LR-N08-0123, Hope Creek - License Conditions 2.C.(21), 2.C.(22)2.g and 2.C.(22)3

Hope Creek - License Conditions 2.C.(21), 2.C.(22)2.g and 2.C.(22)3

ML081480508
Person / Time
Site:	Hope Creek
Issue date:	05/19/2008
From:	Keenan J Public Service Enterprise Group
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
LR-N08-0123
Download: ML081480508 (194)

Text

PSEG Nuclear LLC PO. Box 236,, Hancocks Bridge, NJ 08038-0236 0 PSEG Nuclear L.L. C.LR-N08-0123 May 19, 2008 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Hope Creek Generating Station Facility Operating License No. NPF-57 NRC Docket No. 50-354

Subject:

License Conditions 2.C.(21), 2.C.(22)2.g and 2.C.(22)3

Reference:

1) Letter from Jeffrie Keenan (PSEG Nuclear LLC) to USNRC, May 8, 2008 This letter provides information in accordance with the subject License Conditions.

License Condition 2.C.(21) requires: PSEG Nuclear LLC shall provide the Level 1 main steam safety relief valve vibration acceptance criteria to the NRC staff prior to increasing power above 3339 MWt.Attachment 1 to this letter provides the acceptance criteria.License Condition 2.C.(22)2.g requires: PSEG Nuclear LLC shall submit the flow-induced vibration related portions of the EPU startup test procedure to the NRC staff, including methodology for updating the limit curves, prior to initial power ascension above 3339 MWt.PSEG provided a description of the methodology used to develop the main steam line (MSL) strain gage limit curves for power ascension in Reference

1. Based on subsequent discussions with the NRC staff, PSEG will not use scale model test predictions (i.e., bump-up factors) in developing strain gage limit curves.74 LR-N08-0123 May 19, 2008 Page 2 The limit curves provided in Attachment 2 are based on current in-plant strain gage data and the minimum stress ratio calculated from the strain gage data. If required during power ascension, the method for updating the limit curves will follow the approach described below:* Collect in-plant MSL strain gage data.* Calculate the stress ratio at the limiting steam dryer locations (loads will be based on Acoustic Circuit Model (ACM) Rev. 4, and stresses will be determined using the HCGS harmonic domain finite element model methodology)." Generate revised limit curves based on the lowest calculated alternating stress ratio.Biases and uncertainties in the updated limit curves will be those described in Attachment

2. The revised stress ratios will be the most limiting determined by the frequency shift on the loads between plus 10% and minus 10%. In-plant acoustic signal frequencies may change slightly (< 1 Hz) with increased steam flow. While the observed changes have negligible impact on the dryer structure, they can result in an unnecessary challenge to the limit curve. To address the shift of in-plant data, the HCGS limit curves may be shifted to the right or to the left less than or equal to 1 Hz.The limit curve criteria are considered satisfied as long as the signal falls under the shifted limited curve. A similar approach was used during power ascension testing for Vermont Yankee.Attachment 2 contains information proprietary to Continuum Dynamics, Inc. (C.D.I.).C.D.I. requests that the proprietary information in Attachment 2 be withheld from public disclosure in accordance with 10 CFR 2.390(a)(4).

An affidavit supporting this request is included with Attachment

2. A non-proprietary version of the document in Attachment 2 is provided in Attachment 3.License Condition 2.C.(22)3 requires: PSEG Nuclear LLC shall prepare the EPU startup test procedure to include: a. the stress limit curves to be applied for evaluating steam dryer performance;

b. specific hold points and their duration during EPU power ascension;

c. activities to be accomplished during hold points;d. plant parameters to be monitored;

e. inspections and walk downs to be conducted for steam, FW, and condensate systems and components during the hold points;f. methods to be used to trend plant parameters; LR-N08-0123 May 19, 2008 Page 3 g. acceptance criteria for monitoring and trending plant parameters, and conducting the walkdowns and inspections;

h. actions to be taken if acceptance criteria are not satisfied; and i. verification of the completion of commitments and planned actions specified in its application and all supplements to the application in support of the EPU license amendment request pertaining to the steam dryer prior to power increase above 3339 MWt.PSEG Nuclear LLC shall provide the related EPU startup test procedure sections to the NRC staff prior to increasing power above 3339 MWt.Attachment 2 to this letter provides the stress limit curves described in item (a) of the License Condtion.

HCGS procedure HC.OP-FT.ZZ-0004 (Q) provided in Attachment 4 includes the topics required by this License Condition.

The information contained in this letter and attachments is provided to comply with License Conditions.

There are no new regulatory commitments contained in this submittal.

Should you have any questions regarding this submittal, please contact Mr. Paul Duke at 856-339-1466.

Sincerely, nager -Lcensn Attachments (4)1. Safety Relief Valve Level 1 Vibration Acceptance Criteria 2. C.D.I. Technical Note No.07-29P, Revision 2 3. C.D.I. Technical Note No. 07-29NP, Revision 2 4. EPU Startup Test Procedure (HC.OP-FT.ZZ-0004(Q))

cc: S. Collins, Regional Administrator

-NRC Region I J. Lamb, Project Manager -USNRC NRC Senior Resident Inspector

-Hope Creek P. Mulligan, Manager IV, NJBNE LR-N08-0123 ATTACHMENT I Hope Creek Generating Station Facility Operating License NPF-57 Docket No. 50-354 Safety Relief Valve Level 1 Vibration Acceptance Criteria Vibration instrumentation is installed on four of the fourteen Safety Relief Valves (SRVs)so that vibration levels can be monitored during power ascension above the Current Licensed Thermal Power (CLTP). Main steam safety relief valve (SRV) vibration acceptance criteria were developed from detailed finite element analysis of the SRVs.The acceptance criteria are to ensure: " The SRV will not open inadvertently causing leakage," The pilot internals will not sustain wear-related damage to the point of inoperability," The valve body will not sustain damage due to high cycle fatigue, and* The pre-load on the bolts attaching the Solenoid Operated Valve (SOV) to the pilot housing will not relax resulting in loss of instrument air.To supplement the analytical effort, PSEG measured the vibration on the SRVs at current licensed thermal power (CLTP) conditions in the power ascension to 3339 MWt in November 2007. These measurements provide a baseline for comparison of vibration at EPU conditions.

In addition, resonant frequencies of the SRVs as installed in the plant were identified.

The Level 1 vibration acceptance criterion is 1.0 g (peak) at any applicable resonant frequency.

LR-N08-0123 ATTACHMENT 4 Hope Creek Generating Station Facility Operating License NPF-57 Docket No. 50-354 Extended Power Uprate Power Ascension Testing HC.OP-FT.ZZ-0004(Q)

PSEG Internal Use Only PSEG NUCLEAR L.L.C Page I of 1 HC.OP-FT.ZZ-0004(Q)

-Rev. 3 EXTENDED POWER UPRATE POWER ASCENSION TESTING USE CATEGORY II SPONSOR ORGANIZATION:

Hope Creek Operations/Engineering

• Biennial Review Performed:

Yes No ,/ NA* Packages and Affected Document Numbers-incorporated into this revision: CP No._ CP Rev. -AD No. _ Rev No. _ None v"* The following OTSCs were incorporated into this revision:

None REVISION

SUMMARY

The following changes incorporate approved OTSC 2A:* Revised Attachment 11, Table 11-4, Steps 5 through 15 as required to see "DEMAND" as found reading The following changes incorporate approved OTSC 2B* Revised Attachment 11, Table 11-4 by adding Steps 16 through 24 to return to Automatic operation.

Other changes: 9 Attachment 3, Steps 9.4 and 9.5 -Deleted "prior to operation above CLTP"* To compensate for failed Accelerometers, the following changes were made to Attachment 4, Table 4-1: 1. Renamed existing heading from Acceptance Criteria (g-rms) to Piping Acceptance Criteria (g-rms).2. Deleted SRV Channel 32 from Piping Acceptance Criteria (g-rms) table.3. Added new section to Table 4-1 for SRV Acceptance Criteria (g).4. Added statement to 3.0 Acceptance Criteria for MS Line SRVs for channel 32." Procedure Section 5 -Converted numerous numbered steps to bullets to allow concurrent execution of the steps." Procedure Section 5 -Added PERFORM HC.OP-FT.BB-0001 (Q), Jet Pump Data Collection at multiple power levels. This test is being performed to collect data -There is no requirement or commitment to perform the test.* Attachment 11 -Modified the steps for adjusting RFP flow and data collection." Attachment 11 -Revised Acceptance Criteria for Manual Feedwater flow step changes." Step 2.1.18. -Revised Level 2 definition.

• Inserted NOTE for Step 4.1.5" Revised Prerequisite 4.2.14 to require procedures to be ready for issue (not issued).IMPLEMENTATION REQUIREMENTS Effective Date 5/16/08.None HC.OP-FT.ZZ-0004(Q)

IEXTENDED POWER UPRATE POWER ASCENSION TESTING TABLE OF CONTENTS Section Title Page 1.0 P U R PO S E/SC O PE ..........................................................................................

2 2.0 DEFINITIONS/RESPONSIBILITIES

................................................................

6 3.0 PRECAUTIONS AND LIMITATIONS

.............................................................

12 4.0 TERMINATION CRITERIA & PREREQUISITES

............................................

15 5.0 PROCEDURE

.......................................

........ 31 5.1 Startup to 3005 M W th .........................................................................

31 5.2 Increasing to 3339 M W th ...................................................................

37 5.3 Increasing to 3422 M W th ....................................................................

41 5.4 Increasing to 3506 M W th ....................................................................

44 5.5 Increasing to 3589 MWth ....................................................................

49 5.6 Increasing to 3673 M W th ....................................................................

52 5.7 Increasing to 3723 MWth ..................................

58 5.8 Rem aining at 3723 M W th ....................................................................

62 6 .0 R E C O R D S ....................................................................................................

..69 7.0 R E FE R E N C E S ..............................................................................................

69 ATTACHMENTS Attachment 1, SM/CRS Data and Signature Sheet .............................................................

71 Attachment 2, Test Deficiencies

& Resolutions

....................................................................

74 Attachm ent 3, Dryer Data Collection

....................................................................................

75 Attachment 4, Flow Induced Vibration Data .........................................................................

84 Attachm ent 5, Radiation Surveys .......................................................................................

92 Attachment 6, Turbine Valve Scram Bypass Setpoint Data Collection

...................................

100 Attachm ent 7, Core Perform ance Data ..................................................................................

103 A ttachm ent 8, C hem istry D ata ................................................................................................

106 A ttachm ent 9, M oisture C arryover ..........................................................................................

111 Attachment 10, Feedwater Runout Data Collection

.........................

..... 115 Attachm ent 11, Feedwater Level Changes .............................................................................

120 Attachm ent 12, DEHC Pressure Changes ..............................................................................

165 Attachm ent 13, IRM /APRM Overlap Data ..............................................................................

170 Attachment 14, EPU System Performance

& Monitoring Plans ..............................................

172.Attachment 15, IPA Briefing Worksheet

..................................................................................

173 Attachment 16, Turbine Stop, Bypass and MSIV Valve Testing .............................................

178 Hope Creek Page 1 of 188 Rev. ,3 HC.OP-FT.ZZ-0004(Q)

.1.0 PURPOSE The purpose of this Test Procedure is to confirm acceptable plant performance following EPU-related changes made in Refueling Outage (RF) 14, and for operation at an extended power up-rate (EPU) power level of 3723 MWth in accordance with License Change Request H05-01 and DCP 80048085, EPU Implementation.

Administrative controls for EPU implementation and for the commencement of power ascension activities following RF14 are also provided.This Test Procedure provides step by step guidance and verification for performing Power Ascension Testing requirements for Extended Power Uprate (EPU) conditions.

The test is performed in two parts; 1) during startup and power ascension following RF14 testing several EPU-related BOP changes made, and 2) during power ascension to EPU conditions following the approval of LCR H05-01. The Test Procedure supplements HC.OP-IO.ZZ-0003(Q), Startup from Cold Shutdown to Rated Power and HC.OP-IO.ZZ-0006(Q), Power Changes During Operation, to provide direction to maneuver the plant from initial startup to 3723 MWth (97% LPU), the final target power level.First and foremost is the safety of the reactor, nuclear plant and personnel.

This procedure was written with this specifically in mind, providing the necessary criteria, instructions and precautions to successfully execute the Power Ascension Testing for EPU conditions.

As such, performance of this procedure is considered an Infrequent Plant.Activity (IPA) in accordance with station procedures requiring the highest level of Senior Line Management involvement (Attachment 15).Hope Creek Page 2 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 1.1 Scope This procedure serves to document the plant physical modifications, instrumentation setpoint changes, administrative requirements, and prerequisite testing necessary to startup following EPU-related changes made in RF14, and to implement EPU as well as establish power ascension test acceptance criteria to raise reactor power above 3339 MWth to 3723 MWth.1.1.1. As defined in EPU Project Task Report T1 005: Startup Test Specifications (VTD 430069(002))

and the HCGS Power Ascension Test Plan, this procedure's objective is to:* Maintain control of and knowledge of the reactor coolant chemistry and radiochemistry at extended uprate conditions.

• Monitor radiation levels at extended uprate power conditions to assure that personnel exposures are maintained ALARA, radiation survey maps are accurate, and radiation zones are properly posted.* Measure and evaluate core thermal power and fuel thermal margins to ensure a careful, monitored approach to the next power uprate level.* Monitor feed-water level control system for acceptable reactor water level control and the digital electro-hydraulic control system (DEHC) for proper pressure control.* Confirm acceptable calibration of the feedwater flow elements and Crossflow system following installation of the new HP turbine (RF14)and at uprated power conditions.

Hope Creek Page 3 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 1.1.2. Demonstrate that affected plant parameters and equipment performance remains within acceptable limits as power is increased from 3339 MWth to 3723 MWth.1.1.3. Monitor plant system response via EPU System Performance Monitoring

&Analysis Plans (see Attachment 14).1.1.4. Provide Shift Operations personnel clear instructions on testing and operational maneuvers to be performed as power is increased in a step-wise manner to assure safe plant operation.

1.1.5. Provide management reviews and approvals of the test data and the authorization to increase power level in a safe, controlled, step wise manner.1.1.6. Assure that procedures requiring revision to operate at uprated power conditions have been revised as required and are available to plant personnel.

1.1.7. Assure that regulatory commitments have been completed as required to increase power above 3339 MWth. This includes commitments contained within the License Change Request (LCR), correspondence with the NRC as documented in Requests for Additional Information (RAI), and as defined in the NRC issued Safety Evaluation Report (SER). This will be accomplished via the prerequisite section of this procedure.

1.1.8. Verify that training has been completed to meet licensing commitments and provide safe operation of the plant.1.1.9. Document and collect data, including baseline data starting at 3005 MWth (90% of the pre-EPU power level), which will be used to prepare an EPU Power Ascension Test Report to be submitted to the NRC upon completion.

Hope Creek Page 4 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 1.1.10. Discussion

• The EPU Project utilized a generic methodology from General Electric for evaluating plant systems and equipment for operating at uprated power levels. This methodology provided system, program, and equipment task evaluations that identified the acceptability to operate at an increased power level. These task evaluation documents provided input into the testing program which is implemented by this test procedure." The steps contained in this document were a culmination of inputs from numerous sources. The GE Licensing Topical Report (GELTR) required operational tests for systems which have revised performance requirements because of the extended power uprate. A test plan was submitted with LCR H05-01 (Attachment

23) which provided an overview of the tests to be performed.

A review of the original start-up test specifications was completed and tests were selected based on the change resulting from the extended power uprate. Finally, test requirements were added based on Engineering judgment, discussion with plant personnel and Lessons Learned from other plant power uprates.* Test requirements that are satisfied by completion of existing surveillances, calibrations or post modification testing need not be repeated for the purposes of this procedure unless specifically identified in this procedure.

• Plant maneuvers and operation shall be performed in accordance with applicable HCGS Procedures including power changes in accordance with: HC.OP-IO.ZZ-0003(Q), Startup from Cold Shutdown to Rated Power or HC.OP-IO.ZZ-0006(Q), Power Changes During Operation.

• For power ascension activities above 3339 MWth, a Power Ascension Control Center (PACC) is established to support implementing this procedure.

Personnel from various functional areas, together with senior managers, are assigned to provide continuously available resources to address issues that may arise during the performance of this procedure.

Additional peer assessments and reviews will be available, if required.The PACC may be staffed during certain power ascension testing activities following RF14 (e.g., turbine roll and synchronization, startup level control tuning, turbine valve testing, 90% level and pressure step changes, etc.) as determined by the Test Manager.Hope Creek Page 5 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.2.0 DEFINITIONSIRESPONSIBILITIES

2.1 Definitions

2.1.1. CLTP -The pre-EPU licensed thermal power level of 3339 MWth.2.1.2. CPPU -Constant Pressure Power Uprate -Operating at increased steam and feedwater flows without increasing maximum reactor recirculation flow or reactor vessel operating pressure.2.1.3. Decay ratio -is a term used to describe the amplitude dampening of an oscillatory signal. Decay ratio is less than 0.25 if there are no more than two positive peaks.IF more than two positive peaks exist, THEN decay ratio must be calculated as follows:* Draw baseline through inflection points of trace.* Amplitudes of peaks should be measured from this reference line, e.g., AO, Al, A2, A3, and A4 as shown in Figure below.0 Calculate ratios of amplitudes between successive peaks of same polarity, e.g., A2/AO, A3/A1, A4/A2.* Decay ratio determined by averaging all ratios determined in previous step, e.g., 0 Decay Ratio = (A2/AO + A3/A1 + A4/A2) I 3.2.1.4. DEHC -Digital Electro-Hydraulic Control -the electrical/mechanical system which controls the turbine control valves and turbine bypass valves based on main steam pressure.

This is the primary reactor and turbine pressure control system.2.1.5. FIV -Flow Induced Vibration Hope Creek Page 6 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 2.1.6. Intrusive Activities

-activities that have the potential to or change parameters associated with reactor power including backwashing condensate prefilters, pump swaps, raising or lowering reactor power, changing reactor pressure, level, etc.2.1.7. LPU -License Power Uprate or 3840 MWth.2.1.8. Non intrusive activities

-activities that do not change any parameters associated with reactor power including data collection, obtaining chemistry samples, etc.2.1.9. OLTP -Original Licensed Thermal Power prior to implementation of Crossflow or 3293 MWth.2.1.10. PACC -Power Ascension Control Center. The PACC will be setup using the Outage Control Center (OCC) process.2.1.11. Power Plateau -a 5% increase in power from 3339 MWth (CLTP) as well as the final target power level. Relative to 3339 MWth (CLTP), the power plateaus for this test are at 3506 MWth (105%), 3673 MWth (110%), and 3723 MWth (111.5%) with the Crossfiow correction factor applied.2.1.12. Power Increment

-a 2.5% increase in power from 3339 MWth (CLTP).Relative to 3339 MWth, the power increments for this test are at 3422 MWth (102.5%) and 3589 MWth (107.5%).

The step from 3673 MWth (110%) to 3723 MWth (111.5%) with the Crossflow correction factor NOT applied is also treated as a Power Increment.

2.1.13. RTP -Rated Thermal Power (3339 MWth prior to EPU implementation or 3840 MWth once EPU is implemented).

2.1.14. RE -Reactor Engineering 2.1.15. TPU -Target Power Uprate or 3723 MWth (111.5% CLTP).2.1.16. IPA -Infrequent Plant Activity as defined by HU-AA-121 1,"Briefings

-Pre-Job, Heightened Level of Awareness, Infrequent Plant Activity and Post-Job Briefings." Hope Creek Page 7 of 188'Rev. 3 HC.OP-FT.ZZ-0004(Q)

W 2.1.17. Level 1 -Criteria associated with plant safety. When a criterion is not met, TERMINATE the test and: " Hold at the most secure point and place the plant in a condition that is judged to be satisfactory and safe, based upon prior testing, reducing power if necessary.

• Follow plant operating procedures, test procedures or the Technical Specifications in the decision of actions to be taken." Generate a notification and pursue resolution of the problem through investigating related adjustments as well as measurement and analytical methods.* Following resolution, repeat the applicable test portion to verify that the Level 1 requirement is satisfied.

0 Hope Creek Page 8 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 2.1.18. Level 2 -Criteria associated with design performance or plant parameters that are not expected to be exceeded while implementing this procedure and are a value that is not immediately adverse to plant or equipment safety.When a criterion is not met, place the test on HOLD and:* Hold at the most secure point and place the plant in a safe condition including reducing power if necessary.

• Generate a notification and pursue resolution of the problem through investigating related adjustments as well as measurement and analytical methods.o Repeat the applicable test portion to verify that the Level 2 requirement is satisfied following the resolution, or the as-found condition is evaluated to be satisfactory As-Is and approved by PORO.2.1.19. Other Acceptance Criteria -Criteria associated with routine pla nt surveillance testing, plant operating procedures, rounds, alarm responses, etc. When this criteria is not met, plant procedures will be followed.

Criteria contained in the EPU System Performance Monitoring

& Analysis Plans not met will be communicated to the Test Team and evaluated as either part of the testing program or corrective action program, as appropriate.

2.2 Responsibilities

2.2.1. Test Director -The Test Director is the head of the Implementation

& Power Ascension Test Team and in this capacity reports to the HCGS Plant Manager. The Test Director is responsible for completion of the Test Plan.This individual works closely with the Project Manager to allocate resources and establish the program and administrative/technical procedures required to support the Power Ascension Test Plan in accordance with corporate commitments, regulatory commitments and project schedule.

The Test Director coordinates and directs all parties participating in this test program.Hope Creek Hope Creek Page 9 of 188 Rv Rev. 3 HC.OP-FT.ZZ-0004(Q) 2.2.2. Test/IPA Manager -Is a member of PSEG Nuclear Management designated by the Plant Manager. The Test Manager has the authority and experience to exercise continuous responsibility for the test program. The Test Manager is required to be in a management position senior to the Shift Manager (SM). The Test Manager shall provide overall line management authority for the safe conduct of this infrequently performed test or evolution.

The'Test Manager does not replace any individual involved in the test or evolution, nor directly supervise the evolution.

The Test/IPA Manager's function is management oversight.

This position will by fulfilled by a lead (dayshift) and backup (evening) individual during power ascension activities.

Additional requirements of this position can be found in HU-AA-1 211. The Test Manager also has the authority to waive optional tests as identified in this procedure.

2.2.3. Shift Manager -The Shift Manager (SM) has the responsibility for the safe operation of the plant at all times. The SM's approval is required prior to performance of any test or power ascension activities and has the authority to stop the test at any time. The SM's approval is also required to continue testing if a test is terminated.

2.2.4. Control Room Supervisor

-the Control Room Supervisor (CRS) provides direction to Licensed Operators and other on-shift Operations personnel involved in the performance of power ascension or test activities.

2.2.5. EPU Implementation

& Test Team -Under the direction of the Team Leader, this team is responsible for the preparation and development of the Test Program and all associated documentation including the test procedure(s), IPA materials, and ITP package. The team will consist of lead individuals in the areas of Operations, Implementation, and Power Ascension.

During testing activities, this team will support the Test Manager in monitoring test activities and results. The Team Leader is a member of PSEG Management and is responsible for the qualifications of the Test Team. During testing activities the Team Leader will work closely with the Test Manager and IPA Coordinator to track progress and ensure successful completion of-the test procedure(s).

Hope Creek Page 10 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 2.2.6. IPA Coordinator

-This position will be fulfilled by the EPU Implementation

&Test Team Operations Lead and is responsible for overall implementation of the test procedure(s).

Specific responsibilities are defined in HU-AA-1211I (Test Coordinator).

This individual will maintain control of all test activities and seek assistance from support departments as necessary.

The IPA Coordinator(s) or their designees will be responsible for signing off steps as completed within this procedure.

The IPA Coordinator shall have the following duties and responsibilities with respect to the activities being controlled by this procedure.

The SM shall not be assigned as this individual.

• Reports test status and significant issues to station management.

• Coordinates the activities requiring completion by this procedure to assure they are completed in a safe and timely manner.* Responsible for assuring the test procedure is updated and maintained current with work and testing activities controlled by this procedure.

• Reviews the exceptions to this procedure and expedites the resolution if exceptions affect power ascension testing." Authorizes the next step in power ascension testing if the test data results meet the acceptance criteria.* May add additional equipment performance monitoring data collection at any time during the performance of this procedure.

• Assures that shift personnel are knowledgeable of test activities being controlled and performed by this procedure." Maintains the Test Deficiency Log (Attachment

2) and approves deficiency resolutions.

Hope Creek Hope Creek Page 11 of 188 Rv Rev. 3 HC.OP-FT.ZZ-0004(Q) 2.2.7. Test Team Members -A qualified individual from either Engineering or a support organization, designated by the project and PSEG Management to perform a lead role in their area of expertise and to work as part of the Power Ascension Control Center. The Test Team Members will have the following responsibilities with respect to the activities being controlled by this procedure.

• The Test Team Member may assist in the development, review and/or presentation of technical aspects of this evolution." Has technical and administrative control of applicable portions of this procedure.

• Maintains a log during test activities and works with members of the PACC.* Supports making changes to the acceptance limits of systems and equipment, if necessary, following an engineering technical evaluation that justifies the change in accordance with CC-AA-309-1 01, Engineering Technical Evaluations.

2.2.8. Operations Support Personnel

-Operations Control Room personnel and auxiliary operators will perform the necessary plant control manipulations to operate various valves, equipment, and systems.3.0 PRECAUTIONS AND LIMITATIONS 3.1 For RF14 power ascension activities, reactor power levels given in this procedure are referenced to 3339 MWth (100% CLTP). Following EPU implementation, reactor power levels are referenced to 3840 MWth (100% LPU) unless otherwise noted.3.2 System and equipment performance shall be closely monitored to assure that operating limits and test criteria are not exceeded.

Notifications shall be submitted as required per LS-AA-120.

Any test discrepancies noted are reported to the Test Team Leader and the IPA Coordinator for an evaluation to determine plant impact (e.g., discrepancy resolved, power ascension terminated, and/or power reduction commenced).

Evaluations to resolve test discrepancies are to be attached as part of Attachment 2.Hope Creek Page 12 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 3.3 If during power operation any of the following occurs it may be indication of-vessel internals damage and debris carry over (i.e., unexplained changes after considering any known instrument offsets).

Notify the Shift Manager, the Plant Manager, the Test Team Leader and the IPA Coordinator immediately." Unbalance of Main Steam Line steam flow indication

-5% greater than baseline values." Unbalance RPV water level >3 inches between level instruments from different reference legs.* Sudden drop in steam dome pressure >2 psig.* Unexpected or unexplained step increase of moisture carryover (see Attachment 9 for acceptance criteria).

3.4 IF during any pressure or level step changes, the system shows signs of becoming unstable or the acceptance limits are approached, THEN stabilize the condition, OTHERWISE exit the condition.

The next larger step change shall not be performed until an acceptable response is achieved from the previous smaller steps. This may require repeating a previous step.3.5 Reactor Engineering shall ensure the testing will avoid operation in the exclusion regions of the power to flow map.3.6 The IPA Coordinator with the assistance of the Test Team shall coordinate the review and evaluation of the data package for each step of this procedure for acceptance criteria compliance.

3.7 ALARA principles should be balanced with observing plant systems during power ascension system inspections.

Walk-downs shall be performed by multi-disciplined teams that have pre-established routes, objectives, and stay-times.

Cameras shall be used in lieu of actual walk-downs, where appropriate.

3.8 Power level tolerances are -38 MWth, + 0 MWth. This procedure generally refers to average power (i.e., 2 or 5 minute thermal averages on the plant process computer) and not instantaneous power unless specified otherwise.

3.9 Intentional operation greater than the current plateau (3339 MWth, 3506 MWth, 3673 MWth, and 3723 MWth) is not permitted.

The average CTP level over any 12-hour period shall not exceed the current plateau power level. Once EPU is implemented, it is permissible to exceed the current power plateau by as much as 2% (nominal 3723 MWth) for as long as 15 minutes. Lesser power excursions are permitted for longer periods (i.e., 1% excess for 30 minutes, 1/2% for one hour, etc.) as long as the 12-hour average does not exceed the current power plateau.Hope Creek Page 13 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 3.10 After any change in plant power level above 3339 MWth by the steps in this procedure, a 4- hour stabilization period shall occur prior to recording system and equipment performance data with the exception of dryer and FIV data. Following the stabilization period and during the data collection period the plant shall be maintained in as stable a condition as is possible (i.e., no backwashing and pre-coating condensate demineralizers, major equipment lineup changes, etc.) until data collection has been completed.

3.11 Reactor recirculation adjustments to maintain the specified power level tolerance do not invalidate the 4-hour stabilization period.3.12 Record dryer and FIV data every hour during power ascension above 3339 MWth (each 33 MWth change in reactor power)-and within one hour after achieving the next Power Plateau or Power Increment per Attachments 3 and 4.3.13 CRIDS points specified during testing are typically used for trending purposes only. Contact the Test Team to evaluate any unavailability of CRIDS or other test data points. Alternative data source locations may be used if authorized by the Test Team Leader.3.14 Individual steps within this procedure can be deferred with prior IPA Test Manager approval.Hope Creek Page 14 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.4.0 TERMINATION CRITERIA AND PREREQUISITES 4.1 Termination Criteria 4.1.1. IF an unexpected action results during performance of this procedure:

STOP, PLACE SYSTEM OR COMPONENT IN A SAFE CONDITION, AND NOTIFY THE SHIFT MANAGER, THE TEST MANAGER AND THE IPA COORDINATOR.

FOR PLANT OCCURRENCES NOT DIRECTLY ASSOCIATED WITH THIS PROCEDURE, ALL IMMEDIATE AND SUBSEQUENT ACTIONS PER ABNORMAL, EMERGENCY, & OTHER OPERATING PROCEDURES APPLY. UPON STABILIZATION, THE SM WITH SUPPORT FROM THE PACC SHALL ASSESS THE CONDITION AND DETERMINE THE IMPACT TO TESTING.4.1.2. TERMINATE the IPA upon the occurrence of: " Exceeding any Level 1 Criteria (see Attachments for specific criteria).

• Any specific termination/abort criterion defined in applicable procedures or attachments." Any related event that causes an unexpected reactivity transient, such as that associated with reactor water level, pressure, core flow, temperature, or control rod position.* Any unanticipated event related to the test which requires entering a Technical Specification Limiting Condition for Operation (LCO)." Any IPA related event that is reportable or potentially reportable to the NRC, such as reactor scram, ECCS actuation, an uncontrolled radiation release or other Notification of noteworthy concern." Any other condition which, in the determination of the IPA Coordinator, Test Manager, upper management or SM, requires the IPA to be terminated.

4.1.3. IF this test is TERMINATED, THEN record and document the occurrence on the test deficiency log (Attachment

2) and generate a notification.

Any deficiencies affecting operability must be reviewed by the SM and the Test Manager.4.1.4. IF the decision is made to restart or continue an IPA which was terminated/aborted, the Test Manager and/or IPA Coordinator shall perform the following prior to proceeding with the test:* Obtain Plant Manager approval and review by PORC (if required by the Plant Manager).WContinued on next page Hope Creek Page 15 of -188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.4.14 (continued)

.Obtain SM permission.

• Ensure resumption will not have an unacceptable impact on plant status, operating equipment, or the remainder of the evolution.

• Verify prerequisites are met and conditions have not changed since entering the terminated/aborted condition.

If conditions have changed, complete applicable steps on the original prerequisites page or on additional pages and attach to the procedure.

• Document the re-verification of prerequisites and continuation in the Control Room Log.* Ensure the Operating crew has been briefed to refocus on the task.NOTE All Holds or Test Results that do not satisfy an acceptance criterion require review by PORC and approved by the Test Manager. Following resolution, the applicable test section(s) will be re-performed to verify that the acceptance criteria was satisfied, or accepted as-is, as appropriate.

Refer to PATP Section 3.4 for additional guidance.4.1.5. IF an unexpected event occurs at any time during system testing or Level 2 criteria exceeded, the system shall be placed in a safe and stable mode using existing operating procedures.

Testing activities shall be suspended and placed on HOLD until the event is understood and the SM and the IPA Coordinator has granted permission to resume testing. The Test Team Leader or IPA Coordinator shall document the decision making in the test deficiency log (Attachment 2), recording the resolution and approvals granted and ensure a notification is generated.

Some examples of where a HOLD might be used are;" Ifan inadequate number of qualified personnel is available on site or via telephone to ensure successful completion of the evolution.

• To resolve concerns with the evolution or with personnel assigned to the evolution.

Upon loss of required communications.

• If plant impacts or conflicts with other procedures are identified that are not addressed by the procedures governing the special evolution.

4.1.6. IF during the performance of this procedure, testing is stopped for whatever reason, THEN refer to Termination Criteria (Section 4.1.4) for actions to be taken PRIOR to resuming testing.Hope Creek Page 16 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 0 4.2 Prerequisites NOTE Prerequisites 4.2.1 through 4.2.8 require completion prior to Startup from RF14 and do not have to be completed in sequence up to Step 4.2.9.4.2.1. Pre-Refuelincq Outage 14 Modifications (Test Team or.Responsible Encgineer):

VERIFY the following modifications are installed and tested, and all concerns or open items associated with the change have been addressed such that Startup from RF14 can proceed. Any exceptions are to be noted in Attachment 2.Initial Date Time DCP 80062464, 500 kV Breaker DCP 80043099, Cooling Tower Flow Distribution DCP 80045795, Cooling Tower Fill & Fill Support DCP 80048289, GSU Transformer Phase A DCP 80043091, GSU Transformer Phase B DCP 80048295, LP Turbines DCP 80048294, Digital EHC System Upgrade DCP 80055430, Turbine Supervisory

& Vibration Monitoring DCP 80048549, Moisture Separator Upgrade DCP 80062466, EPU Piping Vibration Monitoring DCP 80071246, Flow Control Trip Card Replacement DCP 80043101, MELLLA DCP 80060797, No. 2 & 3 FWH Dump Valves DCP 80048551, Iso-Phase Bus Duct Cooling DCP 80067811, MS Relief Valves Setpoint Change DCP 80072785, 'A' Steam Jet Air Ejector DCP 80084814, EPU Piping Vibration Monitoring DCP 80086589, Resin Strainer________________

I ___________________

______________

I _________________

Hope Creek Page 17 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.2. RF14 EPU-Related Changes (Test Team or Responsible Engineer)Verify the following EPU changes scheduled for implementation during RF14 have been installed in the field and support power ascension activities.

Initial Date Time DCP 80048085, Table 1-2, Instrumentation Scaling Changes (RF14)DCP 80048085, Table 1-3, Instrumentation Setpoint Changes (RF14)DCP 80048085, Table 1-4, Instruments Replaced (RF14)DCP 80048085, Table 1-5, Digital FW Control System Changes DCP 80048085, Table 1-6, Other Required Changes (RF14)DCP 80048085, TACS Re-Balance to Affected Components DFCS Factory Acceptance Testing (FAT) Completed DFCS Site Acceptance Testing (SAT) Completed Functional Test for the PCP Trip Runback Logic Completed DCP 80048085, Act. 314, Appendix J Required Testing Completed DCP 80048085, Balance of SAP Operations (RF14 Pre-Power Ascension activities are complete and appropriately updated)DCP 80048085, SCP Suction Pressure Trip Time Delay DCP 80048085, RCIC Exhaust Pressure Setpoint Change Hope Creek Page 18 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.3. RF14 EPU-Related Modifications (Test Team or Responsible Engineer):

VERIFY the following modifications are installed, preoperational testing is complete, and all concerns or open items associated with the change have been addressed such that startup from RF14 can proceed. Any exceptions are to be noted in Attachment 2.Initial Date Time DCP 80071904, HP Turbine & SSE Relief Valves DCP 80090588, MS Small Bore Piping Weld Upgrades DCP 80090587, MS DW Vibration Monitoring DCP 80093383, RCIC Turbine Exhaust Strut DCP 80062467, Structural Calculations 4.2.4. Other Prerequisites (Test Team or Responsible Engineer):

VERIFY the following EPU related issues or activities are completed or resolved such that Startup from RF14 may commence.Initial Date Time 1 st Stage Turbine RPS Bypass License Change Request (H07-02) received, reviewed by the Test Team, and implemented.

EOP and bases calculations updated (DCP 80048085, Op 311)Temporary Modifications Necessary to Support Main Turbine Warranty Testing have been Installed System Performance Monitoring

& Analysis Plans have been prepared and approved in support of RF14 and EPU Power Ascension Testing.Hope Creek Page 19 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.5. Operations RF14 Training (Training)

The required training to operate the plant with the changes to the DFCS and other EPU-related BOP changes made in RF14 has been conducted.

Classroom training includes plant design changes in support of EPU including setpoint changes, changes to parameters, procedures and system operation, and this Power Ascension Test.Initial Date Time 4.2.6. RF14 Procedure Review and Issuance The EPU Project has resulted in the completion of many modifications and system operating parameter changes. These changes affect many Site procedures.

Some of these procedures will be implemented following RF14, others will be implemented upon receipt of the EPU operating license as directed by DCP 80048085.

This prerequisite requires the responsible Department Head review the procedures under their control and verify that:* Training of personnel within their department has been completed as required by the revised procedures supporting EPU changes made in RF14.* By signing for their respective department procedures, the responsible department head verifies that plant procedures assigned to the department required for power ascension have been revised accordingly.

Functional Area Dept Head/ Signature Exceptions Date/Time Maintenance Chemistry Operations Engineering I Record exceptions on the Test Deficiency Log and enter the log number on this page, otherwise N/A Hope Creek Page 20 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.7. RF14 Startup -All test team members have read and understood:

• HC.OP-FT.ZZ-0004(Q), Extended Power Uprate Power Ascension Testing* HC.OP-IO.ZZ-0003(Q), Startup from Cold Shutdown to Rated Power* HU-AA-121 1, Briefings

-Pre-Job, Heightened Level of Awareness, Infrequent Plant Activity and Post-Job Briefings Initial Date Time Test Team Leader NOTE All participants involved in the IPA brief are to be listed on Page 1 of the Attachment 15, HLA/IPA Briefing Worksheet.

Those individuals involved in this test as Performers and Verifiers are required to sign Attachment 1, Section 3.1.4.2.8. Reauired Pre-Job Briefings (IPA Coordinator) 0 Initial Date Time" A RF14 EPU Startup pre-job brief has been performed per HU-AA-1211 for all Test Team members.* A RF14 EPU Startup pre-job brief has been conducted per HU-AA-1211 for all Operating Crews 4.2.9. HCGS Plant Manager Approval -Startup from RF14 The HCGS Plant Manager authorizes plant startup from RF14 with the new HP turbine -and other BOP changes made in support of the EPU project.Initial Date Time 4.2.10. Shift Manager's Permission

-Startup from RF14 The SM's Permission has been granted to commence plant startup from RF14 with the new HP turbine and other BOP changes made in support of the EPU project.SM DATE-TIME Hope Creek Page 21 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE Prerequisites 4.2.11 through 4.2.24 require completion prior to EPU Implementation and Power Ascension above 3339 MWth and do not have to be completed in sequence up to Step 4.2.25.4.2.11. EPU Prerequisites (Test Team or Responsible Engineer):

VERIFY the following EPU related issues or activities are completed or resolved such that EPU implementation and power ascension may commence.Initial Date Time Final Transient Analyses Recommendations (DCP 80048085, Op 306)OPRM ALIA2, BI/B2, C1/C2, D1I/D2 ENABLE and TRIP setpoints changed (60068153; DCP 80048085 AD K51)Condensate Indicated Flow Issue (Notification 20310455)Frequency of Level 2 Initiations (Notification 20314249)Notification 20299386, Unverified Assumptions (Op 304)4.2.12. Operations EPU Training (Training)

The required training to operate the plant under EPU conditions has been conducted.

Classroom training includes plant design changes in support of EPU including setpoint changes, changes to parameters, procedures and system operation, all related Technical Specification changes, and this Power Ascension Test. Simulator training has provided Operators with a demonstration of transients that show the greatest change in plant response at EPU power levels compared to the original maximum power level.Comments from training have been addressed such that power ascension testing can proceed.Initial Date Time Hope Creek Page 22 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE This prerequisite does not pertain to any particular Just-in-Time training Operations Management chooses to conduct for Operations personnel prior to performance of power ascension testing.Training Comments: Initial Date Time 4.2.13. SuDport DeDartment EPU Trainina The required training to operate and maintain the plant under EPU conditions has been conducted.

Comments from training have been addressed such that implementation and power ascension testing can proceed.Functional Area Dept Head/ Signature Exceptions Date/Time Maintenance Chemistry Radiation Protection Engineering I Record exceptions on the Test Deficiency Log and enter the log number on this page, otherwise N/A Hope Creek Page 23 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.14. Procedure Review and Issuance The EPU Project has resulted in the completion of many modifications, Technical Specification revisions and system operating parameter changes.These changes affect many Site procedures.

This prerequisite requires the responsible Department Head review the procedures under their control and verify that: " They have reviewed the procedures under their control for minor modifications, design changes, temp modifications, and license amendments." Have evaluated the impact of the differences between the Final License amendment and the proposed License amendment on various procedure changes." Training of personnel within their department has been completed as required by the revised procedures.

• Procedures required for EPU implementation and power ascension are ready for issue.* By signing for their respective department procedures, the responsible department head verifies that plant procedures assigned to the department required for power ascension have been revised accordingly.

Functional Area Dept Head/ Signature Exceptions 1 Date/Time Maintenance Operations Chemistry Radiation Protection Engineering Training Emergency Preparedness Reactor Engineering Regulatory Assurance Nuclear Oversight Record exceptions on the Test Deficiency Log and enter the log number on this page, otherwise N/A Hope Creek Page 24 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.15. Safety Evaluation Report (SER) Review The NRC Final Safety Evaluation Report and License Amendment have been received and reviewed against the License Amendment Request and any differences have been evaluated for their affect on;* Plant Operating Procedures

• Plant Processes and Programs" This Power Ascension Test Procedure This evaluation has been completed and there are no additional changes to the documents listed above prior to EPU implementation or the start of Power Ascension Testing as performed by this procedure.

Evaluation Comments: Verified By: EPU Project Manager/Date 4.2.16. EPU Proiect Action Items (Test Team)Throughout the EPU Project, action items have been tracked on an internal Action Item List. This tracking mechanism has been reviewed for items requiring completion prior to or during power ascension testing. The items requiring completion prior to EPU power ascension testing have been completed or will be completed as controlled by this procedure.

Comments: Initial Date Time Hope Creek HPage 25 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.17. Steam Dryer Action Items The commitments and planned actions specified in the application and all supplements to the application in support of the EPU license amendment pertaining to the steam dryer required prior to power ascension have been completed.

Comments: Verified By: Test Team Leader/Date 4.2.18. Technical Specifications and LCO Tracking Log (Operations)

The LCO Tracking Database (HC.OP-AP.ZZ-108, Attachment 5-1) has been reviewed and evaluated for any impact on the ability of the plant to support EPU implementation and power ascension testing and has been found acceptable for the power increase.

Exceptions requiring action shall be listed below by exception number and shall be annotated in the Test Deficiency Log (Attachment 2).Comments: Initial Date Time Hope Creek Page 26 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.19. Operability Determinations/CROD Review (Operations)

All Operability Determinations/CRODS that have EPU constraints have been evaluated for their impact on Power Ascension and have been found acceptable.

Exceptions requiring action shall be listed in Attachment 2.Comments: Initial Date Time 4.2.20. Temporary Modifications Loc Review (Plant Engineering)

The Temporary Modification Log has been reviewed and all installed alterations have been evaluated for their impact on this Power Ascension Test and have been found acceptable.

Exceptions requiring action shall be listed in Attachment 2.Comments: Initial Date Time Hope Creek Page 27 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.21. Work Clearance Documents/Equipment Taqging (Operations)

The equipment tagged out-of-service that can affect the ability of the plant to support power ascension testing has had its plant impact reviewed and evaluated and found acceptable for the power increase.

Exceptions requiring action shall be listed below and shall be annotated in Attachment 2.Review Comments: Initial Date Time 4.2.22. EPU Implementation

& Power Ascension

-All test team members have read and understood:

• HC.OP-FT.ZZ-0004(Q), Extended Power Uprate Power Ascension Testing* HC.OP-IO.ZZ-0003(Q), Startup from Cold Shutdown to Rated Power* HC.OP-IO.ZZ-0006(Q), Power Changes During Operation* HU-AA-1211, Briefings

-Pre-Job, Heightened Level of Awareness, Infrequent Plant Activity and Post-Job Briefings Initial Date Time Test Team Leader Hope Creek Page 28 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE All participants involved in the IPA brief are to be listed on Page 1 of the Attachment 15, HLA/IPA Briefing Worksheet.

Those individuals involved in this test as Performers and Verifiers are required to sign Attachment 1, Section 3.1.4.2.23. EPU Implementation Required Pre-Job Briefings (IPA Coordinator)

A pre-job brief has been performed per HU-AA-1211 for all PACC personnel.

A pre-job brief has been performed per HU-AA-1211 for all Test Team members.A pre-job brief has been conducted per HU-AA-1211 for all Operating Crews Initial Date Time 4.2.24. EPU Administrative Controls The signature below signifies that EPU related instrument scaling, set-point, digital feed-water system, and other device and plant configuration changes associated with EPU implementation may commence with all issues resolved or otherwise addressed.

All prior prerequisites are either complete or are sufficiently in progress such that EPU implementation can proceed.Siiqnature Date Time Regulatory Assurance Manager EPU Project Manager Engineering Director Operations Director Reactor Engineering Manager Nuclear Oversight Manager Maintenance Director Chemistry Manager RP Manager Hope Creek Page 29 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 4.2.25. Plant Operations Review Committee

-EPU Implementation PORC recommends license implementation for Extended Power Uprate to the Plant Manager.PORC Review Meeting #: Initial Date Time 4.2.26. HCGS Plant Manager Approval -EPU Implementation The HCGS Plant Manager authorizes implementation of License Change Request H05-01.Initial Date Time 4.2.27. Control Room Implementation

-EPU Implementation VERIFY that new license has been implemented in the control room.Initial Date Time 4.2.28. Shift Manager's Permission

-EPU Implementation The SM's Permission has been granted to commence EPU License Implementation for Extended Power Uprate.SM DATE-TIME 4.2.29. All prerequisites are complete and any exceptions are authorized and approved.Verified By: Verified By:.IPA Coordinator/Date/Time Test Manager/Date/Time Hope Creek Page 30 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.0 PROCEDURE NOTE This procedure assumes Startup from RF14 and the subsequent power ascension to 3339 MWth occurs prior to EPU license implementation (Sections 5.1 and 5.2). EPU implementation and power ascension to 3723 MWth occurs at a later date (Sections 5.3 to 5.8). Thus, this procedure may be maintained open for a period of time. This delay is not considered a Hold or Termination per the criteria contained in Section 4.0.IF during the performance of this procedure, testing is stopped for whatever reason, THEN refer to Termination/Hold Criteria, for actions to be taken PRIOR to resuming testing.The IPA Coordinator with the assistance of the Test Team shall coordinate the review and evaluation of the data package for each step of this procedure for acceptance criteria compliance.

5.1 Startup to 3005 MWth Plant startup, maneuvers and operation shall be performed in accordance with applicable HCGS procedures including power changes in accordance with HC.OP-IO.ZZ-0003(Q), Startup from Cold Shutdown to Rated Power. This Test Procedure contains only those steps directly associated with performance of EPU-related power ascension testing. Activities specified not directly associated with the test are labeled as Optional and can be waived by the Test Manager.CAUTION Steam demand input to the RWM is an RF14 re-scaled parameter and changes in steam demand can affect the LPSP of the RWM. The RWM should be monitored during rod movement and during any changes to steam demand (e.g., opening the MSIV's, rolling turbines, opening bypass valves), to ensure rod motion is being monitored by the RWM.DFCS performance shall be carefully monitored during startup due to the extent of RF14 changes made. Any anomalies shall be brought to the attention of the Test Manager.5.1.1. VERIFY Prerequisites 4.2.1 through 4.2.10 have been completed and any deficiencies are documented in Attachment 2.5.1.2. VERIFY operability of the RWM lAW Step 5.2.4 of HC.OP-IO.ZZ-0003.

RETAIN a copy of HC.OP-IO.ZZ-0003, Attachment 2, with this test procedure.

Initial Date Time Hope Creek Page 31 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.1.3. WHEN the reactor pressure vessel is at normal operating pressure and temperature, CONTACT reactor engineering to commence data taking for HC.RE-FT.ZZ-0002(Q), Alternate Indication of Reactor Power.5.1.4. PERFORM IRM to APRM Overlaps lAW Step 5.3.40 of HC.OP-IO.ZZ-0003.

RECORD ranges and readings of the IRMS and APRMs on Attachment 13.5.1.5. With the APRMs indicating 7 to 10% and prior to entering Mode 1, ENSURE reactor engineering has performed Alternate Power Checks lAW Section 5.2 of HC.RE-FT.ZZ-0002(Q) and results are satisfactory.

5.1.6. PERFORM Section 5.2 (Mode 2) of HC.IC-LC.AE-0013(Q), Reactor Feedpump Recirc Valve'Tuning, to optimize digital feedwater tuning in the Startup Level Control mode (Optional).

5.1.7. With all APRMs indicating over 10%, VERIFY the RWM remains below the LPSP.5.1.8. At approximately 10% RTP (334 MWth), PERFORM the Mode 1 sections of HC.IC-LC.AE-0013(Q), Reactor Feedpump Recirc Valve Tuning, to optimize digital feedwater tuning in the Startup Level Control modes including DIP control (Optional).

Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 32 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE The post-EPU Main Turbine First Stage Pressure RPS Bypass set-point has been reduced to 104.2 psig. This parameter should be monitored closely during shell warming to avoid a reactor scram. The turbine roll and generator synchronization should occur with the minimum allowable number of bypass valves open to provide margin to this set-point.

The Main Turbine Roll, Synchronization, Soak, and Over-speed Test per HC.OP-FT.AC-0004, are performed per existing station procedures.

No additional specific EPU Power Ascension or High Pressure Turbine DCP retests are associated with these activities.

5.1.9. ENSURE Pressure Set in DEHC is set to 905 psig prior to main turbine roll.5.1.10. NOTIFY the Test Team prior to main turbine roll for GE and/or engineering walk-down of the new HP turbine.5.1.11. Upon main generator synchronization, COMMENCE Turbine Valve Scram Bypass Set-point Data Collection in accordance with Attachment 6.5.1.12. With the main generator synchronized, CONTACT System Engineering to commence continuous Incremental Regulation Data Collection (main steam line flow versus pressure regulator data output) lAW the DEHC System Performance and Monitoring plan.This data is to be recorded until maximum EPU power is reached.5.1.13. Prior to exceeding 25% RTP (834 MWth), PERFORM APRM calibrations and all I&C required surveillance procedures lAW Step 5.4.17 of HC.OP-IO.ZZ-0003.

Initial Date Time Initial Date Time Initial Date Time Verf Date Time Hope Creek Page 33 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.1.14. Prior to exceeding 25% RTP (834 MWth), ENSURE Reactor Engineering has re-performed alternate power checks lAW HC.RE-FT.ZZ-0002(Q) satisfactory.

In addition, VERIFY that all other HC.RE-IO.ZZ-0001(Q) required checks are satisfactory prior to raising power above this level.RE Date Time Verf Date Time 5.1.15. Prior to exceeding 30% RTP (1001 MWth), ENSURE the following:

RX RECIRC PUMP RPS TRIP BYP (C1-E3) AND TCV FAST CLOSE & MSV TRIP BYP (C5-C2)are NOT illuminated, AND All four Trip Units C71-N652A/C (10-C-609)

AND C71 -N652B/D (10-C-611)

INDICATE the bypass logic is no longer in effect.Initial Date Time Verf Date Time 5.1.16. Prior to exceeding 30% RTP (1001 MWth), Test Team to CONFIRM Turbine Valve Scram Bypass Data (Attachment

6) supports exceeding 30% RTP and that the "pre-test" Technical Specification required set-point calculation is conservative.

Initial Date Time Verf Date Time 5.1.17. At approximately 30% reactor power (1001 MWth), STOP taking Turbine Valve Scram Bypass Set-point Data Collection (Attachment 6). Forward results to the Test Team for evaluation.

Initial Date Time 5.1.18. At approximately 30% RTP (1001 MWth), PERFORM applicable sections of HC.IC-LC.AF-0006, Feed-water Heater Level System Tuning (Optional).

Hope Creek Page 34 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.1.19. At approximately 40% RTP (1336 MWth), PERFORM the remaining Mode 1 sections of HC.IC-LC.AE-0013(Q), Reactor Feedpump Recirc Valve Tuning, to tune the RFP minimum flow recirculation valves (Optional).

Initial Date Time 5.1.20. At approximately 40% RTP (1336 MWth), PERFORM Pressure Regulator tests for low power baseline lAW Attachment 12.Initial Date Time NOTE Operation of either RR Pump above a speed of 1500 rpm requires taking vibration readings in accordance with ER-HC-370-1001.

Notify the Test Team if this speed is approached.

5.1.21. As Reactor Recirculation Pump speeds are increased to the following speeds contact the Test Team and PERFORM MG SET Voltage Regulator Tuning in accordance with HC.IC-PM.BB-0005(Z) (Optional).

50-55% speed (840-930 RPM) Date/Time 70-75% speed (1175-1260 RPM) Date/Time 80-85% speed (1340-1425 RPM) Date/Time 90-95% speed (1500-1590 RPM) Date/Time Initial Date Time 5.1.22. At approximately 70% power, PERFORM applicable sections of HC.IC-LC.AF-0006, Feed-water Heater Level System Tuning (Optional).

Initial Date Time 5.1.23. With reactor power between 2967 MWth to 3005 MWth (90% CLTP), and with three (3) Feedwater pumps running, PERFORM the following:

• ENSURE Pressure Set in DEHC is set to 905 psig AND Crossflow is Not Applied.* REQUEST RE to complete Attachment 7 for 3005 MWth.Continued Next Page Initial Date Time Initial Date Time Hope Creek Page 35 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.5.1.23 (continued)

• PERFORM dryer and FIV data collection for 90% CLTP baseline in accordance with Attachments 3 & 4.* PERFORM the Moisture Carryover and Radiation Survey evaluations for 90% CLTP baseline in accordance with Attachments 5 and 9.* AFTER a four hour hold, VERIFY performed or request System Engineering to collect System Performance Monitoring

& Analysis baseline data at 3005 MWth.* AFTER a four hour hold, PERFORM Pressure Regulator tests for 90% CLTP baseline lAW Attachment 12.* AFTER a four hour hold, PERFORM Feedwater System tests for 90% CLTP baseline lAW Attachment 11.AFTER a four hour hold, TAKE Maximum Feedwater Runout Data for 90% CLTP baseline lAW Attachment 10.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time NOTE Turbine Control Valve testing will be performed at several power levels and dependent on results, may be re-performed at higher power levels in approximately 2% to 5% increments as determined by the Test Manager.* AFTER a four hour hold, COMMENCE HC.OP-FT.AC-0006(Q), Turbine Valve Power Level Functional Test for #1 Control Valve.ENSURE completion of Attachment 4 and Attachment 6 of HC.OP-FT.AC-0006 for inclusion in data package.initial Date Iime Hope Creek Page 36 of 188 Rev. 3 5.1.24. Test Team to EVALUATE Baseline Data at 90%CLTP as satisfactory.

Authorization to continue power ascension (Test Manager).5.2 Increasinq to 3339 MWth HC.OP-FT.ZZ-0004(Q)

Initial Date Time 5.2.1. With reactor power above 90% (3005 MWth), PERFORM applicable remaining sections of HC.IC-LC.AF-0006, Feed-water Heater Level System Tuning (Optional).

Initial Date Time 5.2.2. IF needed, PERFORM the following" RAISE reactor power and maintain 95% RTP (3134 MWth to 3172 MWth).* ENSURE Pressure Set in DEHC is set to 905 psig AND Crossflow is Not Applied.5.2.3. PERFORM Main Turbine Stop, Bypass Valve, and Partial MSIV closure 95% CLTP baseline tests lAW Attachment 16.5.2.3A COMPLETE HC.OP-FT.AC-0006 for Control Valve #1.ENSURE completion of Attachment 4 and Attachment 6 of HC.OP-FT.AC-0006 for inclusion to data package.5.2.4. ADJUST Pressure Set in DEHC to the pre 90% CLTP baseline data collection set point or as directed by the Shift Manager, AND RAISE reactor power and maintain 100% RTP (3339 MWth) lAW HC.OP-IO.ZZ-0006(Q).

5.2.5. PERFORM dryer and FIV data collection at 100%CLTP in accordance with Attachments 3 and 4.Initial Date Time Initial Date Time Initial Date Time Initial 'Date Time Initial Date Time Hope Creek Page 37 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE At this point in the procedure testing will be suspended for receipt of the EPU license as requested via LCR H05-01. All normal operating, abnormal and other procedures and their limits or thresholds govern plant operation.

5.2.6. VERIFY EPU Implementation Prerequisites 4.2.11 through 4.2.29 have been completed and any deficiencies are documented in Attachment 2.5.2.7. ANNOUNCE EPU Implementation and NOTIFY I&C and the Test Team to implement the remaining EPU required changes lAW DCP 80048085.DCP 80048085, Plant Process Computer and SPDS Changes for EPU DCP 80048085, 'A' , 'C' , and 'E' Channel APRM Setpoints Changes DCP 80048085, 'A' and 'C' Channel MS to NSSSS Scaling & MS High Flow Isolation Setpoint Changes DCP 80048085, 'B', 'D', and 'F' Channel APRM Setpoints Changes DCP 80048085, 'B' and 'D' Channel MS to NSSSS Scaling & MS High Flow Isolation Setpoint Changes DCP 80048085, COLR and CMS Data Bank changes for EPU 5.2.8. RE-PROGRAM Hydrogen Water Chemistry System for 11.0 scfm at EPU conditions per VTD 311966 Initial Date Time Initial Date Time Hope Creek Page 38 of 188 Rev. 3 5.2.9. Reactor Engineer to ENSURE reactor heat balance data, APRM/OPRM readings & setpoints, and other core performance data are consistent with expected conditions prior to EPU implementation.

HC.OP-FT.ZZ-0004(Q)

RE Date Time Verf Date Time NOTE To provide accurate predictions of plant and core performance during the test, power will be raised to each new power increment or plateau along a constant rod pattern using recirculation flow. A "Rods for Flow" power maneuver may be necessary prior to exceeding 3339 MWth, or at any time during the test, to establish and maintain recirc flow margin.Instructions will be provided by the RE Reactivity Management Plan. The reactivity plan shall also assure margin to the RR pump MG Set High-Speed stops during all power ascension test activities.

5.2.10. NOTIFY Reactor Engineering to remove Crossflow from service (Not Applied), and ADJUST Reactor Power as necessary to maintain 3339 MWth (3301 MWth to 3339MWth).

5.2.11. With Reactor Power between 3301 MWth to 3339 MWth (100% CLTP), PERFORM the following: " REQUEST RE to complete Attachment 7 for 3339 MWth and to predict anticipated thermal limits for evaluation and prediction of core performance at 3422 MWth per Attachment 7." PERFORM dryer and FIV data collection for 100% CLTP (87% RTP) baseline in accordance with Attachments 3 and 4." PERFORM the Moisture Carryover evaluation for 100% CLTP (87% RTP) baseline in accordance with Attachment 9.Initial Date Time Initial Date Time Continued on next page Hope Creek Page 39 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.2.11 (Continued)

• VERIFY performed or request System Engineering to collect System Performance Monitoring

& Analysis baseline data at 3339 MWth.Initial Date Time" PERFORM Pressure Regulator tests for 100% CLTP (87% RTP) baseline lAW Attachment 12.* PERFORM FeedWater System tests for 100% CLTP (87% RTP) baseline lAW Attachment 11." TAKE Maximum Feedwater Runout Data for 100% CLTP (87% RTP) baseline lAW Attachment 10.Initial Date Time NOTE During the following step, power needs to be held constant with no intrusive activities in progress.

Once data collection is started, changes in recirculation flow or control rod motion may result in invalidating the data. Coordinate any necessary power changes with the RE and Test Team, prior to the performance of this next step.* CONTACT the Test Team to commence Crossflow computer tuning and data acquisition.

Coordinate with the Test Team to maintain steady-state conditions, as necessary, in gathering this data." PERFORM Main Turbine Stop, Bypass Valve, and Partial MSIV closure 100% CLTP (87% RTP)baseline tests lAW Attachment 16.5.2.12. Test Team to EVALUATE Baseline Data at 100%CLTP (87% RTP) as satisfactory.

Authorization to continue power ascension (Test Manager).Initial Date Time Initial Date Time Hope Creek Page 40 of 188 Rev..3 HC.OP-FT.ZZ-0004(Q) 5.2.13. Authorization for Exceeding 3339 MWth: A. Plant Manager's permission has been granted to exceed 3339 MWth.B. Shift Manager's permission has been granted to exceed 3339 MWth.Initial Date Time Initial Date Time NOTE To provide accurate predictions of plant and core performance during the test, power will be raised to each new power increment or plateau along a constant rod pattern using recirculation flow. A "Rods for Flow" power maneuver may be necessary prior to exceeding 3339 MWth to establish these conditions and achieve equilibrium Xenon. Instructions will be provided by the RE Reactivity Management Plan. The reactivity plan shall also assure margin to the RR pump MG Set High-Speed stops during all power ascension test activities.

EPU power ascension testing above 3339 MWth will be conducted in approximately 83 MWth increments and 167 MWth plateaus.The maximum power increase will not exceed a 167 MWth in a 24-hour period. The power ascension rate will be limited to 1% CLTP or 33 MWth per Hour.Steam Dryer Moisture Carryover Analysis shall be performed per Attachment 8, and commenced within one hour of achieving the next power plateau or increment per Attachment 9.Dryer and FIV data collection readings (strain gauge and accelerometer data) are to be taken every hour during power ascension (every 33 MWth change in reactor power) and within one hour after achieving the next power plateau or increment per Attachments 3 and 4.Reactor Power will need to be held constant for approximately 2 minutes before and during the dryer and FIV data collection per Attachments 3 and 4.5.3 Increasing to 3422 MWth Allowing no other concurrent intrusive activities, RAISE reactor power by 83 MWth to 3422 MWth (3384 MWth to 3422 MWth) in accordance with HC.OP-IO.ZZ-0006, as follows: 5.3.1. While raising reactor power, PERFORM dryer and FIV data collection after the first 33 MWth change in reactor power and each 33 MWth thereafter per Attachments 3 and 4.Hope Creek Page 41 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.3.2. Within one hour after achieving 3422 MWth (3384 MWth to 3422 MWth), COMMENCE moisture carryover determination per Attachment 9 (non intrusive).

Initial Date Time 5.3.3. MAINTAIN reactor power (3384 MWth to 3422 MWth) for four hours while performing the following non-intrusive activities:

• PERFORM dryer and flow induced vibration data collection and EVALUATION per Attachments 3 and 4 (non intrusive).

Data SHALL be obtained within one hour of achieving 3422 MWth.Initial Date Time* REQUEST RE to: 1. VERIFY current reactor conditions are within acceptable values of the power-flow map and thermal limits are met per Attachment 7 and to predict anticipated thermal limits for evaluation and prediction of core performance at 3506 MWth per Attachment 7.(non intrusive).

Initial Date Time 2. VERIFY all inputs to the heat balance acceptable by reviewing the plant computer (non intrusive).

Initial Date Time 0 PERFORM HC.OP-FT.BB-0001(Q), Jet Pump Data Collection.

Initial Date Time* After four hours, REQUEST Rad Pro to take Plant Area Radiation and Process Monitor readings and to verify the Main Steam Line Radiation Monitor response is within expected dose ranges (non intrusive).

Initial Date Time Continued on next page Hope Creek Page 42 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.5.33 (Continued)

After four hours, NOTIFY System Engineering to collect System Performance Monitoring

&Analysis data at 3422 MWth.5.3.4. Authorization for Exceeding 3422 MWth: A. Test Manager's permission has been granted to exceed 3422 MWth.B. Shift Manager's permission has been granted to exceed 3422 MWth.Initial Date Time Initial Date Time Initial Date Time 0 Hope Creek Page 43 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE Dryer and FIV data collection readings (strain gauge and accelerometer data) are to be taken every hour during power ascension (33 MWth change in reactor power) and within one hour of achieving the next power plateau or increment per Attachments 3 and 4.Reactor Power will need to be held constant for approximately 2 minutes before and during the dryer and FIV data collection per Attachments 3 and 4.5.4 Increasinq to 3506 MWth Allowing no other concurrent intrusive activities, RAISE reactor power by approximately 83 MWth to 3506 MWth (3468 MWth to 3506 MWth) in accordance with HC.OP-IO.ZZ-0006, as follows: 5.4.1. While raising reactor power: A. PERFORM dryer and FIV data collection after each 33 MWth change in reactor power per Attachments 3 and 4.B. PERFORM dryer and FIV data collection and EVALUATION per Attachments 3 and 4 after achieving 3506 MWth (3468 MWth to 3506 MWth).Data SHALL be obtained within one hour of achieving 3506 MWth.C. NOTIFY the test team to complete report preparation that evaluates dryer and FIV data (strain gauge results, evaluations, acceptance criteria, etc,) and makes a recommendation to PORC to continue power ascension.

PORC Review Meeting #: 5.4.2. Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of achieving 3506 MWth take moisture carryover samples per Attachments 8 and 9 (non intrusive).

5.4.3. PERFORM HC.OP-FT.BB-0001(Q), Jet Pump Data Collection.

Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 44 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

Initial Date Time 5.4.4. MAINTAIN reactor power 3468 MWth to 3506 MWth for a total of four hours.NOTE Steps 5.4.5 through 5.4.7 may be performed concurrently.

5.4.5. Once the dryer data has been evaluated and approved by PORC and the Plant Manager PERFORM the following (non-intrusive):

A. With assistance from the PACC, TRANSMIT the dryer data files to the Nuclear Regulatory Commission (NRC).Initial B. CONFIRM receipt via telephone or facsimile to the NRC Project Manager. DATE STAMP OR PROVIDE other positive acknowledgment of NRC receipt.Initial Date Time C. Once confirmation that the NRC has received the dryer and FIV data, RECORD below the start and end time of the 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock (refer to step 5.4.9).Start of 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock: End of 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock Date /Time Date / Time Initial Date Time Initial Date Time Hope Creek HPage 45 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.4.6. After the 4-hour stabilization period, PERFORM the following:

Cognizant Engineers to perform walkdowns per the EPU System Performance and Monitoring Plans (Attachment 14), including inspections where practicable based on ALARA and safety reasons, a review of CRIDS indications, local indications, control room indications, etc., for systems (components) affected by EPU. Any discrepancy noted shall be discussed with the IPA Coordinator.

Include this documentation within Attachment 14 to this procedure (non intrusive).

Initial Date Time Plant Engineering Manager" CONTACT the Test Team to perform FIV walk-downs of non-critical piping in accordance with Attachment 4 (non intrusive).

• TAKE Maximum Feedwater Runout Data lAW Attachment 10 and prepare runout evaluation (non intrusive).

Initial Date Time NOTE During the following step, power needs to be held constant with no intrusive activities in progress.

Once data collection is started, changes in recirculation flow or control rod motion may result in invalidating the data. Coordinate any necessary power changes with the RE and Test Team, prior to the performance of this next step.* CONTACT the Test Team to continue Crossflow computer tuning and data acquisition.

COORDINATE with the Test Team to maintain steady-state conditions, as necessary, in gathering this data.* PERFORM radiation surveys and request Rad Pro to take Plant Area Radiation and Process Monitor readings per Attachment 5 (non intrusive).

O Continued on next page Initial Date Time Hope Creek Page 46 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.4.6 (Continued)

• CONTACT Chemistry to perform the 3506 MWth required chemistry readings in accordance with Attachment 8 (non intrusive):

Initial Date Time* CONTACT Rad Pro to Verify the Main Steam Line Radiation Monitor response is within the expected dose range for this power plateau (non-intrusive).

Initial Date Time* CONTACT the RE to confirm thermal limits are acceptable and consistent with those predicted for this power plateau and verify current reactor conditions are within acceptable values of the power-flow map and to predict anticipated thermal limits for evaluation and prediction of core performance at 3589 MWth per Attachment 7.(non-intrusive).

Initial Date Time REQUEST RE to Verify all inputs to the heat balance are acceptable by reviewing the plant computer (non intrusive).

Initial Date Time* Allowing no other concurrent intrusive activities, PERFORM Pressure Regulator tests per Attachment 12 (intrusive).

Initial Date Time Allowing no other concurrent intrusive activities, PERFORM Feedwater System tests per Attachment 11 (intrusive).

Initial Date Time* AFTER authorization from the Test Manager, PERFORM Main Turbine Stop, Bypass Valve, and Partial MSIV closure 105% CLTP tests lAW Attachment 16, otherwise N/A.Hope Creek Page 47 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.4.7. COMPLETE a report to be presented at PORC used as a basis to recommend to the HCGS Plant Manager to continue the power ascension (non intrusive).

PORC Review Meeting #: Initial Date Time 5.4.8. Authorization for Power Ascension The results of testing and data collection performed at the last power level plateau have been analyzed and presented to the HCGS Plant Manager, and approval to proceed has been obtained (non intrusive).

Initial Date Time 5.4.9. After 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> (or time otherwise agreed upon with the NRC -annotate Step 5.4.4.C accordingly) from the time the NRC received the dryer and FIV data and evaluation submittal and with no objections from the NRC, then have the PACC contact the NRC Project Manager and inform the NRC that HCGS is continuing with the power ascension (non intrusive).

Initial Date Time Verf Date Time 5.4.10. COMPLETE independent validation that all EPU related license conditions at the current power level have been satisfied.

Print / Sign (Regulatory Assurance)

DATE-TIME Hope Creek Page 48 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE EPU power ascension testing above 3339 MWth will be conducted in approximately 83 MWth increments and 167 MWth plateaus.The maximum power increase will not exceed a 167 MWth in a 24-hour period. The power ascension rate will be limited to 1% CLTP or 33 MWth per Hour.Steam Dryer Moisture Carryover Analysis shall be performed per Attachment 8, and commenced within one hour of achieving the next power plateau or increment per Attachment 9.Dryer and FIV data collection readings (strain gauge and accelerometer data) are to be taken every hour during power ascension (every 33 MWth change in reactor power) and within one hour after achieving the next power plateau or increment per Attachments 3 and 4.Reactor Power will need to be held constant for approximately 2 minutes before and during the dryer and FIV data collection per Attachments 3 and 4.5.5 Increasinq to 3589 MWth Allowing no other concurrent intrusive activities, RAISE reactor power by 83 MWth to 3589 MWth (3551 MWth to 3589 MWth) in accordance with HC.OP-IO.ZZ-0006, as follows: 5.5.1. While raising reactor power, PERFORM dryer and FIV data collection after each 33 MWth change in reactor power per Attachments 3 and 4.Initial Date Time 5.5.2. Within one hour after achieving 3589 MWth (3551 MWth to 3589 MWth), COMMENCE moisture carryover determination per Attachment 9 (non intrusive).

Initial Date Time Hope Creek Page 49 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.5.3. MAINTAIN reactor power (3551 MWth to 3589 MWth) for four hours while performing the following non-intrusive activities:

• PERFORM dryer and flow induced vibration data collection and EVALUATION per Attachments 3 and 4 (non intrusive).

Data SHALL be obtained within one hour of achieving 3589 MWth.Initial Date Ti* REQUEST RE to: me 1. VERIFY current reactor conditions are within acceptable values of the power-flow map and thermal limits are met per Attachment 7 and to predict anticipated thermal limits for evaluation and prediction of core performance at 3673 MWth per Attachment

7. (non intrusive).

2. VERIFY all inputs to the heat balance acceptable by reviewing the plant computer (non intrusive)." PERFORM HC.OP-FT.BB-0001 (Q), Jet Pump Data Collection.

• After four hours, REQUEST Rad Pro to take Plant Area Radiation and Process Monitor readings and to verify the Main Steam .Line Radiation Monitor response is within expected dose ranges (non intrusive).

• After four hours, NOTIFY System Engineering to collect System Performance Monitoring

&Analysis data at 3589 MWth.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 50 of 188 Rev."3 HC.OP-FT.ZZ-0004(Q) 5.5.4. Authorization for Exceeding 3589 MWth: A. Test Manager's permission has been granted to exceed 3589 MWth.B. Shift Manager's permission has been granted to exceed 3589 MWth.Initial Date Time Initial Date Time Hope Creek Page 51 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE Dryer and FIV data collection readings (strain gauge and accelerometer data) are to be taken every hour during power ascension (33 MWth change in reactor power) and within one hour after achieving the next power plateau or increment per Attachments 3 and 4.Reactor Power will need to be held constant for approximately 2 minutes before and during the dryer and FIV data collection per Attachments 3 and 4.5.6 Increasinq to 3673 MWth Allowing no other concurrent intrusive activities, RAISE reactor power by approximately 83 MWth to 3673 MWth (3635 MWth to 3673 MWth) lAW HC.OP-IO.ZZ-0006, as follows: 5.6.1. While raising reactor power: 0 A. PERFORM dryer and FIV data collection after each 33 MWth change in reactor power per Attachments 3 and 4.B. PERFORM dryer and FIV data collection and EVALUATION per Attachments 3 and 4 after achieving 3673 MWth (3635 MWth to 3673 MWth).Data SHALL be obtained within one hour of achieving 3673 MWth.C. NOTIFY the test team to complete report preparation that evaluates dryer and FIV data (strain gauge results, evaluations, acceptance criteria, etc,) and makes a recommendation to PORC to continue power ascension.

PORC Review Meeting #: 5.6.2. Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of achieving 3673 MWth, commence moisture carryover samples per Attachments 8 and 9 (non intrusive).

Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 52 of 188 Rev. 3 5.6.3. PERFORM HC.OP-FT.BB-0001(Q), Jet Pump Data Collection.

5.6.4. MAINTAIN reactor power 3635 MWth to 3673 MWth for a total of four hours.HC.OP-FT.ZZ-0004(Q)

Initial Date Time Initial Date Time NOTE Steps 5.6.5 through 5.6.7 may be performed concurrently.

5.6.5. Once the dryer data has been evaluated and approved by PORC and the Plant Manager PERFORM the following (non-intrusive):

A. With assistance from the PACC, TRANSMIT the dryer data files to the Nuclear Regulatory Commission (NRC).B. CONFIRM receipt via telephone or facsimile to the NRC Project Manager. Date stamp or provide other positive acknowledgment of NRC receipt.C. Once confirmation has been received that the NRC has received the dryer and FIV data, RECORD below the start and end time of the 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock (refer to step 5.6.9).Initial Date Time Start of 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock: End of 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock Date / Time Date / Time Initial Date Time Initial Date Time Hope Creek Page 53 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.6.6. After the 4-hour stabilization period, PERFORM the following:

Cognizant Engineers to perform walkdowns per the EPU System Performance and Monitoring Plans (Attachment 14), including inspections where practicable based on ALARA and safety reasons, a review of CRIDS indications, local indications, control room indications, etc., for systems (components) affected by EPU.Any discrepancy noted shall be discussed with the IPA Coordinator.

Include this documentation within Attachment 14 to this procedure (non intrusive).

Plant Engineering Manager* CONTACT the Test Team to perform FIV walkdowns of non-critical piping in accordance with Attachment 4 (non intrusive).

TAKE Maximum Feedwater Runout Data lAW Attachment 10 and prepare runout evaluation (non intrusive).

Initial Date Time Initial Date Time Initial Date Time 0 Hope Creek Page 54 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE During the following step, power needs to be held constant with no intrusive activities in progress.

Once data collection is started, changes in recirculation flow or control rod motion may result in invalidating the data. Coordinate any necessary power changes with the RE and Test Team, prior to the performance of this next step.0* CONTACT the Test Team to continue Crossflow computer data acquisition Coordinate with the'Test Team to maintain steady-state conditions, as necessary, in gathering this data.* PERFORM radiation surveys and request Rad Pro to take Plant Area Radiation and Process Monitor readings per Attachment 5 (non intrusive).

• CONTACT Chemistry to perform the 3673 MWth required chemistry readings lAW Attachment 8 (non intrusive):

• CONTACT Rad Pro to Verify the Main Steam Line Radiation Monitor response is within the expected dose range for this power plateau (non-intrusive)." CONTACT the RE to confirm thermal limits are acceptable and consistent with those predicted for this power plateau and verify current reactor conditions are within acceptable values of the power-flow map and to predict anticipated thermal limits for evaluation and prediction of core performance at 3723 MWth per Attachment 7.(non-intrusive).

Initial Date Time Initial Date Time Initial Date Time Continued on next page Hope Creek Page 55 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.5.6.6 (Continued)

• REQUEST RE to Verify all inputs to the heat balance are acceptable by reviewing the plant computer (non intrusive).

Initial Date Time* Allowing no other concurrent intrusive activities, T PERFORM Pressure Regulator tests per Attachment 12 (intrusive).

Initial Date Time" Allowing no other concurrent intrusive activities, PERFORM Feedwater System tests per Attachment 11 (intrusive).

Initial Date Time* AFTER authorization from the Test Manager, PERFORM Main Turbine Stop, Bypass Valve, and Partial MSIV closure 110% CLTP tests lAW Attachment 16, otherwise N/A.Initial Date Time 5.6.7. COMPLETE a report to be presented at PORC used as a basis to recommend to the HCGS Plant Manager to continue the power ascension (non intrusive).

PORC Review Meeting #: Initial Date Time 5.6.8. Authorization for Power Ascension The results of testing and data collection performed at the last power level plateau have been analyzed and presented to the HCGS Plant Manager, and approval to proceed has been obtained (non intrusive).

Initial Date Time Hope Creek Page 56 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.6.9. After 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> (or time otherwise agreed upon with the NRC -annotate Step 5.6.4.C accordingly) from the time the NRC received the dryer and FIV data and evaluation submittal and with no objections from the NRC, then have the PACC contact the NRC Project Manager and inform the NRC that HCGS is continuing with the power ascension (non intrusive).

Initial Date Time 5.6.10. COMPLETE independent validation that all EPU related license conditions at the current power level have been satisfied.

Print / Sign (Regulatory Assurance)

DATE-TIME Hope Creek Page 57 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE EPU power ascension testing above 3339 MWth will be conducted in approximately 83 MWth increments and 167 MWth plateaus.The maximum power increase will not exceed a 167 MWth in a 24-hour period. The power ascension rate will be limited to 1% CLTP or 33 MWth per Hour.Steam Dryer Moisture Carryover Analysis shall be performed per Attachment 8.Dryer and FIV data collection readings (strain gauge and accelerometer data) are to be taken every hour during power ascension (every 33 MWth change in reactor power) and within one hour after achieving the next power plateau per Attachments 3 and 4.Reactor Power will need to be held constant, (within -38 MWth, +0 MWth) for approximately 2 minutes before and 15 minutes during the dryer and FIV data collection per Attachments 3 and 4.5.7 Increasing to 3723 MWth Allowing no other concurrent intrusive activities, RAISE reactor power by 50 MWth to 3723 MWth (3685 MWth to 3723 MWth) in accordance with HC.OP-IO.ZZ-0006, as follows: 5.7.1. While raising reactor power, PERFORM dryer and FIV data collection after the first 33 MWth change in reactor power and each 33 MWth thereafter per Attachments 3 and 4.Initial Date Tim(5.7.2. Within one hour after achieving 3723 MWth (3685 MWth to 3723 MWth), COMMENCE moisture carryover determination per Attachment 9 (non intrusive).

Hope Creek Page 58 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.7.3. MAINTAIN reactor power (3685 MWth to 3723 MWth) for four hours while performing the following non-intrusive activities:

PERFORM dryer and flow induced vibration data collection and EVALUATION per Attachments 3 and 4 (non intrusive).

Data SHALL be obtained within one hour of achieving 3723 MWth.Initial Date Ti REQUEST RE to: 1. VERIFY current reactor conditions are within acceptable values of the power-flow map and thermal limits are met per Attachment 7 (non intrusive).

2. VERIFY all inputs to the heat balance acceptable by reviewing the plant computer (non intrusive).

• PERFORM HC.OP-FT.BB-0001(Q), Jet Pump Data Collection (non intrusive)." After four hours, REQUEST Rad Pro to take Plant Area Radiation and Process Monitor readings and to verify the Main Steam Line Radiation Monitor response is within expected dose ranges (non intrusive).

• After four hours, NOTIFY System Engineering to collect System Performance Monitoring

&Analysis data at 3723 MWth.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 59 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE During the following step, power needs to be held constant with no intrusive activities in progress.

Once data collection is started, changes in recirculation flow or control rod motion may result in invalidating the data. Coordinate any necessary power changes with the RE and Test Team, prior to the performance of this next step.* CONTACT the Test Team to take the Crossflow computer data acquisition (Attachment 11, Feedwater Flow Calibration

-Test 23) readings.Coordinate with the Test Team to maintain steady-state conditions, as necessary, in gathering this data.Initial Date Time" AFTER authorization from the Test Manager, PERFORM Main Turbine Stop, Bypass Valve, and Partial MSIV closure 111.5% CLTP tests lAW Attachment 16, otherwise N/A.Initial Date Time NOTE The following step may take up to three weeks to complete calculations and evaluations necessary to determine the cross-flow correction factor. At the discretion of the Test Manager and Management, reduced PACC staffing may be considered during this time-frame." CONTACT the Test Team to complete the Feedwater Flow Calibration and Crossflow computer evaluation and to determine the Crossflow correction factor.Initial Date Time" The Test Team has REVIEWED the completed Feedwater Flow Calibration data and recommended Crossflow correction factor (Test Team Leader).Initial Date Time Hope Creek HPage 60 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.7.4. Authorization to Apply the Crossflow Correction Factor and Adjust Reactor Power to 3723 MWth.A. Test Manager's permission has been granted to Adjust Reactor Power to 3723 MWth.B. Shift Manager's permission has been granted to Adjust Reactor Power to 3723 MWth.Initial Date Time Initial Date Time Hope Creek Page 61 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

NOTE Dryer and FIV data collection readings (strain gauge and accelerometer data) are to be taken every hour during power ascension (33 MWth change in reactor power) and within one hour after achieving the next power plateau or increment per Attachments 3 and 4.Reactor Power will need to be held constant for approximately 2 minutes before and during the dryer and FIV data collection per Attachments 3 and 4.5.8 Remaining at 3723 MWth Once the Crossflow correction factor is determined, allowing no other concurrent intrusive activities, ADJUST reactor power as necessary to 3723 MWth (3685 MWth to 3723 MWth) in accordance with HC.OP-IO.ZZ-0006, as follows: 5.8.1. While raising reactor power: A. PERFORM dryer and FIV data collection after each 33 MWth change in reactor power per Attachments 3 and 4.B. After 3705 MWth OR 50% of the power step change is achieved as determined by the Test Team, CONTINUE Crossflow computer tuning and data acquisition (Feedwater Flow Calibration

-Test 23). COORDINATE with the Test Team to maintain steady-state conditions, as necessary, in gathering this data.C. CONTINUE the power ascension to 3723 MWth after confirmation by the Test Team of satisfactory Crossflow data evaluation.

Initial Date Time Initial Date Time Initial Date Time Continued on next page Hope Creek Page 62 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

@ 5.8.1 (continued)

D. PERFORM dryer and FIV data collection and EVALUATION per Attachments 3 and 4 after achieving 3723 MWth (3685 MWth to 3723 MWth).Data SHALL be obtained within one hour of achieving 3723 MWth.Initial Date Time E. NOTIFY the test team to complete report preparation that evaluates dryer and FIV data (strain gauge results, evaluations, acceptance criteria, etc,) and makes a recommendation to PORC to remain at 3723 MWth.PORC Review Meeting #: 5.8.2. Within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of achieving 3723 MWth, commence moisture carryover samples per Attachment 9 (non intrusive).

5.8.3. MAINTAIN reactor power 3685 MWth to 3723 MWth for a total of four hours.I_ _ _Initial Date Time Initial Date Time Initial Date Time NOTE Steps 5.8.4 through 5.8.6 may be performed concurrently.

5.8.4. Once the dryer data has been evaluated and approved by PORC and the Plant Manager PERFORM the following (non-intrusive):

A. With assistance from the PACC, TRANSMIT the dryer data files to the Nuclear Regulatory Commission (NRC).B. CONFIRM receipt via telephone or facsimile to the NRC Project Manager. Date stamp or provide other positive acknowledgment of NRC receipt.Initial Date Time Initial Date Time Continued on next page Hope Creek Page 63 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

.5.8.4 (continued)

C. Once confirmation that the NRC has received the dryer and FIV data, RECORD below the start and end time of the 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock (refer to step 5.8.8).Start of 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock: Date /Time _Initial Date Time End of 96 hour0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> clock Date I Time Initial Date Time 5.8.5. After the 4-hour stabilization period, PERFORM the following:

° Cognizant Engineers to perform walkdowns per the EPU System Performance and Monitoring Plans (Attachment 14), including inspections where practicable based on ALARA and safety reasons, a review of CRIDS indications, local indications, control room indications, etc., for systems (components) affected by EPU. Any discrepancy noted shall be discussed with the IPA Coordinator.

Include this documentation within Attachment 14 to this procedure* (non intrusive).

Initial Date Time Plant Engineering Manager" CONTACT the Test Team to perform FIV walkdowns of non-critical piping in accordance with Attachment 4 (non intrusive).

Initial Date Time" TAKE Maximum Feedwater Runout Data lAW Attachment 10 and prepare runout evaluation (non intrusive).

Initial Date Time PERFORM radiation surveys and request Rad Pro to take Plant Area Radiation and Process Monitor readings per Attachment 5 (non intrusive).

Initial Date Time Continued on next page Hope Creek Page 64 of 188 Rev."3 HC.OP-FT.ZZ-0004(Q)

.5.8.5 (Continued)

• CONTACT Chemistry to perform the 3723 MWth required chemistry readings in accordance with Attachment 8 (non intrusive):

Initial Date Time* CONTACT Rad Pro to Verify the Main Steam Line Radiation Monitor response is within the expected dose range for this power plateau (non-intrusive).

Initial Date Time* CONTACT the RE to confirm thermal limits are acceptable and consistent with those predicted for this power plateau and verify current reactor conditions are within acceptable values of the power-flow map (Attachment 7)(non-intrusive).

Initial Date Time* REQUEST RE to verify all inputs to the heat balance are acceptable by reviewing the plant computer (non intrusive).

Initial Date Time* CONTACT System Engineering to complete the Incremental Regulation Data Gathering Evaluation and ENSURE all Level 2 Criteria contained in Section 3.3.1.6 of GE Task Report T1 005 are met.Initial Date Time Continued on next page Hope .Creek Page 65 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.8.5 (Continued)

NOTE Dose Rates as well as MS line radiation monitor readings will be affected by the performance of the following step. This test requires close coordination between Operations, Chemistry, Engineering, and Radiation Protection personnel.

The final EPU radiation surveys need to be taken at the highest achievable HWCI flow rate per the benchmark test in order to bound operation at 3723 MWth.* CONTACT Chemistry to perform the HWCI Benchmark Test in accordance with HC.CH-PT.AX-0001, Hydrogen Benchmark Test (Intrusive).

• CONTACT Radiation Protection to perform radiation surveys and Plant Area Radiation and Process Monitoring readings during the HWCI Benchmark Test at the highest HWCI flow-rate during the test lAW Attachment

5. Note the highest flow-rate below during the test: Initial Date Time HWCI Flow Rate SCFM VERIFY with Radiation Protection that the Main Steam line radiation monitors at set lAW HC.SE-GP.SP-0001.

5.8.6. COMPLETE a report to be presented at PORC used as a basis to recommend to the HCGS Plant Manager to remain at the final TPU power level (non intrusive).

PORC Review Meeting #: Initial Date Time Initial Date Time Hope Creek Page 66 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 5.8.7. Authorization to Remain at 3723 MWth (TPU)The results of testing and data collection performed at the final power level plateau have been analyzed and presented to the HCGS Plant Manager, and approval to remain at this power level has been obtained (non intrusive).

5.8.8. After 96 hours0.00111 days <br />0.0267 hours <br />1.587302e-4 weeks <br />3.6528e-5 months <br /> (or time otherwise agreed upon with the NRC -annotate Step 5.8.4.C accordingly) from the time the NRC received the dryer and FIV data and evaluation submittal and with no objections from the NRC, then have the PACC contact the NRC Project Manager and inform the NRC that HCGS is remaining at the current power level (non intrusive).

Initial Date Time Initial Date Time Verf Date Time 5.8.9. Authorization to Remain at 3723 MWth (TPU)Regulatory Assurance Print / Sign Date/Time Hope Creek Page 67 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

High Pressure Turbine Warranty Testing and Test Completion 5.8.10. In accordance with RE guidance, reduce reactor power in accordance with HC.OP-IO.ZZ-0006, with Crossflow applied to 3673 MWth (3635 MWth to 3673 MWth). PERFORM Main Turbine contract performance testing in accordance with the ITP for DCP 80071904.5.8.11. RAISE reactor power to 3723 MWth lAW HC.OP-IO.ZZ-0006 and ADJUST pressure setpoint to achieve Rated Pressure.5.8.12. PERFORM additional Load Variations lAW HC.OP-IO.ZZ-0006(Q)

Power Changes During Operation.

5.8.13. The results of testing and data collection performed at the target power level plateau have been analyzed and presented to the HCGS Plant Manager and Power Ascension Testing is considered complete and satisfactory. (Non intrusive)

Initial Date Time Initial Date Time Initial Date Time Plant Manager Print / Sign 5.8.14. COMPLETE Attachment 1., Section 2, indicating a satisfactory test.5.8.15. PERFORM an "End of Evolution" critique.CAPTURE lessons learned.5.8.16. Test Complete (Test Manager)Date/Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 68 of 188'Rev. 3 HC.OP-FT.ZZ-0004(Q)

V' 6.0 RECORDS This procedure requires that "data packages" and other performance monitoring data collection be attached to this procedure.

Known attachments have been identified.

For additional attachments, select the next sequential attachment number and record the attachment number in this index, with the document title, number of pages and associated procedure step and on the attached document.

Indicate the consecutive page number and total attachment pages at the bottom of each page.RETAIN the entire procedure.

Verified By: Test Manager/Date

7.0 REFERENCES

7.1 License Change Request H05-01, Hope Creek Generating Station Extended Power Uprate, Revision 1.7.2 Design Change Package 800480855, EPU Implementation, Revision 0.7.3 VTD 430069(002), GE EPU Task Report T1 005, Startup Test Specifications, Revision 2, April 2004.7.4 Licensing Topical report, "Generic Evaluations for General Electric Boiling Water Reactor Extended Power Uprate," NEDC-32523P-A Class III, February 2000 (ELTR-2).7.5 Licensing Topical report, "Generic Guidelines for General Electric Boiling Water Reactor Extended Power Uprate," NEDC-32424P-A Class III, February 1999 (ELTR-1).7.6 NRC Standard Review Plan, Section 14.2.1, Generic Guidelines for Extended Power Up-rate Testing, Draft Rev. 0, December 2002.7.7 HU-AA-1211, Briefing Pre-Job, Heightened Level Of Awareness, Infrequent Plant Activity And Post-Job Briefings.

7.8 HC.OP-IO.ZZ-0006(Q), Power Changes During Operation.

7.9 HC.OP-IO.ZZ-0003(Q), Startup from Cold Shutdown to Rated Power.7.10 HC.OP-AP.ZZ-0108(Q), Operability Assessment and Equipment Control Program.7.11 NC.CC-AS.ZZ-0040, Qualification/Certification of Station Modification Inspection and Test Personnel.

7.12 CC-AA-309-101, Engineering Technical Evaluations.

7.13 NEDO-33159, Extended Power Uprate (EPU) Lessons Learned and Recommendations, BWR Owners Group Issued, Revision 0.0 Hope Creek Page 69 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

REFERENCES (continued) 7.14 ASME OM-S/G-1 994, Standards and Guides for Operation and Maintenance of Nuclear Power Plants, Part 3, 1994 Edition, Requirements for Preoperational and Initial Start-Up Vibration Testing of Nuclear Power Plant Piping Systems.7.15 ASME Boiler and Pressure Vessel Code,Section III Appendices, 1989 Edition.7.16 Estimating High Frequency Flow Induced Vibration in the Main Steam Lines at Hope Creek 1; A subscale Four Line Investigation of Standpipe Behavior, CDI Report 06-16, dated June 2006, VTD 430113.7.17 MPR Letter 1108-0011-HDG01, H. Giesecke to H. Trenka, Evaluation of Hope Creek SRVs for Operation at EPU, VTD 430114.7.18 Flow-Induced Vibration, Main Steam, Feedwater

& Feedwater Heater Drains, Falcon Power, June 14, 2006, VTD 430115.7.19 Hope Creek EPU Vibration Monitor Summary Report, Structural Integrity Associates Report SIR-06-230, dated June 2006, VTD 430116.S 0 Hope Creek Page 70 of 188*Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 1 (Page 1 of 3)SM/CRS DATA AND SIGNATURE SHEET EXTENDED POWER UPRATE POWER ASCENSION TESTING 1.0 PERMISSION TO PERFORM THE TEST SHIFT MANAGER DATE-TIME DATE-TIME HCGS PLANT MANAGER 2.0 POST TEST INFORMATION 2.1 The data acquired during the performance of this test has been reviewed for completeness and compliance with all applicable requirements.of the HCGS Power Ascension Test Program; and the test is considered:

2.1.1. SATISFACTORY (All test acceptance criteria satisfactory)

SHIFT MANAGER PLANT OPERATIONS REVIEW COMMITTEE DATE-TIME MTG. NO DATE-TIME HCGS PLANT MANAGER 2.1.2. UNSATISFACTORY (Any test acceptance criteria not met, provide comments in Remarks below)SHIFT MANAGER DATE-TIME ,Hope Creek Page 71 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT I (Page 2 of 3)SM/CRS DATA AND SIGNATURE SHEET EXTENDED POWER UPRATE POWER ASCENSION TESTING 2.1.3. Remarks (add additional sheets as necessary)

Hope Creek Page 72 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT I (Page 3 of 3)SM/CRS DATA AND SIGNATURE SHEET EXTENDED POWER UPRATE POWER ASCENSION TESTING PROCEDURE PERFORMER(S)

AND VERIFIER(S)

I have read and understand steps of this procedure that I am responsible to perform (all departments).

Add additional sheets as necessary.

PRINT NAME SIGNATURE INITIALS DATE/TIME Hope Creek Page 73 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 2 (Page I of 1)TEST DEFICIENCIES

& RESOLUTIONS EXTENDED POWER UPRATE POWER ASCENSION TESTING This log is intended to document test deficiencies or issues. Plant deficiencies unrelated to power ascension testing shall be entered into the normal corrective action program.Note: Attach additional pages as necessary.

Provided a similar format is used, this log can be maintained by the PACC electronically.

Approval of each deficiency requires IPA Coordinator signature.

NUMBER NOTIFICATION DESCRIPTION RESOLUTION OWNER APPROVED______I__

I___________

I____________

__________I_______1________

a h Hope Creek Page 74 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 1 of 9)DRYER DATA COLLECTION (TEST NO. 101)As stated in the body of this procedure, while raising reactor power above 3339 MWth, main steam line strain gauge and vibration data is to be collected at a minimum of once per hour (or every 33 MWth given a 1% CLTP/hr power ascension rate). Reactor recirculation piping vibration readings are also taken for trending.The hourly (1%) data is taken for trending; whereas data taken at each of the 2.5% power.increments and 5.0% power plateaus requires formal evaluation and comparison to acceptance criteria.This Attachment is to be filled out at each of the power levels specified below. All data collected should be retained as part of the test package as well as any evaluations performed.

Data is obtained in conjunction with FIV data documented in Attachment 4.1.0 Reactor Power The following test was performed with a reactor power of (circle one): 3005 MWth Baseline 3339 MWth Baseline (Prior to EPU and Post EPU)3372 MWth Trending 3405 MWth Trending 3422 MWth Power Increment Evaluation 3455 MWth Trending 3488 MWth Trending 3506 MWth Power Plateau Evaluation 3539 MWth Trending 3572 MWth Trending 3589 MWth Power Increment Evaluation 3622 MWth Trending 3655 MWth Trending 3673 MWth Power Plateau Evaluation 3706 MWth Trending 3723 MWth Power Increment Evaluation (Crossflow Not Applied)3723 MWth Power Plateau Evaluation (Crossflow Applied)Performed By Verified By DATEJTIME DATE-TIME 0 Hope Creek Page 75 of 188 Rev. .3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 2 of 9)DRYER DATA COLLECTION (TEST NO. 101)NOTE Additional data collection may be performed at other power levels as directed by the IPA coordinator or Test Team.Strain gauges and accelerometers are assumed to be installed and tested beforehand.

Reactor power, steam flow, and recirc flow needs to be held steady for approximately 2 minutes before and during the data collection at each test step. The data shall be recorded within one hour of reaching each power increment or plateau.The data is then processed and plotted by the Test Team. Engineering shall provide plots and a written summary of data changes. Engineering shall assess the margin to the limit curve, assess the rate of change in sequential data, and provide a recommendation whether power ascension should continue.2.0 Test Team To Monitor The Followina CRIDS Points: " A2609 Main Steam Line Flow A" A2610 Main Steam Line Flow B" A2611* A2612" A212 Main Steam Line Flow C Main Steam Line Flow D Total Steam Line Flow* A2574 Reactor Water Level* A2575 Reactor Water Level* A2576 Reactor Water Level" A205 Reactor Water Level* A2578 Reactor Pressure 2.1 RECORD Reactor Recirculation Pump Speed and Core Flow (Control Room): A RR Pump Speed_ rpm (System 1)B RR Pump Speed_ rpm (System 1)Total Core Flow. Mlbm/hr (1-BB-FR-R613-B21)

Initial Date Time Initial Date Time HopeCreek Page 76 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 3 of 9)DRYER DATA COLLECTION (TEST NO. 101)3.0 CONFIRM that the Data Acquisition Systems (DAS) on 102'elevation of the reactor building and on 120' elevation of the Turbine Building are on and operational.

4.0 CONFIRM that the test team is prepared to acquire and process data Initial Date Time Initial Date Time NOTE If at any time during testing, Recirc Pump speeds approach or exceed 1500 RPM, the Test Team should be contacted to determine whether Recirc piping vibration data should be obtained lAW ER.HC-370-1001, Hope Creek Reactor Recirculation Piping Vibration Monitoring.

5.0 When the plant is at steady state power, INSTRUCT the test team to collect main steam line strain gauge and accelerometer data.6.0 CONFIRM that both strain gauge and accelerometer data collection was successful.

Record time and date below: Time and date: 7.0 CONFIRM with the test team that the data acquisition has been completed within one hour and commenced evaluation of collecting the strain gauge and accelerometer data. Record date and time of data evaluation completion (n/a if for trending).

Date and time evaluation complete: Initial Date Time Initial Date Time 8.0 IF valid main steam line strain gauge and accelerometer data cannot be recorded within one hour of initially reaching a Power Increment or Plateau, THEN an orderly power reduction shall be made to a lower power level at which data had previously been obtained and evaluated as satisfactory.

Any such power level reduction shall be completed within two hours of determining that valid data was not recorded or was unsatisfactory.

Initial Date Time Hope Creek Page 77 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 4 of 9)DRYER DATA COLLECTION (TEST NO. 101)9.0 Evaluation (power increments

& plateaus only -otherwise, n/a): 9.1 IF the conditions of Table 3-1 can not be met, THEN: 9.1.1. An orderly power reduction shall be made to a lower power level at which data had previously been obtained and evaluated as satisfactory.

Any such power level reduction shall be completed within two hours of determining that valid data was not recorded.Initial Verf 9.2 IF the Level 2 performance criteria is exceeded based on Table 3-2 THEN: 9.2.1. SUSPEND reactor power ascension until an engineering evaluation concludes that further power ascension is justified.

9.2.2. INITIATE a notification.

Initial Date Time Verf Date Time Initial Date Time Initial Date Time Verf Date Time 9.2.3. EVALUATE the cause of any exceedance of the performance criteria.9.2.4. Before resuming reactor power ascension, the steam dryer performance data shall be reviewed as part of an engineering evaluation to assess whether further power ascension can be made without exceeding the Level 1 criteria.Initial Date Time Verf Date Time Hope Creek Page 78 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 5 of 9)DRYER DATA COLLECTION (TEST NO. 101)9.2.5. OBTAIN Plant Manager permission to continue the power ascension.

Initial Date Time Verf Date Time 9.3 IF the Level I performance criteria is exceeded based on Table 3-2, THEN: 9.3.1. INITIATE a reactor power reduction to a previously acceptable power level (i.e., reduce power to a previous step level). Complete power reduction within two hours.9.3.2. TERMINATE the test lAW Section 4.0 of the procedure.

9.3.3. INITIATE a Notification.

9.3.4. EVALUATE the cause of any exceedance of the performance criteria.Initial Date Time Verf Date Time Initial Date Time Initial Date Time Initial Date Time Verf Date Time Hope Creek Page 79 of 188'Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 6 of 9)DRYER DATA COLLECTION (TEST NO. 101)9.3.5. COMPLY with all EPU license conditions applicable to Steam Dryer performance, AND OBTAIN independent verification of the same by Regulatory Assurance personnel prior to additional power ascension..

9.3.6. OBTAIN Plant Manager permission to continue the power ascension.

Verf Date Time Initial Date Time Verf Date Time 9.4 IF any frequency peak from the MS line strain gage data exceeds the Level 1 limit curve established by PSEG and submitted to the NRC staff, THEN: 0 9.4.1. REDUCE reactor power to where the Level 1 limit curve was not exceeded.

Engineering shall reevaluate and document the continued structural integrity of the steam dryer and provide that evaluation to the NRC staff by facsimile or electronic transmission to the NRC project manager prior to further increases in reactor power.Initial Date Time Verf Date Time 9.5 IF any frequency peak from the MS line strain gauge data exceeds the Level 2 limit curve established by PSEG and submitted to the NRC staff, THEN: 9.5.1. DO NOT proceed with further power increases until Engineering reevaluates dryer loads and reestablishes the limit curve.Initial Date Time Verf Date Time Hope Creek Page 80 of 188-Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 7 of 9)DRYER DATA COLLECTION (TEST NO. 101)9.6 IF resonant frequencies are identified on the drywell MS line accelerometers as increasing above nominal levels in proportion to strain gage instrumentation data, THEN: 9.6.1. DO NOT proceed with further power increases.

Engineering shall evaluate the continued structural integrity of the steam dryer and provide that evaluation to the NRC staff by facsimile or electronic transmission to the NRC project manager prior to further increases in reactor power.Initial Date Time Verf Date Time 9.7 IF the Level 1 or Level 2 performance criteria are NOT exceeded based on Table 3-2, THEN: 9.7.1. RECOMMEND to PORC that power ascension testing should continue (Power Plateau) or, RECOMMEND to the Test Manager that power ascension testing should continue (Power Increment).

Initial Date Time Verf Date Time 9.7.2. At the completion of Power Ascension activities, WITHIN 60 days, the MSL strain gauge data shall be used to calculate the steam dryer fatigue usage to demonstrate that continued power operation is acceptable (N/A if not at the final Power Plateau).Initial Date Time Verf Date Time 9.8 INCLUDE all dryer performance data and water level trend data with this package.Initial Date Time Hope Creek Page 81 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 8 of 9)DRYER DATA COLLECTION (TEST NO. 101)Table 3-1 Parameter Surveillance Frequency 1. Main steam line pressure data Hourly when initially increasing power above a from strain gauges (dryer previously attained power level (accomplished by data) taking data every 33 MWth).AND At least once at every Power Increment and Power Plateau (83 MWth) above 3339 MWth (Note 1)2. Main steam piping Hourly when initially increasing power above a accelerometer data from previously attained power level (accomplished by accelerometers in drywell taking data every 33 MWth).AND At least once at every Power Increment and Power Plateau (83 MWth) above 3339 MWth (Note 1)3. Reactor Recirculation piping If at any time during testing, Recirc Pump speeds vibration data (trending only- approach or exceed 1500 RPM, the Test Team optional for test) should be contacted to determine whether Recirc piping vibration data should be obtained.4. RPV NR water level Hourly when initially increasing power above a previously attained power level (accomplished by taking data every 33 MWth).AND At least once at every Power Increment and Power Plateau (83 MWth) above 3339 MWth Notes to Table 3-1: 1. The strain gauge and accelerometer surveillance shall be performed hourly when increasing power above a level at which data was previously obtained.

The intent of this is met by taking data every 33 MWth assuming a 1% CLTP/hr power ascension rate. The surveillance of both the strain gauge data and accelerometer data is also required to be performed once at each Power Increment and Power Plateau (83 MWth change) above 3339 MWth within one hour. If the surveillance is met at a given power level, additional surveillances do not need to be performed at-that power level where data had previously been obtained.If valid strain gauge data cannot be recorded hourly orwithin one hour of initially reaching a 83 MWth power increment or plateau, an orderly power reduction shall be made to a lower power level at which data had previously been obtained and evaluated as satisfactory.

Any such power level reduction shall be completed within two hours of determining that valid data was not' recorded.0 Hope Creek Page 82 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 3 (Page 9 of 9)DRYER DATA COLLECTION (TEST NO. 101)Table 3-2 Performance Criteria Not to be Exceeded Required Actions if Performance Criteria Exceeded and Reauired Completion Times* Level 2: 1. Suspend reactor power ascension until an engineering evaluation concludes that further* Pressure data exceed Level 2 power ascension is justified.

Spectral 2. Before resuming reactor power ascension, the* Confirmed and unexplained steam dryer performance data shall be reviewed unbalance of RPV water level as part of an engineering evaluation to assess> 3 inches between level whether further power ascension can be made instruments from different reference without exceeding the Level 1 criteria.legs.Level 1: 1. Initiate a reactor power reduction and achieve a previously acceptable power level (i.e., reduce* Pressure data exceed Level 1 power to a previous step level). Complete power Spectra 1 reduction within two hours 2. Comply with all EPU license conditions applicable to Steam Dryer performance, AND Obtain independent verification of the same by Regulatory Assurance personnel prior to additional power ascension.

.1 The EPU spectra shall be determined and documented in an engineering calculation or report.Acceptable Level 2 spectra shall be based on maintaining

< 80% of the ASME allowable alternating stress value of Sa.Acceptable Level 1 Spectra shall be based on maintaining the ASME Sa.Hope Creek Page 83 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 1 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)This test is performed in conjunction with Attachment 3, Dryer Data Collection.

As stated in Attachment 3, hourly data is taken for trending purposes only.Flow Induced Vibration (FIV) data is required to be evaluated at each of the EPU power increments (2.5% steps) and power plateaus (5.0% steps) and FIV walk-downs are required to be performed at each power plateau (5.0% step). This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any evaluations associated with its completion.

Data is gathered in conjunction with the acquisition of dryer data contained in Attachment

3. Refer to Attachment 3 for steps associated with obtaining vibration data.1.0 REACTOR POWER The following test was performed with a reactor power of (circle one): 3005 MWth Baseline 3339 MWth Baseline (Pre EPU and Post EPU)3372 MWth Trending 3405 MWth Trending 3422 MWth Power Increment

-Evaluation Only 3455 MWth Trending 3488 MWth Trending 3506 MWth Power Plateau -Evaluation and Walkdowns 3539 MWth Trending 3572 MWth Trending 3589 MWth Power Increment -Evaluation Only 3622 MWth Trending 3655 MWth Trending 3673 MWth Power Plateau -Evaluation and Walkdowns 3706 MWth Trending 3723 MWth Power Increment (Crossflow Not Applied) -Evaluation Only 3723 MWth Power Plateau (Crossflow Applied)-Evaluation

& Walkdowns Initial Date Time Verf Date Time Hope Creek Page 84 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 2 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)2.0 PROCEDURE 2.1 RECORD Reactor Recirculation Pump Speed and Core Flow (Control Room): A RR Pump Speed rpm (System 1)B RR Pump Speed rpm (System 1)Total Core Flow Mlbm/hr (1-BB-FR-R613-B21) 2.2 Table 4-1 lists the accelerometers mounted on critical piping. In addition, accelerometers are mounted on MS line Safety Relief Valves (SRV) "A", "B", "P", and "J". Accelerometer vibration data shall be recorded concurrently with steam dryer data, as outlined in Attachment

3. This includes taking piping vibrating trending data at nominal 1% power increases.

Accelerometers mounted on the SRV pilots (channels 31 and 33-42) are used as input to both the piping acceptance criteria (expressed in g-rms) and the SRV vibration acceptance criteria (expressed in g's). Channel 32 is used only for the acceptance criteria for the solenoid operator valve (SOV) on the SRV.2.3 COMPLETE Table 4-1 at the power specified in Section 1.0 and evaluate against established acceptance criteria, Section 3.0. Note that any UNSAT indication requires a Notification and an Engineering Evaluation.

IF Level 1 criteria is exceeded, REQUEST Operations to lower reactor power to the last tested power level.2.4 At the Power Plateaus ONLY, (3506 MWth, 3673 MWth, and 3723 MWth with Crossflow applied) perform the FIV walkdown and visual inspections as specified by Table 4-2.Hope Creek Page 85 of 188 Rev. 3 HC..OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 3 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)Table 4-1 -EPU FIV Recorded Values Recorded Acceptance Le vei Drywell Criteria (g-rms) Level Piping (g-rms)channel Approximate at % % of % of# Channel ID location on piping Level 2 Level 1 CLTP level 2 level 1 1 26A-FW-220X 12" A line 0.446 0.557 2 26A-FW-220Y 12" A line 0.998 1.248 3 27A-FW-280X 12" B line 0.350 0.438 4 27A-FW-280Z 12' B line 0.116 0.145 5 28A-FW-160X Near 24/12 red. 0.662 0.828 6 28A-FW-160Y Near 24/12 red. 0.714 0.893 7 13A-MSA-81X 26" by MSIV, 107' 0.350 0.438 8 13B-MSA-81Y 26" by MSIV, 107' 0.508 0.635 9 14A-MSB-534X 26" by venturi 0.258 0.323 10 14B-MSB-534Y 26" by venturi 0.274 0.343 11 15A-MSA-22JX SRV "J" disch. 0.414 0.518 12 15B-MSA-22JZ SRV "J" disch. 0.238 0.298 13 16A-MSB-40PX SRV P" disch. 0.810 1.013 14 16B-MSB-40PY SRV "P" disch. 0.097 0.121 15 16C-MSB-40PZ SRV "P' disch. 0.506 0.633 16 17A-MSA-430Y RCIC line 0.994 1.342 17 17B-MSA-430Z RCIC line 0.775 0.969 18 25A-FW-50X 24" by valves 0.336 0.420 19 25B-FW-50Y 24" by valves 0.444 0.555 20 25C-FW-50Z 24" by valves 0.420 0.525 21 29A-FW-ZO002X 12" C line 0.374 0.468 22 29B-FW-ZOO02Y 12" C line 1.247 1.559 23 29C-FW-ZO002Z 12" C line 0.282 0.352 24 20A-MSA-14X vert riser, 154' 0.467 0.584 25 20B-MSA-14Z vert riser, 154' 0.392 0.490 26 21A-MSB-490Y horiz by SRVs 0.237 0.296 27 21B-MSB-490Z horiz by SRVs 0.187 0.234 28 22A-MSB-460X vert riser 140' 0.379 0.474 29 22B-MSB-460Y vert riser 140' 0.212 0.265 30 22C-MSB-460Z vert riser 140' 0.306 0.383 Note: Record any failed sensors here and indicate NS in the Table above meaning "no signal" due to failed instrument:

40 Hope Creek Page 86 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 4 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)Table 4-1 -EPU FIV Recorded Values (continued)

Piping Acceptance Recorded Criteria (g-rms) Level SRV (g-rms)channel Accelerometer at % % of % of# Channel ID location on SRV Level 2 Level 1 CLTP level 2 level 1 31 SRV A lateral Pilot Operator 0.840 1.05 33 SRV A axial Pilot Operator 0.600 0.75 34 SRV J lateral Pilot Operator 1.288 1.61 35 SRV J vertical Pilot Operator 0.264 0.33 36 SRV J axial Pilot Operator 0.344 0.43 37 SRV B lateral Pilot Operator 0.968 1.21 38 SRV B vertical Pilot Operator 0.312 0.39 39 SRV B axial Pilot Operator 0.712 0.89 40 SRV P lateral Pilot Operator 0.472 0.59 41 SRV P vertical Pilot Operator 0.240 0.30 42 SRV P axial Pilot Operator 0.704 0.88 SRV Acceptance Recorded SRV Criteria (g) Level (g)channel Accelerometer at % % of % of# Channel ID location on SRV Level 2 Level 1 CLTP level 2 level 1 31 SRV A lateral Pilot Operator 0.800 1.000 32 SRV A vertical SRV SOV 0.800 1.000 33 SRV A axial Pilot Operator 0.800 1.000 34 SRV J lateral Pilot Operator 0.800 1.000 35 SRV J vertical Pilot Operator 0.800 1.000 36 SRV J axial Pilot Operator 0.800 1.000 37 SRV Blateral Pilot Operator 0.800 1.000 38 SRV B vertical Pilot Operator 0.800 1.000 39 SRV B axial Pilot Operator 0.800 1.000 40 SRV P lateral Pilot Operator 0.800 1.000 41 SRV P vertical Pilot Operator 0.800 1.000 42 SRV P axial Pilot Operator 0.800 1.000 Note: Record any failed sensors here and indicate NS in the Table above meaning "no signal" due to failed instrument:

Hope Creek HPage 87 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 5 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)Table 4-1 -EPU FIV Recorded Values (continued) 0 Recorded Acceptance Le el Steam Criteria (g-rms) Level Tunnel (g-rms)channel Approximate at % % of % of Channel ID location on piping Level 2 Level 1 CLTP level 2 level 1 1 05A-FW-731X downstream 0.275 0.344 2 05A-FW-731X downstream 0.267 0.334 3 06A-FW-817Y upstream 0.209 0.261 4 06A-FW-817Z upstream 0.272 0.340 5 01A-MSA-Z013X nearer pen 0.170 0.212 6 01B-MSA-ZO13Y nearer pen 0.195 0.244 7 02A-MSA-ZO18X after first elbow 0.159 0.199 8 02B-MSA-ZO18Y after first elbow 0.130 0.163 9 02C-MSA-ZO18Z after first elbow 0.190 0.237 10 03A-MSB-ZO003X nearer pen 0.180 0.225 11 03A-MSB-ZOO03Y nearer pen 0.179 0.224 12 04A-MSB-ZO008X after first elbow 0.173 0.216 13 04B-MSB-ZOO08Y after first elbow 0.198 0.248 14 04C-MSB-ZO008Z after first elbow 0.262 0.328 15 07A-ES-46X by 6A FWH 0.118 0.148 16 07B-ES-46Y by 6A FWH 0.325 0.406 17 08A-ES-Z010X by 6B FWH 0.064 0.080 18 08B-ES-ZO10Y by 6B FWH 0.213 0.266 19 08C-ES-Z010Z by 6B FWH 0.260 0.325 20 09A-ES-230GX by 6B FWH 0.032 0.040 21 09B-ES-230GY by 6B FWH 0.276 0.345 22 IOA-ES-ZO08X by 6C FWH 0.045 0.056 23 1OB-ES-ZO08Y by 6C FWH 0.262 0.328 24 1OC-ES-ZO08Z by 6C FWH 0.106 0.132 Note: Record any failed sensors here and indicate NS in the Table above meaning "no signal" due to failed instrument:

Hope Creek Page 88 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 6 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)Table 4-2 -FIV Walkdowns Heater Bay, Condensate and Feedwater Pump Rooms Plant Location Vibration Level Observation Sat/Unsat Sign/Date Comments*0 Primary Condensate Pump Room Piping J/(54 ft turbine building)Secondary Condensate Pump Room Piping J_(54 ft turbine building)Feedwater Pump Room Piping & Surrounding Area (137 ft Turb.Bldg.)

No. 6 Feedwater Heater Rooms (Note 1)No 3, 4 and 5 Feedwater Heater Rooms (Note 1)Condenser Bay Piping Systems: Main Steam Piping MS Low Point Drains ,/Extraction Steam /Heater Drains Note 1: Cameras may be used in lieu of actual walk-downs where appropriate for ALARA reasons.*Attach additional Sheets as necessary.

Hope Creek HPage 89 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 7 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)3.0 ACCEPTANCE CRITERIA Acceptance criteria associated with critical piping are specified in Table 4-1.Level 1: Vibration level exceeds the acceptance criteria.

Request Operations to lower reactor power to the last known tested power level.Level 2: Vibration level exceeds 80% (but less than 100%) of acceptance criteria.

Hold at that power level and evaluate prior to resuming power ascension.

This may include performing further analysis with the specific vibration levels recorded.Non-instrumented piping: Level 1: Vibration levels are both significant and have increased significantly above the vibration at the previous power level.Level 2: Vibration levels have increased significantly above the vibration at the previous power level and further increases would be viewed as raising a serious concern.Note: For main piping, if the level of vibration is too small to be perceived, and the possibility of fatigue issues is judged to be minimal, the piping system is acceptable.

Any observed vibration levels judged by walkdown personnel to be a potential concern will be monitored utilizing hand-held vibration meters and evaluated.

MS Line SRVs: Vibration data from the SRVs are to be compared against the acceptance criteria of 1.0 g at any SRV resonant frequency (For channel 32, the acceptance criteria of 1.0 g is at the SOV resonance frequency).

The acceptance criteria was established to preclude FIV causing (a) valve seat leakage (b) wear (c) overstress, and (d) relaxation of the bolting attaching the solenoid assembly to the pilot assembly, Level 1 and 2 limits are: Level 1: Vibration level exceeds the acceptance criteria.

Lower reactor power to the last tested power level.Level 2: Vibration level exceeds 80% (but less than 100%) of acceptance criteria.

Hold at the power level and evaluate prior to resuming power ascension.

This may include performing further analysis with the specific vibration levels recorded.System/Components:

Baseline inspections of systems and components were performed at CLTP (documented in LCR H05-01, Attachment 8, Summary of FIV Investigation at EPU conditions).

Results of EPU power ascension testing, inspections and walk-downs will be compared to baseline inspection results to determine if acceptability is maintained.

Performed by: Sign/Date (Design Engineering)

Verified by: Sign/Date (Design Engineering)

Acceptance Criteria Met __Sign/Date (Design Engineering)

Hope Creek Page 90 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 4 (Page 8 of 8)FLOW INDUCED VIBRATION (TEST NO. 100)RECORD instruments used and calibration due dates (attach additional sheets as necessary):

Hope Creek Page 91 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 1 of 8)RADIATION SURVEYS (TEST 2)As discussed in the body of this procedure, Plant Area Radiation and Process Monitors will be monitored at 3005 MWth, 3339MWth, 3422 MWth , and 3589 MWth as part of System Monitoring trending activities associated with this test.This Test requires Radiation Surveys and formal evaluation of selected Plant Area Radiation and Process Monitors at each of the EPU power plateaus.

This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any evaluations or RM-1 1 printouts associated with its completion.

1.0 REACTOR POWER The following test was performed with a reactor power of (circle one): 3506 MWth w/HWCI in Service @ SCFM 3673 MWth w/HWCI in Service @ SCFM 3723 MWth w/HWCI in Service @ SCFM (Crossflow Applied)3723 MWth w/HWCI Maximized During HWCI Benchmark Test Note: Reactor Power tolerance for each plateau is -38 MWth, +0 MWth.Initial Date Time 2.0 INSTRUMENTATION List instrument(s) used, serial number and calibration due date.Hope Creek Page 92 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 2 of 8)RADIATION SURVEYS (TEST 2)3.0 PROCEDURE 3.1 At the Reactor Power specified in Section 1.0 above, PERFORM the radiation surveys contained in Table 5-1.3.2 At the Reactor Power specified in Section 1.0 above, OBTAIN printouts of Process Monitors and Area Radiation Monitors from the Radiation Monitoring System (RM-1 1). EVALUATE results against similar printouts with the plant at 100% power and 9 SCFM HWCI flow.3.3 EVALUATE the results obtained in Section 3.2 above against the design basis criteria contained in Tables 5-2 and 5-3.3.4 RETAIN all RM-1 I printouts and attach to this portion of the procedure.

4.0 ACCEPTANCE CRITERIA Level 1: The radiation doses of plant origin and the occupancy times of personnel in radiation zones shall be controlled consistent with the guidelines of the Standard for Protection Against Radiation outlined in 10 CFR 20 (Ref. GE Task TI 005).Level 2: 1) Radiological Boundaries and posting have been established lAW site procedures following the power uprate to the specified MWth Level.2) Personnel Dose Monitoring and appropriate ALARA controls have been implemented in accordance with site procedures following the power uprate to the specified MWth level.3) Radiation levels remain below design basis projected levels as shown in Table 5-2, Setpoint Bases-Radiation Zone Maps, and in Table 5-3 for the Gaseous Radiation Monitors, or an evaluation is performed to justify a higher setpoint.Note: Calculation H-1 -ZZ-MDC-1 956 states that setpoints associated with the Liquid Effluent monitors in Table 5-3 are based on default pre-EPU values which may require change. This will be based on post-EPU implementation continuous and batch release data which will be collected during subsequent cycles as part of the post-EPU monitoring program. Since the releases are governed by other plant procedures, they are not considered acceptance criteria for this test.Initial Date Time Verf Date Time Hope Creek Page 93 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 3 of 8)RADIATION SURVEYS (TEST 2)TABLE 5-1 -RADIATION SURVEYS BASE DESCRIPTION CONTACT GENERAL POINT MAP # DOSE RATE AREA DOSE (MR/HR) RATE (MR/HR)H07A 0700-A PLANT ROOF H11A 1100-A TURBINE 54' SOUTH Hlll 1100-A TURBINE 54' SOUTH H11M 1100-A TURBINE 54' SOUTH H11L 1100-A TURBINE 54'SOUTH H12B 1200-A TURBINE 77'-87'ELEVATIONS H12J 1200-A TURBINE 77'-87'1200_A ELEVATIONS H12K TURBINE 77'-87'ELEVATIONS H12S TURBINE 77'-87'ELEVATIONS H120 TURBINE 77'COMMON 1200-C AE ____AREA H12P TURBINE 77'COMMON 1200-C AREA AREA H13D TURBINE 102' COMMON 1300-C A E _ _ _ _ _ _ _ _ _AREA H13W TURBINE 102' COMMON 1300-C AE AREA H13G TURBINE 102' -111'1300-ELEVATIONS H13H TURBINE 102'- 111'1300-A ELEVATIONS___________

H3M 1300-A TURBINE 102' 111'ELEVATIONS H13P TURBINE 102'- 111'ELEVATIONS H13T TURBINE 102'- 111'1- ELEVATIONS Hop1Cee PagBIE 942of 188Re'0 Hope Creek Page 94 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 4 of 8)RADIATION SURVEYS (TEST 2)TABLE 5-1 -RADIATION SURVEYS (CONTINUED)

BASE MAP # DESCRIPTION CONTACT GENERAL POINT DOSE RATE AREA DOSE (MRIHR) RATE (MR/HR)H14B TURBINE 120' SERVICE AIR 1400-B MEZZANINE H14F TURBINE 120' SERVICE AIR MEZZANINE H15B 1500-A TURBINE 137' ELEVATION H15M 1500-A TURBINE 137' ELEVATION H150 1500-A TURBINE 137' ELEVATION H15R 1500-A TURBINE 137'_ELEVATION H15V 1500-A TURBINE 137'_ELEVATION H15W 1500-A TURBINE 137'_ELEVATION H15X 1500-A TURBINE 137' ELEVATION H15F 1500-A TURBINE 137' ELEVATION H15E 1500-A TURBINE 137'_ELEVATION H15D 1500-A TURBINE 137'_ELEVATION H15K 1500-A TURBINE 137' ELEVATION H15T 1500-A TURBINE 137' ELEVATION H17A 1700-A TURBINE 171' ELEVATION H17B 1700-A TURBINE 171' ELEVATION 0 Hope Creek H CPage 95 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 5 of 8)RADIATION SURVEYS (TEST 2)TABLE 5-1 -RADIATION SURVEYS (CONTINUED)

BASE MAP # DESCRIPTION CONTACT GENERAL POINT DOSE RATE AREA DOSE (MR/HR) RATE (MR/HR)H33A 3300-C UNRESTRICTED MACHINE SHOP H33D 3300-C UNRESTRICTED MACHINE SHOP H31L 3100-A S/RW-54 H31A 3100-A S/RW-54 H31M 3100-A S/RW-54 H31B 3100-A S/RW-54 H34A 3400-A S/RW 124' ELEVATION

-UNCONTROLLED LOCKER AREA H34B 3400-B S/RW 124' ELEVATION

-UNCONTROLLED LOCKER AREA H41A 4100-A RX 54' ELEVATION H41B 4100-A RX 54' ELEVATION H43A 4300-A RX 102' ELEVATION H43B 4300-A RX 102' ELEVATION H43G 4300-A RX 102' ELEVATION H43J 4300-A RX 102' ELEVATION H44A 4400-A RX 132' ELEVATION H44B 4400-A RX 132' ELEVATION H44G 4400-A RX 132' ELEVATION H44H 4400-A RX 132' ELEVATION___ I ____ I ___________

I _____ [ ______Hope Creek Page 96 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 0 ATTACHMENT 5 (Page 6 of 8)RADIATION SURVEYS (TEST 2)TABLE 5-2 -DESIGN BASIS RAD MONITOR SETPOINTS Hope Creek Generating Station Area Radiation Monitor (ARM) Setpoint Data Serial Service Grid High Unit Setpoint Reference No. Icon Alarm Basis Setpoint Radiation Value Zone Maps 1 Personal Airlock Area 9RX700 2.50E+00 mR/hr < 2.5 mR/hr Calc H-1-ZZ-I I_ MDC-1956 2 Motorized Equipment 9RX701 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ--latch Area MDC-1956 3 Open Equipment Hatch 9RX702 7.50E+00 mR/hr Historical Calc H-1-ZZ-_ ,rea 145'. MDC-1956 4 Open Equip Hatch 162 9RX703 5.00E+00 mR/hr Historical Calc H-1-ZZ-_ ,rea Rad I MDC-1956 5 Safeguard Instrument 9RX704 1.50E+01 mR/hr Historical Calc H-1-ZZ-Room MDC-1956 6 Equipment Airlock Area 9RX705 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ-6moom MDC-1956 RWCU Demineralizer Calc H-1-ZZ-7 9RX706 2.50E+00 mR/hr <2.5 mR/hr C-1956 System ARM MDC-1956 8 Spent Fuel Storage Pool 9RX707 1.38E+01 mR/hr <2.5 mR/hr Calc H-I-ZZ-8mrea MDC-1956 9 Radwaste Drum Shipping 9RX709 1.00E+03 mR/hr Historical Calc H-1-ZZ-9Xrea MDC-1956 TS Table 10 Main Control Room 9RX710 2.50E+00 mR/hr 37 Table 1 3.3.7.1-1 11 Chemistry Lab Sample 9RX711 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ-Rrea MDC-1956 Calc H-1-ZZ-12 Auxiliary Hatch Area 9RX712 2.50E+00 mR/hr <2.5 mR/hr C-1956 MDC-1956 Calc H-1-ZZ-13 Restricted Machine Shop 9RX713 2.50E+00 mR/hr <2.5 mR/hr C-1 956 I MDC-1956 Calc H-1-ZZ-14 Restricted Machine Shop 9RX714 2.50E+00 mR/hr <2.5 mR/hr C-1 956 M DC-1956 Calc H-1-ZZ-15 FRVSV LRP Area 9RX720 2.50E+00 mR/hr <2.5 mR/hr MDC-1 956 Calc H-1-ZZ-16 FRVSV Skid Area 9RX721 2.50E+00 mR/hr <2.5 mR/hr C-1956 MDC-1956 Hope Creek Page 97 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 7 of 8)RADIATION SURVEYS (TEST 2)TABLE 5-2 -DESIGN BASIS RAD MONITOR SETPOINTS Hope Creek Generating Station Area Radiation Monitor (ARM) Setpoint Data Serial Service Grid High Unit Setpoint Basis Reference No. Icon Alarm Radiation Zone Setpoint Maps Value 17 Outside of Reactor Bldg 9RX723 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ-Sample Station MDC-1956 18 Offgas Treatment Control 9RX724 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ-8 oom MDC-1956 19 Liquid Radwaste Control 9RX722 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ-Room MDC-1956 20 Offgas Vial Sample 9RX716 2.50E+00 mR/hr <2.5 mR/hr Calc H-1-ZZ-Station MDC-1956 Calc H-1-ZZ-21 Technical Support Center 9RX620 2.50E+00 mR/hr <0.5 mR/hr C-1956 MDC-1956 22 Inside of Reactor Building 9RX708 5.00E+01 mR/hr Historical Calc H-1-ZZ-Sample Station MDC-1956 23 Radwaste Sample 9RX717 1.00E+01 mR/hr Historical Calc H-1IZZ-Station MDC-1956 Calc H-1-ZZ-24 New Fuel Storage Area 9RX612 6.54E+00 mR/hr Historical MDC-1956 MDC-Z1956 26 Outside TIP Room 9RX698 6.OOE+02 mR/hr Historical C-1956 I MDC-1956 Calc H-1-ZZ-27 Inside TIP Room 9RX699 4.OOE+04 mR/hr Historical CalcH-1-ZZ-I MDC-1956 Hope Creek Page 98 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 5 (Page 8 of 8)RADIATION SURVEYS (TEST 2)Table 5-3 -Liquid & Gaseous Rad Monitor Data Hope Creek Generating Station Liquid & Gaseous Effluent (ODCM) Radiation Monitor Data Service Grid High Unit Setpoint Reference Icon Alarm Basis Setpoint Value Normal 9RX508 5.58E-04 plCi/ml Release Release Calc H-1-ZZ-Liquid Radwaste Monitor Condensate MDC-1956 9RX508 7.55E-05 ýtCi/ml Storage Tank Release 2 Cooling Tower Calc H-1-ZZ-3lowdown Monitor 9RX506 8.94E-06 pCi/mI ODCM MDC-1956 Turbine Building 9RX505 9.82E-04 pCi/ml Batch Calc H-I-ZZ-3 _3irculating Water Release Only MDC-1956 ewatering 9RX505 6.38E-07 Ci/ml Continuous Calc H-1-ZZ-\Aonitor 1 1 1 m1Release MDC-1956 North Plant Vent Monitor PIG -Gas 9RX597 1.60E-05 pCi/ml 4 PIG -Particulate 9RX600 1.OOE-03 pCi/ml Annual offsite Calc H-1-ZZ-PIG -Iodine 9RX601 1.OOE-05 pCi/ml dose limit of Effluent 9RX590 3.08E+03 gCi/sec 500 mR/yr Noble Gas Low 9RX602 N/A ICi/mlI South Plant Vent Monitor PIG -Gas 9RX596 8.OOE-06 pCi/ml PIG -Particulate 9RX604 1.00E-03 gCi/ml Annual offsite Calc H-1-ZZ-PIG -Iodine 9RX605 1.0OE-05 pCi/ml dose limit of MDC-1956 Effluent 9RX580 3.08E+03 pCi/sec 500 mR/yr Noble Gas Low -9RX606 N/A -Ci/mlI FRVS Vent Monitor 6 Effluent 9RX680 1.45E+03 ýpCi/sec Annual offsite Calc H-1-ZZ-dose limit of M C 1 5 Noble Gas Low 9RX640 N/A pCi/ml 500 mR/yr MDC-1956 0 Hope Creek Page 99 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 6 (Page 1 of 3)TURBINE VALVE SCRAM BYPASS SETPOINT DATA COLLECTION (TEST 22)DESCRIPTION:

The "pre-test" GE Turbine First Stage Pressure set-point calculation has concluded that the new HP turbine Technical Specification Turbine First Stage Bypass Permissive (TFSP) relationship to reactor power is as follows (GE Task T0506): Tech. Spec.Analytical Value Allowable Value Nominal Trip Setpoint 1st Stage Pressure 125.3 psig 112.3 psig 104.2 psig EPU Power 24%<24%<24%CLTP Power 27.6%<27.6%<27.6%Since the "pre-test" calculation has a potential error because of turbine manufacturing tolerances, the purpose of this test is to validate the heat balance for the turbine at reduced power used to establish the above limits, and based on measured values to determine if a "bias" needs to be applied to the "pre-test" estimate that needs to be accounted for in the set-point calculation.

The set-point adjustment procedure is detailed in GE Task T0506, Rev. 1, Attachment

2.1.0 PROCEDURE

1.1 VERIFY that the main generator has been synchronized to the grid.1.2 VERIFY that ALL feedwater heaters are In-Service AND that Pressure Set (DEHC) is set to 905 psig.1.3 VERIFY that STR signals 1, 56, and 161 are available in GETARS (1AC480) and CRIDS points A2621 and A213 are available.

Initial Date Time Initial Date Time NOTE During all data collection steps all turbine bypass valves must be shut and plant parameters at steady state conditions.

Heat balance for this procedure can either be done by a manual heat balance calculation lAW RE-RA.ZZ-0001 (Q) or from the Plant Process Computer as determined by the Reactor Engineer.Notification 20312405 documents that CRIDS point A2621 historically reads 13 psig higher than A213.0 Hope Creek Page 100 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

• ATTACHMENT 6 (Page 2 of 3)TURBINE VALVE SCRAM BYPASS SETPOINT DATA COLLECTION (TEST 22)1.4 VERIFY that there is a "TCV Fast Close & MSV TRIP BYP" alarm in window C5-C2 of 10C690.Initial Date Time 1.5 IF during power increases, the "TCV FAST CLOSE & MSV TRIP BYP" alarm in window C5-C2 clears, STOP the power increase and COMPLETE the last column of Table 6-1 Initial Date Time 1.6 At approximately 2% power increments from generator sychronization, COMMENCE recording data and complete Table 6-1, as follows: A. RUN GETARS (1AC480) and record Signal 1, 56 and 161 data on Table 6-1 AND CRIDS #A2621 and #A213, Main Turbine 1 st Stage Pressure.Initial Date Time B. Reactor Engineering to RECORD reactor power on Table 6-1. 1_ _ 1__ 1_ _Initial Date Time C. RECORD the trip status and meter indication of the Main Turbine 1 st Stage Pressure trip units N652A-D (10C609/611) on Table 6-1.Initial Date Time 1.7 PRIOR to EXCEEDING a reactor power of 30% RTP (1001 MWth), ENSURE that all four N652 A-D trip units, indicate that the bypass is not in affect and that overhead alarm C5-C2 is clear.Initial Date Time Verf Date Time 1.8 Test Team to perform the "post-test" setpoint calculation and adjustment using the procedure outlined in GE Task Report T0506, Revision 1, Attachment 2.Initial Date Time 1.9 IF the "post-test" setpoint evaluation indicates that a "bias" needs to be applied, PREPARE a Notification to adjust the set-point and document in Attachment 2 to this test procedure.

CR Number (N/A, if applicable):_

Initial Date Time Hope Creek Page 101 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 6 (Page 3 of 3)TURBINE VALVE SCRAM BYPASS SETPOINT DATA COLLECTION (TEST 22)1.10 Acceptance Criteria: 1.10.1 Level 1: The Turbine 1 st Stage Pressure Bypass trip units N652A, B, C and D must be clear prior to exceeding a reactor power of 30% in accordance with Technical Specification requirements.

1.10.2 Level 2: The Turbine 1 st Stage Pressure Bypass trip units N652A, B, C and D must clear prior to exceeding an Analytical Value of 125.3 psig as determined in the GE "pre-test" set-point calculation.

Initial Date Time Verf Date Time TABLE 6-1 REACTOR POWER VERSUS TURBINE 1 ST STAGE PRESSURE Reactor Power 16% 18% 20% 22% 24% 26% 28% 30% TRIP (via APRMs)Reactor Power RE-Ht.Balance Reactor Power Signals 1, 56 Main Turb. Is Stg Pressure CRIDS A2621 Main Turb. 1 st Stg Pressure CRIDS A213 Main Turb. 1 st Stg Pressure Signal 161 N652A% /Tripped Y or N N652B % /Tripped Y or N N652C % /Tripped Y or N N652D% /aTriwed Y or N-.a ___________

-__________

__________

U __________

U U U __________

L Hope Creek Page 102 of 188 Rev. 3 0 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 7 (Page 1 of 3)CORE PERFORMANCE DATA (TEST 19)POWER/Core Flow MFLCPR MAPRAT MFLPD Flow Level 1 Limit MFLCPR MAPRAT MFLPD Within P/F Map< 105M#/hr Core Max Value < 1.00 < 1.00 < 1.00 Limits Power Level Predicted/

Predicted/

Predicted/

Predicted/

Initials Actual Actual Actual Actual 3005 MWth (-90% CLTP)No Crossflow 3339 MWth (-100% CLTP)No Crossflow 3422 MWth (-102.5% CLTP)No Crossflow Hope Creek Page 103 of 188 Rev. 3 0 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 7 (Page 2 of 3)CORE PERFORMANCE DATA (TEST 19 Core Flow MFLCPR MAPRAT MFLPD POWER/Flow Level 1 Limit <105M#/hr MFLCPR MAPRAT MFLPD Within P/F Map Core Max Value < 1.00 < 1.00 < 1.00 Limits Power Level / Predicted/

Predicted/

Predicted/

Predicted/

Initials Actual Actual Actual Actual 3506 MWth (-105% CLTP)No Crossflow 3589 MWth (-107.5% CLTP)No Crossflow 3673 MWth (-110% CLTP)No Crossflow Hope Creek Page 104 of 188 Rev. 3 0 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 7 (Page 3 of 3)CORE PERFORMANCE DATA (TFSRT 1 m CORE PERFORMANCE DA Core Flow MFLCPR MAPRAT MFLPD POWER/Flow Level 1 Limit MFLCPR MAPRAT MFLPD Within P/F Map Core Max Value < <1.00 < 1.00 < 1.00 Limits Power Level / Predicted/

Predicted/

Predicted/

Predicted/

Initials Actual Actual Actual Actual 3723 MWth (-111.5% CLTP)No Crossflow 3723 MWth (-111.5% CLTP)Crossflow Applied Notes Performed by Approved by Name DT-IM DATE-TIME DATE-TIME Name Hope Creek Page 105 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 8 (Page 1 of 5)CHEMISTRY DATA (TEST 1)The following readings are to be taken by Chemistry Personnel during the HCGS EPU Power Ascension (above 3339 MWth) in accordance with the frequency specified.

Readings and samples are taken in accordance with established plant procedures and practices.

1.0 PROCEDURE 1.1 Chemistry to take the readings as specified in Tables 8-1, 8-2, 8-3 and 8-4 during power ascension activities.

1.2 Readings may be suspended due to delays only after discussion with the Test Team and IPA Coordinator.

Record the reason for any suspension in Attachment 2.1.3 All readings Must be Evaluated against established acceptance criteria at the following power plateaus 3506 MWth, 3673 MWth, and 3723 MWth (w/Crossflow Applied).1.4 Acceptance Criteria Level 1: Chemical factors defined in Technical Specifications must be maintained within the limits specified.

The Activity of gaseous and liquid effluents conforms to license limitations.

Water quality is known at all times and remains within the requirements of the chemistry program procedures.

Level 2: N/A.Hope Creek Page 106 of 188 Rev. 3 0 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 8 (Page 2 of 5)CHEMISTRY DATA (TEST 1)1.5 Chemistry results taken at the following power plateaus have been reviewed and are in accordance with the Acceptance Criteria as follows: 3506 MWth 3673 MWth 3723 MWth (w/Crossflow Applied): Initial Date Time Verf Date Time Initial Date Time Verf Date Time Initial Date Time Verf Date Time 1.6 Records INCLUDE all data and evaluations performed to this attachment.

Hope Creek Page 107 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 8 (Page 3 of 5)CHEMISTRY DATA (TEST 1)TABLE 8-1 -EXTENDED POWER UPRATE (SHIFTLY READINGS -once/12 hours)Date/Time/Initial RWCUIN Conductivity

_ I D02 ____ ________ ___RWR Conductivity

_ I DH2__ _ ___ _ ___ _ _RWCU EFF"A" Conductivit"B" Conductivity FFW Conductivity DH2 D02 CDI Conductivity I D02 Hope Creek Page 108 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 8 (Page 4 of 5)CHEMISTRY DATA (TEST 1)TABLE 8-2 -EXTENDED POWER UPRATE -DAILY READINGS (once/24 hours)TABLE 8-3 -EXTENDED POWER UPRATE -2X/Week RECORD date and time and a check for sample completed

-DO NOT enter data on this sheet Date/Time/Initial RWCUIN Metals FFW Metals OFFGAS Isotopic CPFI Metals MOISTURE CARRYOVER

__ _ _ _ _ _ __ _ _ _ _ _ __ _ _ _ _ _ __ _ _ _ _ _ __ __ _ _Hope Creek Page 109 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 8 (Page 5 of 5)CHEMISTRY DATA (TEST 1)TABLE 8-4 -EXTENDED POWER UPRATE -Additional Samples (test specific)RECORD only moisture carryover data (Refer to Attachment 9 for instructions)

RECORD date and time and a check for isotopic sample completed

-do not enter isotopic data on this sheet Test 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 1 hour Specific following following following following following following following following 3005 MWth 3339 MWth 3422 MWth 3506 MWth 3589 MWth 3673 MWth 3723 MWth 3723 MWth w/X flow Date /Time RWCUIN Isotopic Moisture Carryover OFFGAS Isotopic Hope Creek Page 110 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 9 (Page 1 of 4)MOISTURE CARRYOVER (TEST 1)As stated in Attachment 23 to LCR H05-01, Revision 1, Moisture Carryover is to be obtained and evaluated at a minimum of every 2.5% (approximately 84 MWth) during power ascension activities above 3339 MWth. This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any associated completed plant procedures.

The following test was performed with a reactor power of (circle one): 3005 / 3339/ 3422 / 3506 / 3589 / 3673 / 3723 MWth I 3723 MWth with X-flow Applied Note: Reactor Power tolerance is -38 MWth, +0 MWth from the above.Initial Date Time CAUTION Any of the following may be indications of vessel internals damage and potential debris generation (loose parts). (SIL 644 Revision 2)* Main Steam Line steam flow indication imbalance of 5% or more.* RPV water level difference

>3 inches step change between level instruments from different reference legs." Sudden drop (:1 minute) in steam dome pressure of >2 psig.* Statistically significant step increase of moisture carryover

>50% of previous value (per HC.CH-SA.ZZ-0004, Determination of Reactor Percent Moisture Carry Over).* Unexpected trends in parameter values that may be indicative of loss of steam dryer integrity, particularly unexplained changes in trends.Note that moisture carryover is very sensitive to power level and may increase more substantially at EPU conditions.

An increased feed-to-steam mismatch may validate an increase in moisture carryover.

Hope Creek Page 111 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 9 (Page 2 of 4)MOISTURE CARRYOVER (TEST 1)1.0 PROCEDURE 1.1 MONITOR the following CRIDS points;0 0 0 0 0 0 0 0 0 A2574 A2575 A2576 A2578 A212 A2609 A2610 A2611 A2612 REACTOR WATER LEVEL REACTOR WATER LEVEL REACTOR WATER LEVEL REACTOR PRESSURE TOTAL STEAM FLOW MAIN STEAM LINE A FLOW MAIN STEAM LINE B FLOW MAIN STEAM LINE C FLOW MAIN STEAM LINE D FLOW Initial Date Time 1.2 Hold Criteria: 1.2.1. Moisture carryover exceeds 0.10%.1.3 REQUEST Chemistry to perform moisture carryover testing per HC.CH-SA.ZZ-0004, Determination of Reactor Percent Moisture Carry Over. Include all results as part of this Attachment.

1.4 RECORD: Reactor Power MWth Mlbm/hr Recirc Flow (PPC)Moisture Carryover Initial Date Time 0 Hope Creek Page 112 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 9 (Page 3 of 4)MOISTURE CARRYOVER (TEST 1)1.5 EVALUATE results as follows: 1.5.1. IF moisture carryover is less than 0.10%, THEN no further actions are required.Initial Date Time Verf Date Time 1.5.2. IF moisture carryover is greater than 0.10%, THEN: A. NOTIFY Shift Manager and IPA Coordinator.

B. TAKE actions per Table 9-1.C. REQUEST Reactor Engineering to store data for individual bundle powers (core radial power distribution) and flows for the approximate time Chemistry obtained the moisture carryover samples per HC.CH-SA.ZZ-0004(Q).

Include results in this attachment.

Initial Date Time Initial Date Time Verf Date Time Initial Date Time Verf Date Time 1.6 Acceptance Criteria: 1.6.1. Level 1: Moisture Carryover shall remain less than 0.3% (GE Task T0306, maximum LPU evaluated level).1.6.2. Level 2: A. MSL moisture content ratio as determined by Chemistry shall be less than or equal to 0.10 % OR B. MSL moisture content ratio as determined by Chemistry shall be between 0.10% and 0.30% only WITH an approved engineering evaluation that supports continued plant operation.

Hope Creek Page 113 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 9 (Page 4 of 4)MOISTURE CARRYOVER (TEST 1)Table 9-1 Performance Criteria Not to be Exceeded Required Actions if Performance Criteria Exceeded and Required Completion Times Level 2: 1. Promptly suspend reactor power ascension until an engineering evaluation concludes that further power* Moisture carryover exceeds 0.1% ascension is justified.-OR-2. Before resuming reactor power ascension, the steam* Moisture carryover exceeds 0.1% and dryer performance data shall be reviewed as part of an increases by > 50% over the average of engineering evaluation to assess whether further power the three previous measurements taken ascension can be made without exceeding the Level 1 at > 3339 MWt criteria.Level 1: 1. Promptly initiate a reactor power reduction and achieve a previously acceptable power level (i.e., reduce power to a* Moisture carryover exceeds 0.30% previous step level) within two hours, unless an engineering evaluation concludes that continued power operation or power ascension is acceptable.

.2. Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, re-measure moisture carryover and perform an engineering evaluation of steam dryer structural integrity.

If the results of the evaluation of dryer structural integrity do not support continued plant operation, the reactor shall be placed in a hot shutdown condition within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. If the results of the engineering evaluation support continued power operation, implement step 3 below.3. If the results of the engineering evaluation support continued power operation, reduce further power ascension step and plateau levels to nominal increases of 41 MWth and 83 MWth , respectively, for any additional power ascension.

TABLE 9-1 NOTES: IF the Level 1 or Level 2 performance criteria are exceeded, THEN either suspend reactor power ascension (Level 2 Performance Criteria) or reduce reactor power (Level 1 Performance Criteria), initiate a Notification, and evaluate the cause of any exceedance of the performance criteria.Reactor power operation that results in moisture carryover that are less than the Level 2 performance criteria in Table 9-1 is representative of fully acceptable steam dryer performance.

Hope Creek Page 114 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 10 (Page 1 of 5)FEEDWATER RUNOUT DATA COLLECTION This Test requires that data associated with the condensate and feedwater system be collected and reactor feed pump runout predicted and analyzed at each of the EPU power plateaus.

This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any evaluations associated with its completion.

1.0 REACTOR POWER The following test was performed with a reactor power of (circle one): 3005 MWth (Baseline) 3339 MWth (Baseline) 3506 MWth 3673 MWth 3723 MWth w/Crossflow Applied Note: Reactor Power tolerance for each plateau is -38 MWth, + OMWth Hope Creek Page 115 of 188 Rev. -3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 10 (Page 2 of 5)FEEDWATER RUNOUT DATA COLLECTION 2.0 PROCEDURE 2.1 OBTAIN the following data for feedwater runout analysis within -38 MWth, + 0 MWth of the specified power level (include units). Attach all trend data to this procedure.

DFCS A RFP Speed DFCS A RFP % Output Demand DFCS B RFP Speed DFCS B RFP % Output Demand DFCS C RFP Speed DFCS A RFP % Output Demand A2710 RFP A Discharge Flow (FT-1755A)

A2711 RFP B Discharge Flow (FT-1755B)

A2712 RFP C Discharge Flow (FT-1755C)

A2719 RFP A Discharge Pressure (PT-1 774A)A2720 RFP B Discharge Pressure (PT-1774B)

A2721 RFP C Discharge Pressure (PT-1774C)

A2722 RFP A Suction Pressure (PT-1 777A)A2723 RFP B Suction Pressure (PT-1777B)

A2724 RFP C Suction Pressure (PT-1777C)

Continued on next page Hope Creek Page 116 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 10 (Page-3 of 5)FEEDWATER RUNOUT DATA COLLECTION 2.1 (continued)

A2716 A2717 A2718 A2014 A2015 A2016 A2011 A2012 A2013 B2111 B2112 A2578 A212 B2030 B3200 B2046 B2047 B2048 RFP A Min Flow Line Flow (FT-1770A)

RFP B Min Flow Line Flow (FT-1770B)

RFP C Min Flow Line Flow (FT-1770C)

RFP A Discharge Temp (TE-1804A)

RFP B Discharge Temp (TE-1804B)

RFP C Discharge Temp (TE-1804C)

RFP A Suction Temp (TE-1779A)

RFP B Suction Temp (TE-1779B)

RFP C Suction Temp (TE-1 779C)FW Line A Avg. Temp (Final)FW Line B Avg. Temp (Final)Reactor Narrow Range Pressure Total Steam Flow Total Reactor FDW Flow Cond Demin Total Flow A SCP Flow B SCP Flow C SCP Flow Hope Creek Page 117 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 10 (Page 4 of 5)FEEDWATER RUNOUT DATA COLLECTION A3184 A3185 A3186 A2684 A2430 A2685 A2696 A2666 A2667 A2668 A2725 Condenser A Pressure Condenser B Pressure Condenser C Pressure Cond A Hotwell Level Cond B Hotwell Level Cond C Hotwell Level PCP Discharge Pressure SCP A Suction Pressure SCP B Suction Pressure SCP C Suction Pressure RFP Disch Hdr Pressure Initial Date Time 2.2 COLLECT the following data locally: Condensate Demineralizer System DP = psi (PI-2688, 77ft Turbine Building, Outside of Elevator)Condensate Pre-Filter System DP =(PLC, 77ft Turbine Building)psi Initial Date Time Initial Date Time Initial Date Time 2.3 FORWARD collected data to the Test Team to perform the Feedwater Runout analysis.Hope Creek Page 118 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

W ATTACHMENT 10 (Page 5 of 5)FEEDWATER RUNOUT DATA COLLECTION 2.4 Analysis of Data: Whencompleted, attach analysis to this procedure.

Feedwater Runout flow obtained by analysis is predicted to result in the following flow condition:

mlb/hr (Maximum runout capacity)Initial Date Time Verf Date Time mlb/hr (Minimum excess capacity)Initial Date Time Verf Date Time 3.0 ACCEPTANCE CRITERIA: O Level 1: The maximum feedwater runout capacity, as determined from measured data in comparison to expected values and adjusted to the specified pressure shall not exceed the value specified in the OPL-3 (136.5% of rated feedwater flow)22.9 Mlbm/hr for the cycle specific feedwater controller failure maximum demand analysis.< 22.9 Mlbm/hr (Ref. GE Task 0900) *Level 2: Feedwater flow capability should be at least 5% greater (17.6 Mlbm/hr) than the normal steady state operating feedwater flow rate (105% of rated feedwater flow)at full EPU power.> 17.6 Mlbm/hr **NOTES< 19.28 Mlbm/hr prior to EPU implementation

> 15.73 MIbm/hr prior to EPU implementation 4.0 DATA EVALUATION:

SAT or UNSAT Initial Date Time Verf Date Time Hope Creek Page 119 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 1 of 45)FEEDWATER SYSTEM (TEST 23)The purpose of this test is to demonstrate:

a) That each feedpump controller operates properly in response to feedwater flow step changes at EPU conditions.

Small 2000 gpm (5% LPU rated) and large 4000 gpm (10% LPU rated) flow demand steps are performed on each feedpump.b) That the digital feedwater control system has acceptable response to reactor water level setpoint changes up to 4-inches in 3-Element Control and up to 2-inches in Single Element Control at EPU conditions.

As discussed in the body of this procedure, the manual flow and feedwater level step change tests will be performed at the 90%, 100%, 105%, and 110% power plateaus (Ref. GE Task Report T1 005, Startup Test Specifications).

This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any supporting data obtained.NOTE The IPA Coordinator and/or on-duty licensed operators may recommend adjustments to the Master Level Control set-point for subsequent flow steps. The SM may authorize such adjustments in accordance with applicable system operating procedures.

1.0 Reactor Power The following test was performed with a reactor power of (circle one): 3005 MWth 3339 MWth 3506 MWth 3673 MWth Note: Reactor Power tolerance for each plateau is -38 MWth, +0 MWth.Initial Date Time Verf Date Time Hope Creek Page 120 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 2 of 45)FEEDWATER SYSTEM (TEST 23)2.0 Precautions and Limitations 2.1 Reactor water level should be watched closely since it can change rapidly due to Feedwater Control System manipulations.

Large feedwater flow changes without feedwater heating can cause flux scrams.2.2 This procedure is not intended to be substituted for the system operating procedure.

Refer to HC.OP-SO.AE-0001(Q) for detailed instructions and precautions.

2.3 Unless otherwise specified, all operations required are performed at panel 10C651 or at the Digital Feedwater system Engineering Work Station (EWS). If step changes are initiated at the EWS, continuous communications SHALL be maintained between the EWS and the Control Room, and a licensed operator SHALL authorize all step and level changes and be present at the EWS.2.4 With a RFP controller in MANUAL, monitor RPV level closely. If the RPV level approaches either the SCRAM setpoint or the RFP trip setpoint, manually adjust the RFP flow controller to return the RPV level to the normal operating range and ENTER HC.OP-AB.RPV-0004(Q), Reactor Level Control.2.5 If a level step change becomes divergent in Single Element Control, the control status should be returned to 3-Element Control after operators have stabilized level using HC.OP-AB.RPV-0004(Q).

3.0 During testing, the Test Team is to monitor and trend the following CRIDS points:* B5026 SPDS APRM Average Power* A205 Median Reactor Narrow Range Level 1 B2030 Total Feedwater Flow* A2578 Rx Pressure Narrow Range* A2725 RFP Discharge Header Pressure* A2666 A SCP suction pressure* A2667 B SCP suction pressure* A2668 C SCP suction pressure* A2722 A RFP suction pressure* A2723 B RFP suction pressure* A2724 C RFP suction pressure* A2684 Condenser Hotwell Level Initial Date Time Hope Creek Page 121 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q) 1 ATTACHMENT 11 (Page 3 of 45)FEEDWATER SYSTEM (TEST 23)4.0 Termination/Hold Criteria 4.1 Termination Criteria (Level 1): 4.1.1 Reactor Water Level Decay Ratio IF the decay ratio approaches 1.0 for reactor water level, TERMINATE testing.4.1.;2 Failure to Control water level A. IF necessary, THEN enter:* HC.OP-AB.RPV-0004(Q), Reactor Level Control, TERMINATE testing 4.1.3 After conditions have stabilized:

B. REFER to Termination Criteria in main body of this procedure, section 4.1 S 4.2 Hold Criteria (Level 2): 4.2.1 APRM Flow Bias Scram MAINTAIN at least a 7.5% margin to the APRM flow biased scram set-point.

IF the margin to the scram setpoint is less than 7.5% or an APRM UPSCALE alarm is received, then HOLD testing AND NOTIFY Reactor Engineering.

4.2.2 Reactor Water Level Changes: A. IF the decay ratio exceeds 0.25 for reactor water level, THEN HOLD testing.B. IF reactor water level changes by more than 5 inches (overshoot), THEN HOLD testing.4.2.3 2000 gpm Manual Flow Step Changes: IF any of the following criteria is not met for each RFP, then HOLD testing.A. Maximum time to 10% of a step disturbance is 1.1 seconds.B. Maximum time from 10% to 90% of a step disturbance is 1.9 seconds.C. Peak Overshoot

(% of step disturbance) is 15%.D. Settling time, 100% +/-5% of step disturbance is less than or equal to 14 seconds.Hope Creek Page 122 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 4 of 45)FEEDWATER SYSTEM (TEST 23)4.2.4 For 4000 gpm Manual Flow Step Changes: IF the following criteria is NOT met for each RFP, THEN HOLD testing: A. For manual flow step changes, the average rate of response (computed between 10% and 90% of response)of the feedwater flow to the step flow demand shall be between 10% and 25% of rated pump flow per second.4.2.5 IF a HOLD condition is reached, after conditions have stabilized:

A. REFER to Hold Criteria in main body of this procedure, section 4.1.5.0 DETERMINE APRM flow biased upscale setpoints from the following CRIDS points: APRM A (GRIDS Point A2176)APRM C (CRIDS Point A2180)APRM E (CRIDS Point A2184)APRM B (CRIDS Point A2178)APRM D (CRIDS Point A3481)APRM F (CRIDS Point A2186)Initial Date Time Verf Date Time Hope Creek Page 123 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 5 of 45)FEEDWATER SYSTEM (TEST 23)CAUTION If during any Reactor Water Level Step Change, the FW System shows signs of becoming unstable or the termination criteria listed in Step.4.0 is approached, enter HC.OP-AB.RPV-0004(Q), Reactor Level Control to stabilize or exit the condition.

The next larger Step change shall not be performed until an acceptable response is achieved from the previous smaller Steps. This may require repeating a previous Step.Level swings experienced during this evolution will cause minor power and pressure swings. No other reactivity changes can occur during this evolution.

6.0 PERFORM Feedwater Manual Flow Step Changes in 3-Element Control as Follows: NOTE Communications need to be maintained between CR Panel 10C651, Engineering Work Station and field test personnel, as appropriate.

Feedwater Manual Flow Step Changes should be performed in the sequence specified (informational tests may be waived); however, the sequence of pumps being tested may be modified from A-B-C to a difference sequence with SM approval.

The time each step was performed will satisfactorily reflect the sequence of performance.

Engineering Work Station (EWS) Personnel may perform control or reactor level manipulations under the supervised direction of a licensed operator.This testing may produce core power excursions due to the feedwater addition.

The power levels of these operational transients may exceed the steady-state power level of the test condition.

These excursions are expected in the EPU power ascension test program.6.1 CONTACT the Test Team to ENSURE that the signals listed on Table 11-1 are available, and programmed into GETARS (1AC480) or other suitable recording device.6.2 CONTACT the Test Team to ENSURE plant conditions(i.e., condensate and RFP suction pressures, demineralizer differential pressures, RFP speeds) are consistent with expected conditions, prior to initiating the RFP step changes.Initial Date Time Initial Date Time 6.3 DELETED STEP Hope Creek Page 124 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

WATTACHMENT 11 (Page 6 of 45)FEEDWATER SYSTEM (TEST 23)6.4 DISPATCH data takers and assisting test personnel, if needed, and establish communications between the Test Team and others involved in the test. All final test data will be collected using GETARS (1AC480) or suitable recording device.Initial Date Time NOTE GETARS (1AC480) should be used to collect all final demonstration test data (+/- 4 inch level step changes AND all flow step changes).

Use of other recording devices, such as the Control Room Narrow Range Level instrument recorders, may be used to evaluate the smaller level step changes at the direction of the IPA coordinator.

6.5 OBTAIN GETARS 1AC480 Histogram to the printer for channels 1 to 120 for 10 scans.Initial Date Time 6.6 PLACE the RFP A Controller in MANUAL by PRESSING RFPT A SPEED CTRLR A/M pushbutton and OBSERVE "M" Illuminates, while leaving the remaining two RFPs in AUTO.Initial Date Time 6.7 RECORD the RFP flows and controller outputs below.RFP A Flow gpm CTRLR DMND Output %_ _RFP B Flow gpm CTRLR DMND Output %RFP C Flow gpm CTRLR DMND Output %____Initial Date Time NOTE Reactor Feed Pump Turbine critical speed is approximately 3400 rpm. Operation within the range of 3250 rpm to 3550 rpm should be minimized.

6.8 Slowly LOWER RFP A Flow by 2000 gpm. RECORD the RFP flows and controller outputs below, RFP A Flow gpm CTRLR DMND Output %RFP B Flow gpm CTRLR DMND Output %RFP C Flow gpm CTRLR DMND Output %Af Initial Date Time Hope Creek Page 125 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 7 of 45)FEEDWATER SYSTEM (TEST 23)6.9 Slowly RAISE RFP A Flow to the value noted in Step 6.7.Initial Date Time NOTE Subsequent stopping and starting of GETARS (1AC480) will be at the discretion of the Test Team Member supporting this test. If this individual chooses to leave GETARS on line, an"N/A" will be inserted in the appropriate step initial block.6.10 START GETARS (1AC480) and obtain 10 seconds of steady-state data before proceeding with the next step and leave the recorder running.NOTE The demand change should be made at the Engineering Work Station since the Control Room PDS variable response rates may introduce errors or cause significant overshoot.

The IPA Coordinator will determine the location the step changes are made.If introducing demand changes to the controller in the Control Room it is important to establish one continuous change in demand to the new set point rather than multiple small "bumps." The size of the flow change should be between 1800 gpm and 2200 gpm.6.11 REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.8 OR in the Control Room, PRESS RFPT A SPEED CTRLR DMND DECREASE push-button to the value recorded in Step 6.8.6.12 WHEN steady-state conditions are attained, REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.7 OR in the Control Room, PRESS RFPT A SPEED CTRLR DMND INCREASE push-button to the value recorded in step 6.7.Initial Date Time Initial Date Time Hope Creek Page 126 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 8 of 45)FEEDWATER SYSTEM (TEST 23)6.13 WHEN steady state conditions are attained, stop GETARS (1 AC480).6.14 Check each individual RFP discharge flow and verify that all operating pumps are reading approximately the same.ADJUST RFP A flow demand to attain this condition.

6.15 Slowly ADJUST RFP A Flow to 9000 gpm. RECORD the RFP flows and controller outputs below.Initial Date Time Initial Date Time RFP A Flow RFP B Flow RFP C Flow gpm CTRLR DMND Output gpm CTRLR DMND Output gpm CTRLR DMND Output%/0 InitI Dt Time Initial Date Time 6.16 ADJUST the flow of RFP A to approximately 13,000 gpm or to a flow value such that the RFP(s) in AUTO will be operating with at least 7000 gpm flow. RECORD the RFP flows and controller outputs below.RFP A Flow gpm CTRLR DMND Output RFP B Flow gpm CTRLR DMND Output RFP C Flow gpm CTRLR DMND Output%%0 Initial Date Time ,Hope Creek Page 127 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 9 of 45)FEEDWATER SYSTEM (TEST 23)6.17 START GETARS (1AC480) and obtain 10 seconds of steady-state data before proceeding with the next step and leave the recorder running.Initial Date Time NOTE The demand change should be made at the Engineering Work Station since the Control Room PDS variable response rates may introduce errors or cause significant overshoot.

The IPA Coordinator will determine the location the step changes are made.If introducing demand changes to the controller in the Control Room it is important to establish one continuous change in demand to the new set point rather than multiple small "bumps." The size of the flow change should be between 3800 gpm and 4200 gpm.6.18 REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.15 OR in the Control Room, PRESS RFPT A SPEED CTRLR DMND DECREASE push-button to the value recorded in Step 6.15..Hope Creek H Page 128 of 188 Rev..3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 10 of 45)FEEDWATER SYSTEM (TEST 23)6.19 WHEN steady-state conditions are attained, REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.16 OR in the Control Room, PRESS RFPT A SPEED CTRLR DMND INCREASE push-button to the value recorded in step 6.16.6.20 WHEN steady state conditions are attained, stop GETARS (1AC480).6.21 Slowly return the RFP A flow demand setpoint to the value recorded in Step 6.7. Check each individual RFP discharge flow and verify that all operating pumps are reading approximately the same. ADJUST RFP A flow demand to attain this condition.

6.22 AFTER all RFP flows have stabilized, shift the RFP A MANUAL/AUTO controller to AUTO in accordance with HC.OP-SO.AE-001.

6.23 OBTAIN a GETARS 1AC480 Histogram to the printer for channels 1 to 120 for 10 scans.6.24 PLACE the RFP B Controller in MANUAL by PRESSING RFPT SPEED CTRLR A/M pushbutton and OBSERVE "M" Illuminates, while leaving the remaining two RFPs in AUTO.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 129 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 11 of 45)FEEDWATER SYSTEM (TEST 23)6.25 RECORD the RFP flows and controller outputs below.RFP A Flow RFP B Flow RFP C Flow gpm CTRLR DMND Output %gpm CTRLR DMND Output %gpm CTRLR DMND Output %NOTE Reactor Feed Pump Turbine critical speed is approximately 3400 rpm. Operation within the range of 3250 rpm to 3550 rpm should be minimized.

0 6.26 Slowly LOWER RFP B Flow by 2000 gpm. RECORD the RFP flows and controller outputs below.RFP A Flow gpm CTRLR DMND Output %RFP B Flow gpm CTRLR DMND Output %RFP C Flow gpm CTRLR DMND Output %6.27 Slowly RAISE RFP B Flow to the value noted in Step 6.25.Initial Date Time Initial Date Time NOTE Subsequent stopping and starting of GETARS (1AC480) will be at the discretion of the Test Team Member supporting this test. If this individual chooses to leave GETARS on line, an"N/A" will be inserted in the appropriate step initial block.6.28 START GETARS (1AC480) and obtain 10 seconds of steady-state data before proceeding with the next step and leave the recorder running.Initial Date Time Hope Creek Page 130 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 12 of 45)FEEDWATER SYSTEM (TEST 23)NOTE The demand change should be made at the Engineering Work Station since the Control Room PDS variable response rates may introduce errors or cause significant overshoot.

The IPA Coordinator will determine the location the step changes are made.If introducing demand changes to the controller in the Control Room it is important to establish one continuous change in demand to the new set point rather than multiple small "bumps." The size of the flow change should be between 1800 gpm and 2200 gpm.6.29 REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.26 OR in the Control Room, PRESS RFPT B SPEED CTRLR DMND DECREASE push-button to the value recorded in Step 6.26.6.30 WHEN steady-state conditions are attained, REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.25 OR in the Control Room, PRESS RFPT B SPEED CTRLR DMND INCREASE push-button to the value recorded in step 6.25.6.31 WHEN steady state conditions are attained, stop GETARS (1AC480).6.32 Check each individual RFP discharge flow and verify that all operating pumps are reading approximately the same.ADJUST RFP B flow demand to attain this condition.

Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 131 of 188 Rev. .3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 13 of 45)FEEDWATER SYSTEM (TEST 23)6.33 Slowly ADJUST RFP B Flow to 9000 gpm. RECORD the RFP flows and controller outputs below.RFP RFP RFP A Flow B Flow C Flow gpm CTRLR DMND Output %gpm CTRLR DMND Output %gpm CTRLR DMND Output %Initial Date Time 6.34 ADJUST the flow of RFP B to approximately 13,000 gpm or to a flow value such that the RFP(s) in AUTO will be operating with at least 7000 gpm flow. RECORD the RFP flows and controller outputs below.RFP RFP RFP A Flow B Flow C Flow gpm CTRLR DMND Output %gpm CTRLR DMND Output %gpm CTRLR DMND Output %Initial Date Time 6.35 START GETARS (1AC480) and obtain 10 seconds of steady-state data before proceeding with the next step and leave the recorder running.NOTE The demand change should be made at the Engineering Work Station since the Control Room PDS variable response rates may introduce errors or cause significant overshoot.

The IPA Coordinator will determine the location the step changes are made.If introducing demand changes to the controller in the Control Room it is important to establish one continuous change in demand to the new set point rather than multiple small "bumps." The size of the flow change should be between 3800 gpm and 4200 gpm.Hope Creek Page 132 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 14 of 45)FEEDWATER SYSTEM (TEST 23)6.36 REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.33 OR in the Control Room, PRESS RFPT B SPEED CTRLR DMND DECREASE push-button to the value recorded in Step 6.33.6.37 WHEN steady-state conditions are attained, REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.34 OR in the Control Room, PRESS RFPT B SPEED CTRLR DMND INCREASE push-button to the value recorded in step 6.34.6.38 WHEN steady state conditions are attained, stop GETARS (1 AC480).6.39 Slowly return the RFP B flow demand setpoint to the value recorded in Step 6.25. Check each individual RFP discharge flow and verify that all operating pumps are reading approximately the same. ADJUST RFP B flow demand to attain this condition.

Initial Date Time Initial Date Time Initial Date Time 0 Hope Creek Page 133 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 15 of 45)FEEDWATER SYSTEM (TEST 23)6.40 AFTER all RFP flows have stabilized, shift the RFP B MANUAL/AUTO controller to AUTO in accordance with HC.OP-SO.AE-001.

6.41 OBTAIN a GETARS 1AC480 Histogram to the printer for channels 1 to 120 for 10 scans..6.42 PLACE the RFP C Controller in MANUAL by PRESSING RFPT C SPEED CTRLR A/M pushbutton and OBSERVE"M" Illuminates, while leaving the remaining two RFPs in AUTO.6.43 RECORD the RFP flows and controller outputs below.RFP A Flow gpm CTRLR DMND Output RFP B Flow gpm CTRLR DMND Output RFP C Flow gpm CTRLR DMND Output Initial Date Time Initial Date Time Initial Date Time Initial Date Time 0 Hope Creek Page 134 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 16 of 45)FEEDWATER SYSTEM (TEST 23)NOTE Reactor Feed Pump Turbine critical speed is approximately 3400 rpm. Operation within the range of 3250 rpm to 3550 rpm should be minimized.

6.44 Slowly LOWER RFP C Flow by 2000 gpm. RECORD the RFP flows and controller outputs below.RFP A Flow RFP B Flow RFP C Flow gpm CTRLR DMND Output %gpm CTRLR DMND Output %gpm CTRLR DMND Output %I I Initial Date Time 6.45 Slowly RAISE RFP C Flow to the value noted in Step 6.43.Initial Date Time NOTE Subsequent stopping and starting of GETARS (1AC480) will be at the discretion of the Test Team Member supporting this test. If this individual chooses to leave GETARS on line, an"N/A" will be inserted in the appropriate step initial block.6.46 START GETARS (1AC480) and obtain 10 seconds of steady-state data before proceeding with the next step and leave the recorder running.Hope Creek Page 135 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 17 of 45)FEEDWATER SYSTEM (TEST 23)NOTE The demand change should be made at the Engineering Work Station since the Control Room PDS variable response rates may introduce errors or cause significant overshoot.

The IPA Coordinator will determine the location the step changes are made.If introducing demand changes to the controller in the Control Room it is important to establish one continuous change in demand to the new set point rather than multiple small "bumps." The size of the flow change should be between 1800 gpm and 2200 gpm.6.47 REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.44 OR in the Control Room, PRESS RFPT C SPEED CTRLR DMND DECREASE push-button to the value recorded in Step 6.44.6.48 WHEN steady-state conditions are attained, REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.43 OR in the Control Room, PRESS RFPT C SPEED CTRLR DMND RAISE push-button to the value recorded in step 6.43.6.49 WHEN steady state conditions are attained, stop GETARS (1AC480).6.50 Check each individual RFP discharge flow and verify that all operating pumps are reading approximately the same.ADJUST RFP C flow demand to attain this condition.

Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 136 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 18 of 45)FEEDWATER SYSTEM (TEST 23)6.51 Slowly ADJUST RFP C Flow to 9000 gpm. RECORD the RFP flows and controller outputs below.11 RFP A Flow RFP B Flow RFP C Flow gpm CTRLR DMND Output gpm CTRLR DMND Output gpm CTRLR DMND Output%/0 Initial Date Time 6.52 ADJUST the flow of RFP C to approximately 13,000 gpm or to a flow value such that the RFP(s) in AUTO will be operating with at least 7000 gpm flow. RECORD the RFP flows and controller outputs below.RFP A Flow RFP B Flow RFP C Flow gpm CTRLR DMND Output %gpm CTRLR DMND Output %gpm CTRLR DMND Output %Initial Date Time 0 6.53 START GETARS (1AC480) and obtain 10 seconds of steady-state data before proceeding with the next step and leave the recorder running.NOTE The demand change should be made at the Engineering Work Station since the Control Room PDS variable response rates may introduce errors or cause significant overshoot.

The IPA Coordinator will determine the location the step changes are made.If introducing demand changes to the controller in the Control Room it is important to establish one continuous change in demand to the new set point rather than multiple small "bumps." The size of the flow change should be between 3800 gpm and 4200 gpm.6.54 REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.51 OR in the Control Room, PRESS RFPT C SPEED CTRLR DMND DECREASE push-button to the value recorded in Step 6.51.Initial Date Time Hope Creek HPage 137 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 19 of 45)FEEDWATER SYSTEM (TEST 23)6.55 WHEN steady-state conditions are attained, REQUEST EWS Personnel to insert a new demand OUTPUT in accordance with Table 11-4 to the value recorded in Step 6.52 OR in the Control Room, PRESS RFPT C SPEED CTRLR DMND INCREASE push-button to the value recorded in step 6.52.6.56 WHEN steady state conditions are attained, stop GETARS (1AC480).6.57 Slowly return the RFP C flow demand setpoint to the value recorded in Step 6.43. Check each individual RFP discharge flow and verify that all operating pumps are reading approximately the same. ADJUST RFP C flow demand to attain this condition.

6.58 AFTER all RFP flows have stabilized, shift the RFP C MANUAL/AUTO controller to AUTO in accordance with HC.OP-SO.AE-001.

6.59 VERIFY plots have been obtained of the data points listed in Table 11-1 and attach them to this procedure.

6.60 REVIEW the GETARS (1AC480) plots recorded during the step changes in flow for signal response AND RECORD whether the signals converge or diverge on Table 11-1.6.61 Using the GETARS (1AC480) plots in Table 11-1, calculate a decay ratio per Table 11-2 for those signals which contain oscillatory modes of response.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 138 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 20 of 45)FEEDWATER SYSTEM (TEST 23)6.62 Complete Section 9.0, Data Collection, and Table 11-3 for each of the flow steps made. Evaluate all results against the Acceptance Criteria contained in Section 10.0.6.63 ALL RFP step change results are SATISFACTORY and feedwater level step changes can proceed (IPA Coordinator).

Hope Creek Page 139 of 188 Rev. -3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 21 of 45)FEEDWATER SYSTEM (TEST 23)7.0 Insertion of step changes in vessel water level (three element control): NOTE The 2 and 3 inch level setpoint steps are informational and recommended to demonstrate the level control response prior to performing the formal level setpoint steps (i.e., 4 (+/- 1) inches).They can be waived by the Test Manager after evaluation by the Test Team.7.1 CONTACT the Test Team to ENSURE that the signals listed on Table 11-1 are available, and programmed into GETARS (1AC480) or other suitable recording device.7.2 CONTACT the Test Team to ENSURE plant conditions (i.e., condensate and RFP suction pressures, demineralizer differential pressures, RFP speeds) are consistent with expected conditions, prior to initiating the Level step changes.7.3 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001 AND Digital Feed is in 3-Element Control.7.4 DISPATCH data takers and assisting test personnel, if needed, and establish communications between the Test Team and others involved in the test. All final test data will be collected using GETARS (1AC480) or suitable recording device.Initial Date Time initial Date Time NOTE GETARS (1AC480) should be used to collect all final demonstration test data (+/- 4 inch level step changes AND all flow step changes).

Use of other recording devices, such as the Control Room Narrow Range Level instrument recorders, may be used to evaluate the smaller level step changes at the direction of the IPA coordinator.

7.5 OBTAIN a GETARS 1AC480 Histogram to the printer for channels 1 to 120 for 10 scans Initial Date Time Hope Creek Page 140 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 22 of 45)FEEDWATER SYSTEM (TEST 23)7.6 DELETED STEP NOTE Communications need to be maintained between CR Panel 10C651, Engineering Work Station and field test personnel, as appropriate.

Engineering Work Station (EWS) Personnel may perform control or reactor level manipulations under the supervised direction of the licensed operator.This testing may produce core power excursions due to the feedwater addition.

The power levels of these operational transients may exceed the steady-state power level of the test condition.

These excursions are expected in the EPU power ascension test program.7.7 ESTABLISH Reactor Level setpoint at 10C651 to 33 inches with Master Control in AUTO by PRESSING Lvl Setpoint DEC on the Master Level Controller.

7.8 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) at or near zero.7.9 INFORM the Test Team that reactor water level step changes will commence when performing the next step.7.10 START GETARS (1AC480) and obtain at least 10 seconds of steady state data.7.11 REQUEST EWS personnel perform a 2-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 2 inch GREATER than the current value of 33 inches, OR at 10C651, at the Master Level Controller, PRESS Lvl Setpoint INC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches)Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek HPage 141 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 23 of 45)FEEDWATER SYSTEM (TEST 23)7.12 DELETED STEP I I I I 7.13 VERIFY Reactor Level at approximately 35 inches AND ALLOW sufficient time for vessel level to stabilize for the following step changes.7.14 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

7.15 ESTABLISH Reactor Level setpoint at 10C651 to 37 inches with Master Control in AUTO by PRESSING Lvl Setpoint INC on the Master Level Controller 7.16 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) at or near zero.7.17 INFORM the test team that reactor water level step changes will commence when performing the next step.7.18 REQUEST EWS personnel perform a 2-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 2 inch LESS than the current value of 37 inches OR at 1 0C651, at the Master Level Controller, PRESS Lvl Setpoint DEC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches)Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 142 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 24 of 45)FEEDWATER SYSTEM (TEST 23)7.19 WHEN the reactor water level has stabilized, stop GETARS (1 AC480).7.20 ALLOW sufficient time for feed water/vessel level to stabilize (level error at or near zero) and as directed by the TEST MANAGER PERFORM data collection and evaluation per Steps 9 and 10.7.21 VERIFY Reactor Level at approximately 35 inches and ALLOW sufficient time for vessel level to stabilize for the following step changes.7.22 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

7.23 ESTABLISH Reactor Level setpoint at 10C651 to 32 inches with Master Control in AUTO by PRESSING Lvl Setpoint DEC on the Master Level Controller.

Initial Date Time Initial Date Time Verf Date Time 0 7.24 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.7.25 INFORM the Test Team reactor water level step changes will commence when performing the next step.7.26 START GETARS (1AC480) and obtain at least 10 seconds of steady state data.Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 143 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 25 of 45)FEEDWATER SYSTEM (TEST 23)7.27 REQUEST EWS personnel perform a 3-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 3 inch GREATER than the current value of 32 inches, OR at 10C651, at the Master Level Controller, PRESS Lvl Setpoint INC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).7.28 DELETED 7.29 VERIFY Reactor Level at approximately 35 inches AND ALLOW sufficient time for vessel level to stabilize for the following step changes.7.30 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

7.31 ESTABLISH Reactor Level setpoint at 10C651 to 38 inches with Master Control in AUTO, by PRESSING Lvl Setpoint INC on the Master Level Controller 7.32 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.7.33 INFORM the test team reactor water level step changes will commence when performing the next step.I I_Initial Date Time 0 Initial Date Time Initial Date Time Initial Date Time-Hope Creek-Page 144 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 26 of 45)FEEDWATER SYSTEM (TEST 23)7.34 REQUEST EWS personnel perform a 3-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 3 inch LESS than the current value of 38 inches OR at 10C651, at the Master Level Controller, PRESS LvI Setpoint DEC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).7.35 WHEN the reactor water level has stabilized, stop GETARS (1AC480).7.36 ALLOW sufficient time for feed water/vessel level to stabilize (level error at or near zero) and PERFORM data collection and evaluation per Steps 9 and 10.VERIFY satisfactory response (Quarter Amplitude Dampening) lAW Table 11-2.7.37 VERIFY Reactor Level at approximately 35 inches AND ALLOW sufficient time for vessel level to stabilize for the following step changes.7.38 ESTABLISH Reactor Level setpoint at 10C651 to 31 inches with Master Control in AUTO, by PRESSING Lvl Setpoint DEC on the Master Level Controller 7.39 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.7.40 INFORM the test team reactor Water level step changes will commence when performing the next step.7.41 START GETARS (1AC480) and obtain at least 10 seconds of steady state data.Initial Date Time Initial Date Time Initial Date Time Verf Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 145 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 27 of 45)FEEDWATER SYSTEM (TEST 23)7.42 REQUEST EWS personnel perform a 4-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 4 inch GREATER than the current value of 31 inches OR at 10C651, at the Master Level Controller, PRESS Lvl Setpoint INC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).I Dt Tm Initial Date Time 7.43 DELETED 7.44 VERIFY Reactor Level at approximately 35 inches AND ALLOW sufficient time for vessel level to stabilize for the following step changes.7.45 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

7.46 ESTABLISH Reactor Level setpoint at 10C651 to 38 inches with Master Control in AUTO, by PRESSING Lvl Setpoint INC on the Master Level Controller 7.47 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.7.48 INFORM the test team that reactor water level step changes will commence when performing the next step.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 146 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 28 of 45)FEEDWATER SYSTEM (TEST 23)7.49 REQUEST EWS/OWS personnel to perform a 4-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 4 inch LESS than the current value of 38 inches OR at 10C651, at the Master Level Controller, PRESS Lvi Setpoint DEC to establish the desired Reactor level setpoint (34 inches) (maximum allowable overshoot is 5 inches).Initial Date Time 7.50 WHEN the reactor water level has stabilized, stop GETARS (1AC480).Initial Date Time 7.51 RESTORE/ENSURE the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is returned to 35 inches lAW HC.OP-SO.AE-0001.

Initial Date Time Verf Date Time 7.52 ALLOW sufficient time for feed water/vessel level to stabilize (level error at or near zero) and PERFORM data collection and evaluation per Steps 9 and 10.Initial Date Time 8.0 Insertion of step changes in vessel water level (single element control): CAUTION IF A LEVEL STEP CHANGE BECOMES DIVERGENT IN SINGLE ELEMENT CONTROL, THE CONTROL STATUS SHOULD BE RETURNED TO 3-ELEMENT CONTROL, AFTER OPERATORS HAVE STABILIZED LEVEL USING HC.OP-AB.RPV-0004(Q).

8.1 INFORM the Test Team to place the digital feedwater system in single element control at the EWS lAW Table 11-6. CONFIRM reactor water level control is in Single Element Control on the CR Digital Feedwater Control Station.Hope Creek Page 147 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 29 of 45)FEEDWATER SYSTEM (TEST 23)8.2 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

8.3 CONTACT and ENSURE Test Personnel are monitoring digital feedwater parameters at EWS Initial Date Time Initial Date Time NOTE Communications need to be maintained between CR Panel 10C651, Engineering Work Station and field test personnel, as appropriate.

Engineering Work Station (EWS) Personnel may perform control or reactor level manipulations under the supervised direction of a licensed operator.This testing may produce core power excursions due to the feedwater addition.

The power levels of these operational transients may exceed the steady-state power level of the test condition.

These excursions are expected in the EPU power ascension test program.8.4 ESTABLISH Reactor Level setpoint at 10C651 to 34 inches with Master Control in AUTO, by PRESSING LvI Setpoint DEC on the Master Level Controller 8.5 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.8.6 INFORM the test team that reactor water level step changes will commence when performing the next step.8.7 START GETARS (1AC480) and obtain at least 10 seconds of steady state data.Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 148.of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 30 of 45)FEEDWATER SYSTEM (TEST 23)8.8 REQUEST EWS personnel perform a 1-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 1 inch GREATER than the current value of 34 inches OR at 10C651, at the Master Level Controller, PRESS Lvl Setpoint INC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).Initial Date Time 8.9 DELETED STEP Initial Date Time Verf Date Time 8.10 VERIFY Reactor Level at approximately 35 inches and ALLOW sufficient time for vessel level to stabilize for the following step changes.8.11 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

8.12 ESTABLISH Reactor Level setpoint at 10C651 to 36 inches with Master Control in AUTO, by PRESSING Lvl Setpoint INC on the Master Level Controller 8.13 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.8.14 INFORM the test team that reactor water level step changes will commence when performing the next step.Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 149 of 188-Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 31 of 45)FEEDWATER SYSTEM (TEST 23)8.15 REQUEST EWS personnel perform a 1-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 1 inch LESS than the current value of 36 inches OR at 10C651, at the Master Level Controller, PRESS Lvl Setpoint DEC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).Initial Date Time 8.16 WHEN the reactor water level has stabilized, stop GETARS (1AC480).Initial Date Time 8.17 ALLOW sufficient time for feed water/vessel level to stabilize (level error at or near zero) and as directed by TEST MANAGER PERFORM data collection and evaluation per Steps 9 and 10.Initial Date Time Verf Date Time 8.18 VERIFY Reactor Level at approximately 35 inches AND ALLOW sufficient time for vessel level to stabilize for the following step changes.Initial Date Time 8.19 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

Initial Date Time 8.20 ESTABLISH Reactor Level setpoint at 10C651 to 33 inches with Master Control in AUTO, by PRESSING Lvl Setpoint DEC on the Master Level Controller Initial Date Time 8.21 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) at or near zero.Initial Date Time Hope Creek Page 150 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 32 of 45)FEEDWATER SYSTEM (TEST 23)8.22 INFORM the test team that reactor water level step changes will commence when performing the next step.8.23 START GETARS (1AC480) and obtain at least 10 seconds of steady state data.8.24 REQUEST EWS personnel perform a 2-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 2 inch GREATER than the current value of 33 inches OR at 10C651, at the Master Level Controller, PRESS Lvl Setpoint INC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).8.25 DELETED 8.26 VERIFY Reactor Level at approximately 35 inches AND ALLOW sufficient time for vessel level to stabilize for the following step changes.8.27 CONFIRM the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is 35 inches lAW HC.OP-SO.AE-0001.

8.28 ESTABLISH Reactor Level setpoint at OWS/EWS to 37 inches with Master Control in AUTO, by PRESSING Lvl Setpoint INC on the Master Level Controller Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Hope Creek Page 151 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 33 of 45)FEEDWATER SYSTEM (TEST 23)8.29 Prior to making level step changes, ENSURE controller is in a "steady state" condition in that level is at the setpoint, with level error ("LVL ERROR" on the Master Panel Display Station) is at or near zero.8.30 INFORM the test team that reactor water level step changes will commence when performing the next step.8.31 REQUEST EWS personnel perform a 2-inch vessel level step change in accordance with Table 11-5 by inserting a new setpoint 2 inch LESS than the current value of 37 inches OR at 1 0C651, at the Master Level Controller, PRESS Lvi Setpoint DEC to establish the desired Reactor level setpoint (35 inches) (maximum allowable overshoot is 5 inches).8.32 WHEN the reactor water level has stabilized, stop GETARS (1 AC480).8.33 RESTORE/ENSURE the RX VESSEL LEVEL MASTER CONTROLLER is in AUTO and reactor vessel level setpoint is returned to 35 inches lAW HC.OP-SO.AE-0001.

8.34 CONTACT the Test Team to restore Digital Feedwater to 3-element control at the EWS lAW Table 11-6 8.35 CONFIRM reactor water level control is in Three Element Control on the CR Digital Feedwater Control Station.Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time Initial Date Time'Hope Creek Page 152 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 34 of 45)FEEDWATER SYSTEM (TEST 23)8.36 ALLOW sufficient time for feed water/vessel level to stabilize (level error at or near zero) and PERFORM data collection and evaluation per Steps 9 and 10.Initial Date Time Verfl Date Time Hope Creek Page 153 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 35 of 45)FEEDWATER SYSTEM (TEST 23)9.0 Data Collection (Test Team): 9.1 COLLECT the following data for each step change in reactor level or feed-water flow step.9.1.1 DETERMINE decay ratio per the definition in Section 2.1.3 (Main Procedure) and Table 11-2 for: Reactor water level 9.1.2 Determine Peak APRM flux (A/B) %9.1.3 DELETED STEP 9.1.4 Determine Maximum water level overshoot inches Initial Date Time Initial Date Time Initial Date Time Initial Date Time 9.2 COMPLETE Tables 11-1 and 11-2 for each of the level steps and Tables 11-1, 11-2 and 11-3 for each of the feed-water flow steps and retain with this procedure.

Hope Creek Page 154 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 36 of 45)FEEDWATER SYSTEM (TEST 23)10.0 Acceptance Criteria: 10.1 RECORD step change in reactor water level. Circle below: Three element single element control Step change and direction:

+ /- 2 3 4 OR RFP Manual Flow Step Change: A, B or C+/- 2000 gpm +/- 4000 gpm 10.2 Level 1 Criteria: 10.2.1 The decay ratio must be less than 1.0 for: Reactor water level 10.3 Level 2 Criteria: 10.3.1 Decay ratio must be less than 0.25 for: Reactor water level 10.3.2 APRM Upscale ALARMS are not received.Initial Date Time Initial Date Time Verf Date Time Initial Date Time Verf Date Time Initial Date Time Verf Date Time Hope Creek H CPage 155 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 37 of 45)FEEDWATER SYSTEM (TEST 23)10.3.3 A margin of 7.5% to the APRM flow biased scram setpoint has been maintained.

A and B APRM only 10.4 CONFIRM the following criteria is met: 10.4.1 Unexpected level changes (overshoot) caused by feedwater flow control system is less than or equal to +/- 5 inches.10.5 For RFP Flow Steps ONLY CONFIRM the Level 2 criteria of is met: 10.5.1 ALL Table 11-3 Level 2 criteria are SATISFACTORY.

Initial Date Time Verf Date Time Initial Date Time Verf Date Time Table 11-3 Initial Date Time Verf Date Time Hope Creek Page -156 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 38 of 45)FEEDWATER SYSTEM (TEST 23)Table 11-1 -GETARS (1AC480) SIGNAL LIST (Duplicate as Necessary)

Step Number: Date/Time:

Reactor Power: Attached Plot: 0 Signal Parameter Name Units CRIDS Converges Diverges Number I APRM NEUTRON FLUX A % A2175 10 SIMULATED HEAT FLUX A %11 SIMULATED HEAT FLUX B %22 NARROW RANGE RPV LEVEL INCHES A2574 24* NARROW RANGE PRESSURE psig A2578 32 APRM NEUTRON FLUX B % A2173 98 FEEDWATER LOOP FLOW A MLB/HR A194 99 FEEDWATER LOOP FLOW B MLB/HR A195 100* TOTAL FEEDWATER FLOW MLB/HR B2030 108 RFP TURBINE SPEED A RPM 109 RFP TURBINE SPEED B RPM 110 RFP TURBINE SPEED C RPM 112 RFP CONTROL VALVE A % A2313 113 RFP CONTROL VALVE B % A2314 114 RFP CONTROL VALVE C % A2315 118 RFP DISCH FLOWA GPM A271 0 119 RFP DISCH FLOW B GPM A2711 120 RFP DISCH FLOW C GPM A2712 101* TOTAL STEAM FLOW MLB/HR A212 115 RFP DISCHARGE PRESS A psig A2719 116 RFP DISCHARGE PRESS B psig A2720 117 RFP DISCHARGE PRESS C psig A2721 Notes:* These signals are filtered by the may be greater than indicated.

Digital Feedwater Control System. The transient values 0 Hope Creek HPage 157 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 39 of 45)FEEDWATER SYSTEM (TEST 23)TABLE 11-2 DECAY RATIO CALCULATION (Duplicate as Necessary)

Step Number: Date/Time:

Reactor Power: Attached Plot: DATA Oscillatory AO Al A2 A3 A4 A2/AO A3/A1 A4/A2 Average Point Value Used Notes: AO through A4 are peak values observed.

A2/AO, A3/A1, and A4/A2 are decay ratios.For the attached plot, a base line drawn through inflection points to establish a reference line which maximum amplitude for each peak can be determined.

Oscillatory variables being analyzed by this Decay Ratio Test are considered acceptable if the average ratio of successive maximum amplitudes of the same polarity is less than 0.25 (otherwise known as 11/4 wave dampened).

Initial Date Time Verf Date Time Hope Creek Page 158 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 40 of 45)FEEDWATER SYSTEM (TEST 23)Table 11-3 -RFP Manual Flow Step Changes (Duplicate As Necessary)

==

Description:==

Step RFP Flow Increase / Decrease Step Number: RFPT tested: Date/Time:

Reactor Power: Attached Plot: Step T 1 0 Tg 0 Tset Peak Average Satisfactory Change Time to Time 10- Time to Overshoot RATE of or Unsat.Description 10% 90% +/- 5% RESPONSE And Initials RFP+2000 gpm RFP-2000 gpm RFP+4000 gpm RFP--4000 gpm T0 = Time to achieve 10% of setpoint (1.1 Seconds Maximum -Criteria applicable to 2000 gpm step changes only).Tg 0 = Time from T 1 oto Reaching 90% of Setpoint (1.9 Seconds Maximum -Criteria applicable to 2000 gpm step changes only)Tset = Settling Time (reaching 100% +/-5%) (14 Seconds Maximum -Criteria applicable to 2000 gpm step changes only)Peak Overshoot

= Maximum Over-Response to Demand. (15% Maximum -Criteria applicable to 2000 gpm step changes only)Average Rate of Response = 10 -25% -Criteria applicable to 4000 gpm step changes only flope Creek Page 159 of 188'Rev. 3 HC.OP-FT.ZZ-0004(Q) qW ATTACHMENT 11 (Page 41 of 45)FEEDWATER SYSTEM (TEST 23)Table 11 RFP Flow Step Change Instructions (Page 1 of 2)(Duplicate As Necessary)

Step #: Date/Time:

Reactor Power: I .Select "SYS" icon.2. Select "CHANGE ENV" icon.3. Select "MAINT ENV" environment via password (HCDFCS) and press enter.4. Select "SELECT" icon.5. Select S3749A PDS, (S3749B PDS, S3749C PDS) in Select Compounds Box, PRESS ENTER 6. Select "DEMAND" block on right side of overview display.O_ 7. RECORD "As found" demand (%) _.(Upper right portion of screen, next to "0")8. RECORD new demand (%)9 Select A/M box at the bottom of the display to change the block from Auto to Manual.10. Select demand field box Upper right portion of screen, next to "0". Text field becomes highlighted after cursor is removed from text field.11. Select text box on bottom of screen. Text field becomes highlighted after cursor is removed from text field.12. Enter new demand.DO NOT PRESS ENTER KEY ON KEY BOARD.13. Licensed Operator concurrently verifies new demand.14. Licensed Operator obtains permission from MCR to integrate new demand 15. Using concurrent verification, PRESS ENTER key on keyboard, resulting in new demand being integrated.(Continued on next page)0 Hope Creek Page 160 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 42 of 45)FEEDWATER SYSTEM (TEST 23)Table 11 RFP Flow Step Change Instructions (Continued)(Page 2 of 2)(Duplicate As Necessary)

NOTE Prior to placing in Automatic, the Measured parameter and the Output (M and 0 in the upper right portion of the screen) should be matched to ensure additional step changes are not created when restoring to Automatic.

16. Verify the Measured parameter and the Output (M and 0 in the upper right portion of the screen) are reasonably close to ensure additional step changes are not created when restoring to Automatic.

Make adjustments to the PDS to match demand values at EWS.17. Licensed Operator verifies with the MCR that the PDS demand is matched.18. Licensed Operator obtains permission from MCR to place the block to Automatic.

19 Select the A/M box at the bottom of the display to change the block from Manual to Auto.20. Select "SELECT" icon.21. Select "EXIT" icon.22. Select "SYS" icon.23. Select "CHANGE ENV" icon.24. Select "PROCOPENV" icon Hope Creek Page 161 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 43 of 45)FEEDWATER SYSTEM (TEST 23)Table 11-5 -Level Step Change Instructions (Duplicate As Necessary)

Step #: Date/Time:

Reactor Power: 1. Select "SYS" icon.2. Select "CHANGEENV" icon.3. Select "MAINTENV" environment via password (HCDFCS).4. Select "SELECT" icon.5. If necessary, enter "MASTERPDS" in Select Compounds Box. PRESS ENTER key on keyboard.6. Select "STUPSPT" block on right side of overview display.7. RECORD current Master Level Control Set point (Upper right portion of screen, under MASTERPDS STUPSPT, right of letter "M")8. RECORD new Master Level Control Set point to be entered 9. Select upper text field of the Master Level Control Set point. Text field becomes highlighted after cursor is removed from text field.(Upper right portion of screen, under MASTERPDS STUPSPT, right of letter "M")10. Select text box on bottom of screen. Text field becomes highlighted after cursor is removed from text field.11. Enter new Master Level Control Set point.DO NOT PRESS ENTER KEY ON KEY BOARD.12. Licensed Operator concurrently verifies new Master Level Control Set point.13. Licensed Operator obtains permission from MCR to integrate new Master Level Control Set point/ 14. Using concurrent verification, PRESS ENTER key on keyboard, resulting in new demand being integrated Hope Creek Page 162 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 44 of 45)FEEDWATER SYSTEM (TEST 23)Table 11-6 Instructions to transfer Rx Level Control from 3-Element to 1-Element Control.1. At EWS (10C612) Select "Sys" on Main Menu Bar.2. Select "ChangeEnv" on Pull Down Menu. A second Pull Down Menu will appear.3. Select "Maint Env" on second Pull Down Menu.4. With Caps Locked, Enter password "HCDFCS" using keypad, then Press "Enter" key.5. Select "Select" on Main Menu Bar. Compound Block Overview Display screen should appear.6. Highlight by clicking Compound "CP6001 10" on left side of screen. All blocks associated with Compound CP6001 10 will appear on right side of screen.7. Select Block "PDTN0O2A" on right side of screen. Analog input module Block PDTNO02A should appear on screen.NOTE Placing Block PDTNO02A to manual will cause Reactor Water Level Control to go from 3-element to 1-element control if not in 1-element already.8. Click on "A/M" box on lower right of screen. "A" next to bar graph in upper right gray section of screen will change from A (Auto) to M (Manual).9. Verify with RO, Reactor Water Level Control is normal.10. Perform any other Maintenance that is required.11. To restore to 3-element Control perform steps 1 thru 4 if not in Maint Environment.

12. Select "Select" on Main Menu Bar. Compound Block Overview Display screen should appear.13. Highlight by clicking Compound "CP6001 10" on left side of screen. All blocks associated with Compound CP6001 10 will appear on right side of screen.14. Select Block "PDTNO02A" on right side of screen. Analog input module Block PDTNO02A should appear on screen.15. Click on "A/M" box on lower right of screen. "M" next to bar graph in upper right gray section of screen will change from M (Manual) to A (Auto).16. Verify with RO that Reactor Water Level Control is normal.17. When all work is finished change back to Operator Environment.

18. Select "Sys" on Main Menu Bar.19. Select "Change-Env" on Pull Down Menu. A second Pull Down Menu will appear.20. Select "Proc _OpEnv" on second Pull Down Menu.21. Select "Maini" on Main Menu Bar.22. Select "Main2" on Main Menu Bar.0 Hope Creek Page 163 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 11 (Page 45 of 45)Table 11-7 TYPICAL SYSTEM RESPONSE CURVE 100%90%aor 10%TO Ti 0 T 9 0 Time Step Input = Time to first pressure peak.Delay Time = To -T in secs.Rise Time = T 1 0 -To in secs.Settling Time T, -To in secs. = Time to reach 5% of final value.Time Constant = Time measured from T to 63% value of step.Decay Ratio = Ratio between successive peaks positive OR negative, not positive AND negative)Hope Creek Page 164 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 12 (Page 1 of 5)PRESSURE REGULATOR (TEST 22)As discussed in the body of this procedure, the pressure regulator step tests will be performed at 40%, 90%, 100%, 105%, and 110% CLTP power levels (Ref. GE Task Report T1005, Startup Test Specifications).

This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any supporting data obtained.1.0 Reactor Power The following test was performed with a reactor power of (circle one): 1336 MWth (Approx.)

40% CLTP Baseline 3005 MWth 90% CLTP Baseline 3339 MWth 100% CLTP Baseline 3506 MWth 105% CLTP Power Plateau 3673 MWth 110% CLTP Power Plateau Note: Reactor Power tolerance for each plateau is -38 MWth, +0 MWth.NOTE The objective of this test is to demonstrate stability of the Digital EHC system while safely maintaining:

• Margin to the APRM scram > 7.5%6 Margin to High Reactor Pressure Scram is > 10 psi (i.e., < 1016 psig)Hope Creek Page 165 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

WATTACHMENT 12 (Page 2 of 5)PRESSURE REGULATOR (TEST 22)2.0 Test team to monitor and trend the following:

CRIDS points:* B5026SPDS APRM Average Power* A205 Median Reactor Narrow Range Level* A2578Rx Pressure Narrow Range* A212 Total Steam Flow* A3076Throttle Pressure* A213 1 st Stage Shell Pressure* A2310A RFPT Steam Pressure* A2311 B RFPT Steam Pressure* A2312C RFPT Steam Pressure* A2534Turbine Bypass Valve Position Initial Date Time* 3.0 Termination/Hold Criteria: 3.1 Level 1 Termination Criteria 3.1.1 IF the decay ratio reaches 1.0 for throttle steam pressure, THEN TERMINATE testing.3.1.2 Fluctuation or Failure to Control Reactor Pressure 3.1.2.1 IF necessary, THEN ENTER HC.OP-AB.BOP-0003(Q), Turbine Hydraulic Pressure, or HC.OP-AB.RPV-0005, Reactor Pressure Control, as appropriate.

3.1.2.2 After conditions have stabilized:

B. REFER to Step 4.1, Termination Criteria in main body of this procedure.

Hope Creek Page 166 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 12 (Page 3 of 5)PRESSURE REGULATOR (TEST 22)3.2 Level 2 Hold Criteria 3.2.1 APRM Flow Bias Scram Maintain at least a 7.5% margin to the APRM flow biased scram setpoint.IF margin to the scram setpoint is < 7.5%, THEN HOLD testing and notify Reactor Engineering.

3.2.2 IF reactor pressure is approaching 1016 psig, THEN HOLD testing and evaluate.3.2.3 IF Decay ratio exceeds 0.25, THEN HOLD testing.3.2.4 Pressure response time from initiation of pressure setpoint step change to turbine inlet pressure peak shall be less than or equal to 10 seconds.3.2.5 After conditions have stabilized:

3.2.5.1 REFER to hold criteria in main body of this procedure step 4.1.5.3.2.5.2 DETERMINE the cause of the failure and repair.DETERMINE APRM flow biased upscale setpoints in accordance with Attachment 5 of HC.OP-FT.AC-0006:

APRM A APRM C APRM E APRM B APRM D APRM F 0 4.0 I Initial Date Time Verf Date Time Hope Creek Page 167 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 1.2 (Page 4 of 5)PRESSURE REGULATOR (TEST 22)5.0 REQUEST the test team to perform pressure control system testing per HC.IC-LC.CH-0001(Z), Pressure Control System (excluding Step 5.3). Step changes shall be made at +/-3 psig AND +/-6 psig.Include all results as part of this Attachment.

Initial Date Time Verf Date Time 6.0 RECORD the following from the test Peak Negative Pressure Step During Test (-) psid Peak Positive Pressure Step During Test (+) psid Max. APRM simulated heat flux peak following step change: %APRM scram setpoint %Scram Avoidance Margin %Peak Reactor Pressure during test __ psig Worst Case Decay Ratio ,for signal No.Initial Date Time Verf Date Time Hope Creek Page 168 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 12 (Page 5 of 5)PRESSURE REGULATOR (TEST 22)7.0 EVALUATION:

7.1 Level 1 Criteria 7.1.1 The decay ratio must be less than 1.0 Throttle steam pressure 7.2 Level 2 Criteria: 7.2.1 The decay ratio must be less than 0.25, or if exceeded must be accepted via engineering evaluation Throttle steam pressure Initial Date Time Verf Date Time 7.2.2 Maximum reactor pressure is less than 1016 psig.7.2.3 A margin of 7.5% to the APRM flow biased and neutron scram flux setpoints has been maintained.

7.2.4 The response time from the start of setpoint input until pressure peak must be within 10 seconds. Measure using CRIDS based on changes to the DEHC setpoint and the maximum (minimum) throttle steam pressure.Initial Date Time Verf Date Time Initial Date Time Verf Date Time Initial Date Time Verf Date Time Hope Creek Page 169 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 13 (Page 1 of 2)IRM/APRM OVERLAP DATA (TEST 10)As directed by this procedure and HC.OP-lO.ZZ-0003(Q), Step 5.3.40, VERIFY the following:

1.0 ENSURE all operable IRM detectors are on scale with the associated UPSC alarm and DNSC lights off.Initial Date Time Verf Date Time 2.0 RECORD the following data: IRM RANGE READING A B C D E F G H Initial Date Time Verf Date Time Initial Date Time Verf Date Time 3.0 ENSURE all operable APRM detectors are on scale with the associated UPSC alarm and DNSC lights off.Hope Creek Page 170 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 13 (Page 2 of 2)IRM/APRM OVERLAP DATA (TEST 10)4.0 RECORD the following data: APRM READING A %B %C %D %E %F %Initial Date Time Verf Date Time 5.0 Acceptance Criteria -Level 1 Technical Specification Requirements for IRM to APRM Overlap have been met.Initial Date Time Verf Date Time Hope Creek Page 171 of 188 Rev. -3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 14 (Page 1 of 1)EPU SYSTEM PERFORMANCE

& MONITORING PLANS DESCRIPTION:

Attachment 14 is a collection of the EPU System Performance

& Monitoring Plans that are controlled separately from this procedure but will be included with this package following completion.

Similar to what was done at another plant (i.e., Vermont Yankee) for EPU, these plans will be developed utilizing the expertise of System Engineers using their existing trending and monitoring programs as a basis, modified for EPU conditions.

At minimum, the System Performance

& Monitoring Plans will be prepared in accordance with ER AA-2003, System Performance Monitoring and Analysis, and ER AA-2030, Conduct of Plant Engineering, and will cover:* Major Impact Systems -As identified in Section 2.0 of DCP 80048085 including reactor feedwater, digital feedwater control, main steam, condensate, extraction steam, condensate demineralizers, condensate prefilters, nuclear boiler, reactor recirculation, and neutron monitoring.

• Selected Minor Impact Systems -Including main turbine, main generator and transformers, turbine auxiliaries, condenser air removal (SJAE), main condenser, circulating water (including cooling tower), turbine HVAC, and Offgas systems.Acceptance Criteria -The EPU System Performance

& Monitoring Plans supplement the Power Ascension Test to ensure the balance of non-tested parameters and systems perform as expected.

Thus, there are no specific Level I (Termination) criteria associated with these plans.All Category 1 and 2 LPU Expected Parameter Responses or Limits currently contained in the EPU System Margin report (DCP 80048085, Supplement

2) will be considered as Level 2 (HOLD) criteria for this test. By definition, CATEGORY 1 and 2 parameters in this category include: 1. High Risk: Operating margin reductions with the potential for plant trips, power reductions, or LCOs, or can result in accelerated equipment degradation with potential for premature repair or replacement.

2. Medium Risk: Operating margin reductions with operations close to alarm set points or other limiting equipment parameters, or with more than minimal reduction in operational flexibility, or that may result in long-term equipment degradation with increased maintenance or monitoring required.

This category also includes margin reductions that are still being evaluated.

Hope Creek Page 172 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

• ATTACHMENT 15 HLA / IPA Briefing Worksheet Page 1 of 5 Evolution or Test Procedure

1. HC.OP-FT.ZZ-0004(Q)

Evolution Description EXTENDED POWER UPRATE POWER ASCENSION TESTING Briefing Participants:

NAME POSITION DEPARTMENT 0 Hope Creek Page 173 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 15 HLA / IPA Briefing Worksheet Page 2 of 5 (short descriptions may be appropriate for some items) '/or NA OVERVIEW the Purpose/Scope of Job: This procedure is in support of the HCGS Extended Power Uprate (EPU) Power Ascension and Test Program. The obiective of this procedure is to confirm acceptable plant performance for operation at EPU conditions up to the Target Power Uprate of 3723 MWth (111.5% of Licensed Thermal Power prior to RF14) per License Change Request (LCR) H05-01. This Test Procedure provides step by step guidance and verification for performing Power Ascension Testing requirements for EPU conditions.

This Test Procedure supplements operations procedure HC.OP-IO.ZZ-0003(Q).

Startup from Cold Shutdown to Rated Power and HC.OP-IO.ZZ-0006(Q), Power ChangesDuring Operation, to provide direction to maneuver the plant from startup to 3723 MWth (96.95% LPU).REVIEW current shift activities to ensure no unacceptable effect on planned evolution.

This IPA is in support of the EPU requirements for startup from RF14 through the former 100% power level (3339 MWt) and entering HCGS Extended Power Uprate (EPU) conditions.

The activity occurs over a period of several weeks.REVIEW all turnover items.Abnormal lineups There are no abnormal line-ups other than data gathering recorder setups.Parallel activities Parallel activities are primarily data -gathering by various plant disciplines and departments (e.g., vibration and system monitoring) which are coordinated by HC.OP-FT.ZZ-0004.

Flagging / robust operational barriers in place HC.OP-FT.ZZ-0004 procedural controls.DESCRIBE the roles and responsibilities of the participants. (identify holder of master copy, job coordinator).

Refer to Section 4.0 of the procedure for Roles & Responsibilities.

EMPHASIZE procedure adherence and maintaining the highest margin of safety.ENSURE command and control is simple and personnel understand who is in charge of each area.REVIEW procedure.

Prerequisites Administrative Controls Precautions Hold Points Limitations and actions Task Sequence Procedure Level of Use Parallel Tasks N/A or C/M Steps DISCUSS potential effects: Interaction with other activities:

Interactions are controlled by HC.OP-FT.ZZ-0004 for EPU.System interactions:

Interactions are not expected to be different than normal operation.

Equipment Effects: None known. Steam and feedwater equipment (e.g., piping, dryer, SRVs) are being monitored by DCP 80048085 and HC.OP-FT.ZZ-0004 controls for EPU.Pressure/temperature effects: There are minimal pressure effects (feedwater) and slight temperature effects. This is a "Constant Pressure Power Uprate" (CPPU).Potential for water hammer or hydraulic transient:

Transients will monitored with EPU vibration and dynamic monitoring recording that is controlled by HC.OP-FT.ZZ-0004 for EPU.Hope Creek Page 174 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 15 HLA / IPA Briefing Worksheet Page 3 of 5 Production Risk Concerns:* Mark or highlight critical step(s) in the activity.* Obtain authorization from Unit of Control Room Supervisor directly prior to performing a critical step or series of critical steps related to production risk.* MonitorNalidate performance of each critical step related to production risk by direct oversight in the field, by work group supervision, unless alternate methods are specifically approved by the responsible department head and documented below.* Identify sensitive panels/equipment.

• Discuss protected pathways and equipment.

Monitoring equipment is installed by prerequisites to and controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU.DISCUSS Configuration Control.There is minimal operational configuration control impact. Extensive EPU setpoint changes are controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU. Extensive EPU design configurations control changes are controlled by DCP 80048085 for EPU.DISCUSS any affects on reactivity or potential impact on reactivity management.

Additional fuel enrichment required for operation at higher power (void fraction) at the same values of core recirculation flow is managed by burnable poison in the core fuel design and confirmed by the Routine startup shutdown margin verification (via the normal in sequence critical).

Attachment 7 addresses Core Performance data.DISCUSS Tech Spec applicability and action statement requirements.

Extensive Technical Specifications changes initiated by LCR H05-01 must be in place and is controlled by HC.OP-FT.ZZ-0004 and the Licensed Operators' official control room Tech Specs.STATE communications expectations and contingency actions if communications are lost. Extensive communication requirements are controlled by HC.OP-FT.ZZ-0004 and the EPU briefings conducted each shift with EPU activities.

DESCRIBE expected results, contingency actions to be taken if unexpected conditions or responses arise, possible risks and consequences.

TASK STEP EXPECTED RESULT CONTINGENCY Pressure Regulator Testing Controlled Pressure swings with ACTION adequate damping Ops Pressure Control Abnormal Feedwater Transient Testing Controlled Level swings with Procedure adequate damping Steady State Data Gathering No criteria should be exceeded Ops Level Control Abnormal Procedure Exceeded criteria is controlled by HC.OP-FT.ZZ-0004 and DCP 80048085.DESCRIBE the abort/stop work criteria and identify the associated owner.Extensive EPU Level 1 and Level 2 acceptance criteria are controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU.DESCRIBE "bounds" for the activity-within what parameters must the activity be controlled and what limits are in place for adjustments:

Extensive EPU Level 1 and Level 2 acceptance criteria are controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU.Hope Creek Page 175 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 15 HLA / IPA Briefing Worksheet Page 4 of 5 DISCUSS any differences from normal practices.

Extensive EPU restrictions on operation and data gathering are controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU.DETERMINE personnel readiness Has everyone performed a similar evolution before?Is everyone confident in their ability to perform?Has everyone read the procedure or work package and does everyone understand the applicable steps?Are special safety qualifications current? (Mask fit, Confined Space, etc.).Is and special training requirement needed?Is anyone fatigued or has not had adequate rest (hours worked)?_DISCUSS any special equipment or access concerns:

tools, ladders, reach rids, fuses.Monitoring equipment is installed by prerequisites to and controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU.DISCUSS any safety concerns or potential hazards: Confined space: N/A to EPU Testing Heat N/A to EPU Testing Chemicals (refer to MSDS if required)

N/A to EPU Testing Asbestos N/A to EPU Testinq 1. Be aware some fibrous gaskets and other work materials may contain ASBESTOS.2. No heating, grinding.

Or brushing to be performed when removing gaskets.Noise N/A to EPU Testing. Unusual noises must be reoorted for investigation Personnel protective equipment requirements Not unique to EPU Testing.Fall protection Not unique to EPU Testing.Lead based paint removal Not unique to EPU Testing Clearances

/ Clearance comments Not unique to EPU Testing Fire Protection requirements Not unique to EPU Testing Other as applicable:

None unique to EPU Testing DISCUSS house keeping concerns.

FME barriers.

Not unique to EPU Testing DISCUSS applicable lessons learned, industry events, and OPEX.EPU testing has been benchmarked from Vermont Yankee, Clinton, and other recent EPU experiences.

HCGS has done a 1.4% power uprate. GE has participated extensively in the HCGS EPU process and brings with that experience for many industry BWR power uprates DISCUSS any ALARA concerns.

RWP#: Not unique to EPU Testing. Various Area Rad monitoring surveys-ares planned and controlled by HC.OP-FT.ZZ-0004 and DCP 80048085 for EPU.Review RWP(s), minimize DAW, RP hold points, stop work conditions, low dose areas, hot spots.Hope Creek Page 176 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 15 HLA / IPA Briefing Worksheet Page 5 of 5 EMPHASIZE the need for caution and conservatism, particularly when uncertainties ar encountered.

DELINEATE Senior Line Manager expectations (for IPA activities).

Extensive EPU command and control and senior line management expectations are specified by and controlled by HC.OP-FT.ZZ-0004.

The 5 Key Questions ASK: What are the Critical Steps in the task?DISCUSS: ASK: What is the Worst Thing that can go wrong?DISCUSS: ASK: What are the Error Likely Situations?

DISCUSS: Distractions

/ time pressure High work load / Performing multiple tasks Overconfidence

/ Stress First shift back to work Poor Communications Abnormal line-ups / conditions Poor or vague work instructions Fatigue or inadequate rest (hours worked)First time performing a task Other identified precursors ASK: What Defenses are we relying upon?DISCUSS: STAR Verification techniques Peer check Attention to detail/Questioning attitude First check Ensure correct Unit and train Flagging/Robust operational barriers OOPS What actions will assure proper configuration control?DISCUSS: CLOSE the briefing as follows: 1. Review limitations, hold points, termination criteria, and actions if unexpected conditions arise. 2 2. ENSURE everyone understands their role and the chain of command.3. ASK each individual participating for questions or concerns (Positive Engagement).

3 4. ENSURE all concerns are addressed and questions answered, then CLOSE the briefing.

.4 Briefing led by Hope Creek Page 177 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 1 of 11)TURBINE STOP, BYPASS AND MSIV TESTING The purpose of this test is to determine the maximum power level for performing periodic turbine valve and MSIV testing without challenging reactor scram or turbine trip set-points.

Tests at 95% and 100% CLTP will be performed using established surveillance procedures following installation of the new HP turbine. The individual test results are then used to determine the next test power level or the maximum safe power level at which testing can be performed while maintaining adequate margins to scram and other set-points.

This Attachment is to be filled out each time the test is performed and retained as part of the test package as well as any supporting data obtained such as completed surveillance test procedures.

1.0 REACTOR POWER The following test was performed with a reactor power of (circle one): 3172 MWth 3339 MWth 3506 MWth 3673 MWth 95% CLTP Baseline 100% CLTP Baseline 105% CLTP Power Plateau 110% CLTP Power Plateau 111.5% CLTP Power Plateau Determined by IPA Coordinator 3723 MWth w/X flow Applied_ _MWth Note: Reactor Power tolerance for each plateau is -38 MWth, +0 MWth.0 Hope Creek Page 178 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 2 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 2.0 PRECAUTIONS/PREREQUISITES 2.1 Test team to monitor and trend the following during valve testing: CRIDS points: B 65026SPDS APRM Average Power* A205 Median Reactor Narrow Range Level* A2578 Rx Pressure Narrow Range* A212 Total Steam Flow* A3076Throttle Pressure* A213 1 st Stage Shell Pressure* A2534Turbine Bypass Valve Position* A2535Total Control Valve Position* A2622 Moisture Sep Drain Tank Level 1039A* A2623 Moisture Sep Drain Tank Level 1039B* A2624Moisture Sep Drain Tank Level 1040A* A2625 Moisture Sep Drain Tank Level 1040B Initial Date Time 2.2 This test results in a half scram. ENSURE no other testing or maintenance is in progress that will adversely affect the performance of this test.Initial Date Time 2.3 Turbine vibration and Moisture Separator Drain Tank Level response should be monitored for changes during the test.Initial Date Time 2.4 Load Set-point shall be verified at 100% by selecting "Control", then the "Speed-Load" screen.Initial Date Time Hope Creek Page 179 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 3 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 2.5 Average reactor steam dome pressure as displayed on the PPC OD-3 OR alternate instrumentation, is limited to the rated pressure of 1020 psia.Initial Date Time 2.6 Test only one turbine stop, bypass valve or MSIV at a time.Initial Date Time 3.0 TERMINATION/HOLD CRITERIA 3.1 Level 1 Termination Criteria The decay ratio must be less than 1.0 for each process variable that exhibits oscillatory response to turbine or MSIV valve changes.The reactor shall not scram or isolate because of the test.Peak thermal power as measured by Simulated Heat Flux shall not exceed 101% of the station licensed power level at the time of testing.3.1.1. After conditions have stabilized:

A. REFER to Step 4.1, Termination Criteria in main body of this procedure.

B. DETERMINE the cause of the failure and repair.C. DOCUMENT resolution per Attachment 2.D. REPEAT test that caused the failure prior to performing larger tests or use previous testing to establish the maximum allowable power level for the tests.Hope Creek Page 180 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 4 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 3.2 Level 2 Hold Criteria 3.2.1. APRM Scram Set-points Maintain at least a 7.5% margin to the APRM neutron flux scram setpoint and a 5.0% margin to the APRM heat flux scram setpoint.IF margin to the scram setpoint is less than the above, OR if APRM Upscale Alarms are received, THEN HOLD testing and notify Reactor Engineering.

3.2.2. IF reactor pressure is approaching 1016 psig, THEN HOLD testing and evaluate.3.2.3. Peak steam flow in each main steam line must remain 10% below the high flow isolation trip setting. Additionally, vessel pressure must remain at least 25 psi above the steam line low pressure isolation.

IF this is not met, THEN HOLD testing and evaluate.3.2.4. IF Moisture Separator Drain Tank level increases beyond 50% of the Dump Valve Control band during a test, THEN HOLD testing and evaluate.3.2.5. After conditions have stabilized:

A. REFER to hold criteria in main body of this procedure.

B. DETERMINE the cause of the failure and repair.C. DOCUMENT resolution per Attachment 2.D. REPEAT step change that caused the failure prior to performing larger tests.E. ATTACH any relevant documentation to this completed procedure per Attachment 2 of the main body of procedure., Hope Creek Page 181 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 5 of 11)TURBINE STOP, BYPASS AND MSIV TESTING NOTE* Testing should be performed at successively increasing power levels, as determined by the Test Team, until the maximum power level for satisfactorily performing this test is established.

The limiting main turbine stop valve, bypass valve, or MSIV, need only be stroked for subsequent tests as determined by the Test Team.* The reactor pressure, neutron flux and steam flow transients are anticipated to be minimal due to implementation of very slow closing and opening rates in the Digital EHC system. If transient data obtained from plant instrumentation indicates that scram setpoints are not challenged, the systematic plotting of data at succeeding power levels provided in this procedure is not required.4.0 PROCEDURE 4.1 VERIFY that the signals listed on Table 16-1 are available, and programmed into GETARS (1AC480)or other suitable recording device.4.2 DETERMINE APRM flow biased upscale setpoints from the following CRIDS points: APRM A (CRIDS Point A2176)APRM C (CRIDS Point A2180)APRM E (CRIDS Point A2184)APRM B (CRIDS Point A2178)APRM D (CRIDS Point A3481)APRM F (CRIDS Point A2186)Initial Date Time Initial Date Time Hope Creek Page 182 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 6 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 4.3 Test Team to VERIFY that expected Peak Heat Flux during the test will NOT exceed 101% AND that Expected Peak Pressure, Neutron Flux and Simulated Heat Flux will NOT exceed scram margin criteria.

IF detailed analysis is required to determine this, a method is provided in Attachment 5 of HC.OP-FT.AC-0006(Q).

4.4 DISPATCH data takers and assisting test personnel, if needed, and establish communications between the Test Team and others involved in the test. All final test data will be collected using GETARS (1AC480) or suitable recording device.4.5 OBTAIN a GETARS 1AC480 Histogram to the printer for channels 1 to 157 for 10 scans.4.6 VERIFY that the plant is stabilized at the required test condition and that communications between the Test Team and others involved in the test, have been established.

Initial Date Time CAUTION IF BPVs 1 through 7 open during Main Turbine stop valve testing, stop the"Test OFF", and refer to the HOLD criteria listed in Section 3.2 above.4.7 Prior to commencing the valve under test, START GETARS (1AC480) to monitor the signals per Table 16-1 AND OBTAIN at least 10 seconds of steady-state data prior to beginning the test.Initial Date Time test by SELECTING Initial Date Time Hope Creek Page 183 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 7 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 4.8 PERFORM the stroke of the valve(s) under test in accordance with ONE of the following:

• HC.OP-ST.AC-0005, Turbine Bypass Valve Testing -Monthly* Section 5.1 of HC.OP-FT.AC-0005, Turbine Stop Valve Testing" Section 5.2 of HC.OP-IS.AB-0101, Partial Stroke -MSIVs 4.9 After the stroke of the valve(s) under test is complete AND the plant has stabilized STOP GETARS (1AC480).4.10 Test Team to EVALUATE data in accordance with Section 5.4 of HC.OP-FT.AC-0006 for compliance with Section 3.0 listed Acceptance Criteria and to DETERMINE if additional testing at higher power is warranted.

Date Time Initial 0 Initial Date Time Hope Creek HPage 184 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 8 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 5.0 DATA ANALYSIS 5.1 Using Attachments 4 and 6 of HC.OP-FT.AC-0006 for each of the valves under test, RECORD the limiting Reactor Parameter Margins and VERIFY Section 3.0 acceptance criteria is met.Initial Date Time 5.2

Description:

Bypass Valves Valve Stroked: Date/Time:

Max. Reactor Power: Attached Plot: Max. APRM neutron flux peak following valve stroke: %APRM neutron flux scram setpoint %Neutron Flux Scram Avoidance Margin _ % (>7.5% required)Max. APRM indicated Heat Flux: % (<101% required)APRM Heat Flux scram setpoint %Heat Flux Scram Avoidance Margin _ % (>5.0% required)Peak Reactor Pressure during test __ psig Reactor Pressure Scram Avoidance Margin _ psig (>10 psi required)Maximum Indicated Steam Flow % of setpoint Scram Avoidance Margin % (>10% required)Worst Case Decay Ratio _, for signal No.Initial Date Time Verf Date Time Hope Creek Page 185 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 9 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 5.3

Description:

Turbine Stop Valves Valve Stroked: Date/Time:

Max. Reactor Power: Attached Plot: Max. APRM neutron flux peak following valve stroke: %APRM neutron flux scram setpoint %Neutron Flux Scram Avoidance Margin _ % (>7.5% required)Max. APRM indicated Heat Flux: % (<101% required)APRM Heat Flux scram setpoint %Heat Flux Scram Avoidance Margin _ % (>5.0% required)Peak Reactor Pressure during test _ psig Reactor Pressure Scram Avoidance Margin _ psig (>10 psi required)Maximum Indicated Steam Flow % of setpoint Scram Avoidance Margin _% (>10% required)Worst Case Decay Ratio ,for signal No.Initial Date Time Verf Date Time Hope Creek Page 186 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 10 of 11)TURBINE STOP, BYPASS AND MSIV TESTING 5.4

Description:

MSIVs Valve Stroked: Date/Time:

Max. Reactor Power: Attached Plot: Max. APRM neutron flux peak following valve stroke: %APRM neutron flux scram setpoint %Neutron Flux Scram Avoidance Margin _ % (>7.5% required)Max. APRM indicated Heat Flux: % (<101% required)APRM Heat Flux scram setpoint %Heat Flux Scram Avoidance Margin _ % (>5.0% required)Peak Reactor Pressure during test __ psig Reactor Pressure Scram Avoidance Margin _ psig (>10 psi required)Maximum Indicated Steam Flow % of setpoint Scram Avoidance Margin % (>10% required)Worst Case Decay Ratio ,for signal No.Initial Date Time Verf Date Time 5.5 Based on the above, Test Team has DETERMINED the maximum power levels for valve stroking as follows: Bypass Valves -Open/Close MWth Stop Valves -Full Close MWth MSIVs -Partial Close MWth Initial Date Time[ __I T__I Verf Date Time 5.6 Test Team to DETERMINE necessary changes to turbine valve or MSIV test procedures AND INITIATE a notification to make such changes as necessary.

Initial Date Time Hope Creek Page 187 of 188 Rev. 3 HC.OP-FT.ZZ-0004(Q)

ATTACHMENT 16 (Page 11 of 11)TURBINE STOP, BYPASS AND MSIV TESTING Table 16-1 -GETARS (IAC480) SIGNAL LIST (Duplicate as Necessary)

==

Description:==

Valve Stroked: Date/Time:

Reactor Power: Attached Plot: Signal Parameter Name Units CRIDS Diverges Number (YES/NO)1 APRM NEUTRON FLUX A % A2175 10 SIMULATED HEAT FLUX A %11 SIMULATED HEAT FLUX B %16 INBOARD MSIV A/B OPEN Open/Closed D5881, 5 18 INBOARD MSIV C/D OPEN Open/Closed D5882, 6 19 OUTBOARD MSIV A/B/C/D Open/Closed D5889, D42 10 22 NARROW RANGE RPV LEVEL INCHES A2574 24* NARROW RANGE PRESSURE PSIG A2578 26* MAIN STEAM FLOW LINE A MLB/HR A2609 27* MAIN STEAM FLOW LINE B MLB/HR A2610 28* MAIN STEAM FLOW LINE C MLB/HR A2611 29* MAIN STEAM FLOW LINE D MLB/HR A2612 30/33 APRM ROD BLOCK A/B % A2176, A2178 32 APRM NEUTRON FLUX B % Al 73 42 TOTAL CORE FLOW MLB/HR A190 100* TOTAL FEED FLOW MLB/HR B2030 101* TOTAL STEAM FLOW MLB/HR A212 127 GROSS ELECTRICAL OUTPUT MWE A3298 132-135 MSV 1, 2, 3, 4 OPEN Open/Closed D2007,8,9,1 0 139 TOTAL BYPASS VALVE POS. % A2534 138 BYPASS FLOW DEMAND %141 PRESSURE SETPOINT psig 149-157 BPV 1-9 POSITION %Notes:* These signals are filtered by the Digital Feedwater Control System. The transient values may be greater than indicated.

• • Refer to HC.OP-FT.AC-0006, Attachment 2, for a listing of CRIDS points or control room indicators associated with the above GETARDS PID.numbers.Hope Creek Page 188 of 188 Rev. 3