ec 5000033794, revision 1, indian point 2 station blackout ... · heat exchangers located adjacent...

EC 5000033794 REVISION 1 IP2 STATION BLACKOUT AND APPENDIX R DIESEL GENERATOR SET

of 59 EC5000033794 ECN 5980

Attachment ____ Page

ATTACHMENT 9.1 ENGINEERING CHANGE COVER SHEET

EC# 5000033794 Rev. No. 1

Created from: ECR IP2-04-18905 EC Type: DC SubType: NC

Proj. Pri: Facility: IPC Unit: 2 System: ARDG

Outage: N W/O Required: Y Alt Ref.: ER-04-2-095 Temp?: N Work at Risk?: Y

Keywords

Software: Y Quality Related: Y ECN Trend Code:

Title: IP2 Station Blackout and Appendix R Diesel Generator Set

Summary

See attached.

Resp. Engr. Eric Anderson / Robert Lee Date: 10/18/07

REVIEW

Technical Reviewer Date:

Design Verifier Mechanical / Larry Burbige Date:

Add’l Reviewers (List may be attached)

Electrical / Majeed Khan Civil / Gopal Bhalla

Dept. / Name / Date Dept. / Name /

Date

Dept. / Name / Date Dept. / Name /

Date

APPROVAL

Supervisor (EDEE) Joseph Raffaele Date:

Supervisor (EDME) Valerie Cambigianis Date:

Manager Thomas McCaffrey Date:

Engineering Director Date:

OSRC Date:

GMPO Date:


of 59 EC5000033794 ECN 5980


Table of Contents

1.0 DESCRIPTION .......................................................................... 3

1.1 STRUCTURE, SYSTEM, OR COMPONENT DESCRIPTION ............................................................. 3

1.2 REASON FOR CHANGE .............................................. 3

1.3 DESIGN OBJECTIVE TO RESOLVE PROBLEM .................................................................... 4

2.0 DOCUMENTS ........................................................................... 4

2.1 AFFECTED DOCUMENTS LIST (ADL) ......................... 4

2.2 REFERENCE DOCUMENTS ...................................... 24

2.3 AFFECTED EQUIPMENT LIST ................................... 17

3.0 EVALUATION/DESIGN SUMMARY ........................................ 26

3.1 EVALUATION RESOLUTION ..................................... 26

3.2 DESIGN BASES DISCUSSION .................................. 27

3.3 DESIGN INPUT CONSIDERATIONS .......................... 48

3.4 DISCUSSION OF IMPACT SCREENING RESULTS ................................................................... 48

3.5 RELATIONSHIP WITH OTHER ENGINEERING CHANGES ........................................ 48

3.6 OPERATING EXPERIENCE SEARCH RESULTS ................................................................... 33

3.7 MARGIN ANALYSIS ................................................... 33

4.0 IMPACT ON CURRENT OPERATIONAL BASIS .................... 52

5.0 ENGINEERING INSTRUCTIONS NECESSARY TO IMPLEMENT THE CHANGE ................................................ 53

6.0 ENGINEERED MATERIALS LIST AND VENDOR TECHNICAL INFORMATION ............................................... 58

7.0 SPECIAL PROCESS REQUIREMENTS ................................. 58

8.0 TESTS & INSPECTIONS ........................................................ 59

9.0 ATTACHMENTS ..................................................................... 59

9.1 DISTRIBUTED FOR FIELDWORK/INSTALLATION ..................................... 59

9.2 NOT DISTRIBUTED FOR FIELDWORK...................... 59


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Revision 1 of this Nuclear Change was initiated primarily to address the concerns of ENTERGY NUCLEAR Senior management with respect to the project’s overall cost effectiveness and constructability. Therefore Revision 1 changes are designed to address these concerns and facilitate ease of installation. The following is a summary of the changes to the original design and for clarity are indicated in bold text: • Elimination of the radiator mounted on the Unit 1 service building roof

and its associated missile protection enclosure. Instead tube and shell heat exchangers located adjacent to the DG set will remove heat from the DG engine jacket water and aftercooler cooling circuits, using city water and service water cooling.

• Elimination of the SBO/ App R DG enclosure and CO2 fire suppression

system. Instead, the DG set will be located in the open, with a moat surrounding the DG set and a limited area sprinkler system is provided for fire suppression. The ventilation ductwork is re-sized and extended into the area over the DG area. A larger ventilation fan is provided to remove DG engine heated air and thus, maintain the DG area temperature within acceptable limits.

• Re-route of DG engine exhaust pipe, to be located within the turbine

building up to its penetration through the TB west wall. The exhaust pipe from TB 53 ft. elevation to its discharge is designed to withstand tornado missile loads, and the exhaust pipe discharge missile barrier, is eliminated.

• (NOTE: This Revision 1 supersedes Revision 0 stored in MERLIN as

ER-04-2-095. This revision contains a complete set of drawings and documents for Revision 1; only those drawings and documents associated with this revision must be used. Revision 0 drawings stored in MERLIN as DRN’s for ER-04-2-095 are for information only.)

1.0 Description

1.1 Structure, System, or Component Description

Three gas turbines with black start capability are available at Indian Point 2 to provide an alternate backup power source in case of loss of onsite emergency power and concurrent loss of offsite power (Station Blackout (SBO)), as well as required auxiliary power for Alternate Safe Shutdown (ASS) Systems (ASSS) equipment for Appendix R Dedicated Shutdown. Currently UFSAR section 8.2.1.1 requires that at least one gas turbine is maintained operable at all times. Gas turbine power can be provided to Indian Point 2 from any of the three gas turbines by either of the three 13.8 KV underground feeders or by two 138 KV overhead feeders which connect offsite power to the unit. The overhead feeders, however, cannot be credited for SBO. The gas turbine electrical system is also credited to be available to respond to an Appendix R event or a Station Blackout event for Indian Point 3 when the Indian Point 3 Appendix R diesel generator is out of service.

1.2 Reason for Change

The Gas Turbines are included in IPEC’s Top Ten Equipment Reliability List. They are not reliable, and pose a major burden on Operations, Maintenance and Engineering resources.

Formatted: Indent: Left: 1", Bulleted + Level:1 + Aligned at: 1.5" + Tab after: 1.75" +Indent at: 1.75", Tab stops: 1.25", List tab +Not at 1.75"

Formatted: Indent: Left: 0.5"

Formatted: Indent: Left: 1", Bulleted + Level:1 + Aligned at: 1.5" + Tab after: 1.75" +Indent at: 1.75", Tab stops: 1.25", List tab +Not at 1.75"

Formatted: Font: Bold




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1.3 Design Objective to Resolve Problem

Replacement of the Gas Turbines will improve system reliability and avoid future costs of extensive gas turbine repair and replacement. This modification installs a single diesel generator unit to comply with NRC 10CFR50 Appendix R (Fire Protection) and 10CFR50.63 (Station Blackout) requirements and will serve the same function as the existing three gas turbine generators (GT’s). The three GT’s will be removed from the Unit 2 and 3 Licensing Basis and formally retired in place at a future date under a separate Engineering Change. Before the GT’s are retired, a transition plan will be developed to establish the reliability parameter for the new diesel generator. The GT’s will not be retired until the new diesel generator achieves the required ies the reliability criteria of 0.95 per demand for Standby Systems, as defined in NUMARC 87-00, Appendix B.. The proposed plan is one monitored DG start per week for 20 weeks with 19 successful starts achieving the required reliability criteria of 0.95.

2.0 Documents

2.1 Affected Documents List (ADL)

2.1.1 Documents Added or Changed by this Engineering Change Document Type: DRAWINGS

Specific Document Information Document Required For:

Drawing Number

ECN No if applicable

EC Rev.

Title / Description INST. RTS PRTS

400858 0 Framing for Missile Shielding at Diesel Generator Radiator, Sheet 1

400859 0 Framing for Missile Shielding at Diesel Generator Radiator, Sheet 2

400860 0 Framing for Missile Shielding at Diesel Generator Exhaust, Sheet 1

400861 0 Framing for Missile Shielding at Diesel Generator Exhaust, Sheet 2

400864 0 SBO / App R Diesel Generator Set DGiesel Generator Mounting

400881 0 Flow Diagram – Fuel Oil System 400882 0 Flow Diagram – Diesel Cooling System 400883 0 Composite Piping Arrangement Plan @

EL 53’-0”, 33’-0” & 15’-0”

400884 0 Composite Piping Arrangement Enlarged Part Plans

400885 0 Composite Piping Arrangement Sections 400886 0 HVAC Layout Plan @ EL 53’-0” & 33’-0” 400887 0 HVAC Layout Sections & Details 400888 0 Pipe Supports for Exhaust Line – Index 400889 0 Pipe Supports for Exhaust Line - Notes 400890 0 Pipe Support for Exhaust Line – Mark

No. DG-001

400891 0 Pipe Support for Exhaust Line – Mark No. DG-002

Formatted: Font: (Default) Arial, 10 pt, Bold


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Specific Document Information Document Required For: Drawing Number


EC Rev.









400899 0 Pipe Support for Cooling Water – Index 400900 0 Pipe Support for Cooling Water – Notes 400901 0 Pipe Support for Cooling Water – Mark

No. CW-001

400902 0 Pipe Support for Cooling Water – Mark No. CW-002














400916 0 SBO/App R DG plans @ El. 33’-0” 400917 0 SBO/App R DG Dets & Plans @ El.33’-

0”

501292 0 Pipe Support for Cooling Water –Mark No. CW-016


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EC Rev.







501415 SH4 ECN6511

ECN5978 1 Battery Rack, Battery, and Battery Charger Wiring and Mounting Details



501418 0 Pipe Support for Cooling Water –Mark No. SWT-001






501424 0 SBO/App R DG SetPY8000 Manual Double Wall U/L Listed, Fuel Oil Day Tank, Mechanical

501425 ECN5877

ECN 5877 0 SBO/App R DG SetWiring Diagram, Fuel Oil Day Tank, Electrical

501426- ECN6561

ECN 6561 0 SBO/App R DG SetSurge Tank, Mechanical





501495 0 SBO/App R DG SetMiscellaneous Framing Details Turbine Building Elev. 33’-0” Civil/Structural

501496 0 Alternator Connection provisions 501497 ECN5978

ECN5978 1 Battery and controls location


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EC Rev.


501498 ECN5877

ECN5978 ECN 5877

1 General Arrangement & controls Sh.1

501499- ECN6926

ECN 5978 ECN 5979 ECN 6561 ECN6926

1 General Arrangement & controls Sh.2

501500 ECN5979

ECN 5979 1 General Arrangement & controls Sh.3

501501 ECN5979

ECN 5979 1 General Arrangement & controls Sh.4

501502 ECN5978 0 Battery Charger Assembly Sh.1 501503 ECN5978 0 Battery Charger Assembly Sh.2 501504 0 Control Assembly Sh. 1 501505 0 Control Assembly Sh. 2 501506 0 Control Assembly Sh. 3 501507-ECN6561

ECN 6561 0 Interface outline

501508 0 Generator Installation 501509 0 SBO/App.R DG MCC Specifications 501510 0 SBO/App.R DG MCC Front View 501511 0 SBO/App.R DG MCC Unit Schedule

Sh.1

501512 0 SBO/App.R DG MCC Unit Schedule Sh.2

501513 0 SBO/App.R DG MCC Options & Notes 501514 0 SBO/App.R DG MCC Plan View 501515 0 SBO/App.R DG MCC FVNR Size 1

Schematic

501516 0 SBO/App.R DG MCC Wiring space heaters

501517 0 SBO/App.R DG MCC Feeder wiring 501518 0 SBO/App.R DG MCC FVNR Size 3&4

Schematic

501519 0 SBO/App.R DG MCC Grounding & Neutral Conduit

501520 0 SBO/App.R DG MCC Side View 400952 0 SBO/APP. R DG Fire Protection &

Heat Exchanger Piping Arrangement

400956 0 SBO/APP. R DG, Material List, Mechanical, Pages 1 of 2 and 2 of 2

400957 0 SBO/App R DG HX Supports 400958 0 SBO/App R DG HX Supports 138001 0 Indian Point – Unit No. 1 Generator –

Superheater Bldgs. Arrangement – Plan Floors El. 28’-6” & El. 33’-0”

138114 0 Unit 1 Plumbing & DrainageBelow El. 5’-0”, Plan

138359 0 Unit 1 Piping ArrangementCity Water Loop, Plan

138412 0 Unit 1 Miscellaneous Framing & Grating, Plans at El. 33’-0”


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EC Rev.


138069 0 Unit 1 Steel FramingPlan at El. 53’-0”

138105 0 Piping Arrangement River Water Piping Sections

138106 0 Piping Arrangement River Water Piping Plan

138107 0 Turbine Generator foundation 138337 0 Unit 1 Plan at Elevation 33'-0" 192480 0 Unit 1 Piping Flow Diagram River

Water Service System, Sheet 1 of 2

193183 0 Unit 1 Piping Flow Diagram City Water System, Sheet 3

9321-2033

0 Flow Diagram Service & Cooling Water, River Water & Fresh Water

311804 0 Modification to 2” F.O. supply Piping to GT-1 & Black Start Diesel Gen.

227552 0 Fire Protection System Details 227553 0 Fire Protection System Diagram

Details Sheet 3

251571 0 Expansion Main Facility Elev. 15'-0 Fire Protection System – Wet Pipe Sprinkler, Pages 1 and 2

260586 0 Gas Turbine #1 Flow Diagram Fuel Forwarding System

138040 ECN-4444 1 Unit #1 One line diagram 13.8 KV & 440 V System

138142 0 Unit #1 Diagram of Connection of Station Main Ground Grid

138281 0 Unit #1 Installation of Bus Duct for Generator Excitation Plan

138283 0 Unit #1 Installation of Bus Duct for Generator Excitation Sections & Details

138303 0 Unit 1 CCR Instrument Cubicle front view Sh 2 Node EJA11

138312 ECN-4596 1 Unit 1 Lighting Between El. 15’-33’ Col. 6 to 11, Turbine Generator Building, (Emergency Lighting New)

138313 1 Unit 1 Lighting Between El. 33’-53’ Col. 1 to 6, Turbine Generator Building, (Emergency Lighting New)

138327 ECN-5888 1 Unit #1 13.8 KV Conduit Run Under El. 33’0”

138329 0 Unit #1 Cable Troughs & Conduits Under El 33’0”


138367 1 Unit 1 Lighting Between El. 15’ – 33’ Col. 1 to 5, Turbine Generator Building, (Emergency Lighting New)

138371 ECN-5888 0 Unit #1 13.8 KV Conduit Run Under El 33’0”


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EC Rev.


138379 0 Unit 1 One Line Diagram 125 V DC System

138383 0 Unit No. 1, Cable Troughs & Conduits Under El. 33’0”

138386 ECN4444 1 Unit #1 13.8 KV Conduit Run, Sections & Details, Sheet 1

138387 0 Unit #1 13.8 KV Conduit Run, Sections & Details, Sheet 2




138507 0 Unit #1, Ext. Diag of Conn's for 125 V DC Dist Pnl 1, 2 & 3

138548 ECN-4444 1 Unit 1 Schematic Diagram, Relay Protection of 13.8 KV Indoor Light & Power Aux. Bus

138647 ECN-4444 1 Unit 1 Diag Typical splice arrangement for 13.8kV feeders in splice box

138669 0 Unit #1, Diag of Conn. Instrument Flight Panel Common Sect. Node EJD1

138681 0 Unit 1 Diag of Conn CCR Inst Cubicle Area Mon Pnl (GT1 Supervisory) EJC5

138732 0 Unit #1, Cable Troughs & Conduits, Battery & MG Room, Plan

138734 0 Unit #1 Cable Troughs & Conduits in Terminal Board Room, Plans & Sections

138735 0 Unit #1 Cable Troughs & Conduits in Terminal Board Room, Sections & Details

138891 0 Unit #1 Ext Diag of Connections Substation 11CW1

138892 0 Unit #1 Ext Diag of Connections Substation 11RW1

138898 0 Unit #1 Ext Diag of Conn Annunciator Relay Cabinet in Terminal Bd Rm

138903 0 Unit #1 Ext Diag of Connections Substation 11SA1

138912 0 Unit #1 Ext Diag of Connections Substation 11FD1

138924 0 Unit #1 Diag of Conn 13.8 KV L&P Bus, Section 1, 2 & Bus tie

138991 0 Unit #1, 3 Line Diagram L & P Feeders & Buses

138992 0 Unit #1, 3 Line Diagram Relay Protection & Metering

175814 0 Unit #1, Ext. Conn. Diagram, 60 Cycle AC Gas Turbine Generator


of 59 EC5000033794 ECN 5980




EC Rev.


175856 ECN5877

ECN 5877 1 21.5 MW Gas Turbine & Generator Arrangement of Conduit

175858 ECN5888

ECN-5888 1 Conduit Schedule Gas Turbine & Auxiliaries

175859 ECN5888

ECN-5888 1 Unit 1 Cable Schedule Gas Turbine & Auxiliaries

175864 0 Block Diagram Gas Turbine Installation 176463 0 One Line Diagram for Gas Turbine 177659 ECN5888

ECN-5888 1 Unit #1, Construction Details of Splice Boxes 4A & 4B (2 Sheets)

179692 0 Indian Point Substation, Simplified Schematic for Installation of Startup Transformer for IP2 and Startup Transformer for IP 3 Relay Protection

208377 ECN5980

ECN-4444 ECN5980

0 Main One Line Diagram

208671 ECN-4596 Installation of lighting in the Service Water Valve Pit

225649 0 IP2 Conduit Layout T/G & Heater Bays 226821 ECN4444 1 Indian Point #1, 13.8 KV Swgr, L & P

Aux Bus Section Views (2 sheets)

231592 0 6900 VAC One Line Diagram 250907 ECN5980

ECN-4444 ECN5980

1 Elect Distribution & Transmission System, UFSAR Fig. 8.2-1, 8.2-2

251796 ECN-4596 1 Expanded Maintenance Facility Lighting El/ 15’-0”

312901 0 One Line Diagram Gas Turbine Gen. #1 312909 0 Diag. Of Conn. Protective Relay Panel

4R - GT #1, Node EPA89

400421 ECN-4596 1 App R Emergency Battery Lightingsafe shutdown paths @ Elevation 15’


400428 ECN-4596 1 App R Emergency Battery Lighting Safe Shutdown Paths Table

400426 ECN-4596 1 App R Emergency Battery Lighting Safe Shutdown Paths El. 15’-0”’-0”


400853 Sh.1 ECN6561

ECN5978 ECN-5888 ECN 6561

1 SBO & App. R DG Set, Equipment & Raceway Layout @ El 53’-0”, El 33’-0” & El 15’-0”, Electrical

400853 Sh.2

ECN-5888 1 SBO & App. R DG Set, Equipment & Raceway Layout @ El 15’-0”Electrical

400854 ECN 5978 ECN-5888

1 Electrical Grounding and Lighting Plans

400855- ECN5877

ECN 5978 ECN-5888 ECN 6561 ECN 6811 ECN 5877

1 Diesel Generator Set Cable Block Diagram


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EC Rev.


322429 ECN 5888 1 Straight joint for connecting GT-1 AT-1 to SBO/App.R DG Swgr

138925- ECN6561

ECN-5888 ECN 6561

1 Unit 1 Diag. of Conn’s to 13.8kV L&P Bus Section 3 & 4

400856 ECN6926

ECN-4444 ECN5888 ECN6926

1 Diesel Generator Set Electrical Bill of Materials

400865 1 Diesel Generator Set One Line – 480V Motor Control Center

9321-F-3179 ECN6926

ECN5888 ECN6926

1 Wiring Diagram – 480V MCC 22 Sh.1

400866 ECN6926

ECN6926 1 Diesel Generator Set Diag of Conn –480V MCC (2 Sheets)

400867-ECN 6811

ECN 5978 ECN 6561 ECN 6811

0 Diesel Generator Set Diag of Conn – Diesel Generator & Battery Charger

400868-ECN 6926

ECN 5979 ECN 6561 ECN6926

1 Diesel Generator Set Diag of Conn -DG Control Panel

400869- ECN5877

ECN-4444 ECN 6561 ECN6926 ECN 5877

1 Diesel Generator Set Diag of Conn -DG Auxiliaries

400870 ECN6926

ECN 5979 ECN 6561 ECN 6811 ECN6926

1 Diesel Generator Set Diag of Conn -DG Output Breaker

400871 ECN-4444 1 Diesel Generator Set Diag of Conn -SBO/APP. R 13.8 KV Switchgear

400872 ECN5888

ECN-5888 1 Diesel Generator Set Diag of Conn -SBO/APP. R 6.9 KV Switchgear

400873 ECN6926

ECN-4444 ECN 5979 ECN6926

1 Diesel Generator Set Schematic - DG Area Ventilation Fan

400874 0 Diesel Generator Set Schematic - Fuel Fwd Pump #1

400875 0 Diesel Generator Set Schematic - Fuel Fwd Pump #2

400876 0 Diesel Generator Set Schematic - DG Radiator Radiator Fan

400877- ECN 6561

ECN-4444 ECN 6561

1 Diesel Generator Set Schematic -13.8KV Circuit Breaker ASS

400878 0 Diesel Generator Set Schematic - 13.8KV Circuit Breaker SBOH

400879 0 Diesel Generator Set Schematic - 6.9KV Circuit Breaker SBOL

400880 0 Diesel Generator Set Schematic - 6.9KV Circuit Breaker OSP

9321-F-3004

0 One Line Diagram 480 VAC MCC 21, 22, 23, 25 & 25a


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EC Rev.


9321-F-3073-ECN5888

ECN-5888 0 Conduit Layout, T/G & Htr Bays El. 36’-9“, Sh 3

9321-3022

ECN 4596 1 Lighting System Turb Bldg. El. 15’-0

9321-3023

ECN 4596 1 Lighting System Turb Bldg. El. 36-9

9321-3041

ECN 4596 1 Lighting Panels & circuit diagrams Sh.1

501415 SH.3

ECN 4596 1 SBO/App. R DG termination Box Extension

IP2- -D-000030

0 Lockout Relay LOR Electroswitch Company Model #7806D

IP2- -S-000107

0 3 Line AC Gas Turb#1 Auto Transformer AT1 Diff Protection

IP2- -S-000108

0 Gas Turbine #1 Auto Transformer AT1 Lockout Relay LOR

115R302 Sht. 4

0 Bus Section No. 1 Power & Control Circuits for Incoming Line Unit 1-2

115R302 Sht. 5

0 Bus Section No. 1 Power & Control Circuits for Incoming Line Unit 1-4 & Bus Lockout

633D851 Sht. 0

0 L&P Swgr Lineup #1 Front View

4469D69 Sht. 5

0 W-251G Gas Turbine Generator Field Wiring Connections, Station Auxiliary MCC

VND1975M6110 Sht. 2

0 West MCC 22 Layout Compt 1- 4

VND1975M6114 Sht. 6

0 West MCC 22 Unit Specs Compt 1- 4

115R302 Sht. 1

0 L&P Swgr Lineup #1 & 2 One Line Diagram

124RF728 Sht. 1

0 L&P Bus Section 1 Interconnections

124RF718 Sht. 1

0 L&P Bus Unit 1-2, Internal Wiring Sh 1

124RF718 Sht. 2


124RF719 Sht. 1


119E592 0 Gas Turbine GT-1 Control Schematic 2001MB1372 Sht. 3

0 Woodward Wiring Dwg, GT1 Panels, Sh. 3


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EC Rev.


2001MB1407 Sht. 33

0 Woodward Wiring Dwg, GT1 Panels, Sh. 33

CG52F447

0 Spec & Layout W251G Station Auxiliary MCC

CG52F448

0 Schematic W251G Station Auxiliary MCC

CG52F449

0 Compartment Wiring W251G Station Auxiliary MCC

19 Con Ed IP1/IP2 138kV 60 Cycle Operating Diagram

19A Con Ed IP3 138kV 60 Cycle Operating Diagram

694 Con Ed Buchanan 13.8kV 60 Cycle Operating Diagram

501427 1 Swgr. Front Elev. Floor Plan(B2004-4040-1-M1)

501428 1 Swgr. Outline – Sections(B2004-4040-1-M2)

501429 ECN6926

ECN6926 1 Swgr. One Line Diagram(B2004-4040-1-E1)

501430 1 Swgr. Three Line Diagram(B2004-4040-1-E2)

501431 ECN6561

ECN 5979 ECN 6561

1 Cont. Schem. 52 Breaker (SBO/ASS) (B2004-4040-1-E3 Sht 1)

501432 ECN6926

ECN 5979 ECN 6561 ECN6926

1 Swgr. Remote Trip / Close Wiring(B2004-4040-1-E3 Sht 2)

501433 ECN6926

ECN 5979 ECN 6561 ECN6926

1 Breaker Compartment Door (Rear View) Wiring (B2004-4040-1-WD1 Sht 2)

501434 1 Breaker Inst. Compartment Wiring(B2004-4040-1-WD1 Sht 1)

501435 1 Breaker PT / Switch Compartment Wiring (B2004-4040-1-WD2)

501436 1 Powell Elect. Swgr. Section’s Views(1032305002)

501437 1 Powell Elect. One Line Diagram(1032305003)

501438 1 Powell Elect. Three Line Diagram(1032305004)

501439 1 Cont. Schem. FDR. BKR. 52 - SBOL Unit 5A (1032305005)

501440 1 Cont. Schem. FDR. BKR. 52 – OSP Unit 6B (1032305006)

501441 1 Powell Elect. AC / DC Circuits(1032305007)


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EC Rev.


501442 1 Powell Elect. Wiring Diagram Unit 5A 52-SBOL (1032305008)



501445 1 Powell Elect. Wiring Diagram Unit 6B 52-OSP (1032305011)



501448 1 Powell Elect. Door Detail A(1032305D01)

501449 1 Powell Elect. Door Detail B(1032305D02)

501450 1 Wiring Diagram – Cummins Generator Set (0630-2513 Sht 1)


501452 1 Wiring Diagram – Cummins Generator Set (0630-2513 Sht 4) (Note: No Sht 3)





501457 1 13.8kV Swgr. Door Detail A(1032301D01)

501458 1 13.8kV Swgr. Door Detail 2A(1032301D02)

501459 1 13.8kV Swgr. Door Detail C(1032301D03)

501460 1 13.8kV Swgr. Bill of Materials


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EC Rev.


501461 1 Plan View and Elevations App. R DG 13.8kV Swgr. (1032301001)

501462 1 13.8kV Swgr. Section Views(1032301002)

501463 1 13.8kV Swgr. One Line Diagram(1032301003)

501464 1 13.8kV Swgr. Three Line Diagram(1032301004)

501465 1 Control Schematic Feeder Breaker SBOH (1032301005)

501466 1 Control Schematic Feeder Breaker 52-ASS Unit 2B (1032301006)

501467 1 AC / DC Circuits(1032301007)

501468 1 Wiring Diagram Unit 1 VT-001(1032301008)

501469 1 Wiring Diagram Unit 2A FDR BKR 52-SBOH (1032301009)



501472 1 Wiring Diagram Unit 2B FDR BKR 52-ASS CB (1032301012)



501475 1 Appendix R Diesel Generator Outline(0500-3563 Sht 3)





501480 1 Appendix R Diesel Generator Schematic (0200-3081 Sht 4)



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EC Rev.



501483- ECN 6561

ECN 6561 1 Appendix R Diesel Generator Outline(0179-3276 Sht 1)


501485 1 Appendix R Diesel Generator – 6.9kV Swgr. Front View (1032305001)

501486 1 Appendix R Diesel Generator – 13.8kV Swgr. Front Elev. And Plan View (1032301001)

501487 1 Appendix R Diesel Generator – 13.8kV Swgr. Specifications (1032301S01)

501596 ECN5978

ECN 5978 1 LaMarche Drawing D6-138 Case Type 6 Battery Charger Mounting Details

501597 ECN5978

ECN 5978 1 Cummins Dwg. 0416-0439 – Battery Cell 8D Outline Drawing

501598 ECN4596

4596 1 SBO/App.R DG Seismic conduit support Detail

501599 ECN4596

4596 1 SBO/App.R DG Seismic Bracket for EBL EL-16C

501600 ECN4596

4596 SBO/App.R DG Seismic Bracket for EBL EL-16C

501601 ECN4596

4596 SBO/App.R DG Seismic Bracket for EBL EL-16C

501602 ECN4596

4596 SBO/App.R DG Seismic Bracket Anchorage Detail for EBL EL-16C

501607 ECN5888

ECN 5888 1 SBO/App.R DG Installation of cable splice in Box 4A

501608 ECN5888

ECN 5888 1 SBO/App.R DG Bill of Material for cable splice in Box 4A

501609 ECN5888

ECN 5888 1 SBO/App.R DG Removal of cable splice in Box 3A

501610 ECN5888

ECN 5888 1 SBO/App.R DG Installation of cable splice in Box 3A

501611 ECN5888

ECN 5888 1 SBO/App.R DG Bill of Material for cable splice in Box 3A

501612 ECN5888

ECN 5888 1 SBO/App.R DG Removal of cable splice in Box 4A

501616- ECN 6561

ECN 6561 1 Low coolant probe jacket water surge tank

501617- ECN 6561

ECN 6561 1 Low coolant probe cable harness jacket water surge tank

501618- ECN 6561

ECN 6561 1 Wiring Diagram engine and alternator heaters

9321-F-33853 ECN 5980

ECN 5980 1 Electrical Distribution and Transmission System (IP3)


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Document Type: SPECIFICATIONS


Number Rev. Title / Description INST. RTS PRTS IPEC-SPEC-04-00015

0

Unit 2 Station Blackout (SBO) and Appendix R Medium Voltage Switchgear and 13.8 kV-6.9 kV Dry Type Transformer

9321-01-248-18 17 Fabrication of Piping Systems Turbine Generator Plant, Classes D-8, J-I , and N-1

Document Type: DATABASE


Number Rev. Title / Description INST. RTS PRTS IAS Equipment Database

N/A All new components installed by mod

ECRIS N/A Elect. Cable & Raceway Info Sys

Document Type: CALCULATIONS


Number Rev. Title / Description INST. RTS PRTS

IP-CALC-04-01579 0 SBO and Appendix R Diesel Generator Support and Piping Support

IP-CALC-04-01580 1 Diesel Generator Exhaust Pipe Stress & Supports Design Analysis

IP-CALC-04-01582 0 SBO/App. R DG Project – Cable Sizing Calculation

IP-CALC-04-01583 1 IP2 SBO Appendix R DG - Pressure Drop in DG Exhaust Piping

IP-CALC-04-01584 1 IP2 SBO Appendix R DG - Pressure Drop in the Engine Cooling Water Piping

Specific Document Information Document Required For: Number Rev. Title / Description INST. RTS PRTS

IP-CALC-04-01585 0 IP2 SBO Appendix R DG Replacement - Pressure Drop in the

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Fuel Oil Transfer/Return Piping

IP-CALC-06-(later)27604-017-07.001

20 IP2 SBO Appendix R DG –Determination of DG Set Ventilation Requirements (WGI GOTHIC Analysis)Study of SBO/Appendix R Diesel Generator Room Temperature Distribution

IP-CALC-05-00127 1 SBO/App. R DG Enclosure – HVAC Duct Sizing and Pressure Loss

IP-CALC-06-00263 0 Evaluation of Unit 2 Appendix R DG Exhaust Pipe For Tornado Wind and Missile

IP-CALC-07-00168 0 IP2 Evaluation of Supports for Jacket Water and Aftercooler Cooling Water Tanks for App R Diesel

FEX-00160-02 02 IP2 Evaluation of Alternate Safe Shutdown Power Supplies

IP3-RPT-ED-00922 03 Appendix ‘R’ Diesel Generator System Evaluation

IP3-CALC-EL-02984

0 Appendix ‘R’ Diesel Generator System Evaluation

IP-CALC-04-01589 0 IP2 Load Flow Analysis of the Electrical Distribution System Supplied from the 13.8kV Distribution System

FEX-00101-01 01 13.8kV & 6.9kV Cable Ampacity for Primary and secondary Leads of the New GT-1 Transformer

FEX-00102-00 0 6.9kV Cable Ampacity from Splice Box 4A thru Splice Box 4B to 6.9kV Switchgear

FEX-00201-00 0 IP1 Voltage Profile for Battery 11 and 12

FEX-00138-00 0 IP1 Battery #11 Sizing Calculation

FEX-00143 1 IP2 Load Flow Analysis of the Electrical Distribution System

SGX-00017 1 Non-Safety Related 480V MCC Coordination Calculation For MCC’s 21, 22, 23, 25, 25A, 28, 28A, 210 & 211

FMX-00227 1 Flow Calculation of Service Water System

Document Type: OTHER DOCUMENTS






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SAO-703 24 Fire Protection Impairment Criteria and Surveillance

2-ECA-0.0 Loss of All AC Power 2-ECA-0.1 Loss of All AC Power Recovery

Without SI Required

2-ECA-0.2 Loss of All AC Power Recovery With SI Required

2-COL-24.1.1 Service Water and Closed Cooling Water Systems

2-COL-27.(later) Unit 2 Appendix R Diesel (New) 2-COL-31.1 Gas Turbine 1 2-COL-27.1.11 Lighting System and Emergency

Lighting

2-COL-29.1.1 21 and 22 House Service Boilers 2-COL-29.6 Fire Protection System 2-COL-29.6.1 City Water System 2-ARP-(later) Appendix R Diesel Local Alarm

Response Procedure (New)

2-ARP 1FAF Unit 1 Flight Panel 2-ARP-SCF Condensate and Boiler Feed 2-ARP-SHF CCR Electrical 0-AOP-SEC-1 Response to Security Compromise 2-AOP-480-V-1 Loss of Normal Power to any 480V

Bus

2-AOP-13.8KV Loss of Power to any 13.8KV Bus 2-AOP-138KV-1 Loss of Power to 6.9KV Bus 5

and/or 6

2-AOP-SSD-1 Control Room Inaccessibility Safe Shutdown Control

AOI-27.1.9.2 Providing Appendix R Power from Unit 3

2-ONOP-FP-001 Plant Fires


3-AOP-SSD-1 Control Room Inaccessibility Safe Shutdown Control

3-AOP-13.8KV Loss of 13.8KV Power 3-AOP-138KV-1 Loss of Offsite Power 3-AOP-480V-1 Loss of Normal Power to any

Safeguards Bus

3-ONOP-FP-1 Plant Fires 2-PT-(later) Appendix “R” Diesel Support

System Inspection (New)

2-PT-(later) Appendix “R” DG Functional Test (New)

2-PT-(later) Appendix “R” Channel Checks (New)

2-PT-(later) Appendix “R” Diesel Rated Load and Overspeed Test (New)

PT-A28 Emergency Lights Battery

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Integrity PT-M49A Appendix R Emergency Lighting

Conventional

PT-A041 Gas Turbine 1 Fuel Oil Tank Tightness Test

PI-M92-PI-M009 Aboveground Petroleum Storage Tanks

2-PT-W1 Emergency Diesel Generators 2-PT-V053C Mode Change Checklist, Mode 5 to

Mode 4

2-PT-V053D Mode Change Checklist, Mode 4 to Mode 3

2-PT-V053E Mode Change Checklist, Mode 3 to Mode 2

2-PT-R014 Automatic Safety Injection System Electrical Load and Blackout Test

2-PT-W019 Electrical Verification, Offsite Power Sources and AC Distribution

2-SOP-ESP-001 Local Equipment Operation and Compensatory Actions

3-SOP-ESP-001 Local Equipment Operation and Compensatory Actions

2-SOP-1.3 Reactor Coolant Pump Startup and Shutdown

2-SOP-27.(later) Unit 2 Appendix R Diesel Operation (New)

2-SOP-27.(later) Energization of the 480V Busses from the Appendix R Diesel Generator (New)

2-SOP-27.1.1 Operation of 345KV and 138KV Components

2-SOP-27.1.3 Operation of 13.8KV System 2-SOP-27.1.4 6900 Volt System 2-SOP-27.1.5 480 Volt System 2-SOP-27.1.15 Removing 480 Volt Buses From

Service

SOP-27.3.2 Filling Diesel Fuel Oil Storage Tanks

2-SOP-29.1.1 21 and 22 House Service Boilers SOP 29.19 Number 2 Grade Fuel Oil Ordering,

Deliveries and Receipt

2-SOP 29.20 Emergency Fuel Oil Transfer Using the Trailer

SOP 31.1.4 Gas Turbine 1 Fuel Oil Receipt 2-DSR-(later) Unit 2 Appendix R Diesel ESOMS

Logsheet

Specific Document Information Document Required For: Number Rev. Number Rev. Number Rev.

2-DSR-1 Unit 2 Central Control Room Log Modes 1-4

2-DSR-2 Control Room Supervisor Shift Turnover Log

2-DCR-3 High Tension Log Sheet 2-DSR-08M IP Station Readings

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3-PT-D001 Control Room Operations Surveillance Requirement

2-PT-D001C TS/TRM Station Readings (1200) – 24 Hour Surveillance Requirements

IP-SMM-OU-104 Shutdown Risk Assessment OAP-005 Narrative Logs OAP-008 Severe Weather Preparation OAP-037 Operations Electrical Equipment

Operating Guidelines

OAP-050 Entergy Power Marketing Protocol GRAPH TC-25 Gas Turbine Oil Tank – Calibration

for Each Tank Inches VS. Gallons (GT #1)

GRAPH TC-26A Gas Turbine Oil Tank in Buchanan Range 1-15

GRAPH TC-26B Gas Turbine Oil Tank in Buchanan Range 16-31

2-AOI 31.3 Gas Turbine 3 COL 31.2 Gas Turbine 2 2-COL-31.3 Gas Turbine 3 DSR 13-GT1 Gas Turbine 1 Daily Operability

Check Log

DSR 13-GT2 Gas Turbine 2 Daily Operability Check Log

DSR 13-GT3 Gas Turbine 3 Daily Operability Check Log

LARP 37.1.1 GT-1 Alarms, OpTrend Page 7 LARP 37.1.22-ARP-046

GT-1 Alarms, OpTrend Page 8

2-ARP-047LARP 37.1.3

GT-1 Alarms, OpTrend Page 9

LARP 37.2.1 GT-2 Alarms, OpTrend Page 6 LARP 37.2.2 GT-2 Alarms, OpTrend Page 7 LARP 37.3.1 GT-3 Alarms, OpTrend Page 16 LARP 37.3.2 GT-3 Alarms, OpTrend Page 17 OPERATOR AID 02-06-00

GT-1 Start Diesel Label

2-OSP 31.1.2 Support Procedure – Gas Turbine 1 Local Operations

OSP 31.2.2 Support Procedure – Gas Turbine 2 Local Operations

OSP 31.2.4 Support Procedure – Gas Turbine 2 and 3 Fuel Oil Receipt

2-OSP 31.3.2 Support Procedure – Gas Turbine 3 Local Operations

PT-2Y11A Gas Turbine 1 Blackstart Timing PT-2Y11B Gas Turbine 2 Blackstart Timing


PT-2Y11C Gas Turbine 3 Blackstart Timing PT-A36A Gas Turbine # 1 Overspeed PT-A36B Gas Turbine # 2 Overspeed PT-A36C Gas Turbine # 3 Overspeed 2PT-M-PT-M038A Gas Turbine No. 1

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2-PT-M038B Gas Turbine No. 2 2-PT-M038C Gas Turbine No. 3 Functional 2-SOP 27.5.3 Black Start of Gas Turbine 1, 2 or 3 2-SOP-27.5.8 Gas Turbine 1 Operability Check 2-SOP-31.1.1 Gas Turbine 1 Remote (CCR)

Operations

2-SOP-31.1.2 Gas Turbine 1 Local Operations SOP 31.2.1 Gas Turbine 2 Remote (CCR)

Operations

2-SOP-31.2.2 Gas Turbine 2 Local Operations 2-SOP-31.2.3 Gas Turbine 2 Operability Checks 2-SOP-31.2.4 Gas Turbine 2 and 3 Fuel Oil

Receipt

2-SOP-31.3.1 Gas Turbine 3 Remote (CCR) Operations

2-SOP-31.3.2 Gas Turbine 3 Local Operations 2-SOP-31.3.3 Gas Turbine 3 Operability Check 2-SOP 31.4 GT-2/GT-3 Fuel Oil Tank Foamite

System Operation

WSR 13-GT1 Gas Turbine 1 Weekly Operability Check Log



EO-4087 Con Edison Emergency Restoration Procedure for Nuclear Plants

SO-4-13 Con Edison Normal Restoration Procedure for Nuclear Plants

PFM-57 Emergency Diesel Generator Reliability Program

IP2-UFSAR -Chapter 8

Electrical Systems

IP2-UFSAR -Chapter 9.6

Service Water and City Water Systems

IP3-UFSAR – Chapter 1.3 (GDC 17), 8.1 & 8.2

Electrical Systems

IP3 Technical Requirements Manual - Section 3.7B

1 Appendix R Alternate Safe Shutdown Equipment

IP3 Technical Requirements Manual - Section 3.8B

0 Appendix R Diesel Generator and Electrical Distribution System

IP-RPT-054-00071 1 IP2 10 CFR 50, Appendix R Safe-Shutdown Separation Analysis

IP-RPT-05-00084 0 IP2 Post-Fire Safe Shutdown Manual Action Feasability Report

IP2-RPT-03-00015 3 IP2 Fire Hazards Analysis IAS Equipment Database

Setpoint Data for: FC-8026-1, FC-8026-2, LC-8026, LC-8027, TE-



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8027, TS-7982 & M147-LASIP2-ICPM-1755 City Water Storage tank IP2-CYW DBD 1 City Water System Design Basis

Document

IP2-SW DBD 1 Service Water System Design Basis Docoument

0-CY-1810 Diesel Fuel Oil Monitoring 0-CY-2510 Closed Cooling Water Chemistry

Specifications and Frequency

0-CY-1500 Chemistry Sample Locations 0-CY-2515 Adding Chemicals to Closed

Cooling Systems

SEP-SW-001 1 Generic Letter 89-13 Service Water Program

IP3-RPT-UNSPEC-03499

1 Indian Point Units 2 & 3 Eddy Current Program

Check Valve Program (per evaluation iaw EN-DC-131)

Relief Valve Program (per evaluation iaw EN-DC-314)

2953 Powell Industries Instruction manual for IP2 SBO/APP.R DG 13.8kV/6.9kV Switchgear

2954 Cummins Model DQLA Operators Manual for IP2 SBO/App.R DG

2955 Cummins Manual for IP2 SBO/App.R DG MCC and DG Breaker Switchgear

2956 Cummins Manual for IP2 SBO/App.R DG Day Tank.

2957 Cummins Manual for IP2 SBO/App.R DG Control Wiring

2958 General Switchgear Operator and maintenance manual for IP2 SBO/App.R DG 13.8kV Swgr.

13.8kV Maintenance Rule basis Document

IP2 System Description 27.1 (Electrical systems)

IP3 System Description 27.1 (Electrical System High Voltage

IP2 DBD-221 DBD for IP2 Fire Protection System

2PT- later PM for IP2 SBO/App.R DG protective relays SBO/ASS 50/51 51G, ASS-50/51, 50/51G, SBOH-50/51, 5051G, SBOL-50/51 and 51N, OSP 50/51 and 50/51G

2PT-later PM for IP2 SBO/App.RDG 13.8kV breaker SBO/ASS, SBOH, & ASS

2PT-later PM for IP2 SBO/App.R DG 6.9kV breakers SBOL and OSP

2PT-later PM for IP2 SBO/App.R DG Transformer SBO

2PT-later PM for MCC 22-4M


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2PT-later PM (Surveillance Test for IP2 SBO/App.R DG Battery charger and batteries

2PT-later PM for IP2 SBO/App.R DG13.8/6.9kV Switchgear

2PT-later PM for IP2 SBO/App.R DG Switchgear

2PT-later PM for IP2 SBO/App.RDG 13.8kV-480V Transformer

0-ELC-420-FIR ECN-4596

Appendix R Emergency Light Unit Inspection Battery Replacement & Test

0-ELC-406-FIR ECN-4596

Appendix R Emergency Light Unit Test Inspect Repair and replace

2.1.2 Documents Voided by this Engineering Change Document Type: NONEREPORTS

2.2 Reference Documents

2.2.1 Entergy Specification No. IP2-SPEC-04-00003, Rev. 0, Unit 2 Station Blackout (SBO) and Appendix R Diesel Generator Set

2.2.2 Entergy Specification No. 9321-01-248-18, Rev. 17, Fabrication of Piping Systems Turbine Generator Plant

2.2.3 Specification No. MM92-250, Rev. 2, Insulations (Thermal/Acoustic) (Con Edison Class A and Non-Class)

2.2.4 Entergy Specification No. IPEC-SPEC-04-00015, Rev. 0, Unit 2 Station Blackout (SBO) and Appendix R Medium Voltage Switchgear and 13.8 kV-6.9 kV Dry Type Transformer

2.2.5 Specification No. IPEC-SPEC -FP-1200, Rev. 0, Emergency Generator Room High Pressure Carbon Dioxide (CO2) SystemIP2-RPT-03-00015, Rev. 3, IP2 Fire Hazards Analysis

2.2.6 Cummins Metropower, Inc, Technical Data Package #1, 2700 DQLA GENSET 2.2.7 Cummins Metropower, Inc, Technical Data Package, MCC Switchboard & DG

Breaker Switchgear 2.2.8 Atlas Industrial Manufacturing Co., Tube/Shell Type Heat Exchanger

Specification Sheets for SBO/App R DG Jacket Water and Aftercooler HXs 2.2.9 Cummins Metropower, Inc, Technical Data Package #4, Day Tank 2.2.10 Calculation IP-CALC-04-01577, Rev. 0, Tornado Missile Shielding Design at

Diesel Generator Radiator and Diesel Generator Exhaust PipeCalculation IP-CALC-06-00263, Rev. 0, Evaluation of Unit 2 Appendix R Diesel Generator Exhaust Pipe For Tornado Wind and Missile

2.2.11 ELMP-2005-011, Electrical Load Review, IP2 Appendix R Diesel Generator 2.2.12 Calculation IP-CALC-04-4-015791579, Rev. 0, SBO and Appendix R Diesel

Generator Support and Piping SupportSBO and Appendix R Diesel Generator Support and Piping Support

2.2.13 Calculation IP-CALC-04-01580, Rev. 01, Diesel Generator Exhaust Pipe Stress & Supports Design Analysis

2.2.14 (Not Used) 2.2.15 Calculation IP-CALC-04-01582, Rev. 0, SBO/App. R DG Project – Cable Sizing

Calculation








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2.2.16 Calculation IP-CALC-04-01583, Rev. 1, IP2 SBO Appendix R DG - Pressure Drop in DG Exhaust Piping

2.2.17 Calculation IP-CALC-04-01584, Rev. 1, IP2 SBO Appendix R DG - Pressure Drop in the Engine Cooling Water Piping

2.2.18 Calculation IP-CALC-04-01585, Rev. 0, IP2 SBO Appendix R DG - Pressure Drop in the Fuel Oil Transfer/Return Piping

2.2.19 Report #27604-017-07.001, Rev 2, Calculation IP-CALC-06-(later), Rev. 0, IP2 SBStudy of SBO/Appendix R Diesel Generator Room Temperature DistributionDetermination of DG Set Ventilation Requirements (WGI Report)

2.2.20 IP2 Design Basis Document, Seismic Structures and Devices, Rev. 0, July, 1999 2.2.21 Calculation IP-CALC-054-00127, Rev. 1, HVAC Duct Sizing and Pressure Loss

Calculation 2.2.22 Drawing A218100, Rev. 8, Standard Hanger Details Suitable for Tubing 2.2.23 Drawing B228410, Rev. 3, Standard Hanger Details Suitable for Tubing 2.2.24 Code of Federal Regulation 10 CFR 50.2, 10 CFR 50.48 and 10 CFR 50.63 2.2.25 Appendix R to 10 CFR 50 2.2.26 Regulatory Guide 1.155, dated August 1988 2.2.27 Entergy Procedure 2- AOP-SSD-1 2.2.28 Entergy Procedure AOI-27.1.9.2 2.2.29 NUMARC 87-00, Appendix B 2.2.30 Entergy Quality Assurance Program Manual QAPM 2.2.31 Unit 2 UFSAR, Rev. 18 2.2.32 Unit 2 Technical Specifications, Amendment Nos. 236 and 239 2.2.33 Unit 3 Technical Requirements Manual 2.2.34 Electrical Installation Standards:

2.2.34.1 ENN-EE-S-005-IP 2.2.34.2 ENN-EE-S-006-IP 2.2.34.3 ENN-EE-S-007-IP 2.2.34.4 ENN-EE-S-008-IP

2.2.35 Calculation FEX-00160-02, Rev. 02, IP2 Evaluation of Alternate Safe Shutdown Power Supplies

2.2.36 Engineering Report IP3-RPT-ED-00922, Rev. 3P, Appendix ‘R’ Diesel Generator System Evaluation

2.2.37 Calculation FEX-00101-01, Rev. 01, 13.8kV & 6.9kV Cable Ampacity for Primary and Ssecondary Leads of the New GT-1 Transformer

2.2.38 Calculation FEX-00102-00, Rev. 0, 6.9kV Cable Ampacity from Splice Box 4A thru Splice Box 4B to 6.9kV Switchgear

2.2.39 Calculation FEX-00201-00, Rev. 0, IP1 Voltage Profile for Battery 11 and 12 2.2.40 Calculation FEX-00138-00, Rev. 0, IP1 Battery #11 Sizing Calculation 2.2.41 Unit 2 IPEEE, Individual Plant Examination for External Events 2.2.42 0-RES-400 GEN, Hilti and Drillco Anchor Bolt Installation 2.2.43 0-SYS-401-GEN, Application of Protective Coatings 2.2.44 Drawing A182100, All Stations Hanger Assemblies 2.2.45 Drawing A182101, All Stations Miscellaneous Steel for Standard Hanger

Assemblies 2.2.46 ENN-DC-3000, General Welding Procedure – ASME/ANSI/USAS Code

Welding 2.2.47 ENN-DC-3001, General Welding Procedure – AWS Code Welding 2.2.48 ENN-NDE-10.08, Visual Examination of Welds 2.2.49 ENN-NDE-9.40, Liquid Penetrant Examination 2.2.50 EN-DC-167, Revision 0, Classification of Structures, Systems, and

Components 2.2.51 Calculation IP-CALC-04-01589, Revision 0, IP2 Load Flow Analysis of the

Electrical Distribution System Supplied from the 13.8kV Distribution System




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2.2.52 Calculation IP3-CALC-07-00168, Revision 0, IP2-Evaluation of Supports for Jacket Water and Aftercooler Cooling Water Tanks for App “R” Diesel

2.2.53 IP2-CYW DBD, Rev. 1, Design Basis Document for City Water System 2.2.54 IP2-SW DBD, Rev. 2, Design Basis Document for Service Water System 2.2.55 Piping Specification MP 5323-1, Rev. 12/72 2.2.56 2-COL-24.1.1, Rev. 41, Service Water and Closed Cooling Water Systems 2.2.57 IP-CALC-07-00072, Rev. 0, Containment Habitability for an Appendix R Fire

Scenario 2.2.58 Calculation FMX-00227, Rev. 1, Pipeflow Calculation of the Service Water

System 2.2.59 DE-S-12.809 Setpoint Device Data Form for M147-LAS (Existing) 2.2.60 Calculation FEX-00143, Revision 1, IP2 Load Flow Analysis of the Electrical

Distribution System 2.2.61 Calculation SGX-00017, Revision 1, Non-Safety Related 480V MCC

Coordination Calculation For MCC’s 21, 22, 23, 25, 25A, 28, 28A, 210 & 211 2.2.62 Entergy Specification 9321-01-248-35, Rev. 6A, Service Water Piping 2.2.63 0-VLV-435-CWS, Rev. 0, Annual Preventative Maintenance Testing and

Replacement of Backflow Preventers

2.3 Affected Equipment List (AEL)

The following table identifies the major new equipment which is to be installed. Complete component list is provided in Attachment 9.2.10, Component Classification Document. Equipment Location ID Component Name ActionARDG, ARDG-SIL

SBO/App R Diesel Generator, with silencer and exhaust piping

To be installed

ARDG-JWHX, ARDG-ACHX DG Jacket Water and Aftercooler Heat Exchangers and City and Service Water supply and return piping

To be installed

ARDG-CPNL, ARDG-BATT-1, ARDG-BATT-2, ARDG-BATTCHG/EGF1

DG local control panel, batteries, and battery charger

To be installed

ARDG-FODT Fuel oil day tank, with attached level control panel

To be installed

ARDG-JWST, ARDG-ACST Jacket Water and Aftercooler Surge Tanks

To be installed

EDK41, ARDG-OPNL DG output 13.8 KV switchgear unit with DG Operator Panel

To be installed

SBO/AR Interfacing 13.8KV/6.9KV switchgear

To be installed

SBO/APP R DG MCC DG Auxiliaries Motor Control Center

To be installed

ARDG-REF DG Area Ventilation fan To be installed 3.0 Evaluation/Design Summary

3.1 Evaluation Resolution

The resolution of the gas turbine reliability and maintenance issues is to replace the three Gas Turbines (GT-1, GT-2, and GT-3) with a single Diesel Generator Set with large enough capacity to provide power for the essential electrical loads


of 59 EC5000033794 ECN 5980


to recover from an SBO/Appendix R event. This EC Response addresses installation of the Diesel Generator and supporting systems. Retirement of the Gas Turbines will be addressed in a future EC Response. Before the GT’s are retired, a transition plan will be developed to establish the reliability parameter for the new diesel generator. The GT’s will not be retired until the new diesel generator achieves the required ies the reliability criteria of 0.95 per demand for Standby Systems, as defined in NUMARC 87-00, Appendix B.. The proposed plan is one monitored DG start per week for 20 weeks with 19 successful starts achieving the required reliability criteria of 0.95. The proposed Diesel Generator Set is a Cummins Power Generation Model 2700DQLA, which has been developed based on a design of proven performance and reliability. The SBO/App. R DG will be included in the IPEC Diesel Generator Reliability Program (PFM-57), for monitoring its reliability.

3.2 Design Bases Discussion

Unit 2 Station Blackout and Appendix R Alternate Safe Shutdown (ASS) capabilities are currently provided by one of three available Gas Turbine Generators, should the Emergency Diesel Generators be unavailable to perform these functions. GT-1 is located at IP2, and GT-2 and GT-3 are located near the Buchanan Substation. This arrangement provides adequate spatial separation to insure a reliable power supply in the case of a tornado, or other high wind events. The newreplacement Diesel Generator will be located in an open floor space in the Unit 1 Turbine Building at elevation 33’-0”, under a section of the Unit 1 turbine pedestal. Fire detection and a limited area fire sprinkler system will be provided. The Diesel Generator will be provided with a 8” high curb to contain any loss of contained engine fluids. The DG and additional electrical distribution function are not within any fire area that requires the ASS diesel. The Unit 1 Turbine Building is designed for 200 mph winds per IP2 Individual Plant Examination for External Events, Table 6.2-2. This arrangement justifies the replacement of the three Gas Turbines with a single Diesel Generator set since it provides protection from natural phenomena including tornado winds and potential missiles, although they are not part of the plant licensing basis., and potential tornado missiles. The diesel generator skid, fuel oil day tank, switchgear and associated electrical components are located in an area which is protected by a minimum of two building walls and/or floors, which provide protection from tornado missiles, including the effects of spalling from a missile hitting an exterior masonry wall. The DG exhaust pipe discharge (approx. 4 foot section extending beyond the TB exterior wall) is the only auxiliary component required for operation of the diesel generator, which is located outside the turbine building area. This section of the exhaust pipe, however, is designed to withstand tornado wind and missile loads.which i The Diesel Generator fuel oil supply will be the GT-1 North & South Fuel Oil Storage Tanks, using the fuel forwarding pumps, and are protected by the Turbine Hall structure as well. The equipment, design, procurement, manufacturing, construction, and installation activities associated with the Station Blackout and Appendix R Diesel Generator Set Project are non-safety related, non Class A and non-seismic Category. The diesel generator set was purchased under QA Category “Unit 2 – Class FP” (QP per Reference 2.2.49). An augmented QA program was applied








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for the remainder of the work per the requirements of Entergy’s QA Program. Per Regulatory Guide 1.155 (8/1988), Appendix B, and 10 CFR 50 Appendix R, single failure and redundancy are not required to be considered. Piping is designed to 1998 ASME B31.1 Power Piping Code. Piping supports are designed to ASME B31.1 Power Piping Code, 1998 and AISC Manual of Steel Construction 9th edition, 1989. Building steel is designed to AISC Manual of Steel Construction 9th edition, 1989. Wind and seismic design loads are based on 1997 uniform building code. Ventilation ductwork is to be fabricated and installed to ASHRAE and SMACNA – High Velocity Systems, both latest revisions. Civil The civil installation of the diesel generator will involve four major activities as follows: 1. The support of the diesel generator will be set on ten spring isolators which

are to be mounted on the floor at Elevation 33’-4” on the mezzanine level of the Unit 1 turbine generator pedestal. The installation is shown on modification drawing 400864EC5000033794. The original floor slab at Elevation 33’-0” is topped with an additional four inches of concrete. A steel baseplate will be installed with two drilled in concrete anchors at each isolator location. The bottom portion of the isolator will be welded to the baseplate. The isolators have adjustment nuts for leveling.

2. The electrical and other equipment at or near the generator will be mounted directly

on the concrete floor at Elevation 33’-4”. The load capacity of the existing floor has been reviewed and the weight of the added equipment is within the capacity of the floor. No changes are required to the floor to support the new equipment. Post-installed anchors (drilled in anchors) will be required to anchor the new equipment to the concrete floor.

3. The DG exhaust pipe location in the Unit 1 turbine building is subject to a

median wind capacity of 200 mph per the Indian Point 2 Individual Plant Examination for External Events (Reference 2.2.41, Table 6.2-2). The exhaust pipe configuration is such that the portion adjacent to the brick wall on the west side, has the highest probability of a direct hit, while the rest of the piping will be shielded by the existing physical structure and equipment inside the building. The diesel generator exhaust pipe design maintains the present core damage frequency (CDF) driven by external events, the tornado event being the most critical, as analyzed by IP-CALC-06-00263 (Reference 2.2.10).

4. The piping for the diesel generator set includes coolant piping to and

from the diesel and an exhaust pipe which will be supported from existing steel above at Elevation 53’-0”, and on new steel added above Elevation 53’-0”. The pipe support drawings show the attachments to existing steel, and the structural drawings show the new steel to be installed.

Pipe supports are designed to AISC Manual of Steel Construction, 9th edition, 1989. Rigging plan documentation for transporting and setting the diesel generator on elevation 33’-4” was developed (Ref ECR#1787) and approved prior to installation implementation.



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An (approximate) 8” high (cinder block) curb will be provided around the perimeter of the DG set, and a (poured concrete) curb provided around the 3 ft x 9 ft floor opening adjacent to the DG set for the containment of equipment contained fluids in the event of an equipment leak. The DG control panel will be mounted on a pad, elevating it at least 8” off the floor elevation. Electrical The new Diesel Generator Set is manufactured by Cummins Power Generation, with a rating of 2435 kW at 0.8pf (Prime Rating), 2700 kW at 0.8pf (Standby Rating), 13.8kV, 3 Phase, 60 Hertz, 1800 RPM, for operation on diesel fuel. Prime rating is defined as the maximum power available at a variable load for an unlimited number of hours with a 10% overload capability available for limited time. Standby rating is defined as supplying emergency power for the duration of normal power interruption; no sustained overload capability is available for this rating. The one line configuration of this new DG is depicted on modification drawing 250907-ECN 4444 and the physical location of the new DG and all electrical distribution equipments added by this EC Response are shown on modification drawing 400853-ECN 44444278. The output of the generator is connected to SBO/APP. R 13.8kV Switchgear bus via circuit breaker SBO/ASS, located at DG Breaker Switchgear. The SBO/APP. R 13.8kV Switchgear section has two feeder circuit breakers, ASS and SBOH. The ASS breaker feeds the existing Unit No. 1, 13.8kV L&P Bus Section 3 in order to provide power to Unit No.2 Alternate Safe Shutdown System loads. The SBOH breaker feeds a 13.8kV - 6.9kV, 3750 kVA, delta (primary) – wye grounded (secondary) transformer SBO that in turn feeds the 6.9kV section of the SBO/APP Switchgear via SBOL circuit breaker. The 6.9kV section of the SBO/APP. R Switchgear has one additional 6.9kV circuit breaker OSPPS that is fed from existing Gas Turbine 1 auto-transformer AT-1. The load side buses of breakers SBOL and OSPPS are connected together and it feeds existing 6.9kV Switchgear buses 5 and 6 via breakers GT25 and GT26 respectively. During a SBO event, the new diesel generator will be connected to the existing 6.9kV Switchgear buses 5 and 6 via breakers SBO/ASS, SBOH, transformer SBO, breaker SBOL, and breakers GT25 and GT26. The 13.8kV circuit breakers labeled ASS and SBOH, the transformer SBO and the 6.9kV circuit breakers SBOL and OSPPS are in one switchgear line-up (SBO/APP. R Switchgear) and it is located immediately northeast of the DG set. The electrical auxiliary loads of the DG set and for the DG enclosure are fed from a newly added Motor Control Center (SBO/APP. R DG MCC), located immediately east of the DG set.outside of the east wall of the DG enclosure. This MCC is fed from a manual transfer switch, also located at the MCC. The manual transfer switch has one feed from existing Unit 2 MCC 22, and the other feed from a 13.8kV – 480/277V, 500 KVA transformer, which in turn is connected to the DG bus via a fused disconnect switch. During DG operation, all of the DG auxiliary loads and the DG enclosure auxiliary loads will be powered from the DG. When the DG is in standby mode, these auxiliaries will be powered from the Unit 2 MCC 22. The SBO/APP. R DG MCC one line diagram is depicted on modification drawing 400856EC50000337940049. The output of the generator is connected to the line sides of circuit breaker SBO/ASS and a 600 Amp Load Interrupting Switch (LIS). The LIS feeds a 500





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KVA, 13.8kV-480/277V transformer and this transformer in turn feeds the 400 Amp manual transfer switch at the SBO/APP. R DG MCC. The load side of the SBO/ASS circuit breaker is directly connected to the 13.8kV bus of the SBO/APP. R Switchgear. The SBO/ASS circuit breaker, the LIS and the 500 KVA transformer are in one switchgear line up identified as SBO/APP. R DG Switchgear. This switchgear is located east of the DG set, and d outside the east wall of the DG enclosure, north of the SBO/APP. R Switchgear. As indicated in Ssection 3.1, this DG replaces the existing gas turbines with respect to their functioning as Alternate AC (AAC) Source for coping with station blackout, and as an independent onsite power source for alternative shutdown capability. The list of electrical loads that are required to be operable for a SBO event or for alternative shutdown is not affected by this EC; this EC only replaces the source of power for these loads from the gas turbines to this newly added DG. The existing analyses and procedures that are now in effect to cope for a SBO event or for alternative shutdown will still remain valid except for the changes that are required to implement the replacement power source. The 2435kW (prime rating), 2700kW (standby rating) of the new DG is more than adequate to accommodate the listed loads. See Section 3.7, Margin Analysis – Electrical for a discussion of the required load versus DG rating for the ASSD and SBO scenarios. For an SBO event, the present electrical distribution system configuration is such that the SBO loads are powered via 6.9 kV Switchgear Buses 5 and 6 that in turn are fed from a gas turbine power source (GT-1) via gas turbine auto-transformer AT1. In the modified configuration, the 6.9 kV Switchgear Buses 5 and 6 will be powered from the DG via the SBO/APP. R switchgear. Since alternate offsite power is provided to 6.9 kV Switchgear Buses 5 and 6 via AT1 under normal plant operating conditions, AT1 will normally remain connected to the 6.9 kV Switchgear Buses 5 and 6. On the onset of an SBO event, AT1 will be isolated from the 6.9 kV Switchgear Buses 5 and 6 by opening circuit breaker OSPS, and these buses will be aligned to the SBO/APP. R DG power source. The DG will function as ‘Alternate ac source’ as defined in 10CFR50.2. The path of power supply to the actual SBO loads downstream of 6.9 kV Switchgear Buses 5 & 6 will remain the same and is not affected by this EC. In compliance with 10CFR50, Appendix R requirements, the plant relies upon Alternate Safe Shutdown System (ASSS) for a fire in the Unit 2 CCR or for a fire in any other Unit 2 area that renders normal controls or indications unreliable in the Control Room. The electrical loads that are part of the ASSS are fed from Unit 1, 440 V substation buses 12FD3 and 12RW3. These Unit 1 440 V buses are fed from Unit 1, 13.8 kV L&P Bus Section 3 which in turn is normally fed from the Buchanan 13.8 kV System. In order to comply with Section III.LIIIL of 10CFR50 Appendix R, the gas turbines and/or Unit 3 Appendix R DG function as ‘independent onsite power source’ if offsite power is not available. This EC Response replaces the gas turbine power source by the new SBO/APP. R DG. In the current electrical distribution system configuration, the L&P Bus Section 3 can be powered either from Gas Turbine 1 via L&P Bus Section 2, or from Gas Turbine 3 via L&P Bus Section 4. The necessary breaker alignment required to achieve this is addressed in Procedure 2-AOP-SSD-1, Attachment 6 [Reference. 2.2.27]. Additionally, the L&P Bus Section 3 can also be powered from Unit 3, Appendix R DG, and the necessary breaker alignment for this is addressed in Procedure AOI 27.1.9.2 [Referencef. 2.2.28]. In the modified electrical distribution system configuration, the L&P Bus Section 3 will be fed from the new SBO/APP. R DG via SBO/APP. R DG Switchgear and L&P Bus Section 3 via Breaker ASS and Breaker B3-3 (Ref. 250907-ECN 4444). Con Ed Breaker



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F3-3 must remain open while the SBO / App R DG is powering shutdown load via 13.8kV L&P Bus Section 3. Since the SBO / App R DG is connected to 13.8kV L&P Bus Section 3 via splice box 3A downstream of Breaker B3-3, this breaker must be closed while the SBO / App R DG is powering shutdown load via 13.8kV L&P Bus Section 3. Additionally, until Gas Turbine 3 has been permanently retired, its output Breaker BGT-3 must remain open while the SBO / App R DG is powering shutdown load via 13.8kV L&P Bus Section 3. Since the new DG is significantly smaller in load capacity than any of the GT’s, several Unit Substations will need to be isolated, during this alignment, either by opening the local disconnect switch associated with isolating the Unit Substation or by opening the individual load breakers on the Unit Substation. The affected Unit Substations are as follows: 13SA3, 102NS3 & TSC Unit Substation. This modified configuration adds no electrical distribution or I&C to fire areas dependent upon the ASSS. The path of power supply to actual ASSS loads downstream of L&P Bus Section 3 to Unit Substations 12FD3 and 12RW3 remains the same and is not affected by this EC.

SBO/APP. R DG as Alternate AC Source: The SBO/APP. R DG will be the Alternate AC (AAC) source for complying with the requirements of 10CFR50.63. As defined in 10CFR50.2, an AAC source needs to comply with the following requirements. 1. Is connectable to but not normally connected to the offsite or onsite

emergency ac power systems; 2. Has minimum potential for common mode failure with offsite power or the

onsite emergency ac power sources;

3. Is available within one hourin a timely manner after the onset of station blackout; and

4. Has sufficient capacity and reliability for operation of all systems required for

coping with station blackout and for the time required to bring and maintain the plant in safe shutdown (non-design basis accident).

The guidelines for meeting the above requirements are provided in Regulatory Guide 1.155, Appendices A and B, and NUMARC 87-00, Appendix B. There is some overlap in the guidelines between the RG 1.155 and NUMARC 87-00. Table 1 in RG 1.155 provides a cross-reference to NUMARC 87-00 and notes where the regulatory guide takes precedence. The design, installation and operation of the SBO/APP. R DG added by this EC will comply with the requirements provided in Appendices A and B to RG 1.155. Appendix A to RG 1.155 pertains to quality assurance guidance for non-safety systems and equipment. Specific QA guidance are provided in ten subject areas, e.g. Design Control and Procurement Document Control; Control of Purchased Material Equipment and Services; Inspection; Testing and Test Control; etc. This EC Response and the equipment being added by this EC are designated as Quality Class QP, Augmented Quality Related as defined in the Entergy Quality Assurance Program Manual (QAPM). The quality assurance requirements for “Quality Class QP” systems, components and activities are provided in the QAPM and they conform to the requirements delineated in Appendix A to RG 1.155.



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For AAC source, twelve specific requirements are listed in Appendix B to RG 1.155, “Guidance Regarding System and Station Equipment Specifications”. The design bases for installation and operation of the SBO/APP. R DG conform to these requirements as described below: (1) Safety-Related equipment Guidance – Not required, but the existing Class 1E electrical systems must

continue to meet all applicable safety-related criteria. Design Basis – The SBO/APP. R DG and all associated equipment added

by this EC response are not designated as safety-related equipment, which is acceptable according to this guidance. None of the existing Class 1E electrical systems is modified by this EC Response and they will continue to meet all applicable safety-related criteria.

(2) Redundancy Guidance – Not required. Design Basis – Redundancy is not provided for the SBO/APP. R DG and

all associated equipment added by this EC, which is acceptable according to this guidance.

(3) Diversity from Existing EDG’s Guidance – Refer to Regulatory position 3.3.5 of this guide (RG 1.155). Regulatory Position 3.3.5 states the following design criteria:

1. The AAC power source should not normally be directly connected to the preferred or the blacked-out unit’s onsite emergency ac power system.

2. There should be a minimum potential for common cause failure with the preferred or the blacked-out unit’s onsite emergency ac power sources. No single point vulnerability should exist whereby a weather-related event or single active failure could disable any portion of the blacked-out unit’s onsite emergency ac power sources or the preferred power sources and simultaneously fail the AAC power source.

3. The AAC power source should be available in a timely manner after the onset of station blackout and have provisions to be manually connected to one or all of the redundant safety buses as required. The time required for making this equipment available should not be more than 1 hour as demonstrated by test. If the AAC power source can be demonstrated by test to be available to power the shutdown buses within 10 minutes of the onset of station blackout, no coping analysis is required.

4. The AAC power source should have sufficient capacity to operate the systems necessary for coping with a station blackout for the time required to bring and maintain the plant in safe shutdown.

5. The AAC power system should be inspected, maintained, and tested

periodically to demonstrate operability and reliability. The reliability of the AAC power system should meet or exceed 95 percent as determined in accordance with NSAC-108 or equivalent methodology. The existing (IP3) Diesel Generator Reliability Program, PFM-57, is based on the aforementioned guidance documents, and will be expanded to include the IP2 SBO/APP. R DG.

An AAC power source serving a multiple-unit site where onsite emergency power sources are not shared between units should have, as a minimum,









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the capacity and capability for coping with station blackout in any of the units.

Design Basis – 1. As indicated in the guidance, the SBO/APP. R DG is not normally

directly connected to the preferred or the onsite emergency ac power system. Under normal plant operating condition, the DG is not operating and it is isolated from the plant electrical distribution system by keeping the circuit breaker SBO/ASS open.

2. The Unit No.2 SBO/APP. R DG, and its auxiliary equipment and circuits are physically separated and electrically isolated from the Unit 2’s preferred and onsite emergency power sources and there is no potential for common cause failure. All equipment of the AAC power source are located indoors and thereby protected from any weather related events. All outdoor equipment has been designed to withstand maximum credible tornado event. In addition, no single active failure will disable onsite emergency power sources or offsite preferred power sources and cause simultaneously failure of the SBO/App R DG, since this new AAC source is physically separated and electrically isolated from both preferred sources and onsite emergency power sources.

3. The SBO/APP. R DG will be manually started from a local operating station and connected to the shutdown buses by appropriate breaker alignment within one hour after the onset of station blackout. For the breakers being added by this EC, the required alignment would be, breakers OSP and ASS open and breakers SBO/ASS, SBOH and SBOL closed. The required breaker alignment downstream of breaker SBOL to shutdown buses remains the same and is not impacted by this EC response. The time required to start the SBO/APP. R DG and perform all necessary breaker alignment will be demonstrated by test to be less than one hour.

4. The SBO/APP. R DG has a prime rating of 2435kW and a standby rating of 2,700 kW at 0.8 power factor. This is significantly larger than the existing EDG ratings of 1,700 kW continuous, 1,950 kW for two hours out of the last 24 hours, 2100kW for 2 hours and 2300kW for ½ hour. Since per Section 8.1.1.2 of the UFSAR only one EDG is required to provide power to Unit 2 shutdown loads, the SBO/APP. R DG has sufficient capacity for all of the required shutdown loads.

5. Once a month the SBO/APP. R DG will be started and brought to operating condition that is consistent with its operating functions as AAC power source. Once every refueling outage, a timed start and rated load capacity test will be performed. Inspection, surveillance test, and operating procedures will be developed for the SBO/APP. R DG. Reliability will be maintained at greater than 95 percent as determined in accordance with NSAC-108 or equivalent methodology.

At IPEC, Unit 2 and Unit 3 have dedicated onsite emergency AC power sources and they are not shared between units. The SBO/APP. R DG being added by this EC Response is primarily designed to be the AAC power source for Unit 2, in full compliance with RG 1.155 guidance. However, the electrical distribution system configuration has been designed such that, the Unit 2 AAC power source can be used as a backup to the Unit 3 AAC power source for Unit 3 station blackout events. Similarly, the Unit 3 AAC power source can be a backup to Unit 2 AAC power source for Unit 2 station blackout events. This backup function of Unit 2 and Unit 3 AAC power sources is not a regulatory requirement, and


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as such full compliance to RG 1.155 is not required. In the backup configuration, some segment of the power circuit would remain vulnerable to weather related events. In addition, the capacity and capability of the AAC power sources to shutdown the other Unit require additional analysis. This backup function at both Units will only be implemented if the analysis proves the capability and capacity of each units DG’s to power the respective SBO loads.

(4) Independence from Existing Safety-Related Systems

Guidance – Required if connected to Class 1E buses. Separation to be provided by two circuit breakers in series (1 Class 1E at the Class 1E bus and 1 non-Class 1E).

Design Basis – The Unit 2 Class 1E safety buses are at 480 V level and

the SBO/APP. R DG is at 13.8 kV level. The SBO/APP. R DG gets connected to the Class 1E safety buses via two step-down transformers, two 13.8 kV non-Class 1E circuit breakers, three 6.9 kV non-Class 1E circuit breakers and one Class 1E 480 V circuit breaker, all of the transformers and breakers are in series.

(5) Seismic Qualification

Guidance – Not required. Design Basis – The SBO/APP. R DG power source is not seismically

qualified. (6) Environmental Consideration

Guidance – If normal cooling is lost, needed for station blackout event only and not for design basis accident (DBA) conditions. Procedures should be in place to effect the actions necessary to maintain acceptable environmental conditions for the required equipment. See Regulatory Position 3.2.4.

Design Basis – The equipment that are part of the SBO/APP. R DG power

source are located at elevation 33’ of Unit 1 Turbine Building, below a section of the Unit 1 turbine pedestal. The diesel-generator set, DG control panel, batteries and charger, fuel oil pumps and day tank, the 13.8 kV SBO/APP. R DG Switchgear, 13.8/6.9 kV SBO/APP. R switchgear, 480 V SBO/APP. R MCC, DG set area ventilation fan is located between the DG set and the loading well to the north. The DG jacket water and aftercooler heat exchangers are all located in the same immediate vicinity. The SBO/APP. R DG is in standby mode during normal plant operation. All electrical distribution equipment and the alternator are provided with space heaters, powered from normal plant power source, in order to inhibit any potential condensation that can degrade the system. During a SBO event when the SBO/APP. R DG will be functional, the design basis maximum ambient DG air intake temperature is 122oF (50°C) and all equipment is capable of operating satisfactorily at this temperature. The DG auxiliary loads that are required for DG operation will be powered from the DG source by manually transferring the power source from normal plant power to DG power. The equipment t inin the immediate area of the DG set has been designed for a maximum ambient of 104oF (40°C). , which is higher than the normal expected temperature in these areas during a SBO event. The DG area ventilation fan has been sized to maintain the temperature at the DG











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air intake and at the surrounding electrical equipment locations within the design maximum ambient temperatures of 122oF (50°C) and 104oF (40°C), respectively (Ref(Refeerence 2.2.19).

(7) Capacity Guidance – Specified in 10 CFR 50. §50.63 and Regulatory Position 3.3.5.

Design Basis – Please see earlier Design Basis discussion in paragraph (3).4.

(8) Quality Assurance Guidance – Indicated in Regulatory Position 3.5.

Regulatory Position 3.5 invokes Appendix A to RG 1.155 for QA requirements applicable to non-safety related systems and equipment.

Design Basis – Appendix A to RG 1.155 pertains to quality assurance guidance for non-safety systems and equipment. Specific QA guidance are provided in ten subject areas, e.g. Design Control and Procurement Document Control; Control of Purchased Material Equipment and Services; Inspection; Testing and Test Control; etc. This EC Response and the equipment being added by this EC are designated as Quality Class QP, Augmented Quality Related as defined in EN-DC-167, Revision 0. The quality assurance requirements for “Quality Class QP” systems, components and activities conform to the requirements delineated in Appendix A to RG 1.155.

(9) Technical Specification for Maintenance, Limiting Condition, FSAR, etc. Guidance – Should be consistent with the Interim Commission Policy Statement on Technical Specifications (Federal Registerrar Notice 52 FR 3789) as applicable.

Design Basis – At present, IP2 Technical Specifications do not include any operability requirement for the existing gas turbines. Since the SBO/APP. R DG functionally replaces the gas turbines, no operability requirement for the SBO/APP. R DG needs to be included in the IP2 Technical Specifications. However, operability requirements will be incorporated into the IP2 Technical Requirements Manual (TRM). The 13.8 kV feeder circuits from Buchanan substation (feeder 13W92, preferred for Unit 2 and backup for Unit 3; and feeder 13W93 backup for Unit 2 and preferred for Unit 3) along with associated 13.8/6.9 kV auto-transformer are one of the two qualified off-site power circuits for Unit 2. Operability and surveillance requirement for this off-site power circuit are mandated in the IP2 Technical Specifications. For IP2, this off-site power circuit is connected to 6.9 kV buses 5 and 6 via 6.9 kV circuit breakers GT25 and GT26 respectively. Technical Specifications surveillance requirements assure appropriate breaker lineup for this 13.8 kV off-site power circuit. As part of this EC Response, two 6.9 kV power circuit breakers (breaker SBOL and OSP) are being added that would become associated with the 13.8 kV off-site power circuit. During normal plant operation, breaker SBOL should remain open in order to isolate the SBO/APP. R DG from the 13.8 kV off-site power circuit; and breaker OSP should remain closed in order to connect the 13.8 kV off-site power circuit to 6.9 kV buses 5 and 6. These two circuit breakers do not have any




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control or indication in the CCR and these two breakers would become part of the breaker alignment verification required by SR 3.8.1.1. As stated in UFSAR Ssection 8.1.2.1, the existing gas turbine power sources and systems have been evaluated as meeting the requirements of 10 CFR 50.63. This evaluation is supported by the reference documents 3 through 9, shown in references for Section 8.1 in the UFSAR. This EC Response installs the SBO/APP. R DG as the AAC source for SBO event and will ultimately replace the gas turbines. The evaluation referred by the UFSAR will be amended to reflect this change of AAC source.

(10) Instrumentation and Monitoring Guidance – Must meet system functional requirements.

Design Basis – The functional requirement for the SBO/APP. R DG as AAC power source is that it should be capable of operating during and after a station blackout without offsite or Class 1E power. Instrumentation and monitoring of the SBO/APP. R DG is considered a support function for the system functional requirement. Necessary instrumentation and monitoring provisions have been provided to assure satisfactory operation of the SBO/APP. R DG. Please see Instrumentation and Control Section for additional design basis discussion.

(11) Single Failure Guidance – Not required.

Design Basis – Single failure criteria is not considered for the SBO/APP. R DG.

(12) Common Cause Failure (CCF) Guidance – Design should, to the extent practicable, minimize CCF between safety-related and non-safety related systems.

Design Basis – There is littleno potential for common cause failure of the SBO/APP. R DG with the IP2 safety-related and non-safety related systems. This is ensured e potential is minimized by the following features: 1. Operation of the SBO/APP. R DG is independent of any Unit 2 safety-

related or non-safety related systems. The dc power required to start and provide pre-lubrication to the SBO/APP. R DG is provided from a dedicated battery system, which is completely independent from the Unit 2 dc power system. The dc power required for breaker operation is provided from Unit 1 125 V DC Power System, independent from any Unit 2 system. In the event of loss of 125 V DC power, local manual operation of the SBO / App R DG switchgear can be performed. This is an existing credited response per Appendix R criteria for a loss of DC power event.

2. The fuel oil supply for the SBO/APP. R DG is physically separate from

the emergency diesel generator supply. The fuel oil storage for the emergency diesel generators is in three underground tanks on the east side of the Diesel Building. The fuel oil storage for the SBO/APP. R DG is in an above ground tank in the Unit 1 area.


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3. The SBO/APP. R DG power source is an independent power source from the emergency diesel generators, thereby eliminating the potential for common mode failures between the SBO/APP. R DG and emergency AC diesels. The EDG’s and SBO / App. R DG were built by different manufacturers (ALCO and Cummins respectively) and therefore common mode failures associated with manufacturing processes are virtually eliminated.

4. There is no single point vulnerability where a likely weather-related

event or single active failure would disable the SBO/APP. R DG and the emergency ac or the preferred power sources simultaneously. This is accomplished by physical separation of equipment and multiple paths for routing the power.

SBO/APP. R DG as Independent Onsite Power Source for the ASSS: As indicated in Ssection 3.1, this SBO/APP.R DG replaces the existing gas turbines with respect to their functioning as an Independent Onsite Power Source for alternative shutdown capability. 10 CFR 50, Appendix R, Sections III.L.4 and III.L.5 mandates an Independent Onsite Power System for functioning of equipment and systems required for alternative shutdown capability, where such equipment and system will not be capable of being powered by both onsite and offsite electric power systems because of fire damage. The SBO/APP. R DG would be the power source for the Independent Onsite Power System. Hence, functioning of the SBO/APP. R DG must not be affected by any postulated fire for which ASS System is required. The SBO/APP. R DG and all part of the electrical distribution system being added by this EC Response and that will be required for ASSS loads, are located in Unit 1 area and will not be affected by a postulated fire for which the ASSS System will be required. Design Bases for the SBO/APP. R DG Electrical Distribution System: The SBO/APP. R DG set, including all auxiliaries, and DG switchgear and motor control center have been procured by Entergy equipment specification IP2-SPEC-04-00003 (Ref.erence 2.2.1). The essential ratings for the DG and its auxiliary equipment are provided in the equipment specification. The SBO/APP. R 13.8kV and 6.9kV Switchgear, and the 13.8 kV-6.9 kV SBO Transformer have been procured by Entergy equipment specification IPEC-SPEC-04-00015 (Reference. 2.2.4). The essential ratings for this equipment are provided in the equipment specification. Calculation IP-CALC-04-01582 (Reference. 2.2.15) was performed to determine the power cable sizes for the cables added by this EC. Acceptability of the electrical distribution system (comprising new and existing equipment) with respect to load flow, voltage drop, short circuit and protective device coordination for both steady state and motor starting conditions has been verified by calculation FEX-00160-02 (Reference. 2.2.35) and Engineering Report IP3-RPT-ED-00922 (Reference. 2.2.36). Reference 2.2.35 evaluates the acceptability of the Unit 2 SBO/APP. R DG and the associated electrical distribution system for Unit 2 Alternative Safe Shutdown System loads. As indicated earlier, provision has been made to utilize the Unit 2 SBO/APP. R DG as a back-up power source for Unit 3 ASSS loads; acceptability of the associated electrical distribution


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system for such scenario has been evaluated in Reference 2.2.36 and found to be acceptable. The 125V dc loads added by this EC Response to Unit 1 125VDC Distribution System and battery are summarized in Attachment 9.2.9 to this EC. Calculations FEX-00201-00 and FEX-00138-00 (References 2.2.39 and 2.2.40) have been reviewed with respect to this additional dc loads and it has been determined that this additional load would have minimal impact on the Unit #1 125VDC system. However, these calculations need to be updated to include these additional loads. The 480V DG auxiliaryies and DG Enclosure auxiliary loads are powered from the new SBO/APP. R DG MCC added by this EC Response. The new 120 VAC auxiliary support loads, e.g. DG area lighting, equipment space heaters, etc. are also powered from the SBO/APP. R DG MCC via a 15 kVA , 480-120/208VAC transformer and a 120/208VAC distribution panel. The SBO/APP. R DG MCC can be connected to the DG power supply via 13.8 kV-480VAC transformer or to Unit #2 MCC 22 via a manual transfer switch. The SBO/APP. R DG MCC will be connected to MCC 22 when the DG is in standby mode, and it will be connected to the DG power source when the DG is operating. Per calculation IP-CALC-04-01582, section 7.2.1 (Ref.erence 2.2.15), the estimated maximum load current for the SBO/APP. R DG MCC is 93 Amp at 460VAC when the DG is operating or 39.8 Amp at 460VAC when DG is in standby mode. Since MCC 22 provides the power to the DG auxiliaries during both the standby and operating mode (during testing), the overall load change impact on MCC 22 has been evaluated. Reference 2.2.59 is the load study of record for IP2’s electrical distribution system. The worse case existing operating load on MCC 22 occurs during normal power operation with minimum grid at approximately 136.0kV. Table 8.1-4 in Reference 2.2.59 gives an overall load for MCC 22 as 182.6kVA at 425.1VAC or 248 amps. The DG auxiliaries’ load of 93 amps at 460VAC is equivalent to approximately 101 amps at 425.1VAC. Therefore the total load on MCC 22 during its worse case operating condition, including the DG auxiliary load, becomes approximately 349 amps at 425.1VAC. This worse case load is within the capacity of the 600A continuous bus rating of MCC 22, the rating of the new 250MCM feeder cable from MCC 22 to the DG MCC and the associated incoming 750MCM feeder cable from 480V Safeguards Bus 3A. Reference 2.2.61 is the coordination study for IP2’s non-safety MCC’s including MCC 22. Based on this study, Attachment 2B, Breaker 52/MCC2 feeding MCC 22 has a long time pick-up setting of 470A and therefore the total load of 349 amps will not cause the breaker to trip. Since Revision 1 of this nuclear change increases the size of the DG area ventilation fan from 30HP to 40 HP, the 50A trip unit needs to be replaced with a 70A rated unit. This change affects the cable size for the fan and the cable has been evaluated in Reference 2.2.15. See BM Item 97 on Drawing 400856-ECN 4444. The 200A fuses to be added in MCC22 Compartment 4M feeding the DG auxiliary MCC are Ferraz-Shawmut Type AJT200. These fuses must coordinate with the upstream and downstream protective devices, which include the 480V Safeguards Bus 3A MCC 22 feeder breaker 52/MCC2 and the individual load protective devices on the DG MCC. The time-current characteristics of the 200 amp AJT200 fuses were checked against the 52/MCC2 feeder breaker time current coordination plot in Attachment 2B of Reference 2.2.61. The 200 amp fuses coordinate properly with the upstream MCC 22 feeder breaker according to the criteria set in IP2 Specification EI-2028, Revision 1, Protective Settings and Coordination Criteria IP2. The largest protective device on the DG MCC is the 70 amp molded case circuit


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breaker (MCCB) protecting the DG area ventilation fan. This MCCB is a Siemens Type ED 70 amp breaker. This device presents the worse case coordination condition to the upstream 200A fuses. The time-current characteristics of this MCCB were checked against the 52/MCC2 feeder breaker time current coordination plot in Attachment 2B of Reference 2.2.61 and the 200 amp AJT200 fuses. The MCCB properly coordinates with the upstream 200 amp AJT200 fuses. All remaining devices on the DG MCC have lower pickup settings and properly coordinate with the 200 amp AJT200 fuses. The applicable affected calculations for MCC 22 have been included in Section 2.2.1 of this EC and will be formally updated to reflect this additional load during EC closeout.

Note: Modifications to MCC 22 cannot be implemented while the plant is on line as it feeds equipment that is required for continued plant operation. In the interim temporary 480V power may be utilized for testing the DG auxiliaries. Duraline unit EPY22 that is located on the Turbine operating deck (EL-55’-0” column 4A) may be used for this purpose. A single 3-phase temporary 100-amp 480V feed from the Duraline Distribution center and connected to the SBO/App.R DG MCC should provide adequate testing capacity. The feed shall be 4C#2 Awg cable type (XX) and shall be routed exposed by the field in accordance with the requirements of Maintenance Procedure 2-SYS-001 ELC Rev.2.

Emergency Lighting: During SBO conditions the SBO/Appendix R DG will be cooled by City Water however if the City Water inventory is not adequately maintained it may be necessary to switch over to the Service Water system. Sufficient illumination will be required for access/egress and to perform the actions required to achieve the necessary valve alignment. The valves involved with line up to the Service Water System are indicated in the Mechanical section of this Design Basis discussion. The access/egress paths and associated valves are shown on drawings 400418-ECN4596, 400422-ECN4596 and 400423-ECN4596 along with the associated eight hour Appendix R rated Emergency Battery Light (EBL) unit. In addition other EBLs are required to provide access/egress and area lighting to the DG area and for access/egress to open louvers and doors for ventilation purposes. These EBLs are also listed on drawing 400428-ECN4596. The EBLs shall be installed in accordance with the Engineering Standard for Lighting Systems ENN-EE-S-001-1P rev.1 and as shown on the drawings 400854-ECN-4444, 5000033794-138313, 5000033794-138367, 138312-ECN-4596, 9321-3022-ECN-4596 and 9321-3023-ECN-4596 Instrumentation and Control The diesel engine, generator, and its output breaker are controlled from a Cummins-supplied Operator Panel located on the Cummins DG Control Panel. The Operator Panel interfaces with the DG and its breaker via a Cummins-supplied Control Panel located near the DG set. DG speed, field flashing, breaker position, and synchronizing actions are controlled, indicated, and alarmed at the Operator panel. Upon any alarm condition at the DG Control Panel, a common alarm is actuated in the Central Control Room at Instrument Flight Panel Common Section 1FAF. The DG is manually started and is manually connected to load busses. When shutting down, the DG can be



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paralleled to site busses, in order to lower the DG load, trip the DG output breaker, and shutdown the DG. New 13.8 kV breakers ASS and SBOH are controlled manually from the front of the switchgear. The ASS breaker trips remotely when relay MC-3A (mounted on the door of Unit 3-4 of the L&P switchgear) activates. The ASS breaker cannot be reclosed until the relay is reset. New 6.9 kV breakers OSP and SBOL are controlled manually from the front of the switchgear. The SBOL breaker will trip remotely when the Auto Transformer (AT-1) Differential Protection Lockout Relay (LOR) activates. The SBOL breaker cannot be reclosed until the LOR is reset. For all breakers, control power is derived from 125 VDC Distribution Panel #1 (Node EPG13). Breaker position is indicated locally only. Thermostatically activated space heaters maintain a moisture free environment inside the switchgear. Space heaters are 120 VAC and powered from a new DG Auxiliaries MCC. A new DG Auxiliaries MCC is provided by Cummins. The MCC is powered by the DG output while the DG is running or by MCC #22 when the DG is not running. Selection of power source is via a manual transfer switch located on the front of the new MCC. The new MCC provides power for all DG auxiliaries, DG ventilation fan and lighting. Each motor starter on the MCC is provided with a HAND-OFF-AUTO control switch. Fuel Oil Pump #2 (FOP-12) is powered from the new MCC and is dedicated to the new DG. Fuel Oil Pump #1 (FOP-11) can provide fuel oil to either the new DG or to GT-1. Power for Fuel Oil Pump #1(FOP-11) is taken from the new DG while the pump is supplying the new DG Day Tank, or is taken from the Turbine Auxiliary MCC in the GT Building while the pump is supplying the GT. Selection of power source for Pump #1(FOP-11) is via a manual transfer switch located in the Fuel Oil Pump Room. When the MCC control switches are in AUTO, the start signal(s) for the fuel oil pumps (for supplying the new DG) come from the new DG Day Tank level control system, located on the Day Tank. The control circuit for Fuel Oil Pump #1 (FOP-11) transfer pump, while supplying the GT, is not modified by this EC. The Day Tank level control system is a flexible system providing assignment of “primary” and “secondary” roles to the physical fuel oil pumps. Local indication of level and tank status is available at the local control system on the tank. Normally, FO Pump #2 (FOP-12) operation alone is sufficient to maintain the tank full. Day Tank level controls, indications and alarms are fully described in the PRYCO literature. The Day Tank fuel oil cooler fan cycles on and off based upon the temperature of the returning fuel oil from the DG. When in AUTO, the DG area ventilation fan is energized when the “switched B+” inside the DG Control Panel is energized during a DG manual start and run. Upon DG shutdown, the area ventilation fan de-energizes. If it is desired to operate the area ventilation fan longer to remove excess heat from the area the fan can be operated in manual using the HAND-OFF-AUTO control switch from its MCC compartment. The ventilation fan will also cycle on with the increasing temperature at the setpoint (>98 °F Adjustable) of the DG area thermostat. Upon DG shutdown, the switched B+ is maintained for 30 seconds.





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Associated setpoint information will be generated for entry into the equipment database for the following devices: TE-8027 App R DG Fuel Oil Return to Day Tank Oil Cooler Temp

Sensor FC-8026-1 App R DG Fuel Oil Supply FOP-11 Flow Switch FC-8026-2 App R DG Fuel Oil Supply FOP-12 Flow Switch LC-8026 App R DG Jacket Water Surge Tank Low Level Switch LC-8027 App R DG A/C Cooling Water Surge Tank Low Level Switch TS-7982 App R DG Area Thermostat SBO/ASS 50/51 (Ph A, B &C) and 51G relays SBOL 50/51 (Ph. A, B & C) and 51N relays SBOH 50/51 (Ph. A, B & C) and 50G/51G relays ASS 50/51 (Ph. A, B & C) and 50G/51G relays OSP 50/51 (Ph. A, B & C) and 50G/51G relays City Water Storage Tank Low Level Alarm Set Point Change

As discussed in the Mechanical section of this EC, a total of 655,000 gallons of water in the City Water Storage Tank needs to be protected to ensure availability for SBO and Appendix R events. In order to protect the required minimum 655,000 gallons of water, the City Water Storage Tank low level alarm set point will be raised from 16.0 ft. above tank bottom, to 22.5 ft. above tank bottom. The new set point of 22.5 ft. above tank bottom is based on the following: Each 1 inch of tank height is equivalent to 3134 gallons of water. In order to ensure that a minimum of 655,000 gallons of water is available, 209 in. (approximately 17.4 feet) of usable tank water is required. The bottom 33 inches of water in the tank is considered as unusable because of the following:

1) The tank discharge line is 8 inches from the bottom of the tank. 2) The tank discharge line is 16 inches in diameter. 3) To account for possible vortexing, the 9 inches of tank water

above the top of the tank discharge line is considered unusable, based on engineering judgment.

To account for instrument uncertainty, an additional 28 inches (2.33 ft.) of tank water level is added, based on engineering judgment. Therefore, the new City Water Storage Tank Low Level Set Point will be 270 inches (22.5 ft.) nominal. For calibration of City Water Storage Tank Low Level Alarm Switch M147-LAS, the following information is provided:

• Tank height = 42 ft. – 0 inches. • Device input (to M147-LAS) = 0 - 16.5 psig. • 1 in. of tank height = 3134 gallons. • 1 psig = 27.06799 inches of water. • The centerline (zero pressure reference) of the low level alarm

switch is 4 ft. above the bottom of the tank. • The bottom 33 inches of the tank is unusable volume, as described

above.





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• The as-left tolerance of the low level alarm switch is +/- 1 % of operating range (1 – 35 psig), or +/- 0.34 psig. This corresponds to +/- 0.8 ft. of water.

• The as-found tolerance shall be 1.5X the as-left tolerance, or +/- 1.2 ft. of water, based on engineering judgment.

• City Water Storage Tank Low Level Alarm Switch M147-LAS shall be set to open (to initiate alarm) at 270 inches (22.5 ft.) above tank bottom, or 8.20 psig, decreasing.

• City Water Storage Tank Low Level Alarm Switch M147-LAS resets (clear alarm) at 337.63 inches (28.14 ft.) above tank bottom, or 10.70 psig increasing. (Reset is 2.5 psig above set point).

The specific set point data information, including calibration ranges, and as-found and as-left tolerances, are shown on the Set Point Data Information Forms, Attachment 9.1.7 to this EC. Existing Equipment Database and Set Point Information records in IAS PASSPORT were the references used to obtain existing set point and instrument technical information described above. Mechanical DG Engine Cooling Diesel engine cooling is provided by tube and shell type heat exchangers located adjacent to the DG set. A heat exchanger is provided for each of the two engine coolant circuits (jacket water and aftercooler). Each engine cooling circuit has an expansion tank equipped with a 7 psi pressure cap. There are no atmospheric vents on the tanks. The engine coolant fluid is a 50/50 mix of water and propylene glycol. Two sets of supply and return coolant piping are provided between the diesel engine and the heat exchangers. Per calculation IP-CALC-04-01584 (Ref. 2.2.17), the 6“ jacket water cooling loop and the 4“ aftercooler cooling loop are each sized to satisfy the Cummins criteria for maximum allowable system friction head, 10 and 7 psi respectively. Appropriate drain, vent and fill connections are provided. All piping within 7 feet of the floor is to be insulated with 1-½” hydrous calcium silicate, in accordance with Specification No. MM92-250, for Class B-2 insulation. The diesel engine is supplied with separate vent connections at the high points of the jacket water and aftercooler circuits. Although normally filled with coolant, these lines provide venting back to the elevated expansion tanks adjacent to the DG engine. The ¼” vent connections are connected to ½” pipe by flexible hose at both the engine and expansion tank. All coolant piping is carbon steel in accordance with Entergy Specification No. 9321-01-248-18 (Reference. 2.2.2), Class J-1 (as modified). Pipe supports for the 6” and 4” coolant piping are per modification drawings 400899EC5000033794 through 400915EC5000033794 and 501292EC5000033794 through 501297EC5000033794.

Cooling for the engine jacket water and after cooler systems will be accomplished via two water cooled heat exchangers, one for each service. Engine coolant for the jacket water and after cooler will be piped to the shell side of each respective heat exchanger. Tube side cooling water for both heat exchangers will be supplied from two sources. Potable water supplied from the City Water Storage Tank (CWST) and river water supplied from the Service Water System. The CWST supply is a gravity supply system and will provide a supply pressure equal to the static head at the heat exchangers, or approximately 30-40 psig.


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For a SBO event, the CWST will provide the cooling water for the entire 8 hour coping duration. For an Appendix R event, the CWST will provide the cooling water for initial DG engine cooling. As required by the App R analysis, the Service Water System needs to be aligned and an App R DG powered service water pump (either 23 or 24) started at approximately 75 minutes from the initiation of the event. Once the SWP is started and the service water system is aligned (at approx. 4 hours after initiation of the event), and if required, the service cooling to the DG HXs can be put into service and the CWST supply isolated. Thereafter, the tube side cooling water for both heat exchangers would be supplied from the Unit 2 Service Water Pump. The total cooling water flow requirement for the DG heat exchangers is 205 gpm city water, and 325 gpm for service water, due to the higher SW inlet water temperature (95 °F v. 75 °F for city water). Cooling to the Appendix R diesel generator is transferred from the city water system to the service water system, as required, based on available CWST inventory. Use of service water to cool the Appendix R diesel requires installation of a new 4” crosstie between the service water system and the 4” city water supply line to the diesel coolers. The cross-tie will be manually placed in service approximately 2 hours into the event when one service water pump has started, establishing cooling to a FCU and the CCWHXs. The crosstie will be made in the IP1 River Water system at the 12” blind flange downstream of locked closed valve RW-109 (elevation 25’-3”) and connected to the 4” city water supply line to the Appendix R coolers on elevation 33’. Service water can then be supplied to the diesel generators using the 10” intertie between IP1 (RW-109) and IP2 (SWT-527). The physical connection to the IP1 River Water system is shown on drawing 138105EC5000033794. The cross-tie will be equipped with a manual isolation valve at the connection to the service water system and a manual isolation valve and check valve at the connection to the diesel generator heat exchanger cooling line. The design pipe specification for the cross-tie is in accordance with MP 5323-1 Part DH-2 that has a design pressure rating of 150 psig. The portion of the new service water supply that will be remain filled with service water will be fabricated with 6% molybdenum stainless steel, a superior corrosion resistant material for Hudson River stagnant/low flow conditions. The required actions to place the service water cross-tie in service will be delineated in the new App R DG operating procedure. During an Appendix R event, one service water pump is required to supply 2000 gpm to 22FCU to support containment entry approximately 8 hours into the event (IP-CALC-07-00072). At approximately 28 hours into the event, containment entry is no longer required and 22FCU is removed from service and RHR is initiated. This requires 6070 gpm service water flow to the CCW heat exchangers with spent fuel pool cooling in service (CN-SEE-03-5). During this event the essential and non-essential headers are cross connected so that 22FCU and the CCW heat exchangers can be supplied by one pump. All other loads on the selected header are isolated, as required to achieve the above flow distributions. Review of service water hydraulic calculation FMX-00227 (Rev. 1), Case 3V shows that the flow and pressure from one service water pump is more than adequate to supply 6070 gpm flow to the CCW heat exchangers and 325 gpm to the Appendix R diesel assuming that all loads not required for


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the event are isolated. Case 3V models the recirculation phase of SI with 6435 gpm to the CCW heat exchangers and blowdown flow to all three service water pump strainers. The flow velocities in the piping to the Appendix R diesel coolers are fairly low at 325 gpm, therefore the pressure drop from the service water header to the Appendix R diesel is within the capacity of one service water pump. The Operator will be required to throttle the flow to the CCW heat exchangers and the Appendix R diesel to protect the pump from runout. In order to supply cooling water to the Appendix R diesel (325gpm) and the CCW heat exchanger (~6000gpm) during plant cool down, the operating service water pump must be aligned to the turbine building header by opening SWT-837 and either FCV-1111 or FCV-1112 and isolating major flow paths on the 16” service water turbine building supply header to prevent pump run-out. This would be accomplished by closing normally open valves SWT-658, SWT-23, SWT-19, SWT-19-1, SWT-685, SWT-688, and SWN-4 & SWN-7 or SWN-5 & SWN-6 depending on which service water pump, 23 or 24 is in service. Valves SWT-634, SWT-24, SWT-618, SWT-619, SWT-636, and RW-109 on the header that are normally closed would remain closed in the Appendix R alignment. During the summer months when the plant is on a three header operation, normally open valves – SWT-5, SWT-16, SWT-16-1 and SWT-636 must be closed. To ensure adequate flow to the CCW heat exchangers and the Appendix R coolers, the strainer blowdown valves for the two non operating pumps on the operating SW header must also be isolated. The IP1 to IP2 inter-tie valve SWT-527 would remain an open valve to align service water and/or river water to the 4” Appendix R cooling water line. In order to ensure continuous flow to the diesel coolers, cooling water from the city water supply line should not be isolated until service water has been aligned and flow to the coolers has been verified. Since service water operates at a higher pressure than city water, the higher operating pressure of the service water system will cause the double check valve (backflow preventer, UW-846) in the city water supply line to close so that flow will be directed to the diesel coolers while the city water supply line is being isolated. The installed backflow preventer will be tested to verify its function by a contractor licensed to perform backflow preventer testing, and subject to annual preventive maintenance testing (Ref. 0-VLV-435-CWS). Emergency lighting will be provided to the valves that need to be manipulated during SBO/APP.R conditions. The discussion above for the plant cool down represents the worse case flow conditions for any one of the two operating service water pumps. Plant cool down is initiated well into the event; therefore, not all valves discussed above require emergency lighting. After the service water pump is place in service, flow could be supplied to one FCU (2000gpm) and the CCW heat exchangers. The only load on the CCW heat exchanger at this time would be for cooling one charging pump. Under these conditions, emergency lights would be needed to operate SWN-6, SWN-7, FCV-1111, FCV-1112, SWT-23, SWT-685, SWT-688, SWT-837, SWT-5 and SWT-636 for three header operation.

Procedure 2-AOP-SSD-1, “Control Room Inaccessibility Safe Shutdown Control” will require revision to include the required Operator actions, including the required timeframe, to establish DG engine cooling from the city water and service water systems.


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Based on 205 gpm city water flow required, the total CWST water volume used to cool the APP R DG in a SBO event is approximately 100,000 gallons. During an App R event, the volume of water used from the CWST to cool the APP R DG will be approximately 50,000 gallons. In order to protect this water volume, the low level alarm (M147-LAS) set point for the CWST should be revised. The App R scenario is the bounding event for defining the maximum volume of water that must be protected in the CWST. The following tabulation of protected volumes was used to establish the new low water level alarm set point.

Scenario Volume (gallons) Basis

Fire Fighting 300,000 2500 gpm for 2 hours**Alternate Safe Shutdown

215,000 App R Cool down*

Alternate CCW cooling

30,000 125 gpm for 4 hours

Coincident users 60,000 500 gpm for 2 hours**App R DG 50,000 205 gpm for 4 hours***

TOTAL 655,000 References: * IP-CALC-05-01034 Rev. 1 ** Appendix R Analysis *** Appendix R time line for starting a Service Water Pump Due to the infrequent operation of the SBO/App R DG, and aggressive corrosive nature of brackish river water, if the DG is operated with service water cooling to the heat exchangers, system restoration should include isolation of service water cooling and flushing the heat exchangers with city water for a minimum of 5 minutes. DG Exhaust Pipe The diesel exhaust is routed from the engine toward the west wall of the Unit 1 Turbine Building at approximately elevation 45’–9”, where it transitions to a vertical run and continues inside the Turbine Building and upward through the elevation 53’ floor, before exiting the Turbine Building at elevation 79’-113”. The exhaust piping from El. 53’” to its discharge outside of the Turbine Building is designed for tornado winds and missiles loads. Per Calculation IP-CALC-064-002631583 (Reference. 2.2.106), exhaust piping is sized at 20” upstream and downstream of the silencer; the exhaust pipe section above elevation 53’ has increased wall thickness to Schedule 60 to withstand tornado and missile loads. The diesel engine is designed with two 12” exhaust connections, one for each bank of cylinders, which are combined in a fabricated “Y” section into a common 20” pipe. This results in a total backpressure for the exhaust system of 0.824 psi (22.84” H2O), which is less than 90% of the maximum allowable backpressure of 0.974 psi (27” H2O), as specified by Cummins (Reference. 2.2.6). The 90% criteria is per Entergy Specification No. IP2-SPEC-04-00003 (Reference. 2.2.1). All values include losses through the exhaust silencer. Low point drains are provided as appropriate. All exhaust piping is carbon steel in accordance with Entergy Specification No. 9321-01-248-18 (Reference. 2.2.2), Class D-8 (as modified, which will be modified to reflect the acceptability of the increased wall thickness to Schedule 60 for portions designed for tornado missile and wind loads. The exhaust piping has been stress analyzed to ensure that























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all stresses are within ANSI B31.1 allowables, as documented in Calculation IP-CALC-04-1580 (Reference 2.2.. 13). Pipe supports are per modification drawings 400888EC5000033794 through 400896EC5000033796 and 400898EC5000033794 DRN-06-03427 and DRN-06-03429.All exhaust piping below the 53 ft. elevation, including the Silencer, shall be insulated with 4” hydrous calcium silicate, in accordance with Specification No. MM92-250, for Class A-4 insulation. Above the 53 ft. elevation, the 20” exhaust pipe will be insulated to a height of 8 ft. above the floor for personnel protection. DG Fuel Oil Supply Fuel oil is supplied to a new 800 gallon fuel oil day tank using the existing GT-1 fuel oil storage tanks (2 tanks, each having 30,000 gallon capacity) and pumps located at elevation 15’-0” of the House Boiler structure. The total fuel oil required for the 72 hour period of Appendix R DG operation is approx. 13,000 gallons. A new 1 inch pipe will connect to the existing system at each of the two 2 inch service connections immediately downstream of pumps GT1-FOP-11 and GT1-FOP-12, at valves GT1-GT25 and GT1-GT26. This arrangement allows the alignment of one pump for new DG service while the other pump is aligned to maintain fuel supply to the existing gas turbine GT-1. When GT-1 is retired from service, both pumps can be aligned for DG service without additional piping modifications. The new fuel oil supply piping will consist of a 2 inch mating flange and 2 inch check valve that reduces to 1 inch. The line is sized to provide approximately 20 gpm (1200 gph) flow to an 800 gallon double wall day tank located near the DG Set at elevation 33’-4”. Based on the existing transfer pumps’ performance curve, the pump developed head at 20 gpm is approximately equivalent to the pipe losses between the pumps and day tank, as documented in Calculation IP-CALC-04-1585 (Reference. 2.2.1818). This precludes the need for a self regulating flow or pressure control device in the supply line. Fine tuning of supply flow can be accomplished by adjusting a manual globe valve located at the day tank. The 20 gpm flow rate provides an initial fill rate for the day tank of approximately 40 minutes which is reasonable. When the engine is operating at its full rated capacity, fuel consumption is 172 gph (Reference 2.2.. 6). The operating range of the day tank between transfer pump “ON” and “100% Full” is 5.0 inches or approximately 90 gallons (Reference 2.2.. 9), which results in a pump operating time of 5 to 5-1/2 minutes to replenish the tank when the engine is operating. Day tank overflow protection is provided by a 2 inch gravity return line back to the main fuel oil storage tanks. Based on the elevation of the day tank overflow connection relative to the main storage tank inlet connection, the static head available is adequate to return fuel oil at a rate greater than 20 gpm, as documented in Calculation IP-CALC-04-1585. The return line ties unto the existing gas turbine fuel oil return line by installing a ‘tee’ near an existing union upstream of Return Selector Valve GT1-GT69. The 800 gallon day tank is fabricated from 12 gauge steel, is UL142 listed and designed with a 150% double wall containment with rupture alarm. A 2 inch tank vent and 2 inch containment vent are routed to the outside environment. A separate local emergency vent is also provided. Fuel oil supply and return piping between the day tank and diesel engine is sized at 1-1/2 inch and connects to flexible hose connections on the engine. Isolation valves are provided. Return piping is routed to a high efficiency heat exchanger, mounted on the day tank that lowers the temperature of unused fuel oil returned to the day tank from the engine. All fuel oil piping is carbon steel in accordance with Entergy Specification No. 9321-01-248-18 (Reference 2.2.. 2), Class N-1 (as modified). Pipe supports shall be per notes on modification drawing 400883EC5000033794.in accordance with Entergy Drawings A218100 and B228410 (Ref. 22 and 23).






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The fuel oil day tank level will normally be maintained above the fuel oil connection on the DG engine. The fuel oil supply connection on the day tank is top entry, with pipe stem extending to the bottom of the tank. The DG engine internal fuel pump is capable of initial system prime. Piping arrangements for the DG exhaust, coolant and fuel oil systems are shown on modification drawings 400883EC5000033794 through 400886EC5000033794, 400952EC5000033794, 138359EC5000033794 and 311804EC5000033794. The diesel engine lube oil system is designed by Cummins and is integral to the engine. During long term operation of the diesel during a (72 hour Appendix R event), lube oil inventory will require monitoring to ensure that sufficient lube oil is available. The lube oil consumption rate for the diesel engine running at standby power is approximately 0.2 gallons/hour based on Cummins data. The warrantable oil consumption level is .6 hours/quart (0.42 gallons/hour). An accessory lube oil level regulating system will be provided for automatic addition of lube oil as required to maintain oil level. Fire Detection and Suppression Fire suppression for the DG Set and Fuel Oil Day Tank area will be a limited area fire sprinkler system. The sprinkler system installation will be in accordance with NFPA-13. Local Carbon Dioxide type portable fire extinguishers will be furnished and installed in accordance with NFPA 10 for use on Class B and C fires. EEach extinguishers will be mounted on columns in locations near the DG set and the SBO/App R switchgear.located inside a surface mounted cabinet. The fire sprinkler piping arrangement and extinguisher locations are shown on modification drawings 138001EC5000033794, 227552EC5000033794, 227553EC5000033794, 251571EC5000033794 and 400952EC5000033794. The limited area sprinkler system acts automatically upon fire detection to initiate a local alarm and activate fire suppression.

DG Set Area Ventilation DG set area ventilation Enclosure cooling will be provided by drawing ventilation air from the machine shop area at Elevation 15’-0”, directly below the DG set, and from the mezzanine area at Elevation 33’-0”. Both areas provide unrestricted airflow paths between the IP1 Turbine Building vent shaft and the DG engine air intakes. Additional cooling air is provided by opening the overhead (roll-up) door at Elevation 15’-0”, providing an air supply path through the EL. 33’-0” floor opening to the DG engine air intakes. Administrative procedures will be in place requiring that the overhead door and the mechanical dampers (three damper set directly west of the DG set, above MCC-10V) for the vent shaft be opened prior to starting the DG when the outdoor ambient temperature is above 32oF. The temperature of the DG engine area should be monitored during operation of the DG to ensure that the combustion air inlet temperature (DG engine intake air temperature) does not exceed 122oF. The air inlet from the machine shop will utilize an existing plugged 3’-0” x 9’-8” floor opening. This will require removing the existing 4” concrete plug slab covering the penetration, installing an approximate 86” high curb around the opening for spillage control, and covering the opening with a protective grating. The DG area ventilation system will include an axial ventilation fan (75,000 CFM, 40 HP), and sufficient ducting to remove the hot air in the DG engine overhead area, and discharge it at a point near the IP2 south loading well.




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This arrangement ensures that the air at the DG engine air intakes and at electrical components will remain below their rated temperature limits (i.e., 122oF at the DG engine air intakes, and 104oF for electrical components that support both DG operation and other plant functions). The DG ventilation fan will automatically start when the DG is running.G; setpoint (TBD).

3.3 Design Input Considerations Major design considerations are addressed in Section 3.2, as allowed by the ENN-DC-115 revision in effect at the date of original issue. A Design Input Record has been generated to capture the design input considerations for Revision 1 to the modification package.

3.4 Discussion of Impact Screening Results

A detailed impact screening review was performed and is attached to EC5000033794 Attributes. A summary review has also been included. Because of the large scope of this project, this EC impacts all four design engineering disciplines, including PSA / Safety Analysis Engineering and Piping Design Engineering. Impacted DE programs include: Cable and Raceway Program because of the extensive cable and raceway network being added by this EC; Electronic Databases because of the new components and setpoint changes and additions; Human factors because of the new DG control panels and switchgear; and Margin Management because of the reduced capacity of the DG set versus any one of the existing gas turbines. All of the Maintenance disciplines are impacted because of the large scope of this project involving PM procedure changes with the new components added including the DG Set, heat exchangers, ventilation fan and motor, large transformers, DG Set control and monitoring instruments. Operations is impacted because of the required operating procedure changes, PS&O because of the significant manpower and time resources needed to install the DG Set and Procurement because of the large array of materials needed including cable, conduit, pipe, supports, etc.

3.43.5 Relationship with Other Engineering Changes

ER-04-2-095 is the Revision 0 record of this EC. ER-04-2-095 is stored in Merlin for information.

3.6 Operating Experience Search Results INPO OE database was searched for OE relevant to diesel generator design. OE relevant to diesel generators primarily involved maintenance and periodic testing issues. The following design related OE was reviewed and found to be applicable to this design modification. SOER 03-1 Emergency Power Reliability This SOER is a summary of OE related to diesel generator failures due to design vulnerabilities related to common mode failures, modification process deficiencies, and inadequate post modification testing.




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Vulnerabilities related to common cause and common mode failures have been accounted for in the design. AC and DC power required to operate the Appendix R diesel is completely independent from any IP2 power system. The AC and DC power sources are completely independent of each other such that a weather-related event or single point vulnerability could not cause failure of both power sources. The Appendix R diesel has a dedicated fuel oil supply system with two 100% capacity tanks and pumps and is independent from any IP2 fuel oil supply system. The Entergy Nuclear modification process employs rigorous controls to ensure: the design change is reviewed by knowledgeable personnel, that plant design basis is maintained, equipment meets quality requirements for the system, affected documents are updated to reflect the design change, and that the modified component conforms to the design modification package. The Post-modification test plan verifies diesel generator operability under required conditions (fully loaded), adequately tests all sub-systems to ensure no hidden malfunctions, and incorporates manufacturer recommendations for starting, loading and engine break in. Further, the test verifies proper operation of protective relaying associated with the new 13.8kV Switchgear, 6.9kV Switchgear and 480V Motor Control Center as well as the protective device interface with the diesel generator tie-in to 13.8kV Light & Power Bus Section 4. SOER 02-1 Severe Weather The SOER involves addressing all credible severe weather conditions in the modification (flooding, heavy rain/snow, wind damage, fuel reserve, emergency lighting) Severe weather operation was accounted for and addressed in the modification. The diesel generator is located on 33’ elevation of the IP1 turbine building and is protected from severe weather including tornado winds and tornado missiles. Emergency lighting in the form of self-contained battery powered emergency lighting units have been provided at the key operating points for starting the diesel generator, monitoring its performance and connecting it, via the new switchgear assemblies, to the various loads required for safe plant shutdown. These units are tied to the normal power sources in the area such that a loss of the normal power source automatically energizes the associated emergency lighting unit. SOER 85-5 Internal Flooding of Power Plant Buildings This SOER involves flooding of components due to breaches of water systems connected to large water sources such as rivers and tanks. This will mostly affect equipment located below grade or in areas susceptible to flooding. The design process must therefore assess vulnerability due to internal plant flooding. The diesel generator is located on 33’ elevation of the Unit 1 turbine building. At this location the diesel generator is not in an area susceptible to flooding from storms or from the Hudson River. Internal flooding could occur due to a breach in city water piping located near the engine. An 8” high curb surrounds the diesel generator and associated equipment to contain leakage from the diesel generator. There is a 3’x 9’ floor opening


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within this area and all electrical equipment is mounted at least 8” above floor level. These design features are adequate to eliminate any flooding concerns. SOER 83-1 Diesel Generator Failures This SOER involves failure of emergency diesel generators during testing, corrosion of components, contactor and relay failures, and vibration related failures. The post mod test plan does not involve cold start tests with immediate loading to rated capacity, short runs or tests with no load. The diesel generator will have adequate pre-lubrication during testing. The engine has been shipped from the factory pre-loaded with the proper type and level of lubricating oil. The generator bearings have also been pre-greased at the factory and are ready for operation. The diesel generator is located inside the IP1 turbine building on elevation 33’. Although this area is normally dry, space heaters are provided for all electrical distribution equipment to prevent potential condensation that would degrade the equipment. The cabinets and compartments housing electrical components are designed for indoor use. All conduit openings into these compartments will be sealed to preclude the entrance of dust and moisture. Ventilation openings are provided in breaker and transformer compartments to maintain internal cabinet and compartment temperature as low as possible. The individual components (relays, breakers, etc.) are designed for the environment they are installed in and will be included in the preventative maintenance program to monitor their performance. The SOER also notes that designs should provide alarm indication to alert the operators of a problem with the diesel generator. Diesel generator speed, field flashing, breaker position, and synchronizing actions are alarmed at the operator panel. An alarm condition at the control panel would also alarm in the central control room to alert operators. The design modification includes adequate mounting and supports to account for vibration of piping and components due to diesel generator operation to minimize potential vibration related failures. The diesel generator is mounted on vibration isolators and flexible joints are used for all hard pipe connections to the diesel generator. SER 30-87 Emergency Diesel Generator Design Oversights This SER recommends that the diesel generator design consider the ability to load the generator under operating conditions where the diesel has been tripped (such as following a test) and is subsequently required to restart for emergency operation. This is not a concern for the Appendix R diesel generator since it is manually started and manually loaded. SER 48-83 Potential Problems with Emergency Diesel Generator Room Ventilation


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This SER involves a situation where the diesel generator heat load exceeded the ventilation system capability for operation at outside ambient temperatures above 88 F. The ventilation system for the diesel generator has been sized to maintain the temperature at the air intake to a maximum of 122 F and electrical equipment to a maximum of 104 F. SER 59-82 Diesel Generator Load Sequencer Design Deficiency This SER involves a sequencer timing out so that emergency loads would not be automatically added to the electrical bus supplied by the diesel generator. This is not a concern for the Appendix R diesel generator since it is manually started and manually loaded.

3.7 Margin Analysis

Electrical The SBO / App R DG Set will assume the functional role formerly performed by Gas Turbines GT1, GT2 and GT3 but at reduced capability. The gas turbines have nominal rated outputs between 19MVA, 16MW and 28.0MVA, 23MW, at 0.85pf. The SBO / App R DG Set nominal rated output is 3375kVA, 2700kW Continuous at 0.8pf. The SBO / App R DG Set was sized to be capable of powering the ASSD (Alternate Safe Shutdown) loading from 2-AOP-SSD-1, Attachment 28 or, a single train of safe shutdown (SSD) components on the 480VAC safeguards buses. References 2.2.35 and 2.2.50 provide load tables representing the various load configurations the SBO / App R DG Set will be required to provide power to. The basis for the selected 2700kW rating of the SBO / App R DG Set can be found in these tables. For ASSD loading, Attachment 28 from Reference 2.2.27 is the load list for the ASSD scenarios. All other extraneous loads will need to be electrically isolated, leaving only the minimum required alternate safe shutdown loads. Reference 2.2.35, the load study of record for IP2’s alternate power supplies, provides Load Tables 8.1.9 and 8.1.10, which are based on supplying ASSD loads from the SBO / App R DG Set. The worst case ASSD load is shown in Table 8.1.10 and is 1636kW, 870kVAR, and 1853kVA. This load table is the most representative of the load set that the SBO / App R DG Set would need to supply for ASSD scenarios, which includes its own auxiliary loads such as jacket water and lube oil cooling, fuel supply, ventilation and lighting and monitoring and control power. By comparison, the standby ratings of the SBO / App R DG Set are 2700kW, 2025kVAR, and 3375kVA and the prime ratings are 2435kW, 1825kVAR, and 3043kVA. For SSD loading, Reference 2.2.50, the load flow study of record for IP2’s electrical distribution system fed from the 13.8kV Distribution, lists the SSD loads in Table 8.1-1, which are based on use of the normal plant operating procedures during Hot Shutdown and Cold Shutdown operations. As mentioned above, the SBO / App R DG Set is capable of powering only one safeguards power train with only those loads necessary to bring the plant to Cold Shutdown during a SBO event with the SBO / App R DG Set as the only available AC power source. The worst case load is shown in this table for 480V Safeguards Bus 5A supplied from gas turbine GT-1 during normal operation and is 1611kW, 829kVAR, and 1812kVA. This load table is a


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typical representation of the load set that the SBO / App R DG Set would need to supply for SSD scenarios using a single safeguards power train. The load set includes the SBO / App R DG Set own auxiliary loads such as jacket water and lube oil cooling, fuel supply, ventilation and lighting and monitoring and control power. By comparison, the standby ratings of the SBO / App R DG Set are 2700kW, 2025kVAR, and 3375kVA and the prime ratings are 2435kW, 1825kVAR, and 3043kVA. Mechanical The use of the City Water Storage Tank as the initial (approx. first 2 hours of an App R scenario) source of DG engine cooling water will require a revision to the CWST low level alarm setpoint to protect the additional water inventory required for this service. The CWST has a nominal capacity of 1.5 million gallons, and the existing low level alarm (M147-LAS) setpoint protects the level required for emergency supply of water to the suction of the Auxiliary Feedwater Pumps for both Units 2 and 3. The higher protected tank level as a result of this modification will result in reduced city water inventory available for normal plant operation, and require revision to the M147-LAS setpoint and new procedural controls to implement.

4.0 Impact on Current Operational Basis

Five medium voltage circuit breakers (SBO/ASS, ASS, SBOH, SBOL and OSP) are being added by this EC Response. These breakers do not have any control or indication in the CCR and they are not located in vital areas. Except for breaker SBO/ASS, none of the other breakers have any synchronizing provision or block closing feature to a live bus. Therefore, an operating procedure will be required to define the exact sequence of breaker operation. Breakers SBO/ASS, ASS, SBOH and SBOL must remain open, and breaker OSP must remain closed during all modes of plant operation except when SBO/APP. R DG would be required to mitigate a SBO or Appendix R event or during test. For a SBO event, prior to closing breaker SBO/ASS, breaker OSP must be opened and breakers OSP and ASS must be kept open until DG is shutdown. These two breakers provide isolation from the 13.8kV offsite circuit and, in the SBO scenario, prevent the possibility of an out of synch trip should the 13.8kV system suddenly return. Additionally, since there is no synchronizing equipment on the Con Ed side of the system to IP2, the breakers allow the orderly shutdown of the diesel generator and return to offsite power. Similarly, for an Appendix R event, breaker ASS should be closed to dead L&P Bus Section 3 prior to closing breaker SBO/ASS, and breakers SBOH and SBOL should be kept open until DG is shutdown. During the quarterly routine load test, the breakers SBOH and SBOL should be kept open, close ASS breaker to live L&P Bus Section 3 and then synchronize the DG to live bus across breaker SBO/ASS. Con Ed Breaker F3-1 must remain open while the SBO / App R DG is powering shutdown load via 13.8kV L&P Bus Section 3. Since the SBO / App R DG is connected to 13.8kV L&P Bus Section 3 via splice box 3A downstream of Breaker B3-3, this breaker must be closed while the SBO / App R DG is powering shutdown load via 13.8kV L&P Bus Section 3. Procedure 2-AOP-SSD-1, “Control Room Inaccessibility Safe Shutdown Control” will require revision to include the required Operator actions, including the required timeframe, to establish DG engine cooling from the city water and service water systems.


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5.0 Engineering Instructions Necessary To Implement The Change 5.1 All work associated with this modification is located within and adjacent to the

Unit 1 Turbine Building and Superheater Buildings, the Terminal Board Room, and the Unit 2 Control Room. A plant outage is not required for the implementation of this modification. Tag out of existing plant electrical, control and mechanical systems and components will be required.

5.2 The steps presented below do not imply a specific installation sequence.

Sequence of installation is to be determined prior to implementation. Ensure that all applicable prerequisites and precautions are satisfied prior to start of work.

5.3 This modification will utilize existing components currently dedicated to Gas

Turbine GT-1. All work shall be scheduled and coordinated to minimize the impact on GT-1 operability.

5.4 There are no anticipated radiological impacts associated with this modification.

5.5 Installation details are provided on the following modification drawings for major

equipment. For additional drawing mark-ups see detailed paragraphs below:

• Civil 400858EC5000033794, 400859EC5000033794, 400860EC5000033794, 400861EC5000033794 and 400864EC5000033794

• Electrical 400853-ECN 4444, 0400854-ECN 4444

and& 400855-ECN 4444 04281

• I&C 400867EC5000033794, 400870-ECN4444, 400871-ECN4444, 400872EC5000033794, 400866EC5000033794, 400868-ECN4444, 400869-ECN4444

• Mechanical 400884EC5000033794, 400883EC5000033794, 400885EC5000033794, 400887EC5000033794, and 400886EC5000033794.

-• Supports 400883EC500003379, 400888EC5000033794 through 400896EC5000033796, 400898EC50000 through 400915EC5000033794, and and 501292EC5000033794 through 501297EC5000033794

5.6 The installation of the new equipment and components shall be performed in

accordance with the following manufacturer’s instructions: • Diesel Generator and accessories – Cummins Metropower, Inc.

(Accessories include the Power Command Control Panel, day tank and controls, starting system, switchgear, MCC, and associated circuit breakers.

• Medium Voltage Switchgear – Powell Electrical Manufacturing Co. • 13.8kV – 6.9kV Dry Type Transformer – Virginia Transformer Corp.












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5.7 Installer shall review the “Post Mod Test Plan Form," Attachment 9.4 of EN-DC-117 for inspection/tests that need to be accomplished & documented during the installation phase.

5.8 Scaffolding should not be removed without first confirming it is not needed for

possible post-test insulation installation, inspections, etc. Check with RFE, RE, QC, and Ops Test Group for their requirements prior to removal.

5.9 Welding to be performed per Entergy ENN Welding Procedures.

5.10 Follow applicable sections of Entergy Specification No. 9321-01-248-18, Rev. 16,

Fabrication of Piping Systems Turbine Generator Plant.

5.11 The work requires lifting and moving the diesel generator assembly from the loading Unit 1 laydown area on at Elevation 53’15’-0” to its permanent location, one level below.on El evation 33’-0” of the Unit 1 Turbine Building. The existing Unit 2 Turbine Building crane will be utilized for this work. Rigging documentation for transporting and setting the diesel generator on elevation 33’-4” (the DG set will sit on the existing 4” concrete pad) was developed (Ref. ECR #1787) and approved prior to installation implementation.

5.12 Ceiling mounted lighting fixtures that interfere with the installation of new

components or facilities shall be removed and reinstalled as close as practicable to the new installation.

5.13 All engine cooling piping to be insulated for personnel protection shall not

be insulated until satisfactory completion of in service leak testing. A ll engine coolant cooling water piping within 8 feet of the floor shall be insulated for personnel protection with 1-1/2” hydrous calcium silicate, in accordance with Specification No. MM92-250, for Class B-2 insulation. Insulation shall not be installed until satisfactory completion of system hydrostatic testing. 5.135.14 An

y existing facilities that have been retired in place and interfere with the installation of this modification shall be permanently removed and discarded.

5.145.15 Th

e fuel oil return line will be installed in existing piping in the GT-1 Pump Room as detailed in modification drawings 400884EC5000033794 and 400885EC5000033794. The new connection shall be located as close as practicable to the existing union. The piping system shall be drained and isolated prior to any work.

5.155.16 If

additional piping, conduits, instrumentation, etc. are not specifically covered by this package and are either disconnected, or impacted in any way during the field activities, notify the Planner and RFE for Work Order changes and potential additional post work testing. (Construction/Planning to identify known items requiring removal for inclusion prior to Mod issuance).

5.165.17 W

ork items which can be done before actual modifications begin include:






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- Engraving of a new annunciator window to be installed at window #15 in the Instrument Flight Panel Common Section 1FAF (CCR). (138669EC5000033794)

- Fabrication of a painted steel cover plate and engraving of a new nameplate for the Unit 1 CCR Instrument Cubicle (Excitation Light & Power Section) panel (DRN- 05-00627 and sketch Attachment 9.1.2)

- Engraving of new nameplates for Light & Power Section 1-2 (DRN- 04-04054)

- Engraving of new nameplate for Station Auxiliary MCC Compartment 4K in the Gas Turbine Bldg (CG52F447EC5000033794).

- Engraving of new service description nameplate(s) for MCC 22 compartment 4M. (9321-3179EC5000033794)

5.175.18 The DG is supplied by Cummins. Install the DG grounding in

accordance with 400854-ECN 4444.

5.185.19 The DG output switchgear is supplied by Cummins. The manufacturer is General Switchgear. Install the switchgear at the location shown on 400853-ECN 4444 in accordance with the instructions provided by the vendors.

Provide grounding for the switchgear in accordance with the 400854-ECN 4444.

5.195.20 The SBO/App R Switchgear is supplied by Powell. Install the switchgear

at the location shown on 400853-ECN 4444 in accordance with the instructions provided by the vendor. Provide grounding for the switchgear in accordance with the 400854-ECN 4444.

5.205.21 The SBO/App R DG Auxiliaries Motor Control Center is supplied by

Cummins. Install the MCC at the location shown on 400853EC5000033794 in accordance with the instructions provided by the vendor. Provide grounding for the MCC in accordance with the 400854EC5000033794.

5.215.22 The DG Control Panel is supplied by Cummins. Install the panel at the

location shown on 400853EC5000033794 in accordance with the instructions provided by the vendor. Provide grounding for the panel in accordance with the 400854-ECN 4444.

5.225.23 The DG batteries and battery charger are supplied by Cummins. Install

the batteries and charger at the locations shown on 400853-ECN 4444 in accordance with the instructions provided by the vendor. Provide grounding for the battery racks and charger in accordance with the 400854-ECN 4444.

5.235.24 At the Station Auxiliary MCC Compartment 4K in the Gas Turbine Bldg,

for Fuel Oil Transfer Pump #2, place the control switch to “OFF”. Open the breaker and padlock it open. Install new nameplates to indicate that the compartment is out of service. Note that the pump itself will remain in service, with a different power source. (CG52F447EC5000033794).

5.245.25 Determine the wiring changes required inside the Instrument Flight Panel

Common Section 1FAF (CCR) to activate the 1FAF window 15. Document the existing jumper configuration with respect to the design drawing. Reconfigure the jumpers at the annunciator terminal boards as required, and document the


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final jumper configuration. Install the newly engraved annunciator window at location #15 138669EC5000033794. Likewise, determine the wiring changes required inside the Annunciator Relay Cabinet in the Terminal Board Room to activate the 1FAF window 15. Make the required changes in jumpers and terminate the field cable. (138898EC5000033794)

5.255.26 Inside the Unit 1 CCR Instrument Cubicle (Excitation Light & Power

Section), disconnect the wiring for the G1-1 breaker control switch and its associated indicating lights. Tape off and spare the disconnected wiring in place. Remove the breaker control switch and its associated three indicating lights (DRN- 05-000629). Fabricate a steel plate of size adequate to cover the holes where the switch and lights were removed. Paint the plate to match the panel front color. Install the plate on the panel front. Engrave a new phenolic nameplate to interface to the front panel mimic. Install the new nameplate on the new cover plate. (DRN -05-000627 and sketch 9.1.2 attached).

5.265.27 Inside the Area Monitoring and Gas Turbine Supervisory Panel in the

CCR, disable the Gas Turbine Optrend computer terminal by disconnecting the fiber optic cable(s) and removing power to the terminal. The Gas Turbine Optrend computer terminal in the Gas Turbine Building shall remain operational. Add new jumper wires from spare TB R4 (terminals 9 – 12) to the Lockout Relay spare terminals. Terminate the field cable (138681EC5000033794, 2001MB1407EC5000033794).

5.275.28 Inside the Motor Control Center 22, compartment 4M, install the new

fused disconnect switch draw-out unit. See VND1975MD6114EC5000033794 for fused disconnect switch type, size and rating. Install new nameplate(s) identifying the service description for the compartment. Terminate the field cable (9321-3179EC5000033794).

5.285.29 Inside the L&P Unit 1 Section 1-2, make the following changes.

Remove control power fuses FU-2, FU-3, and FU-4. Remove breaker G1-1 and add power jumpers as indicated. See electrical drawings for power jumper conductor sizing. Disconnect G1-1 CT wires (drawing reference device location “ZB”) at terminal points A7, A9, C1, and DD6, and short them together, effectively shorting the G1-1 CT terminals 1, 2, 4, and 6. Tape off and support the jumper wires that were shorted together so that they cannot short to any panel steel, other terminals, or grounds. Add new jumper wires from the terminal points A7, A9, C1, and DD6 to terminal points CC1, CC3, CC2, and CC4 (respectively) (DRN 05-00648, DRN-05-00649) . Terminate the field cable (DRN- 04-04045, DRN-05-00637, DRN-05-00647, DRN-05-00642).

5.295.30 On the front of the L&P Section 1-2, modify the breaker G1-1

controls and nameplates. Remove the handles on the Local Remote switch (device 43, TS 201) and the breaker control switch (device 52CS, CS 201). Install new nameplates identifying switches as non-functional. Add new nameplate identifying incoming section from SBO / App R switchgear breaker ASS. (DRN- 04-04054, DRN-05-00648)

5.305.31 Termination of cables is performed in accordance with the wiring

drawings. Refer to the Cable Block Diagram 400855-ECN 4444 and the applicable documents identified in Table 1 below. NOTE: The existing 1500MCM PILC cables GT-514P, GT-518P & GT-515P & existing 2500MCM


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PILC cables GT-510P, GT-511P & GT-512P may be disturbed due to excessive bending when making re-connections to the new splices inside boxes 4A & 4B. The cable will be stiff. If the cable is bent so that the paper insulation tape has space between butt turns, then it is possible that when the cables are bent back, the cable insulation could be affected. Therefore, care must be taken when bending these cables to insure that a minimum bending radius of at least 12 times the cable OD is maintained. Since the 1500MCM cable has an OD of approximately 2300 MILS, the minimum bending radius should not be less than 28-inches, the 2500MCM cable has an OD of 3160 mils, the minimum bending radius should not be less than approximately 38-inches

Table 1: Cable Terminations:

Location Equipment Installation Documents Fuel oil pump room Fuel oil pumps, power transfer

switch, fuel oil flow switches 175814EC5000033794 400866-ECN4444 400869-ECN4444

Unit 1 Turbine Bldg roof, Elev. 3353’

DG jacket water tank level switch

400869- ECN4444

Unit 1 Turbine Bldg Elev 33’

DG local control panel 400868- ECN4444


DG batteries, and battery charger

400867EC5000033794


Diesel engine, alternator, and associated heaters

400867EC5000033794


Day tank, with attached level control panel

400869- ECN4444


DG output 13.8 KV switchgear unit with DG Operator Panel

400870E- ECN4444


Interfacing 13.8KV switchgear 400871- ECN4444


Interfacing 6.9KV switchgear 400872- ECN4444


DG Auxiliaries Motor Control Center

400866EC5000033794


DG Area Ventilation fan and thermostat

400869- ECN4444

Deleted Deleted DeletedTerminal Board Room

Auto transformer differential relay panel node EPK27

175814EC5000033794 400872EC5000033794


MCC 22 Compartment 4M 9321-3179EC5000033794

Terminal Board Room

Annunciator relay cabinet 138898EC5000033794

Central Control Room

Instrument Flight Panel Common Section 1FAF

138669EC5000033794


Area Monitoring and GT1 Supv panel

138681EC5000033794


Unit 1 CCR Instrument Cubicle

05-00629

Unit 1 MG Set room, Elev 33’

125 VDC Panel Board #1 138507EC5000033794


13.8 KV swgr, L&P Section 1-2 and 1-4

05-00637



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Location Equipment Installation Documents Unit 1 Turbine Bldg Elev. 33’

13.8 KV swgr, L&P Section 3-4

138925-ECN4444

5.32 Instruments requiring calibration:

a. TS-7982, Unit 1 Turbine Building SBO/App R DG Area Thermostat, is a White-Rodgers Model 201-16, line voltage heavy duty thermostat, switch closes on rising (cooling service), setpoint is screwdriver adjustable, range 35 to 110 °F, 120 VAC @ 25A.

b. PI-8030, SBO/App R DG Fuel Oil Transfer Pump Discharge Header

Pressure Indicator, is an Ashcroft/Dresser Model 35-1009-AW-02L-60 psig gauge, range 0-16 psig, operating pressure is 5-20 psig.

5.33 The CWST low level alarm set point will be changed from 16.0 feet from the

tank bottom, to 22.5 feet from the tank bottom. See the Set Point Data Information Form in the EC folder for details.

5.34 The check and relief valves installed by this modification will be evaluated

in accordance with Check Valve Maintenance and Monitoring Program, EN-DC-131, and the Relief Valve Program, EN-DC-314, respectively, for inclusion in to the check valve and relief valve programs.

5.35 The App R DG heat exchangers, by virtue of their fire mitigating support

function, and being cooled by service water will be included in the IPEC GL 89-13 Heat Exchanger Program and in the Balance of Plant Eddy Current Testing Program.

5.36 The Emergency Battery Lighting Units shall be installed in accordance with

the Engineering Standard for Lighting systems ENN-EE-S-001-IP Rev.1 and as indicated on drawings 138313, 9321-3022ECN 4596, 9321-3023 ECN-4596, 208671 ECN-4596 and 400428 ECN-4596.

6.0 Engineered Materials List and Vendor Technical Information Cummins Metropower, including its sub-suppliers, is the supplier for the Diesel Generator and all its auxiliary equipment. Powell Electrical Manufacturing Co. is the supplier of the SBO/App R switchgear.

Refer to the Electrical Bill of Materials Drawing 400856- ECN4444 for wiring, cables, and miscellaneous equipment not supplied by Cummins or Powell. See also Attachment 9.2.5.

Refer to Mechanical Bill of Materials 400956EC5000033794, Sheets 1 and 2.

7.0 Special Process Requirements

The installation Work Order(s) shall include steps to ensure that the job supervisor(s) fill out the Raceway Installation Ticket(s) and/or Cable Installation Ticket(s) after the installation of the raceway(s) and/or cable(s). The installation Work Orders shall also include instructions for the job supervisor to send a copy of the signed installation ticket(s) to the Responsible Engineer (RE) or Configuration Management supervisor for




of 59 EC5000033794 ECN 5980


ECRIS update. The signed original installation ticket(s) shall be maintained with the installation work package

8.0 Tests & Inspections

See Post Modification Test Plan Form, Attachment 9.4 of EN-DC-117 (Attachment 9.1.1 to this EC)

9.0 Attachments

9.1 Distributed for Fieldwork/Installation

9.1.1 EN-DC-117, Attachment 9.4, “Post Modification Test Plan Form”

9.1.2 Sketch for panel front modifications, Unit 1 CCR Instrument Cubicle

9.1.3 Entergy Specification No. 9321-01-248-18, Rev. 16, Fabrication of Piping Systems Turbine Generator Plant – Pipe Class Data Sheets for Class D-8, Class J-1 and Class N-1 (with revision markup)

9.1.4 (DELETEDot Used)

9.1.5 ECRIS Pull Tickets (DO NOT USE ER-04-2-095 REV. 0 TICKETS)

9.1.6 Modification Drawings listed in Section 2.1.1

9.1.7 CWST Low Level Alarm Setpoint Change Data Sheet

9.2 Not Distributed for Fieldwork

9.2.1 Process Applicability Determination Form, EN-LI-100, Attachment 9.1

9.2.2 50.59 Review Form, EN-LI-101, Attachment 9.1

9.2.3 Markup of Procedure 2-ARP 1FAF, Unit 1 Flight Panel

9.2.4 IT Pre-Approval Form & Software Catalog Form, ENN-IT-104, Attachment 9.1 and Attachment 9.2

9.2.5 Data Sheet for Fuel Oil Pressure Gauge

9.2.6 Data Sheet for DG Area Thermostat

9.2.7 Fire Protection Program Review Forms, EN-DC-128, Attachment 9.1, Attachment 9.2 and Attachment 9.3

9.2.8 Environmental Impact Review EN-EV-115 Attachment 9.1, Attachment 9.2 and Attachment 9.3

9.2.9 DC Loads Added to Unit 1 125V dc Distribution Panel No. 1

9.2.10 Component Classification Document for EC5000033794, Rev. 1

9.2.11 Electrical Separation Review Forms (Attachments 7.1 – 7.4)











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