise as necessary. Ensure that Control Room communications is (or will be) immediately available.

4. Supplemental References

a. Instruction Manual GEK-32439 and GEK-9612

b. DWG G191168, Core Spray System

c. Letter, VYNPC to NRC, WVY 80-41, LRW Primary Coolant System Pressure Isolation Valves, dated 3/14/80

d. Memo, J.S.Chizever to S.R.Miller, Evaluation of Core Spray Minimum Flow During Small Break LOCA Events, dated 06/16/91, file VYS125/91 (INS9080040P I)

OP 4123 Rev. 36 Page 4 of 27

e. Letter, VYNPC to USNRC, FVY 87-34, dated 3/20/87, Notification of Potential Existence of a Design Defect in Accordance with 10CFR21.21

f. Memo, VYS 125/87, R.E.Swenson to S.R.Miller, dated 11/25/87

g. SER 69-84, Damage to Main Steam and Feedwater Systems Caused by Water Hammer and Rapid Thermal Transients

h. SURV 88003010P1, Commitment Item, dated 2/4/88

i. MOOID 87 150P2, YNSD Evaluation of Core Spray Discharge Pressure

j. Vermont Yankee Inservice Testing Program

k. SOER 83-09, INPO Report, Manually Seated and Backseated Valves

1. SR 91-12, Service request 91-12, MOV Maintenance Verification Options, OPVY 548/91, dated 8/29/91

m. QAD Surveillance 97-0001

n. BMO 97-29 Rev. 1, RHR and CS Pump Minimum Flow

0. Memo VYE 67/97, R.N.M. to R.G.J., Core Spray and RHR Pump Starts dated 6/17/97 P. Memo SYSENG 98-136, Revision of Surveillance Procedures to Incorporate Instrument Uncertainty, dated 5/27/98

9. ER2001-6 16, Connection and disconnection of pressure gauges to Core Spray with out radiological precautions.

r. AP 0009, Event Reports S. OP 0150, Conduct of Operations and Operator Rounds

t. AP 02 11, Predictive Maintenance Program U. AP 0522, Radiologically Significant Plant Event Response for RP Personnel V. OP 21 12, Reactor Water Clean-up System W. OP 21 15, Primary Containment X. OP 2123, Core Spray Y. OE 3 107, EOP/SAG Appendices aa. AP 4000, Surveillance Testing Program ab. AP 6807, Collection, Temporary Storage and Retrieval of QA Records ac. PP 7006, Primary Containment Leak Rate Testing Program ad, PP 7013, Inservice Testing Program PRECAUTI0NS/LI MITATI0 NS

1. When closing any motor-operated throttle valve, hold the control switch to CLOSE for at least 2 sec. after the valve indicates closed to insure that the valve closes fully.

2. During valve operability tests, PUMP DISCHARGE CS must be locally verified closed prior to opening PUMP DISCHARGE CS-1 l A B , and PUMP DISCHARGE CS-11A B must be locally verified closed prior to opening PUMP DISCHARGE CS-12-. These valves are locally verified closed by observing the valve stem position.

(VY letter to NRC, WVY 80-41)

OP 4123 Rev. 36 Page 5 of 27

3. When opening a manual containment isolation valve that is within the primary containment boundary, as defined by PP 7006, Primary Containment Leak Rate Testing Program, when primary containment integrity is required, either enter the TS LCO (TS 3.7.A.8) or apply all of the following administrative controls:

Station a dedicated operator in the immediate vicinity of the valve controls to rapidly close the valve when directed by the Control Room.

Establish communications with the Control Room that is immediately available using either Gaitronics, sound powered phones, radios, telephones or other means.

These administrative controls will ensure that the manual containment isolation valve can be rapidly closed when primary containment isolation is required. (NVY99004-02)

4. Limit CS pump starts to two in15 minutes followed by a 20-minute run or a 45-minute shutdown for cooling. (Memo VYE 67/97)

5. When FW PUMP P 1A and P 1B are running simultaneously, monitor 4KV Bus 1 amperage carefully during operation of CORE SPRAY PUMP P 1B to avoid exceeding the maximum allowable bus current of 2720 amps.

6. Ensure that the Core Spray systems are maintained filled, vented and pressurized.

7. A safety-related motor operated valve shall be declared inoperable if electrically seatedhackseated bypassing the normal controls or if it has been manually engaged, unless an evaluation determines that continued valve operability is ensured or until remote motor operation can be demonstrated. (SOER 83-09) (SR 91-12)

8. This system may be susceptible to water hammer damage during startup and possibly during other evolutions. (SER 69-84)

9. Minimize CS pump operation at minimum flow. Operating a CS pump at 4710gpm for

>4 hours may result in pump degradation. (BMO 97-29 Rev. 1, FVY 87-340P2),

(INS9080040P1, ER970694-01)

10. MOV seat leakage following valve stroking may be caused by valve spring pack relaxation due to spring set.

11. When operating motor operated valves not specifically identified as throttle valves, the control switch should be placed to the desired position just long enough to verify valve motion and then released. If there is doubt that the valve has stroked fully, the switch may be operated again, but should not be held in position since motor damage or breaker tripping or both may occur.

OP 4123 Rev. 36 Page 6 of 27

PREREQUISITES 1, Power Supplies:

a. 4KV Buses 3 and 4 energized.

b. 480V MCC-8B and MCC-9B energized.

C. 120V Inst. AC Dist. Panel Ckts. 5, 7, 9 and 43 closed (CRP 9-46).

d. 120/240V Vital AC Subpanel A Ckt. 9 and Ckt. loclosed (CRP 9-45).

e. 120V DC Dist. Pnls. DC-IC Ckt. 2 and DC-2C Ckt. 2 energized.

f. ECCS 24VDC System operable.

2. System lined up per Appendix A of OP 2 123, Core Spray

3. Maintenance Department notified that pump vibration readings will be required per AP 021 1 Predictive Maintenance Program for the Core Spray Pump Operability Test.

(IST Rqmt).

4. A calibrated stopwatch is available for power operated valve timing.

5. Suction and discharge pressure test gauges that satisfy the requirements of procedure section Cyare available for the Core Spray Pump Operability Test.

6. If FULL FLOW TEST CS-26A(B) is to be cycled, then limit the initial torus water volume (ERFIS point C029) to 69,500 cubic feet to ensure that the upper Administrative Limit boundary in Figure 1 of OP 21 15 Primary Containment is not exceeded.

7. Shift Supervisors authorization to perform testing has been obtained.

OP 4123 Rev. 36 Page 7 of 27

C. Core Spray Pump Operability Test (Quarterly and Refueling Outage)

(Use VYOPF 4123.OlNB as appropriate for each pump. Steps that have an asterisk (*)

have a corresponding signoff on the surveillance form.)

NOTE Vibration testing is required only during surveillance tests required by the IST Program.

1. Notify the RP Department that:

e The A(B) Core Spray Loop will be breached to install test gauges.

e Core Spray testing will be performed.*

2. Locally, install temporary test gauges possessing the characteristics listed below on the selected Core Spray pump suction and discharge lines as follows:

Instrument Accuracy Range Safety Class Location {minimum) Minimum/Maximum {minimum)

PI-14-36A(B) Test Connection Isolation Valve CS-806A(B) Quick Disconnect 0.25% 0 psig / 15 psig sc3 Test Connection Isolation Valve CS-807A(B) Quick Disconnect 0.25% 0 psig / 400 psig sc3

a. IF the suction and discharge lines are posted as contaminated, THEN contact RP to determine if any special radiological controls are required.

b. IF the suction and discharge lines are not posted as contaminated, THEN the following steps shall be used to accomplish the connections. (In lieu of these steps, RP may be contacted for specific direction and those directions followed.)

1) Obtain and wear rubber gloves.

2) Place a suitable containment device or absorbent material under the test fitting / connection and slowly open.

3) Break and make connections as required.

4) Remove and dispose of the rubber gloves as contaminated.

5) Perform any required valve manipulations without rubber gloves.

OP 4123 Rev. 36 Page 18 of 27

c. Install a temporary suction pressure test gauge at the A (B) Core Spray Pump as follows:

1) Close / check closed PI-14-36A Test Connection CS-806A(B).

2) Remove the plug from the quick disconnect at CS-806A(B).

3) Install the temporary suction pressure test gauge to the quick disconnect at CS-806A(B).

d. Install a temporary discharge pressure test gauge at the A (B) Core Spray Pump as follows:

1) Close / check closed Test Connection CS-807A(B).

2) Remove the plug from the quick disconnect at CS-807A(B).

3) Install the temporary discharge pressure test gauge to the quick disconnect at CS-807A(B).

e. Verify or establish each test gauge at approximately the same elevation as the centerline of the Core Spray Pump suction or discharge piping.

f. Report the test gauge serial numbers and calibration due dates to the Control Room for documentation on the surveillance form.*

g. Fill and vent CS Loop A(B) per VYOPF 4123.07A(B).*

h. Prior to starting the pump, visually inspect all accessible piping and components of the Core Spray loop to be tested. (QAD Sum. 97-0001)*

OP 4123 Rev. 36 Page 19 of 27

CAUTION When Primary Containment is Required:

8 A dedicated operator shall remain in the immediate vicinity of the valve controls with immediately available communications established with the Control Room until CS-806A(B) and CS-S07A(B) are closed. (NVY990004-02) e The Manual Containment Isolation Valve shall be rapidly closed when Primary Containment Isolation is required during accident conditions. (NVY990004 02)

1. When primary containment is required, station a dedicated operator in the immediate vicinity (must be able to rapidly close the valves when directed by the Control Room) of CS-806A(B) and CS-807A(B) and establish communication between the operator and the Control Room that is immediately available. *

3. In the Control Room, perform the following

a. IF FW PUMP P 1A and P 1B are running simultaneously, and 4KV Bus 1 load is >2500 amps, THEN do not start Core Spray Pump 'B' until only one running feed pump is being supplied from 4KV Bus 1.

b. IF a feed pump auto start occurs while Core Spray testing is in progress, THEN secure Core Spray Pump 'B' if 4KV Bus 1 amps are 22500.

c. During power operation, IF either Core Spray subsystem is inoperable or placed in the full-flow test mode, THEN enter the applicable Tech. Spec LCO for Core Spray:*

e With one Core Spray subsystem inoperable or in full-flow test, enter the 7-day LCO of TS 3.5.A.2.

e With both Core Spray subsystems inoperable or in full-flow test, enter the 24-hr. LCO of TS 3.5.A.6.

OP 4123 Rev. 36 Page 20 of 27

CAUTION Operating a Core Spray pump with flow d 7 1 0 gpm for >4 hours may result in pump degradation. (EN70694 01)

d. Start the Core Spray pump to be tested.

CAUTION If MINIMUM FLOW CS-5A(B) closes with no flow path available, the Core Spray pump must be secured to prevent pump damage.

e. Verify that MINIMUM FLOW CS-SA(B) remains open.*

f. Verify that annunciator 3-A-7 'ADS PERMISSIVE RHWCS RU"ING'energizes.*

g. Check that the appropriate RRU started automatically.*

NOTE Although Core Spray flow of 3 100-3150 gpm is acceptable, set flow as close as reasonably achievable to the reference value listed on VYOPF 4 123.01A(B).

h. Throttle FULL FLOW TEST CS-26A(B) to obtain 3 100-3150 gpm as read on PUMP FLOW FI-14-50A(B). (ER970137-03, ER970822-03)

1) Verify MINIMUM FLOW CS-SA(B) closes as flow increases.*

1. Maintain test parameters until all readings and measurements have been taken.

OP 4123 Rev. 36 Page 21 of 27

JPM- 20023F Rev. 6,06101 Page 1 of 6 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Initiate a Manual Scram (OE 3 107 Appendix F)

Failure Mode: RPS Can Not be Reset

Reference:

OE 3 107 Appendix F, Initiation of a Manual Scram (Rev. 15)

Task Number: 2000200501 Task Performance: AO/RO/SRO __ RO/SRO Only X SE Only -

Sequence Critical: Yes - No 2 Time Critical: Yes - No 2 Individual Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation - Performance X Discuss Setting: Classroom - Simulator X Plant Performance Expected Completion Time: 12 minutes Evaluation Results:

Performance: PASS - FAIL- Time Required:

Prepared by:

Date Reviewed by: 4 Approved by:

Operations Training Superintendent

JPM- 20023F Rev. 6,06/01 Page 2 of 6 Directions:

Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the individual has failed the Job Performance Measure.

After providing the initiating cue, ask the individual "Do you understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform all actions.

You are requested to "talk-through" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

A hydraulic ATWS has occurred, and reactor power remains above 2%. EOP-2 has been entered and is being used to control plant parameters. ADS has been inhibited. RPS and ARVRPT have been initiated.

Initiatiw Cues:

The CRS has directed you to implement OE 3 107 Appendix F (Initiation of a Manual Scram).

Task Standards:

Inward rod motion achieved by inserting a manual scram at CRP 9-5.

Required Materials:

0 OE 3 107 Appendix F, Initiation of Manual Scram (latest revision) 0 Four long alligator clip jumpers 0 Flathead screwdriver 0 Electrical tape

JPM- 20023F Rev. 6, 06/01 Page 3 of 6 Simulator Setup:

0 Any full-power IC 0 Insert mfRD-12A and miRD-12B at 98% - Hydraulic ATWS 0 Insert mfN&-06A, B, C, and D - APRM INOPS 0 Inhibit ADS 0 Initiate ARVRPT 0 Depress PB-1 on FWLC master controller

JPM- 20023F Rev. 6,06101 Page 4 of 6 Evaluation Performance Steps 4 TIME START:

SATIUNSAT Step 1: Obtain procedure and review pre-requisites, obtains tools from EOP Tool Box.

Standard: Procedure obtained; pre-requisites reviewed and verified, tools obtained.

SATKJNSAT Step 2: If plant conditions allow, reset the SCRAM Standard: Identify that plant conditions do NOT allow reset of the scram.

SATIUNSAT Step 3: If plant conditions allow, reset ARI/RPT Standard: Operator resets ARVRPT by depressing the ARVRPT reset pushbuttons at CRP 9-4.

SATIUNSAT *Step 4: Install the followinp iumpers at CRP 9-15 RelayIPost # to Relay/Post #

SA-K1OA / 2 + SA-K11E / 4 SA-K1OC 12 + 5A-K11G/4 Standard: Jumper alligator clips attached to terminal posts as indicated above Note: OE 3 107 Appendix Figure 1 provided for reference as Attachment A to this JPM SAT/UNSAT *Step 5: Install the following iumpers at CRP 9-17 Relay/Post # to Relaymost #

SA-KlOB / 2 + SA-Kl1F / 4 SA-K1OD / 2 + SA-K11H / 4 Standard: Jumper alligator clips attached to terminal posts as indicated above

JPM- 20023F Rev. 6,06/01 Page 5 of 6 SATIUNSAT *Step 7: Reset the Scram Standard: Operator resets the scram by taking the Scram Reset switch at CRP 9-5 to position 2/3 + 1/4 RESET SATKJNSAT Step 8: Confirm or reset ARURPT lopic trips Standard: Operator confirms that ARJ/RPT logic trips are reset by observing ARVRPT annunciators NOT in alarm.

SATKJNSAT Step 9: Reset drift alarms Standard: Operator takes Control Rod Drift Reset switch at CRP 9-5 to RESET SATNNSAT Step 10: Opedconfirm open CRD 32A/B, 33A/B/C/D Standard: Operator observes red lights on for six valves on lower right hand side of control room panel 9-5 bench board.

SATIUNSAT Step 11: Verify SDV-A and SDV-B are drained or drainine by CRP 9-5 or local indication Standard: Operator observes open indication for SDV vent and drain valves Interim Cue: If A 0 contacted to verify local indications of SDV draining, inform Operator that the SDV is draining. If Operator intends to wait until the SDV is completely drained, wait approximately two minutes, then inform Operator as CRS to initiate manual scram.

SATKJNSAT *Step 12: Insert a manual scram Standard: Operator inserts a manual scram by depressing Manual Scram Pushbuttons A and B at CRP 9-5.

SATKJNSAT Step 13: Observe inward rod movement and repeat steps 6 throuph 10 Standard: Operator recognizes inward rod motion and prepares to repeat steps 6 through 10.

Interim Cue: Once Operator identifies inward rod motion and indicates intention to repeat steps 6 through 10, inform Operator that no further actions are required for this JPM.

JPM- 20023F Rev. 6,06/01 Page 6 of 6 TIME FINISH:

Terminating Cue: Inward rod motion achieved by reset and initaion of manual scram.

Evaluator Comments:

System: 212000 A4.17 Ability to manually operate and/or monitor in the control room:

(CFR: 41.7 / 45.5 to 45.8)

Perform alternate reactivity/ shutdown operations .

Importance RO 4.1 SRO 4.1 System: 295039 EA1.01,.03 Ability to operate and/or monitor the following as they apply to SCRAM CONDITION PRESENT AND REACTOR POWER ABOVE APRM DOWNSCALE OR UNKNOWN :

(CFR: 41.7 / 45.6)

Reactor Protection System RO4.6" SRO4.6" ARI/RPT/ATWS: Plant-Specific RO 4.1" SRO 4.1" System Generic WA's:

JPM- 20023F Rev. 6,06/01 Page 1 of 1 Tear-Out Sheet Initial Conditions:

A hydraulic ATWS has occurred, and reactor power remains above 2%. EOP-2 has been entered and is being used to control plant parameters. ADS has been inhibited. RPS and ARVRPT have been initiated.

Initiatinv Cues:

The CRS has directed you to implement OE 3 107 Appendix F (Initiation of a Manual Scram).

APPENDIX F INITIATION OF A MANUAL SCRAM AND INDIVIDUAL CONTROL ROD SCRAMS PURPOSE The purpose of this procedure is to manually initiate a SCRAM or SCRAM individual control rods at the Individual Rod Test and Monitoring Panel, defeating RPS and AEU/RPT logic trips if necessary, to insert the control rods to or beyond position 02.

REFERENCES

1. CWD Sheets 805,808,812,815,817 through 827,862, and 867

2. OP 2134, Reactor Protection System ATTACHMENTS

1. Figure1 ATWS Spiral Insert Sequence I

2. FigureII ATWS Spiral Insert Sequence 11

3. Figure III HFA Relay Connections PREREQUISITES

1. At least one RPS bus energized (MCC 8A, MCC 8B or MCC 9A).

2. Instrument air system in service (MCC 7B, 8C, 9C or 11B).

3. Four long alligator clip jumpers, flathead screw driver, and electrical tape from the EOP toolbox in the Control Room.

PROCEDURE

1. IF plant conditions allow, THEN:

e Reset the SCRAM.

e Reset the ARL'RPT logic trips.

2. IF reactor pressure is less than 500 psi, THEN OPENkheck OPEN CRD-56, CRD Charging Water Header Supply.

3. IF the RPS and ARI/RPT logic trips are reset, THEN go to Step 8.

Appendix F OE 3107 Rev. 16 Page 1 of 8

APPENDIX F (Continued) r0 NOTES Installing the jumpers below will bypass & scram l signals except for the manual scram and mode switch to shutdown.

e Figure III may be used as an aid in identifying relay post locations.

4. IF RPS can not be reset due to plant conditions, THEN install the Initial followingjumpers to defeat the RPS logic trips:

a. At CRP 9-15: (CWD 805 and 808)

Relaypost # to RelayPost #

0 5A-KlON2 ___+ 5A-KllEI4 0 5A-K1OC I 2 ___+ 5A-Kl1GI4

b. At CRP 9-17: (CWD 812 and 815)

Relaypost # to RelayRost #

5.

0 e

5A-KlOBl2 5A-KlODl2 -___, 5A-KllF14 5A-K11H/4 IF ARVRPT can not be reset due to plant conditions, THEN lift and tape the following leads to defeat the ARVRPT logic trips:

0 CRP 9-3: AA75 double lead (CWD 867) 0 CRF 9-4: KK30 double lead (CWD 862)

6. Reset/confirm reset the SCRAM.

7. Confirm ARYRPT logic trips reset.

8. Reset drift alarms.

9. OPENIconfirm OPEN CRD-32A(B) SDV VENT VALVES and CRD-33A(B)(C)(D) SDV DRAIN VALVES.

10. Verify SDV-A and SDV-B are drained or draining by CRP 9-5 or local indication.

Appendix F OE 3107 Rev. 16 Page 2 of 8

APPENDIX F (Continued)

NOTE Steps 11 and/or 12 may be performed in any order as directed by the CRS, but not concurrently.

11. Manual SCRAM Initiation

a. Insert a manual scram.

b. IF inward rod movement was observed and any control rod remains withdrawn beyond position 02, THEN repeat Steps 1 through 11.a.

C. IF all control rods fail to move inward, THEN inform the CRS.

12. Individual Control Rod Scrams (Only perform when RPS and ARVRPT are reset, SDIV valves open)

a. IF shift manpower allows, THEN establish communications between CRP 9-5 operator and CRP 9-16 operator.

NOTES e The appropriate rod select template (I/@ may be used as an aid, if desired.

0 The operator may initial, checkoff, or comment in the space provided after each control rod as appropriate.

b. At CRP 9-16, insert control rods using the following method, using the sequence given on Figure I:

r CAUTION The time the control rod test switch is in the center or full down position should be minimized. Since the SDV vent and drain valves are open, a flow path exists from the reactor through the scram valves to the SDV to the secondary containment.

1) Place the individual Control Rod Test Switch to the SCRAM (CENTER or FULL DOWN) position. [UND95008-02]

2) Wait at least 10 seconds, or until the control rod indicates insertion to at least position 02, and return the Control Rod Test Switch to the NORMAL (FULL UP)position. [UND95008-02]

Appendix F OE 3107 Rev. 16 Page 3 of 8

APPENDIX F (Continued)

3) IF the sequence of Figure 11is inadvertently started, THEN noti@ the CRS, insert all possible control rods in that sequence and proceed to the sequence given on Figure I.

4) IF, while inserting control rods, a control rod is mispositioned, THEN notify the CRS, insert that control rod to 00 and continue in the sequence.

5) IF, while inserting control rods, a control rod in the sequence cannot be moved or is at 00, THEN skip that control rod and continue in the sequence.

c. WHEN all possible control rods have been inserted per Figure I@), THEN continue to insert control rods per Figure II(1).

d. WHEN all control rods that can be inserted have been inserted, THEN inform the CRS.

Satisfactorily completed nwithout, [7 with attached exception(s).

Shift Manager: I /

Name (Print/Sign) Time Date InitiaWerified RESTORATION

1. IF installed, THEN remove the following jumpers to restore the W S logic trips:

a. At CRP 9-15: (CWD 805 and 808)

RelayPost # to RelayPost #

e 5A-K1OM2 ___, 5A-K11E/4 I e 5A-K1OC/2 5A-Kl l GI4 l

b. At CRP 9-17: (CWD 812 and 815)

RelayPost # to RelayPost #

e 5A-K1OBI2 ___, 5A-K11F/4 I e 5A-KlODl2 5A-K11H/4 l Appendix F OE 3107 Rev. 16 Page 4 of 8

APPENDIX F (Continued)

InitialNerified

2. IF leads were lifted, THEN remove the electrical tape and replace the following leads to restore the ARVRPT logic trips:

0 CRP 9-3: AA75 double lead (CWD 867) 1 CRP 9-4: KK30 double lead (CWD 862) l

3. VERIFY that all test switches at CRP 9-16 are in the NORMAL (FULL UP) position. I

4. Position CRD-56 CRD Charging Water Header Supply as required by other appendices. IF not required by other appendices, THEN OPEN CRD-56. I Satisfactorily completed 0without, with attached exception(s).

Shift Manager: f I Name (PrintlSign) Time Date Appendix F OE 3107 Rev. 16 Page 5 of 8

APPENDIX F (Continued)

FIGURE I Control A W S SPIRAL INSERT SEQUENCE i Step Rod (ROD SELECT TEMPLATE I) 1 22-23 -

2 18-27 ___

3 22 4 26-27 -

5 30-23 -

6 26 7 22 8 18 9 14 10 10-27 __

11 14-31 -

12 18 13 2239 -

14 26 15- 30 16 3427 -

42-27: 17 38-23 -

18 34 19 30 20 26 21 22-07 __

22 18 23 14 24 10-19 __

25 06 26 02 27 06 28 10 29 14-39 ___

30 18 31 26 32 30 33 34 03 -------' 18-03 4 26-03 34 38 35 42 36 42 02 06 IO 14 30 34 38 42 37 38 38 34 39 30 40 2603 ___

41 18 42 14 43 10 44 06 45 02 Appendix F OE 3 107 Rev. 16 Page 6 of 8

APPENDIX F (Continued)

FIGURE II Control ATWS SPIRAL INSERT SEQUENCE II Step Rod (RODSELECT TEMPLATE 11) 46 18-23 ___

47 22 48 26 49 22-19 _ _

50 18-15 -

51 14 1 52 10 39 53 14-27 __

54 18-31 -

55 22-35 -

35 56 26-31 __

57 30 58 34-23 -

31 59 30-19 -

60 26-15 -

61 22-11 __

27 62 18-07 __

63 14-11 -

64 10 23 65 06-19 __

66 02-23 __

67 06-27 -

19 68 10-31 __

69 14 70 18-39 _ _

15 71 22 72 26-39 -

73 30-35 _ _

I1 74 34-31 I _

07 I I 78 34-15 ___

79 30-11 __

03 22-03 80 26 81 22-03 __

02 06 10 14 18 22 26 30 34 38 42 82 83 0611 -

84 06-35 __

85 1039 -

86 34-39 __

87 38 88 38 89 34 Appendix F OE 3107 Rev. 16 Page 7 of 8

APPENDIX F (Continued)

FIGURE I11 HFA EXTERNAL RELAY CONNECTIONS I o EXTERNAL CONNECTiONS HFA RELAY (REAR-VIEW)

Appendix F OE 3107 Rev. 16 Page 8 of 8

JPM 27 106 Rev. 0, 10/00 Page 1 of 5 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Advance Off Gas System, OG-5 16 Valve Transfer.

Failure Mode:

Reference:

OP 2150. Advanced Off Gas System And Air Evacuation Equipment Task Number: 2717190101 Task Performance: AO/RO/SRO - RO/SRO X SRO Only Sequence Critical: Yes - No Time Critical: Yes- N o 2 Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation - Performance X Discuss -

Setting: Classroom - Simulator X Plant Performance Expected Completion Time: 10 minutes Evaluation Results:

Performance: PASS - FAIL Time Required:

JPM 27106 Rev. 0, 10/00 Page 2 of 5 Directions: Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "Do you understand the task?"

Read to the Derson being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Simulator and you are to perform the actions.

You are requested to "talk through" the procedure, stating the parameters you are verieing or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

Reactor is at 100% power.

Initiating Cues:

The CRS directs you to swap ejector suction pressure control from OG-5 16A to OG-5 16B per OP 2 150, Section Y.

Task Standards:

Ejector suction pressure control is successfully swapped from OG-516A to OG-5 16B.

Required Materials:

OP 2 150, Advanced Off Gas System And Air Evacuation Equipment Simulator Setup:

IC- 19 (or any IC with OG-5 16A is service)

(Validated in IC-7. Works with Turbine Generator S/U and RUPS 89A JPMs)

JPM 27 106 Rev. 0, 10/00 Page 3 of 5 Evaluation Performance Steps TIME START:

Note: All Steps performed on CRP 9-6 unless otherwise noted.

SATKJNSAT Step 1: Obtain Procedure OP 2150 and review admin limits. precautions and prerequisites.

Standard: OP 21 50 obtained. Admin limits, precautions and prerequisites reviewed.

~~

Interim Cue: Prerequisites SAT.

SATKJNSAT Step 2: Verifv that the second stage eiector steam supplv valve AS-FCV-2B is open.

Standard: Operator observes valve AS-FCV-2B red light ON and green light OFF.

SATKJNSAT Step 3: Verify that OG-516B is closed.

Standard: Operator observes OG-5 16B green light ON and red light OFF and OG-5 16B controller is set at 0% open.

SATAJNSAT *Step 4: Open SJAE B first stage steam supplv valve AS-FCV-1B.

Standard: Operator positions AS-FCV-1B hand switch to OPEN and observes red light ON and green light OFF.

SATKJNSAT Step 5: Note the valve position on OG-516A controller.

Standard: Operator notes the valve position on OG-5 16A controller on CRP 9-50.

SATNNSAT Step 6: Close OG-516A.

Standard: Operator changes display to read 0 and pushes "SEL" button,PC-OG-1102A, on CRP 9-50.

SATAJNSAT *Step 7: Place OG-516A control switch to CLOSE.

Standard: Operator positions OG-5 16A control switch to CLOSE.

JPM 27 106 Rev. 0, 10/00 Page 4 of 5 SAT/UNSAT *Step 8: Place OG-516B control switch to OPEN.

Standard: Operator positions OG-5 16B control switch to OPEN.

SATKJNSAT *Step 9: Depress OG-516B RESET push-button.

Standard: Operator depresses OG-5 16B RESET push-button, PC-OG-5 16B, on CRP 9-50.

SAT/UNSAT Step 10: Verifv reset pushbutton light illuminates.

Standard: Operator verifies reset light for PCV-OG-516B, on CPR 9-50.

SAT/UNSAT *Step 11: Slowlv open OG-516B and adiust so that valve position is equal to previous position of OG-516A.

Standard: Operator changes display of PC-OG-1102B to indicate previous OG-5 16A valve position and pushes "SEL" pushbutton on CRP 9-50.

~

N0TE:This step may be performed incrementally to prevent excessive flows.

SAT/UNSAT Step 12: Close SJAE first stage steam supplv AS-FCV-1A.

Standard: Operator positions AS-FSV-1A hand switch to CLOSE and observes green light ON and red light OFF.

JPM 27106 Rev. 0, 10/00 Page 5 of 5 TIME FINISH:

Terminating Cue: Ejector suction pressure control is successfully swapped from OG-5 16A to OG-516B.

Evaluators Comments:

System: 271000 WA's: A4.01,02,03,04,06,09 Ability to manually operate and/or monitor in the control room:

(CFR 41.7 / 45.5 to 45.8)

Reset system isolations RO 2.8 SRO 2.8 System flows RO 2.9 SR02.9 System temperatures RO 2.8 SR02.8 Condenser vacuum R03.4 SRO 3.5 System indicating lights and alarms RO 3.3 SR03.2 Offgas system controls/components RO 3.3 SR03.2

JPM 27 106 Rev. 0, 10/00 Page 1 of 1 Student Handout Initial Conditions:

Reactor is at 100% power.

Initiating: Cues:

The CRS directs you to swap ejector suction pressure control fiom OG-5 16A to OG-5 16B per OP 2150, Section Y.

VERMONT YANKEE NUCLEAR POWER STATION OPERATING PROCEDURE OP 2150 REVISION 27 ADVANCED OFF GAS SYSTEM AND AIR EVACUATION EQUIPMENT USE CLASSIFICATION: REFERENCE 1 LPC No. 1 Effective Date I Affected Pages 1 02/06/03 6 & 54 of 61 2 07/01/03 App D Pg 2 of 2 I Implementation Statement: N/A Issue Date: 01/14/03 OP 2 150 Rev. 27 Page 1 of 61

TABLE OF CONTENTS PURPOSE .......................................................................................................................................................... 4 DISCUSSION .................................................................................................................................................... 4 ATTACHMENTS ............................................................................................................................................. 8 REFERENCES A N D COMMITMENTS......................................................................................................... 8 PRECAUTIONS/LIMITATIONS..................................................................................................................... 9 PREREQUISITES ........................................................................................................................................... 11 PROCEDURE.................................................................................................................................................. 13 A. Startup of P.53.1A. Main Condenser Mechanical Vacuum Pump (Hogger)........................ 13 B. Placing SIF-1A Shutdown Iodine Filter into Service............................................................. 15 C. Removing SIF-1A Shutdown Iodine Filter from Service ...................................................... 18 D. Cooldown of Dryer Trains ...................................................................................................... 19 E. Cooldown of AOG Chiller Trains A/B .................................................................................. 21 F. Placing P-154-1A(B) VACUUM PUMP A(B) in Service .................................................... 22 G. Startup of the Coolant Booster System .................................................................................. 24 H. Warmup of SYSTEM A/B RECOMBINER Trains .............................................................. 25 I. Warmup of Auxiliary Steam Lines......................................................................................... 27 J. Placing REC-lOO-lA(B) Recombiner into Service ............................................................... 28 K. Pumpdown of the Main Condenser ........................................................................................ 31 L. Transfer of Steam Packing Exhauster .................................................................................... 34 M. Place AS-PCV-1, Main Steam to SJAE, into Service ........................................................... 34 N. Manual Transfer of Recombiner Trains ................................................................................. 35

0. Recombiner Train Transfer - Operate to Manual ................................................................... 37 P. Recombiner Train Transfer - Manual to Operate ................................................................... 37 Q. Transfer ofD-lOO-lB(A) Dryer Skids ................................................................................... 38 R. Transfer ofP-154-1A(B) Vacuum Pump ............................................................................... 39 S. Guard Bed TK-lOO-lA(B) Transfer ....................................................................................... 41 T. Isolation of TK-lOl-lA, Charcoal Adsorber A, or TK-lOl-lB, Charcoal Adsorber B ........41 U. P-154-1A(B) Vacuum Pump Transfer - Auto to Manual ...................................................... 42 V. P-154-1A(B) Vacuum Pump Transfer - Manual to Auto ...................................................... 42

w. OG-SOlA(B), Vacuum Pump Bypass, Controller - Manual to Auto .................................... 43 X. OG-SOlA(B) Vacuum Pump Bypass, Controller - Auto to Manual ..................................... 43 Y. OG-5 16, Ejector Suction Press Control A(B), Valve Transfer.............................................. 43 Z. Shutdown of Advanced Off Gas System................................................................................ 45 AA . Bypassing the Dryer and Adsorber Trains.............................................................................. 48 BB . Restoring the Dryer and Adsorber Trains to Service ............................................................. 50 cc. Operation with Both Dryer Trains in Parallel ........................................................................ 51 DD. Recombiner Train Automatic Switchover.............................................................................. 52 EE. Isolation of Both SYSTEM A/B RECOMBINER Trains ..................................................... 53 OP 2150 Rev . 27 Page 2 of 61

FF. Standby Vacuum Pump Automatic Start ............................................................................... 54 GG. High Stack Filter Differential Pressure .................................................................................. 54 HH . Air Purge of 12-OG-100Line to Main Condenser ................................................................ 55 II. Vacuum Dragging of TK-104-1 Drain Tank (Requires Two Operators).............................. 57 JJ . Startup of P.53.1A, Main Condenser Mechanical Vacuum Pump (Hogger)

Following Tnp or Unplanned Stoppage................................................................................. 59 KK. Transfer of AOG Drain Tank Pumps ..................................................................................... 60 LL. Transfer of Coolant Booster Pumps ....................................................................................... 61 FINAL, CONDITIONS .................................................................................................................................... 61 OP 2150 Rev. 27 Page 3 of 61

PURPOSE To specify the steps necessary to ensure proper operation of the Ac,Jancec Off Gas (AOG) system and Air Evacuation Equipment by Operations Department personnel.

DISCUSSION The AOG system is the gaseous radwaste treatment system used to reduce radioactive gaseous effluents by collecting primary coolant system off gas fiom the primary system and providing for delay or holdup to reduce the total radioactivity prior to its release to the environment to as low as practicable. It is used in its designated mode of operation to reduce the noble gases whenever the SJAE is in operation.

The process used to reduce krypton and xenon radioactivity is selective retention by charcoal adsorption. The system has been analyzed for operation with air flow rates of 100 s c h .

The off gas release rates must be controlled and the plant radiation monitors utilized to ensure compliance with the Offsite Dose Calculation Manual requirements. This will ensure compliance with Technical Specification requirements. (VYCES9401SOP 1)

Off gas entering the system is diluted with steam at the second stage air ejector to prevent a flammable mixture of hydrogen fiom entering the recombiners. This results in less than a 3 percent by volume hydrogen concentration.

The major components of each recombiner flow path are a preheater, a hydrogen-oxygen recombiner, and a desuperheating condenser. The preheater ensures that the vapor entering the recombiner is heated to at least 300°F so that all the water vapor in the stream is superheated steam.

During passage through the recombiner, the H2 and 0 2 are recombined in an exothermic reaction which increases the steam temperature to ~520°F.This recombination results in a maximum effluent H2 concentration of 0.1% by volume. This recombination further minimizes the volume of gas to be processed which will increase the delay time. The mixture is then cooled and the steam condensed. The remaining water droplets leaving the condenser are removed in a moisture separator, combined with condensate fi-om the condenser and returned to the main condenser hotwell.

The reduced volume of gas flows through 40% of the original holdup volume and passes through two stages of moisture removal (preceded by prefilters which remove particulates generated in the delay pipe). A mechanical refrigeration system, using circulated demineralized water as the heat exchange media, cools the stream in a cooler/condenser to remove water. The stream is further dried by passing through a dryer bed which is designed to remove the remaining moisture by a molecular sieve desiccant to a dew point of less than -40°F (4% RH). There are two dryers per train, one which is absorbing moisture from the off gas, while the other is being regenerated by circulating heated air through the bed in closed cycle.

OP 21 50 Rev. 27 Page 4 of 61

The chilleddryer concept improves the reliability of the system. If the refrigerant system fails, then the two dryer trains can be operated in parallel so that one bed per train is operating to remove the moisture and maintain the off gas near the design dew point (-40°F) while the system is being repaired.

The air leaving the dryer next enters a guard bed which protects the charcoal in the main vessels from excessive moisture in the event of a malfunction in the upstream moisture removal systems and provides a holdup time for Xe'37. The guard bed can provide 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months of moisture protection for the main charcoal beds.

The off gas next passes through seven charcoal adsorber beds containing a minimum of 90,000 lbs. of charcoal. Six tanks ensure design performance but seven tanks are normally used.

The first two tanks can be bypassed and used for storing a batch of high activity gas for static decay if necessary. The remaining five tanks are in series with no bypass features which would allow off gas discharge to the stack without significant delay. The off gas is then filtered for particulates through an after filter prior to the vacuum pumps.

A water-sealed vacuum pump boosts the stream pressure to slightly over atmospheric pressure before it is vented through the stack. A modulating bypass valve recirculates process gas around the pump as required to maintain the desired pressure in the AOG system. The control setpoint is established to ensure that the air ejectors operate with reasonably constant backpressures. During periods of high flow rates, both pumps can be operated in parallel.

Discharge of the vacuum pump then passes through the remaining 60% of the holdup volume to the station stack.

Two bypass lines are installed around the dryer and adsorber trains. The dryedadsorber subsystem may be bypassed if temporarily unavailable during startup or normal reactor operation provided releases are within the limits of 10CFR20. Prior to this mode of operation, the B stack filter must be placed in service and the A stack filter isolated, because there are elements installed in the B Stack Filter but not in the A Filter. Use of either of the bypass lines requires off gas be exhausted through the recombiner/condenser subsystems.

1. The line with AOG BYPASS OG-145 and OG-146 uses FE-OG-1805 to measure off gas flow. This line is monitored for Noble Gas Activity between the charcoal bed system and the plant stack. Effluent releases via this pathway for more than 7 days requires special reporting per the Offsite Dose Calculation Manual.

2. The line with OG-551 and 06-573, Dryer Adsorber Train Bypass, uses FE-OG-1302 to measure off gas flow. This line bypasses the Noble Gas Activity Monitor discussed in T/S Table 3.2.4 and ODCM Table 3.1.2. Effluent releases via this pathway may continue for a period of up to 7 days provided that at least one of the stack monitoring systems is operable and off gas system temperature and pressure are measured continuously per T/S Table 3.2.4 Note 1 and ODCM Table 3.1.2 Note 2. This procedure does not direct use of this bypass line.

OP 2150 Rev. 27 Page 5 of 61

The following trips (valve closures) are associated with the air evacuation and off gas systems:

1. The pressure and temperature monitors on the AOG inlet line, OG-100, will close OG-5 16A/B, Ejector Suction Press Control AB,under the following conditions:

a. PS-21E/21G, SJAE Disch Off Gas Press, two out of two, high pressure (7.5 psig).

b. TIS-l9C/D, SJAE Disch Off Gas Temp, two out of two, high temperature (375OF).

c. PS-21E, SJAE Disch Off Gas Press, and TIS-l9D, SJAE Disch Off Gas Temp, two out of two, high pressure (7.5 psig) and high temperature (375'F).

d. PS-21G, SJAE Disch Off Gas Press, and TIS-19C, SJAE Disch Off Gas Temp, two out of two, high pressure (7.5 psig) and high temperature (375°F).

2. PS-101-34AD3, SJAE Reg Steam Supply Press, will close OG-516A/B, Ejector Suction Press Control A/B,on low steam pressure (50 psig) with a low pressure signal from both switches.

3. Rad Level to Holdup and Stack, RAN-OG-3127 and RAN-OG-3 128 will close OG-FCV-11, Off Gas to Stack Isolation, at the stack and, Delay Pipe Solenoid Drain to Radwaste Bypass, OG-3 under the following conditions:

a. When the AOG dryer skid and adsorber bed bypass valves OG- 145 or OG- 146 are closed and either radiation monitor has a Hi-Hi trip signal present for 30 minutes, or either radiation monitor downscale alarm is present or power switch in OFF for 30 minutes.

b. When the AOG dryer skid and adsorber bed bypass valves OG-145 and OG-146 are open and either radiation monitor has a Hi-Hi trip signal present for 2 minutes, or either radiation monitor downscale alarm is present or power switch in OFF for 2 minutes.

4. High radiation (3 x N) sensed in steam tunnel from main steam lines:

a. will trip the mechanical vacuum pump,

b. close vacuum pump suction valve AE-FCV-35,

c. trip steam packing exhausters,

d. close steam packing exhauster discharge valves AE-l2A/B.

OP 2150 Rev. 27 Page 6 of 61 LPC #I

5. PS-OG-1403, which monitors AOG inlet pressure, will close AS-FCV-36, AS-FCV-36A and AS-FCV-37 on high pressure (4 psig).

The following alarms are associated with the air evacuation and off gas systems:

a. SJAE off gas recorder 17-152 on CRP 9-2 will annunciate AEOG RAD HI at 0.1 6 Ci/sec and AEOG RAD HI-HI at 1.5 Ci/sec on CRP 9-3.

b. The SJAE monitors 17-15OAA3 on the off gas sample chamber also provide a one-out-of-two downscale annunciator.

C. AOG radiation monitors RAN-OG-3 127/3128 2 minute and 30 minute timer start will annunciate AOG OUT RAD HI-HI TIMER START on CRP 9-50.

d. TS-l9C/D will annunciate high AOG inlet line, AOG-100, temperature at 375°F.

e. PS-21F/H will annunciate high AOG inlet line, AOG-100, pressure at 7.5 psig.

f. PS-OG-1403 will annunciate high AOG inlet pressure at 2.5 psig.

g. PS-31 and PS-30 will annunciate steam air ejector inlet pressure low and high at 95 psig and 150 psig respectively.

The shutdown iodine filter, installed on the discharge of the mechanical vacuum pump and the steam packing exhauster, provides the ability to route the common discharge through the filter to its discharge to the stack. The system consists of an enclosure housing a demister, heater, prefilter, and charcoal filter. To ensure proper operation of the filter, periodic draining during plant operation is necessary.

An inlet pressure sensor downstream of the inlet isolation valve provides both pressure indication at Rack 27 and over pressure protection by closing the isolation valves and opening the bypass valve. A hydrogen detection probe located in the discharge pipe provides indication at Rack 27 of the % of lower explosive limit (LEL) of hydrogen in the piping. Concentrations greater than 20% of LEL sounds an alarm in the Control Room. Inlet and outlet temperatures can be read on the filter enclosure. Inlet temperature is also available on a digital readout on the filter control panel at Rack 27.

Control switches for the three valves and for the filter heater are located on Rack 27. If these switches are in the REMOTE position, then the filter can be placed in or out of service by the shutdown iodine filter control switch on CRP 9-23.

Liquid drainage from the unit and its inlet piping extends from the SJAE room to the mechanical vacuum pump room through a drain trap to the atmospheric drain tank. A gauge glass indicates water level in the trap and its inlet piping.

OP 2150 Rev. 27 Page 7 of 61

ATTACHMENTS

1. Appendix A Advanced Off Gas System Valve Lineup

2. Appendix B AOG Sample Lineup

3. Appendix C Stack Lineup

4. Appendix D AOG Drain Pit Closeout

5. Appendix E OG-5 16AB Operating Guidelines

6. VYOPF 2150.01 AOG and Air Evacuation Startup Checklist REFERENCES AND COMMITMENTS

1. Technical Specifications and Site Documents

a. TS Section(s) 1.0, 3.2

b. TRM Section(s) - None

c. ODCM Section(s) 3/4.1, 3/4.3, 314.6

d. UFSAR Sections 7.12 and 9.4

e. Offsite Dose Calculation Manual f Tech. Spec. Proposed Change Number 78 (FVY 84-6), Revised Vermont Yankee Radiological Effluent Technical Specifications (RETS), Dated 1/23/84

g. Tech. Spec. Amendment No. 193, RETS

2. Codes, Standards, and Regulations

a. None

3. Commitments

a. ER960237-02, Revise OP 2150 per Recs. 2 and 3; RE: Manual Bypass Line Startup Bypass Valves PORC Review and Plant Manager Approval

b. VYCES94018OP1, 10CFR50.59 Safety Evaluation For AOG Operation with Increased Air Leakage C. ER 980131, Online Recombiner Shift to Standby

d. NRC Inspection, INS9605

4. Supplemental References

a. AOG DWG, A-7 19 Series (P&ID, Flow, Elementary Diagram)

b. DWG 191156, Main and Auxiliary Steam C. DWG 191157, Condensate, Feedwater and Air Evacuation

d. DWG 191162, Misc. System (Stack Section)

e. DWG 191263, Off Gas Sampling and Radiation Monitoring

f. DWG 33600 A:207,208,209,210,211,212,213,214,216, and 217

g. DWG VY-E-75-001

h. MSA-Shutdown Iodine Filter Unit - Instruction Manual

1. SYS ENG 97-48, Operate SJAE at Design Pressure 120 PSIG

j. OPVY 98-71REiG98-31,Guidance/justification for Operation of AOG System in Bypass Mode OP 2 150 Rev. 27 Page 8 of 61

k. AP 0009, Event Reports

1. OP 0105, Reactor Operations

m. AP 0 155, Current System Valve and Breaker Lineup and Identification

n. OP 21 13, Main and Auxiliary Steam

0. RP 2170, Condensate System

p. OP 2185, CondensateDemineralized Water Transfer System

q. RP 2188, Advanced Off Gas Closed Cooling Water

r. OT 3 120, Condenser High Back Pressure

s. AP 6807, Collection, Temporary Storage and Retrieval of QA Records

t. PP 7603, Environmental Program PRECAUTIONS/LIMITATlONS

1. Ensure there is condensate flow through the recombiner off gas condenser prior to admitting steam to the recombiner trains.

2. Exercise care to prevent entry of any moisture into the guard beds and charcoal adsorbers.

3. Since radioactive off gas is circulating through the AOG system, exercise appropriate radiation safety techniques.

4. Do not run the mechanical vacuum pump:

a. without sealing water,

b. above 5% reactor thermal power (75 MWT),

C. with the RMS in RUN

5. Ensure there is condensate flow through the SJAE intercondenser before admitting steam.

6. Do not exceed 10 inches of water differential pressure across the stack filters as read locally (the "A" stack filter element has been removed).

7. Ensure that the standby steam packing exhauster (SPE) discharge valve AE-l2A(B) is closed to prevent back flow to the gland exhaust condenser.

8. If the control switch on CRP 9-6 for OG-516A(B), Ejector Suction Press Control A(B),

has been placed in the CLOSE position or a system trip signal applied, then the control switch must be placed in the OPEN position, the trip signal cleared and, on CRP 9-50, the Trip Reset pushbuttons depressed before the controller will be functional. When the plant is shut down, the trip signal is due to low steam pressure.

9. The Radiation Protection Department must be notified of system changes which have a potential to change area radiation levels to ensure appropriate surveys are initiated.

OP 2150 Rev. 27 Page 9 of 61

10. Two bypass lines are installed around the dryer and adsorber trains. The dryerladsorber subsystem may be bypassed if temporarily unavailable during startup or normal reactor operation provided releases are within the limits of 10CFR2O. Prior to this mode of operation, the B stack filter must be placed in service and the A stack filter isolated, because there are elements installed in the B Stack Filter but not in the A Filter. Use of either of the bypass lines requires off gas be exhausted through the recombiner/condenser subsystems. (INS9605, ER960237-02)

a. The line with AOG BYPASS OG-145 and OG-146 uses FE-OG-1805 to measure off gas flow. This line is monitored for Noble Gas Activity between the charcoal bed system and the plant stack. Effluent releases via this pathway for more than 7 days requires special reporting per the Offsite Dose Calculation Manual.

b. The line with OG-551 and 06-573, Dryer Adsorber Train Bypass, uses FE-OG-1302 to measure off gas flow. This line bypasses the Noble Gas Activity Monitor discussed in T/S Table 3.2.4 and ODCM Table 3.1.2. Effluent releases via this pathway may continue for a period of up to 7 days provided that at least one of the stack monitoring systems is operable and off gas system temperature and pressure are measured continuously per T/S Table 3.2.4 Note 1 and ODCM Table 3.1.2 Note 2. This procedure does not direct the use of this bypass line.

11. When transferring power supplies from MCC-1 1C to MCC-lOC, ATS-IF-1 momentarily deenergizes. The deenergization of this transfer switch may cause the on line AOG recombiner to swap from OPERATE to STANDBY. To prevent the unwanted recombiner swap, place the affected recombiner to MANUAL prior to transferring power supplies. (ER 980 131)

12. During power operation with steady state SJAE off gas monitor readings, the manual purge valve, OGS-134, may be opened to determine monitor background. It will be opened for periods not to exceed 1 minute and only at the request of the Chemistry Manager.

13. When the off gas radiation level at the sample chamber shows an unexplained increase of 25% or 5000 pCi/sec (whichever is greater), during steady state operation, (normal being the nominal value for that day), a reactor coolant sample for iodine and off gas sample shall be drawn.

14. If gland exhaust contribution to stack gas release is excessive, then place the shutdown iodine filter into service.

15. If the delay pipehystem outlet flow exceeds 30 scfm as indicated on FI-2002/2004, then initiate corrective action to determine its cause and effect repairs prior to exceeding 100 scfm.

OP 2150 Rev. 27 Page 10 of 61

16. Steam jet air ejector effluent shall not be routinely discharged unless it is processed through the AOG system. During plant startup when bypass operation facilitates bringing the system on line and in operational situations where there are multiple train failures, the system may be bypassed with Shift Manager approval provided the applicable requirements of T/S Table 3.2.4 and ODCM Table 3.1.2 are met.

PREREQUISITES

1. Local system valve positioned per appendices A, B, C, and D.

2. Power supplies available:

a. 480 volt MCC-1OC and 11C

b. Power Distribution and Control Center A and B C. 120/208 volt lighting Panel 1P

d. 120/208 volt power Panel PP1

e. 480 V MCC 7B, 9C, 10B

f. 120 V AC LP-1AE Ckt 7 Seal Tank Valves

g. 120 V IAC Ckt 12 Recorders

h. 120 V IAC Ckt 53, CRP 9-50 Train C Instruments

i. 120 V IAC Ckt 54, CRP 9-50 Train B Instruments

j. 120 V IAC Ckt 60, PCV-OG-516B Control Power

k. 120 V VAC Ckt 4 Timer and Ckt 5 Solenoid Valves

1. 24 V DC Bus A and B Ckt 6 Radiation Monitor

m. 120 V AC DP-9 Ckt 30 Drain Valves

n. 120/208 CRP 9-46 Ckt 3, 16,30 and 58

0. 125 V DC DC2C Ckt 9, Annunciator Power Pa IP1 Ckt 1, Misc. AOV's Indication

4. IPl Ckt 3, Misc. Equip Control Power/Indication

r. VAC-A Ckt 1, PCV-OG-516A Control Power S. VAC-A Ckt 5, FCV-108-11, SE-107-3, FCV-101-36,36A and 37 Control Power

t. VAC-A Ckt 21, C W 9-50 Train A Instruments U. AC-DP9 Ckt 3, TIS-102-19C and 19D Power

3. Advanced off gas closed cooling water system in operation.

4. Instrument air system in service.

5. Demineralized water system in operation.

6. Condensate system in operation.

7. Demineralized water reservoirs filled 60-77 inches.

8. Refrigeration equipment lubricated and charged with freon.

9. Vacuum pump seal water system filled with demineralized water.

OP 2 150 Rev. 27 Page 1 1 of 61

10. Dryer seal water system filled with demineralized water.

11. TBCCW available to main condenser vacuum pump seal water cooler.

12. Main steam line radiation detectors in operation and reset.

13. Stack and off gas radiation monitors in operation and reset.

14. Filter heater energized from MCC 10B and its control panel circuit breaker closed.

15. Shutdown iodine filter control panel energized.

OP 2150 Rev. 27 Page 12 of 61

W. OG-501A(B), Vacuum Pump Bypass, Controller - Manual to Auto NOTE This section is written for OG-501AYVacuum Pump Bypass. For OG-501BYVacuum Pump Bypass, use component numbers in Darenthesis,

1. Adjust setpoint, on VLV CONTROLLER FOR PCV-OG-501A(B),

PC-OG-11OA(B), using knurled knob on controller until the hairline is at a pressure equal to the measured pressure as indicated by the movable red pointer.

2. Place PC-OG-llOlA(B), VLV CONTROLLER FOR PCV-OG-501A(B) to AUTO.

X. IG-SOlA(B) Vacuum Pump Bypass, Controller - Auto to Manual NOTES e This section is written for OG-501A, Vacuum Pump Bypass.

For OG-501BYuse component numbers in parenthesis.

e No balancing is required. Valve will remain in the same position until adjusted.

1. Place VLV CONTROLLER FOR PCV-OG-501A(B), PC-OG-lOlA(B) to M.

Y. OG-516, Ejector Suction Press Control A(B), Valve Transfer I NOTES e This section is written for transfer from OG-5 16B, Ejector Suction Press Control B to OG-5 16A. For transfer from OG-516A to OG-5 16B use component numbers in parenthesis.

e Appendix E provides Operating Guidelines for OG-5 16A/B.

1. Verify that AS-FCV-2A(B), After (2nd Stage) Air Ejector Steam Supply, is open.

2. Verify that OG-516A(B), Ejector Suction Press Control A(B), is closed.

3. OPEN AS-FCV-lA(B), Inter (1st stage) Air Ejector Steam Supply.

4. Note OG-5 16B(A), Ejector Suction Press Control B(A), valve position.

OP 2150 Rev. 27 Page 43 of 61

5. CLOSE OG-5 16B(A), Ejector Suction Press Control B(A), (both OG-5 16A and OG-5 16B are now closed). (CRP 9-50)

6. Place OG-516B(A), Ejector Suction Press Control B(A), control switch to CLOSE. (CRP 9-6)

7. Place OG-516A(B), Ejector Suction Press Control A(B), control switch to OPEN.

(CRP 9-6)

8. Depress OG-5 16A(B), Ejector Suction Press Control A(B), RESET pushbutton, then immediately proceed to next step.

0 Verify RESET pushbutton light illuminates.

9. Slowly OPEN OG-516A(B), Ejector Suction Press Control A(B), and adjust so that the valve position is equal to the valve position determined in Step 4.

10. CLOSE AS-FCV-lB(A), Inter (1st stage) Air Ejector Steam Supply.

OP 2150 Rev. 27 Page 44 of 61

JPM - 27601 Rev. 1,10/02 Page 1 of 4 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET

Title:

Respond to Hi SW Strainer AP Failure Mode: N/A

Reference:

Alarm Response Sheet 6-A-6 Task Number: 2767040104 Task Performance: AO/RO/SRO - RO/SRO - SRO Only A 0 Only X Sequence Critical: Yes - No 3 Time Critical: Yes - No 3 Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation X Performance -Discuss -

Setting: Classroom - Simulator - Plant 2 Performance Expected Completion Time: 10 minutes Evaluation Results:

Performance: PASS - FAIL - Time Required:

Prepared by: S//f&

Reviewed by:

SRO LicksedlCertified Reviewer Approved by:

&L-M/&

Y Superintendent Operations Trainingi&

m+ Date

JPM - 27601 Rev. 1, 10/02 Page 2 of 4 Directions: Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsatl' classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "Do you understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Plant and you are to simulate the actions.

You are requested to "talk throueh" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions: Normal Rx operation, 90% power. Alarm 6-A-6, SERV WTR STRN A AP HI, has actuated Initiating:Cues: The CRS directs you to respond to the "A" SW high AP alarm using Alarm Response Sheet 6-A-6 Task Standards: SW strainer "A" bypass valve is throttled open and the strainer is in continuous backwash.

Required Materials: Alarm Response Sheet 6-A-6 SERV WTR STRN A AP HI

JPM - 27601 Rev. 1, 10/02 Page 3 of 4 Evaluation Performance Steps TIME START:

I

~~

NOTE: All actions are performed at the intake structure unless otherwise indicated.

~

SATNNSAT Step 1: Obtain Alarm Response Sheet 6-A-6.

Standard: ARS 6-A-6 obtained and reviewed.

SATAJNSAT SteD 2: Check SW pressure to ensure system demands are satisfied.

Standard: Operator asks RO to check SW discharge pressure gauge and determine if pressure is satisfactory.

Interim Cue: SW header pressure reads slightly below NORMAL but system demands are currently being met.

SATAJNSAT SteD 3: Check local AP indication.

Standard: Operator checks local AP gauge at intake structure, DP1-104-36A.

Interim Cue: Inform operator it reads 9 psid.

SATAJNSAT *Step 4: Place the strainer in continuous backwash Standard: Operator places "A" SW strainer in "continuous".

~~

Interim Cue: Local control switch is in continuous. Annunciator 6-A-6 remains illuminated.

JPM - 27601 Rev. 1, 10/02 Page 4 of 4 Evaluation Performance Steps SATNNSAT *Step 5: Flush strainer through the drain.

Standard: Operator flushes strainer through the drain by opening valve SP70-1AX.

~

Interim Cue: Valve turns in counter-clockwise direction until resistance is felt.

SATIUNSAT *Step 6: Crack open strainer bypass valve.

Standard: Operator cracks open strainer Abypass valve, V70-14B.

Interim Cue: Handwheel turns in the counter-clockwise direction.

SATNNSAT Ster, 7: Refer to ON 3148, Loss of Service Water Standard: Operator informs CRS to refer to ON 3 148.

Interim Cue: Acknowledge direction.

TIME FINISH:

Terminating Cue: Strainer A bypass valve is cracked open and strainer is in continuous backwash.

Evaluators Comments:

System: 295018 WAs: AA1.03 Ability to operate and or monitor the following as they apply to a partial or complete loss of component cooling water Affected systems so as to isolate damaged portions (CFR 41.7 / 45.6)

RO 3.3 SRO 3.4

JI'M- 27601 Handout Rev. 1, 10/02 Page 1 of 1 EXAMINEE HANDOUT Initial Conditions: Normal Rx operation, 90% power. Alarm 6-A-6, SERV WTR STRN A AP HI, has actuated Initiatinp Cues: The CRS directs you to respond to the "A"SW high AP alarm using Alarm Response Sheet 6-A-6

ALARM RESPONSE SHEET 6-A-6 I WATER Page 1 of 1 Rev. 3 SERV WTR STRN A AP HI Issued 03/29/95 Causes : Setpoints: Actuating Devices:

1. Failure of the auto backwash 6 psid DPR-104-36A1 cycle.

2. Strainer plugged.

3. Heavy System demand.

References:

CWD-74 G-191159 sh.1 ON 3148 Confirmation:

1. Local AP indication at intake structure.

Automatic Actions:

None Operator Actions:

1. Check SW pressure indication to ensure that system demands are satisfied. Quickly crack open a strainer bypass valve if necessary.

2. Check AP indication locally and place the strainer in continuous if high.

3. If necessary, flush the strainer through drain.

4. If the alarm cannot be cleared, crack open strainer bypass valve and allow the strainer to continuously backwash.

5. Refer to ON 3148, Loss of Service Water.

I

JFM-2 1202F Rev. 7, 10/02 Page 1 of 7 VERMONT YANKEE JOB PERFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Startup the "A" RPS MG Set Failure Mode: Failure of Output Voltage to Reach 120 VAC

Reference:

OP 2134, "Reactor Protection System,"

Task Number: 2127040104 Task Performance: AO/RO/SRO - RO/SRO - SRO Only - A 0 Only X Sequence Critical: Yes - No 3 Time Critical: Yes - No Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation X Performance -Discuss -

Setting: Classroom - Simulator - Plant Performance Expected Completion Time: 15 minutes Evaluation Results:

Performance: PASS - FAIL, - Time Required:

Approved by:

SRO LgensedKertified Reviewer L M z Sup%rintendent Operations Training

d4.3 Date Date

JPM-2 1202F Rev. 7, 10102 Page 2 of 7 Directions:

Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step. If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

After providing the initiating cue, ask the operator "DOyou understand the task?"

Read to the person being evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Plant and you are to simulate all actions.

You are requested to "talk throwh" the procedure, stating the parameters you are verifjrlng or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

0 The "A" RPS MG set is being returned to service after brush replacement.

0 There is an Operator waiting in the Control Room to assist you.

0 Maintenance is not available to assist you.

Initiatinp Cues:

The CRS directs you to startup the "A" RPS MG set per OP 2134 Section A. Inform the CRS when the MG set is ready to be placed in service.

Task Standards:

0 "A" RPS M/G Set running, producing 118*1 volts.

e "A" RPS M/G Set output breaker shut.

0 Power Panels A-1 and A-2 breakers shut.

Reauired Materials:

OP 2134, "Reactor Protection System" (latest revision)

JPM-2 1202F Rev. 7, 10/02 Page 3 of 7 Evaluation Performance Steps TIME START:

SATKJNSAT Step 1: Obtain Procedure, review administrative limits, precautions and prerequisites Standard: OP 2134 obtained, administrative limits, precautions and prerequisites reviewed.

Interim Cue: If asked, all prerequisites have been met.

SATKJNSAT Step 2: At CRP 9-15:

a. RPS "A" Bus NormaYAlt selector switch in either ALT or OFF

b. "A" system power supply circuit breaker SA-CB1A is ON C. The two scram test switches channels Al/A2 test 5A-S2A/C are positioned to normal Standard: Contacts Control Room and verifies that all switches and breakers are properly positioned Interim Cue: When requested, inform Operator that OP 2134 Section A step 1 has been verified.

SATKJNSAT Step 3: Ensure That Power is Available to the M/G Set From MCC-8A Standard: Contacts Control Room and requests verification that power is available to the M/G Set f?om MCC-8A.

Operator may go to the switchgear room and locally verify MCC 8A RPS power available.

Interim Cue: When requested, inform Operator that power is available to RPS M/G set "A" SATKJNSAT Step 4: Ensure M/G Set Generator Output Breaker on the local panel is OFF (MG 3-1A)

Standard: Checks position of MG Output Breaker, observes breaker in the OFF (Down) position Interim Cue: When checked, inform Operator that breaker is in the OFF (Down) position.

JPM-2 1202F Rev. 7, 10/02 Page 4 of 7 Evaluation Performance Steps SAT/UNSAT Step 5: Ensure the Circuit Breakers on RPS Power Protection Panels A1 and A2 are OFF Standard: Checks position of the RPS Power Protection Panel breakers, observes breakers in the OFF (Down) position Interim Cue: When checked, inform Operator that breakers are in the OFF (Down) position.

SATKJNSAT *Step 6: Depress the Motor ON Pushbutton on local control panel to start the drive motor Standard: Simulates starting the "A" RPS MG Set by depressing the Motor ON pushbutton. Verifies that "Motor On" red light is ON, and that MG Set is starting and coming up to speed Interim Cue: When simulated, inform Operator that the pushbutton has been depressed and the "Motor On" red light is ON. The MG Set has started and is coming up to speed.

SATKJNSAT Step 7: When the M/G Set is at Operating Speed Check the Output Voltage is 118 f 1 Volt Standard: Checks MG Set output voltage on local panel "A-C Volts" meter after MG Set reaches normal operating speed Interim Cue: When checked, inform Operator that output voltage indication has not increased and presently indicates 0 volts.

SATRJNSAT *Step 8: If the Output Voltape Does not Approach 118 f 1, Depress "M~otorOn" Pushbutton Again to Reset the Voltage Repulator Standard: Operator depresses the "Motor On" pushbutton a second time Interim Cue: Inform the operator that output voltage is now 116 volts.

SATKJNSAT *Step 9: Adiust Output voltape Adiust Knob to Achieve f 118 Volts Standard: Operator rotates the Voltage Adjust knob in the clockwise direction to raise W G output voltage

JPM-2 1202F Rev. 7, 10/02 Page 5 of 7 Evaluation Performance Steps Interim Cue: As the Operator rotates the Voltage Adjust Knob inform the Operator that output voltage is now indicating 118 volts.

SATKJNSAT *Step 10: Close the M/G Set Generator Output Breaker Standard: Simulates positioning the output breaker to the CLOSED (Up) position Interim Cue: When simulated, inform Operator that the breaker is in the CLOSED (Up) position.

SATKJNSAT Step 11: If Maintenance is available check M/G Output of 118 +/- 1 volts as read on the line side of the molded case breaker in the RPS Power Protection Panel PPP-A-1 as read using a portable calibrated meter Standard: Not Applicable Given in Initial Conditions Interim Cue: If asked Maintenance is not available SATKJNSAT Step 12: At the RPS Power Protection Panel PPP-A-1 perform the following.

a. Verify POWER IN Lamp is ON

b.

Position Panel Output Breaker to OFF (to reset it)

c.

Protection Panel Output Breaker to ON (to re-enerpize it)

d. Check that the POWER OUT lamp on RPS Protection Panel PPP-A-1 is LIT Standard: a. Checks "Power In, Motor Gen" red light ON on Panel A-1

b. Simulates placing breaker in OFF

c. Simulates placing breaker in ON

d. Checks that the POWER OUT lamp on PPP-A-1 is LIT

JPM-2 1202F Rev. 7, 10/02 Page 6 of 7 Evaluation Performance Steps Interim Cue: When checked, inform Operator that:

a. Power In, Motor Gent' red light ON

b. When simulated placing breaker in OFF, inform Operator that breaker is in the OFF (Down) position

c. When simulates placing breaker in ON, inform Operator that breaker is in the ON (Up) position

d. When checked, inform Operator that the POWER OUT lamp on PPP-A-1 is LIT.

SATNNSAT Step 13: At RPS Power Protection Panel PPP-A-2 Derform the following

a. Verifv POWER IN lamp is ON

b.

Position Panel Output Breaker to OFF (to reset it)

C.

Position Panel Breaker to ON (to re-enerpize it)

d. Check that the POWER OUT lamp on Protection Panel PPP-A-2 is LIT Standard:

a. Checks "Power In" light is ON

b. Simulates placing breaker to the OFF position C. Simulates placing breaker to the ON position

d. When simulated, inform Operator that breaker is in the ON (Up) position

e. Checks that the POWER OUT lamp on PPP-A-1 is LIT Interim Cue: When checked, inform Operator that the:

a. The "Power In" lamp on is ON

b. The breaker is in the OFF position

c. The breaker is in the ON Position

d. The POWER OUT lamp on PPP-A-2 is LIT

JPM-2 1202F Rev. 7 , 10102 Page 7 of 7 Evaluation Performance Steps SATKJNSAT Step 14: Inform CRS that the A RPS MG Set is ready to be placed in service Standard: Makes report to CRS

~~~

Interim Cue: Acknowledge report as CRS, and inform Operator that another operator will place the MG Set in service TIME FINISH:

Terminating Cue: A RPS MG Set started and ready to be placed in service (through Step A.12 of OP 2134)

Evaluators Comments:

System: A1.O1 Ability to predict and/or monitor changes in parameters associated with operating the REACTOR PROTECTION SYSTEM controls including:

(CFR: 41.5 / 45.5)

RPS motor-generator output voltage RO 2.8 SRO 2.9 System Generic K/As:

JPM-21202 Handout Rev. 10 10/02 Page 1 of 1 EXAMINEE HANDOUT Initial Conditions:

0 The "A"RPS MG set is being returned to service after brush replacement.

0 There is an Operator waiting in the Control Room to assist you.

0 Maintenance is not available to assist you Initiatinp Cues:

The CRS directs you to startup the "A"RPS MG set per OP 2134 Section A. Inform the CRS when the MG set is ready to be placed in service.

VERMONT YANKEE NUCLEAR POWER STATION OPERATING PROCEDURE OP 2134 REVISION 16 REACTOR PROTECTION SYSTEM USE CLASSIFICATION: REFERENCE Effective LPC No. Date Affected Pages 1 I 10/11/00 11 & 12 of 12 I I I

2 10/05/02 App. A Pg 1 of 1 I 3 I I

10/16/02 II 9 o f 12 I 4 I 10/23/02 I 2,9,12 & ADDED 12A of 12 1 1 Imdementation Statement: N/A I Issue Date: 03/05/99

Dept. Mgr. Proc. No. O P 2134 PORC Rev. No. 16 Plant Mgr. Issue Date 03/05/99 Review Date 03 / 0 5 / 0 4 REACTOR PROTECTION SYSTEM PURPOSE To provide Operations Department personnel with the necessary guidelines to initially start the Reactor Protection System ( R E ) , recover from a tripped MG set, reset an RPS trip (scram signal), and shift the RPS to an alternate power supply.

The use classification of this procedure is Reference Use.

DISCUSSION Each of the two reactor protection trip systems receives power via a separate bus from an RPS high inertia MG set located in the cable vault room. Trip system A on CRP 9-15 receives power from MG-3-1A and trip system B on CRP 9-17 receives power from MG-3-1B. Each motor is 30 h.p. 240/460V, 3 phase, 60 Hz, locally controlled. Each generator is 10 KW, 0.8 pf/

120V, 1phase, 60 Hz. The M/G sets are operated at 118 +1volts output to provide approximately the same margin (i.e., midpoint) between the Tech. Spec. undervoltage (111 VAC) and the overvoltage (125.5 VAC) setpoints. (ER950370-01)

Alternate power is available to either RPS bus from 480V MCC 8B. The RPS power switches are electrically interlocked to prevent feeding both RPS buses from the alternate source at the same time and to prevent paralleling a motor-generator set output with the alternate supply-A scram can be manually initiated by using the pushbutton switches on CRP 9-5. A scram concurrent with a Group 1isolation may be accomplished by interrupting power to the RPS; i.e., opening the power supply breakers on CRP 9-15 and 9-17 or opening the MG set output breakers in the cable vault, or by placing the scram test switches on CRP 9-15 and CRP 9-17 to the TRIP position.

The RPS can be restored to normal operation by manual operation of the SCRAM RESET switch on CRP 9-5 after a ten second delay and when the conditions that caused the trip or scram have been cleared. The physical positions of the RPS relays may be used to identify individual tripped sensors in a group of sensors monitoring the same variable. A computer printout is also provided to identify each tripped channel.

OF' 2134 Rev. 16 Page 1of 12

When de-energizing either RPS bus, the APRMs will automatically transfer to a loss of normal power (LNP) alternate power source. APRMs associated with RPS Bus A will transfer to the Vital AC source and RPS Bus B will transfer to an instrument AC source. The transfer will be alarmed in the Control Room. For those APRM channels which share LPRM inputs, it is necessary to determine which APRM channels will be de-energzed and then to ensure that an adequate number of LPRM inputs will remain operable in the companion APRM cabinet (Tech Spec Table 3.1.1, Note 5). De-energizing one of the RPS buses will cause a half-scram, a half Group 1isolation, a full Group 3 isolation, and loss of power to the associated APRMs, causing them and their associated LPRMs to be inoperable.

If these LPRMs are the shared inputs to a companion APRM channel, and if this APRM channel already has two or more of the other LPRM inputs bypassed, the companion APRM channel would generate an hop. scram signal, which would result in a full scram. APRMs A and D share their LPRM inputs with each other, as do APRMs C and F. (LER 87-14)

A further concern is to ensure that at least 2 LPRMs per level in the companion APRM channels will remain energzed when power is lost from the RPS bus which is being de-energized.

Loss of either RPS bus will cause a full Group 3 isolation by de-energizing the reactor building vent and refuel floor radiation monitors powered by the respective RPS bus. PCIS Div.

1and Div. 2 are both satisfied as all four radiation monitor high rad trips are wired in series in both divisions. During normal operation, all four contacts in each logic are closed. When one sensor trips high or loses power, it opens one of the four in series contacts in Div. 1and Div. 2 causing a full isolation. The downscale trips are in parallel and require both detectors in one location (one powered by each RPS bus) to go downscale or lose power. The CRP 9-15/17 keylock bypass switches only bypass one high trip at a time in each RPS bus.

A safety limit may have been exceeded if a scram has been accomplished by other than the expected signal. If a safety limit is exceeded, Technical SpecificationsSection 6 specifies the required actions to be taken.

The following instructions are included in this procedure:

A. Startup of an RPS M/G Set ................................................................................................................. 4 B. Placing the RPS Alternate Power Supply in Standby...................................................................... 6 C. Shifting RPS Bus Power Supplies ...................................................................................................... 7 D. Reset of Reactor Protection System Trip - Full Scram .................................................................... 8 E. Shutdown of an RPS M/G Set .......................................................................................................... 10 F. RPS Power Protection Panel Trip ..................................................................................................... 11 G. RPS M/G Set Trip .............................................................................................................................. 12 H. Reset of the Reactor Protection System Trip - Half Scram......................................................... 12A ATTACHMENTS

1. Appendix A RPS Breaker Lineup OP 2134 Rev. 16 Page 2 of 12 LPC #4

REFERENCES

1. Technical Specifications

a. Sections 3.1,3.6,3.10 and 4.1

2. Administrative Limits

a. None

3. Other

a. DWG. G191372 Sh. 5, CWDs 800,80OA, 801

b. EDCR 87-413, APRM/LPRM Power Supply Modification C. ER950370-01, R E MG Voltage Not Set Per New Setpoints Established In PDCR 91-016 per C.A.l, Revise OP 2134 To Include New Setpoints (Reactor Protection)

d. SILO292S2, RE: Inadvertent Control Rod Withdrawal. Review For Applicability To VY and Make Recommendations As Necessary

e. AP 0155, Current System Valve and Breaker Lineup and Identification

f. OP 2115, Primary Containment g* OP 2117, Standby Gas Treatment

h. OP 2192, HVAC System PRECAUTIONS

1. When shifting to any RPS alternate power supply:

a. a half scram, half Group 1isolation, and a full Group 3 isolation will occur on the system being switched,

b. a full scram can occur under certain LPRM bypass conditions,

c. a Tech. Spec. violation will occur if the two LPRM per level criteria is not maintained,

d. the RB W A C system will trip,

e. the SGT system will start,

f. power will be lost the AEOG radiation monitor,

g. with the noncoincidence jumpers removed, the transfer initiates a full scram,

h. the APRM power source will shift to the LNP alternate power source.

2. Prior to transferring the APRMs back to the RPS power source or de-energzing an RPS bus and causing the APRMs to be powered from their LNP alternate source, it is necessary to analyze APRM/LPRM status to determine if a I scram or full scram will occur (due to shared LPRMs).

OP 2134 Rev. 16 Page 3 of 12

PREREQUISITES

1. Appendix A RPS distribution panel breakers lineup completed.

2. If plant conditions allow, request Maintenance to assist with setting the RPS M/G set output voltage with a calibrated meter if performing procedure section for Startup of an M/G Set or for RPS Power Protection Panel Trip.

PROCEDURE A. Startup of an RPS M/G Set NOTE The following instructions are for MG-3-1A with references for MG-3-1B indicated bv brackets.

J

1. At CRP 9-15 (9-17, check the following:

a. RPS BUS A(B) PWR SUPP SEL switch in either ALT or OFF.

b. SYSTEM A(B) POWER SUPPLY BKR 5A-CBlA(B) is ON.

c. The two scram test switches CHANNEL A1/A2 (Bl/B2) TEST 5A-S2A/C (B/D) are positioned to NORMAL.

2. Ensure that power is available to the M/G set from MCC 8A (9A).

3. Ensure the M/G Set GENERATOR OUTPUT breaker on the local panel is OFF.

4. Ensure the circuit breakers on RPS Power Protection Panels A1 (Bl) and A2 (B2) are OFF.

5. Depress the MOTOR ON pushbutton on the local control panel to start the drive motor.

6. When the M/G set is at operating speed, check the output voltage is 118 rt1 volt.

7. If the output does not approach 118 +1volts, depress the MOTOR ON pushbutton again to reset the voltage regulator.

8. Adjust the output voltage to 118 rtl volts with the voltage adjust knob on the local panel.

9. Close the M/G set GENERATOR OUTPUT breaker.

OP 2134 Rev. 16 Page 4 of 12

NOTES a When plant conditions allow, the M/G set output voltage should be checked and adjusted by use of a calibrated meter.

(ER950370-01) a The RPS Power Protection Panels have an under voltage trip, the panel supply voltage must be restored prior to closure of the panel output breaker.

10. If Maintenance is available, check M/G output is 118 k1 volts as read on the line side of the molded case breaker in R E Power Protection Panel PPP-A-1 (PPP-B-1) as read using a portable calibrated meter. (ER950370-01)

a. Adjust voltage to 118 51 volts as required.

11. At R E Power Protection Panel PPP-A-1 (PPP-B-1) perform the following:

a. Verlfy POWER IN lamp is ON.

b. Position panel output breaker to OFF (to reset it).

c. Position panel output breaker to ON (to re-energze it).

d. Check that the POWER OUT lamp on RPS Power Protection Panel PPP-A-1 (PPP-B-1) is lit.

12. At R E Power Protection Panel PPP-A-2 (PPP-B-2) perform the following:

a. Verify POWER IN lamp is ON.

b. Position panel output breaker to OFF (to reset it).

c. Position panel output breaker to ON (to re-energize it).

d. Check that the POWER OUT lamp on R E Power Protection Panel PPP-A-2(PPP-B-2) is lit.

13. If the R E bus is being supplied by the alternate power supply, refer to section on "Shifting R E Bus Power Supplies" to place the M/G into service.

14. If R E BUS A(B) PWR SUPP SEL switch is in OFF, ensure power is available from the normal supply by checking power available lights on CRP 9-15 (CRP 9-17), then quickly transfer power supply selector switch to NORM.

OP 2134 Rev. 16 Page 5 of 12

PM-20 106 Rev. 10,08/00 Page 1 of 5 VERMONT YANKEE JOB PEPLFORMANCE MEASURE WORKSHEET Task Identification:

Title:

Place Standbv CRD Flow Control Valve in Service

Reference:

ON 3 145. Loss of CRD Regulating Function Task Number: 2007280501 Task Performance: AO/RO/SRO X RO/SRO - SRO Only -

Sequence Critical: Yes - No J Time Critical: Yes - No J Operator Performing Task:

Examiner:

Date of Evaluation:

Activity Code:

Method of Testing: Simulation X Performance -Discuss Setting: Classroom - Simulator - Plant 3 Performance Expected Completion Time: 10 minutes Evaluation Results:

Performance: PASS - FAIL- Time Required:

4 0pe"rations Training Superintendent Date

JPM-20106 Rev. 10,08/00 Page 2 of 5 Directions:

Discuss the information given on this page with the operator being evaluated. Allow time for him to ask questions before beginning Performance of the task. As each performance step is performed, evaluate the performance of that step by circling either "Sat" or "Unsat". Comments are required for any "Unsat" classification. If a step is preceded by an asterisk (*), it is a critical step, If a critical step is skipped or performed unsatisfactorily, then the operator has failed the Job Performance Measure.

M e r providing the initiating cue, ask the operator "DOyou understand the task?"

Read to the person beinp evaluated:

Before starting, I will explain the initial conditions, provide the initiating cues and answer any questions you have.

This JPM will be performed in the Plant and you are to simulate all actions.

You are requested to "talk through" the procedure, stating the parameters you are verifying or checking and the steps you are performing.

Inform me upon completion of this task.

Initial Conditions:

Plant at power.

A mechanical failure of the operating CRD flow control valve has occurred. ON 3 145 has been entered.

Initiatine Cues:

You are the in-plant operator. The CRS directs you to place the Standby CRD FCV in service in accordance with ON 3145 Step 8.

Task Standards:

The Standby CF2D flow control valve in service.

Required Materials:

ON 3145

JPM-20 106 Rev. 10,08/00 Page 3 of 5 Evaluation Performance Steps TIME START:

SATKJNSAT Step 1: Obtain procedure ON 3145 Step 8 Standard: Procedure obtained, Step 8 reviewed.

Interim Cue: If asked, the in service FCV has failed completely shut .

SATKJNSAT Step 2: Shift CRD Flow Controller on CRP 9-5 to MANUAL & Close FCV-3-19A(B)

Standard: Operator requests Control Room Operator to shift the CRD Flow Controller to MANUAL and zero valve position FCV 19AQ3)

Interim Cue: Inform Operator that the CRD Flow Controller has been shifted to MANUAL and FCV-3-19A(B) controller output is zero.

SATNNSAT Step 3: Close inlet and outlet valve to "A" (B) CRD FCV.

Standard: CRD 68A and 69A (68B/69B) valve handles rotated clockwise until valves full shut.

Interim Cue: Handles rotate freely clockwise, valve stems move inward until resistance is felt, and valve handle stops moving.

SAT/UNSAT *Step 4: Select FCV to be placed in service at the Local Valve Selector switch.

Standard: Local Valve Selector switch located behind FCV 19A (19B), and taken to FCV 19B(A)

Interim Cue: The switch handle rotates freely to the FCV-3-19B(A) position.

JPM-20106 Rev. 10, 08/00 Page 4 of 5 Evaluation Performance Stew SATLJNSAT *Step 5: Position local 3-way valve (CRD-126) to FCV to be placed in service.

Standard: CRD-126, located on panel behind CRD flow control valves taken to FCV 19B(A)

Interim Cue: Valve control knob rotates freely until resistance is felt with the pointer at the FCV 19B(A) position.

SATLJNSAT *Step 6: ODen inlet and outlet valve to Standby CRD FCV.

Standard: CRD-68B and 69B (68N69A) handles rotated counter-clockwise until fwll open.

Interim Cue: Valve handles rotate freely counter-clockwise and valve stems move outward until resistance is felt and handle stops moving.

SATKJNSAT Step 7: Notify Control Room to readiust CRD Parameters at CRP 9-5.

Standard: Operator calls Control Room to inform them the alternate FCV has been placed in service and to adjust CRD parameters:

Interim Cue: When operator desires to contact the Control Room, inform him that CRD parameters have been adjusted. If asked, charging header pressure on PI-3-234 is 1450 psig.

JPM-20106 Rev. 10,08/00 Page 5 of 5 TIME FINISH:

Terminating Cue: The Standby CRD FCV is placed in service.

Evaluators Comments:

System: WA's: 201001 A2.02 Ability to (a) predict the impacts of the following on the CONTROL ROD DRIVE HYDRAULIC SYSTEM ;and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those abnormal

. conditions or operations:

(CFR:41.5 / 45.6)

Valve closures RO 3.2 SRO 3.3 Generic WA's:

JPM-20106 Rev. 10,08/00 Page 1 of 1 Student Handout Initial Conditions:

Plant at power.

A mechanical failure of the operating CRD flow control valve has occurred. ON 3 145 has been entered.

Initiatine Cues:

You are the in-plant operator. The CRS directs you to place the Standby CRD FCV in service in accordance with ON 3 145 Step 8.

NOTE A Back-Fill system taps off the seal purge portion of the CRD system. This Back-Fill system provides assurance that the reactor water level reference leg fluid does not become saturated with non-condensible gases. It is a support system for the four reference legs associated with condensing chambers 2-3-3A & 2-3-3B.

When the reference leg backfill system is at a lower pressure than the reactor, such as when the CRD pumps are secured, the reactor water level instrumentation could provide a non-conservative water level signal (signal that is higher than actual). The erroneous indication is attributed to the reference legs draining back through the reference leg backfill system to the CRD hydraulic control units (HCUs). This condition is caused by insufficient back pressure to fully seat the in-line check valves. [INF-2002-006 011

4. IF both CRD pumps are out of service, THEN place the reactor water level reference leg back-fill system in Standby per OP 2 111 .

5. IF a pump tripped or was removed from service due to low suction pressure, THEN check the suction source and the pump suction filters.

6. IF neither pump can be operated due to clogged suction filters THEN proceed as follows:

a. Stop CRD Pump A(B).

b. Isolate CRD suction filters as follows:

1) Close or confirm closed CRD-l59A(B), CRD Pump A(B) Suction Filter Outlet.

2) Close or confirm closed CRD-35A(B), CRD Pump A(B) Suction Filter Inlet.

3) Open or confirm opened CRD-l56A(B), CRD Pump A(B) Suction Filter Vent.

C. Open CRD-l58A(B), CRP Pump A(B) Suction Filter Bypass.

d. Operate the pump only as needed to keep accumulator alarms cleared.

7. IF a high dp is indicated across the drive water filter (DPIS-3-202), THEN place the alternate drive water filter in service per OP 2 111 (CRD System).

ON 3145 Rev. 10 Page 3 of 7 LPC #3

8. IF a CRD pump is operating, but CRD System flow is insufficient or erratic, THEN place the Flow Controller (FIC-3-301) in MANUAL.

NOTE A flow control failure will be indicated by the inability of the flow control station to maintain the desired flow in either the Manual-Remote or Auto mode and may be indicated by the following:

X Cooling water flow indicator (CPR 9-5) abnormally high or low flow (norm 20-30 gpm).

X CRD flow indicator (CRP 9-5) abnormally high or low flow (norm 48-52 gpm +3 gpm for each reactor recirc pump seal purge in service).

X Computer point ID BO13 (CRD Flow) alarm.

X Marked sluggishness or rapid rod motion during manual control.

X Marked increase or decrease in running pump current.

X Oscillation of the reactor recirc inboard seal pressure instruments.

a. IF flow is still erratic, THEN place the alternate CRD flow control valve (FCV) in service as follows:

1) From CRP 9-5, dial the flow controller (FIC-3-301) in MANUAL to zero valve position.

2) Isolate the flow control valve CRD FCV-l9A(B) being removed fi-om service as follows:

a) Close CRD-68A(B), Inlet To CRD FCV-l9A(B).

b) Close CRD-69A(B), Outlet Of CRD FCV-l9A(B).

3) Select CRD FCV-l9A(B) to be placed in service at the Local Valve Selector Switch.

4) Position local 3-way valve CRD-126, Supply Air to FCV, to flow control valve CRD FCV- 19A(B) to be placed into service.

5) For the flow control valve CRD FCV-l9A(B) being placed in service:

a) Open CRD-68A(B), Inlet To CRD FCV-l9A(B).

b) Open CRD-69A(B), Outlet Of CRD FCV-l9A(B).

6) Adjust CRD parameters at CRP 9-5 to normal operating ranges.

ON 3145 Rev. 10 Page 4 of 7

7) If required, throttle CRD36A(B), CRD Pump A(B) Discharge Stop Check, to maintain charging header pressure at 1420-1470 psig (PI-3-234).

(ER20010809-03)

b. If the FCV failure is due to a loss of its electro-pneumatic control, THEN establish manual pneumatic control as follows:

1) Open CRD-63(CRD-64), Emerg Air to CRD FCV-l9A(B).

2) Position CRD-l46A(B), N o d m e r g Air Select to CRD FCV-l9A(B), f'rom the ELECTRO-PNEUMATIC to MANUAL position.

3) Regulate PCV-133, Emerg Air Control Valve to FCVs, to operate the selected FCV at the desired flow condition by regulating air diaphragm pressure between 3- 15 psig as indicated on PI-3-2 10.

C. When the CRD Flow Controller has been restored, then restore to electro-pneumatic control as follows:

1) Close the In-service FCV by setting PCV-133, Emerg Air Control Valve to FCV, to 0 psig.

2) Position CRD-l46A(B), N o d E m e r g Air Select to CRD FCV-l9A(B), from MANUAL, to ELECTRO-PNEUMATIC position.

3) Close CRD-63 (CRD-64), Emerg Air to CRD FCV-l9A(B).

4) Balance the CRD Flow Controller and restore to BAL per OP 3 145 or OP 2 111.

5) Restore CRD system parameters per OP 2 111.

d. If flow becomes stable, return the CRD Flow Controller to BAL or AUTO.

e. IF the flow control valve malfunction is due to loss of instrument air, THEN take manual control of the inservice valve with its manual-override handwheel.

9. IF drive water pressure cannot be adjusted, THEN proceed as follows:

NOTE A drive station failure may be indicated by the inability to adjust drive water pressure.

CAUTION Do not attempt any rod movement before adjustment of drive water pressure is complete.

a. Suspend rod movements until required drive pressure is obtained (normal 250-275 psig above reactor pressure).

b. Establish communications between the Control Room and drive water station.

C. Close CRD-82, Inlet to CRD PCV-20.

d. Throttle CRD-21 Bypass to CRD PCV-20, to obtain required drive water pressure as indicated on DPI-3-303 (CRP 9-5).

ON 3145 Rev. 10 Page 5 of 7 LPC #2

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