ML081280491

Units 2 & 3, Amendment 4 to License Renewal Application (LRA)

ML081280491
Person / Time
Site:	Indian Point
Issue date:	04/30/2008
From:	Dacimo F Entergy Nuclear Northeast
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-08-074
Download: ML081280491 (47)

Text

SEn tergy Enter-qy Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB P.O. Box 249 Buchanan, NY 10511-0249 Tel (914) 788-2055 Fred Dacimo Vice President License Renewal April 30, 2008 Re& Indian Point Unit Nos. 2 & 3 Docket Nos. 50-247 & 50-286 NL-08-074 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

REFERENCES:

Entergy Nuclear Operations, Inc.

Indian Point Nuclear Generating Unit Nos. 2 & 3 Docket Nos. 50-247 and 50-286 Amendment 4 to License Renewal Application (LRA) 1.ý Entergy Letter dated April 23, 2007, F. R. Dacimo to Document Control Desk, "License Renewal Application" (NL-07-039)

2. Entergy Letter dated April 23, 2007, F. R. Dacimo to Document Control Desk, "License Renewal Application Boundary Drawings" (NL-07-040)

3. Entergy Letter dated April 23, 2007, F. R. Dacimo to Document Control Desk, "License Renewal Application Environmental Report References" (NL-07-041)

4. Entergy Letter dated June 21, 2007, F. R. Dacimo to Document Control Desk, "Station Blackout (SBO) / Appendix R Diesel Generator Commitment for Indian Point Nuclear Generating Unit No. 2 in Response to NRC Review Status of License Renewal Application" (NL-07-078)

5. Entergy Letter dated October 11, 2007, F. R. Dacimo to Document Control Desk, "Supplement to License Renewal Application (LRA)"

(NL-07-124)

6. Entergy Letter dated November 14,'2007, F. R. Dacimo to Document Control Desk, "Supplement to License Renewal Application (LRA) Environmental Report References" (NL-07-133)

ýp-ý'

NL-08-074 Docket Nos. 50-247 & 50-286 Page 2 of 3

Dear Sir or Madam:

In the referenced letters, Entergy Nuclear Operations, Inc. applied for renewal of the Indian Point Energy Center operating license.

In Reference 4, Entergy committed to install and make operational a new Station Blackout (SBO) / Appendix R diesel generator for Indian Point Nuclear Generating Unit No. 2 (IP2) by April 30, 2008. This commitment has been met and Attachment 1 to this letter contains Amendment 4 of theLicense Renewal Application (LRA), consisting of LRA changes resulting, from the completion of the installation of the diesel generator for IP2. Drawings LRA-400881-0 and LRA-400882-0 are discussed on page 2 of and they are included as Enclosures 1 and 2, respectively. to this letter contains the UFSAR changes associated with the SBO I Appendix R diesel generator installation, which will be incorporated into the IP2 and IP3 UFSARs at the next scheduled updates. Although this is not part of Amendment 4 of the LRA, it is being provided as supplemental information to facilitate NRC review.

Entergy Nuclear Operations, Inc. is making no new commitments in this letter.

If you have any questions, or require additional information, please contact Mr. Robert Walpole, Licensing -Manager, at 914-734-6710.

I declare under penalty of perjury that the foregoing is true and correct. Executed on Sincerely, Fred R.* Dacimo Vice President License Renewal

NL-08-074 Docket Nos. 50-247 & 50-286 Page 3 of 3 Attachments:

1.

Station Blackout (SBO) / Appendix R Diesel Generator for IP2; LRA Amendment 4

Enclosures:

1.

Drawing LRA-400881-0

2.

Drawing LRA-400882-0

3.

IP2 and IP3 UFSAR License Basis Document Changes (supplemental information) cc:

Mr. Samuel J. Collins, Regional Administrator, NRC Region I Mr. Sherwin E. Turk, NRC Office of General Counsel, Special Counsel Mr. Kenneth Chang, NRC Branch Chief,- Engineering Review Branch I Mr. Bo M. Pham, NRC Environmental Project Manager Mr. John Boska, NRR Senior Project Manager Mr. Paul Eddy, New York State Department of Public Service NRC Resident Inspector's Office, Indian Point Energy Center Mr. Paul D. Tonko, President, New York State Energy, Research, & Development Authority

ATTACHMENT 1 TO NL-08-074 Station Blackout I Appendix R Diesel Generator for 1P2 LRA Amendment 4 ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 AND 50-286

NL-08-074 Docket Nos. 50-247 & 50-286 Page 1 of 16 Station Blackout / Appendix R Diesel License Renewal Application Amendment 4 (Changes are shown as strikethroughs for deletieRs and underlines for additions) 2.1.1.3.5, Commission's Regulations for Station Blackout (10 CFR 50.63), third paragraph, is changed to read as follows Upon completion of its installation and te.ting, a The new diesel generator, the SBO/Appendix R diesel generator (SBO/ARDG), will-beis the source of alternate AC power credited for IP2 compliance with 10 CFR 50.63. The SBO/ARDG will be the source of a1tenato AC por.... conRtiuiRg th-.ughjhep..i-d of oxt..ded operation. The SBOAARDG will be installed and.pa -i

.na.

pro t cploti.n of NRC review of this application. -The SBO/ARDG Will replace th gas turbines to provides power for Appendix R and station blackout events. The integrated plant assessment for license renewal includes review of the SBO/ARDG. Specifically, the results of that review are included in Section 2.3.3.16 for scoping and screening, and in Table 3.3.2-16-1P2 for the aging management review.

Table 2.2-3, line item is changed-to read as follows.

Gas Turbine Substation Switchgear Section 2.4.3, Turbine Buildings, Auxiliary Structures and Foundation (4P-3)

Buildings, and Other Structures 2.3.3.8, Heating, Ventilation and Air Conditioning, SBO/Appendix.R Diesel Generator Ventilation is changed to read as follows.

Befoeetering the period of extended operation, 1122 will hao com pleted the installationo a new station blackout (S90) and Appendix R diesel-The IP2 SBO/Appendix R diesel generator is credited with providing backup power to the plant to assist in safe shutdown following a fire ador following a station blackout and its associated ventilation equipment is required for this equipment to function. The IP2 SBO/Appendix R diesel will-utilizes louvers, fire da.pe.s. an exhaust fan, and outlet ductwork. The fan will operate when the diesel is in operation.

Section 2.3.3.13 System Description is revised as follows:

Gas Turbine System The gas turbine system description is included in the fuel oil section because its only intended function for license renewal is performed by its fuel oil subsystem.

The purpo~se of the gas turbine (GT) system isto provide an alternate source of standby power for the site. Gas turbine Unit 1 is locr-ated -adjacent to the Un~it 1 turbine building.Ga turbine Units 2 and 3 are located at the Buchanan substation. The gas turbines haye-ee credited as an alternate power supply for the Appendix R and station blackout events;

NL-08-074 Docket Nos. 50-247 & 50-286 Page 2 of 16 howevcr, thoec funcion will be assumed by the 1122 SBO/Appondix R diesel gncruator (SBO/ARDG) prior to the period of oxtcndcd o)poration.

2.3.3.16, Appendix R Diesel Generators, the second and third paragraphs are changed to read as follows.

The SBO/Appendix R diesel generator (SBO/ARDG) willbe is the source of alternate AC power credited for IP2 compliance with 10 CFR 50.63. con"inu thro

,,ugh the p,*'id of oxtonded operation-.The SBO/ARDG replaco the gas turbines toprovides power for Appendix R and station blackout events. The integrated plant assessment for license renewal identified the SBO/ ARDG as within the scope of license renewal.

The SBO/ARDGAppend.x R dieel will be is located inside the Unit 1 turbine building. The SBO/ARDGAppcndix R diesel e...a stallatin will be a self contained packagethat is designed to operate upon a complete loss of power. The package contain*

SBO/ARDG includes batteries, a battery charger, jacket water heater and cooler, turbochargers, aftercoolers, aftercooler coolers, jacket water pump, lube oil heate aidncooler, lube oil pump, and necessary filters and nining6 tF

..e.s. The SBO/ARDGApp,.d.x R dieel geRe-at9 can supply the safe shutdown loads through the 6.9 kV distribution and the emergency 480 V buses and motor control centers or the turbine building switchgear and motor control centers.

2.3.3.16, License Renewal Drawings, Unit 2, is changed to read as follows.

LRA-4008821 LRA-4008862 2.3.3.19, Components Subject to Aging Management Review table on page 2.3-171 is changed to read as follows.

IP2 System Code Area or Components Excluded ARDG (BO./Appendix R Diesel The SBO/Appendix R diesel generator is Generator)

Ret-yet installed for P12; h6wever, it will be in the IP1 turbine hall. The SBO/ARDG system was not reviewed for 54.4(a)(2) for spatial interaction because all of its the passive mechanical components were already included for the-its a--1---ef-the (a)(3) functions.

NL-08-074 Docket Nos. 50-247 & 50-286 Page 3 of 16 Table 2.3.3-16-1P2 is changed to read as follows.

Table 2.3.3-16-1P2 SBO/Appendix R Diesel Generator System Components Subject to Aging Management Review Component Type Intended Function Bolting Pressure boundary Filter housing Pressure boundary Flexible connection Pressure boundary Heat exchanger (bonnet)

Pressure boundary Heat exchanger (fins)

Heat transfer Heat exchanger (housin-q)

Pressure boundary Heat exchanger (shell)

Pressure boundary Heat exchanger (tubes)

Heat transfer Pressure boundary Heater housing Pressure boundary Piping Pressure boundary Pump casing Pressure boundary Sight glass Pressure boundary Silencer Pressure boundary Tank Pressure boundary Thermowell Pressure boundary Tubing Pressure boundary Turbocharger housing Heat-f e &

Pressure boundary Valve body Pressure boundary

NL-08-074 Docket Nos. 50-247 & 50-286 Page 4 of 16 2.4.3, Turbine Buildings, Auxiliary Buildings, and Other Structures, Description, Gas Turbine Generator No. 1, 2 and 3 Enclosure and Fuel Tank Foundation, is changed to read as follows.

Fifth paragraph: The gas turbine generators No. 2 and 3 enclosure is a seismic Class III structure providing shelter and protection from the elements for the gas t'-ib ne and thcir asScciated equipment. The gas turbine No. 2 and 3 enclosure is located at the Buchanan substation. The enclosure houses gas turbine generators No. 2 and 3 and associated switchgear equipment. The switchgear and associated components within the structure support offsite power recovery following station blackout. ;he Site's Appond.x R safo

.hutdoWn analysis. Gas turbine 2 and 3 fuel tank foundation supports the fuel tank, which provides an alternate source of fuel for the emergency diesel generators. These fuel tanks are shared by IP2 and IP3 and credited with providing minimum fuel oil inventory for the emergency diesel generators. If the EDGs require the reserves in these tanks, the contents can be transported by tanker truck.

Ninth Paragraph bullet:

Provide support, shelter and protection for equipment needed for offsite power recovery followinq Gred4ted for station blackout. (10 CFR 50.63) and Appendix R safe shutdown (10 GFR-6048) Components required to restore offsite power following a station blackout (SBO) were conservatively included within the scope of license renewal even though those components are not relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for SBO (10 CFR 50.63).

Tenth paragraph:

The gas turbine substation switchgear structures and foundation provides support equipment required to support offsite power recovery following station blackout. -ahieve a--d maintain hot Sh*utdo.Wn in the.vent a fire proVent. control from 4

h0 central control room.

Thirteenth paragraph bullet:

Provide support for equipment needed for offsite power recovery followinn

.-..e.4e-i"

.upport of Appendix P1 safo shutdown analysis (10 CFR 50.48) and station blackout.(4l-Q GFR-,,.--..

Components required to restore offsite power following a station blackout (SBO) were conservatively included within the scope of license renewal even though those components are not relied on in safety analyses or plant evaluations to perform a function that demonstrates compliance with the Commission's regulations for SBO (10 CFR 50.63).

NL-08-074 Docket Nos. 50-247 & 50-286 Page 5 of 16 3.2.2.2.4 Reduction of Heat Transfer due to Fouling

1.

Reduction of heat transfer due to fouling for copper alloy heat exchanger tubes exposed to lubricating oil in ESF systems is managed by the Oil Analysis Program. There are no stainless steel or steel heat exchanger tubes exposed to lubricating oil in the ESF systems; however, this item is applicable to heat exchanger tubes of the SBO/Appendix R diesel generator. This program includes periodic sampling and analysis of lubricating oil to maintain contaminants within acceptable limits, thereby preserving an environment that is not conducive to fouling. The One-Time Inspection Program will use visual inspections or non-destructive examinations of representative samples to confirm that the Oil Analysis Program has been effective at managing aging effects for components crediting this program.

3.3.2.1.16 Appendix R Diesel Generators, Materials, is changed to add "plastic"

NL-08-074 Docket Nos. 50-247 & 50-286 Page 6 of 16 Table 3.2.1 line item is changed to read as follows.

Table 3.2.1 Summary of Aging Management Programs for Engineered Safety Features Evaluated in Chapter V of NUREG-1801 Table 3.2.1: Engineered Safety Features, NUREG-1801 Vol. 1 Item Number Component Aging Effect/

Aging Management Further Evaluation Discussion Mechanism Programs Recommended 3.2.1-9 Steel, stainless steel, Reduction of heat Lubricating Oil Analysis Yes, detection of aging The Oil Analysis and copper alloy heat transfer due to fouling and One-Time effects is to be evaluated Program manages exchanger tubes Inspection reduction of heat exposed to lubricating transfer in copper alloy oil and stainless steel heat exchanger tubes. The One-Time Inspection Program will be used to confirm the effectiveness of the Oil Analysis Program.

steel or stool heat exposed to h o;il in thA -ESF-systeM&

See Section 3.2.2.2.4 item 1.

NL-08-074 Docket Nos. 50-247 & 50-286 Page 7 of 16 Table 3.3.2-16-IP2 is changed to read as follows.

Table 3.3.2-16-1P2 SBO/ Appendix R Diesel Generator System Summary of Aging Management Evaluation Table 3.3.2-16-1P2: SBO/ Appendix R Diesel Generator System Component Intended Aging Effect Aging Management 1801Table 1

Type Function Material Environment Requiring Agi gM ame 1801 Vol. 2 Item Notes Management Item Bolting Pressure Carbon steel Air - indoor (ext)

Loss of material Bolting integrity VII.I-4 3.3.1-43 A

boundary (AP-27)

Bolting Pressure Stainless steel Air - indoor (ext)

None None VII.J-15 3.3.1-94 C

boundary (AP-17)

Filter housing Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring (A-77)

Filter-heasuing P@ssur-e ar-ba.steel A ir-indoor-it)

Loss of materia External sur.fa.e.

NA19 3-.21--3 Filter housing Pressure Carbon steel Lube oil (int)

Loss of material Oil analysis VII.H2-20 3.3.1-14 B, 316 boundary (AP-30)

Filter housing Pressure Plastic Air - indoor (ext)

None None F..--

F boundary Filter housing Pressure Plastic Air - indoor (int)

None None F

boundary Flexible Pressure Stainless steel Air - indoor (ext)

None None VII.J-15 3.3.1-94 A

connection boundary (AP-17)

Flexi~ble PreSSUre Stainl~es-s seel Exhaustgas (i~nt)

Gfaekag-TLAA mnetal fatigue 14-eanneetieI4 boeundary

&69w~*

Flexible Pressure Stainless steel Exhaust gas (int)

Loss of material Periodic surveillance VII.H2-2 3.3.1-18 E

connection boundary and preventive (A-27) maintenance

NL-08-074 Docket Nos. 50-247 & 50-286 Page 8 of 16 Table 3.3.2-16-1P2: SBO/ Appendix R Diesel Generator System Aging Effect Aging Management NUREG-V.

1 Notes Type Function Material Environment Requiring Programs 1801 Vol. 2 Item Management Item Flexible Pressure Stainless steel Lube oil (int)

Loss of material Oil analysis VII.H2-17 3.3.1-33 B, 316 connection boundary (AP-59)

Heat exchanger Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.H2-3 3.3.1-59 A

(bonnet) boundary monitoring (AP-41)

Heat exchanger Pressure Carbon steel Treated water (int) Loss of material Periodic surveillance G, 305 (bonnet) boundary and preventive maintenance Heat.e.eh.nger Pressuve Gatb*...eel Treated water- (int)

Loss of material Water-ehmisty VUt24 3.3.1 D

(bemifet) bounfdary cotr l csed (A 63) eeeling-wnte Heat exchanger Heat transfer Aluminum Carbon Air.- indoor (ext)

Fouling Periodic surveillance H

(fins) steel and preventive maintenance Heat exchanger Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.H2-3 3.3.1-59 A

(housing) boundary monitoring

--41 Heat exchanger Pressure Carbon steel Air - indoor (int)

Loss of material External surfaces V.A-19 3.2.1-32 E

(housing) boundary monitoring (E-29)

Heat exchanger Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.H2-3 3.3.1-59 A

(shell) boundary monitoring (AP-41)

Heat exchanger Pressure Carbon steel Lube oil (int)

Loss of material Oil analysis VII.H2-5 3.3.1-21 B, 316 (shell) boundary (AP-39)

Heat exchanger Pressure Carbon steel Treated water (int)

Loss of material Periodic surveillance Q, 305 (shell) boundary and preventive maintenance Heat exchanger Pressure Carbon steel Treated water (int)

Loss of material Water chemistry VII.C2-1 3.3.1-48 D

(shell) boundary control - closed (A-63) cooling water

NL-08-074 Docket Nos. 50-247 & 50-286 Page 9 of 16 Table 3.3.2-16-1P2: SBO/Appendix R Diesel Generator System Effect NUREG-Notes Component Intended Material Environment Requiring g

am1801 Vol. 2 Item Type Function Management Programs Item Heat exchanger Heat transfer Copper-ally*

Air - indoor (ext)

Fouling Periodic surveillance G

(tubes)

Stainless steel and preventive maintenance Heat exchanger Heat transfer Copper-aley Lube oil (ext).

Fouling Oil analysis V.A-1l24 3.2.1-9 D, 316 (tubes)

Stainless steel (EP-47-5).

Heat exchanger Heat transfer CPPeF--aley Treated water (int)

Fouling Water chemistry VII.C2--23 3.3.1-52 D

(tubes)

Stainless steel control - closed (AP-806_3) cooling water Heat exchanger Heat transfer Stainless steel Treated water (int)

Fouling Periodic surveillance G--

, 305 (tubes) and preventive maintenance Heat exchanger Heat transfer Stainless steel Treated water Fouling Water chemistry VII.C2-3 3.3.1-52 D

(tubes)

> 140°F (inext) control - closed (AP-63) cooling water Heat exchanger Pressure Stainless steel Air - indoor (ext)

None None VII.J-15 (AP-3.3.1-94 C

(tubes) boundary 17)

Heat exchanger Pressure Stainless steel Lube oil (ext)

Cracking Oil analysis H

(tubes) boundary Heat exchanger Pressure Copper-, aley Lube oil (ext)

Loss of material Oil analysis VII.H2-4-017 3.3.1-2633 D, 316 (tubes) boundary Stainless steel (AP-47-59)

Heat exchanger Pressure opper-alley Treated water (int)

Loss of material Water chemistry VII.E4-2C2-10 3.3.1-5-1-00 D (tubes) boundary Stainless steel control - closed (AP-34A-52_

cooling water Heat exchanger Pressure Stainless steel Treated water (int)

Loss of material Periodic surveillance G, 305 (tubes) boundary and preventive maintenance

NL-08-074 Docket Nos. 50-247 & 50-286 1 Page 10 of 16 Table 3.3.2-16-1P2: SBO/ Appendix R Diesel Generator System Component Intended Aging Effect Aging Management 1801Table 1

Copnn nedd Material Environment Requiring Agn aaeetNotes Type Function Ma ng Programs 1801 Vol. 2 Item Management Item Heat exchanger Pressure Stainless steel Treated water Cracking Water chemistry VII.E3-2 3.3.1-46 D

(tubes) boundary

> 140°F (inext) control - closed (A-68) cooling water Heat exchanger Pressure Stainless steel Treated water Loss of material Water chemistry VII.E3-1 3.3.1-49 D

(tubes) boundary

> 140 0F (i-next) control - closed (A-67) cooling water Heat exchanger Pressure Stainless steel Treated water Loss of material Heat exchanger H

(tubes) boundary

> 140°F (inext)

- wear monitoring Heat exchanger Pressure Stainless steel Treated water Cracking Periodic surveillance 305 (tubes) boundary

> 140OF (int) and preventive maintenance Heater housing Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring (A-77)

Heater housing Pressure Carbon steel Treated water (int)

Loss of material Water chemistry VII.H2-23 3.3.1-47 B

boundary control - closed (A-25) cooling water Piping Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VH.I-8 3.3.1-58 A

boundary monitoring (A-77)

Piping Pressure Carbon steel Air - outdoor (ext) Loss of material External surfaces VII.I-9 3.3.1-58 A

boundary monitoring (A-78) piping Pressure Car-ben.seel Condensation (int Les sf material

,Periodic...

su

"..eillan.e V11.142 21 3l. i j

E boundary and pre-e e

(A 23)

Piping Pressure Carbon steel Exhaust gas (int)

Cracking -

TLAA - metal fatigue H

boundary fatigue Piping Pressure Carbon steel Exhaust gas (int)

Loss of material Periodic surveillance VII.H2-2 3.3.1-18 E

boundary and preventive (A-27) maintenance

NL-08-074 Docket Nos. 50-247 & 50-286 Page 11 of 16 Table 3.3.2-16-1P2: SBO/ Appendix R Diesel Generator System Component Intended Aging Effect* Aging Management NUREG-Table 1 Type Function Material Environment Requiring Programs 1801 Vol. 2 Item Notes Management Item pipig Pressure car.bestiseel

,,be oil (int)

Less of material Oilan1alysis V14.4220 3.4-14 B, 316 bwan4affy (AP 30)

Piping Pressure Carbon steel Treated water (int)

Loss of material Water chemistry VII.H2-23 3.3.1-47 B

boundary control - closed (A-25) cooling water Pipin Pressure Plastic Air - indoor (ext)

None None F

boundary Piping Pressure Plastic Air - indoor (int)

None None F

boundary Pump casing Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring (A-77)

Pump casing Pressure Carbon steel Lube oil (int)

Loss of material Oil analysis VII.H2-20 3.3.1-14 B, 316 boundary (AP-30)

Pump casing Pressure Carbon steel Treated water (int)

Loss of material Water chemistry VII.H2-23 3.3.1-47 B

boundary control - closed (A-25) cooling water Sight glass Pressure Copper alloy Air - indoor (ext)

None None V.F-3 3.2.1-53 C

boundary

> 15% Zn (EP-10)

Sight glass Pressure Copper alloy Lube oil (int)

Loss of material Oil analysis VII.H2-10 3.3.1-26 B, 316 boundary

> 15% Zn (AP-47)

Sight glass Pressure Copper alloy Treated water (int)

Loss of material Selective leaching VII.H2-12 3.3.1-84 A, 307 boundary

> 15% Zn (AP-43)

Sight glass Pressure Copper alloy Treated water (int)

Loss of material Water chemistry VII.H2-8 3.3.1-51 B

boundary

> 15% Zn control - closed (AP-12) cooling water Sight glass Pressure Glass Air - indoor (ext)

None None VII.J-8 3.3.1-93 A

boundary (AP-14)

NL-08-074 Docket Nos. 50-247 & 50-286 Page 12 of 16 Table 3.3.2-16-1P2: SBO/ Anoendix R Diesel Generator System Compone nt Intended A

Table 1 Aging Effect Aging Management NUREG-Notes Type Function Material Environment Requiring Programs 1801 Vol. 2 Item Management Item

-t-Sight glass Pressure Glass Lube oil (int)

None None VII.J-10 3.3.1-93 A

boundary (AP-151 Sight glass Pressure Glass Treated water (int)

None None VII.J-1 1 3.3.1-93 A, 303 boundary (AP-50)

Silencer Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring (A-77)

Silencer Pressure Carbon steel Exhaust gas (int)

Cracking -

TLAA - metal fatigue H

boundary fatigue Silencer Pressure Carbon steel Exhaust gas (int)

Loss of material Periodic surveillance VII.H2-2 3.3.1-18 E

boundary and preventive (A-27) maintenance Tank Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring (A-77)

Tank Pressure Carbon steel Lube oil (int)

Loss of material Oil analysis VII.H2-20 3.3.1-14 B__316 boundary (AP-301 Tank Pressure Carbon steel Treated water (int) Loss of material Water chemistry VII.H2-23 3.3.1-47 B

boundary control - closed (A-25) cooling water Thermowell Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring tA-77)

Thermowell Pressure Carbon steel Treated water (int) Loss of material Water chemistry VII.H2-23 3.3.1-47 B

boundary control - closed (A-25) cooling water Tubing Pressure Stainless steel Air - indoor (ext)

None None VII.J-15 3.3.1-94 A

boundary (APLIT)

Tubing Pressure Stainless steel Lube oil (int)

Loss of material Oil analysis VII.H2-17 3.3.1-33 B, 316 boundary LAP-}

NL-08-074 Docket Nos. 50-247 & 50-286 Page 13 of 16 Table 3.3.2-16-1P2: SBO/ Appendix R Diesel Generator System Aging Effect Maaeet NUREG-Tbe1 Notes Component Intended Aging Efc gn aaeet NRG Table 1 Type Function Material Environment Requiring Programs 1801 Vol. 2 Item Management Item Turbocharger Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

housing boundary monitoring (A-77) w,,eha P.e.&..e Carbon stee4 Air-Loss of m.ateria External surfae V-,A--l-4.243 E

Turbocharger Pressure Carbon steel Exhaust gas (int)

Loss of material Periodic surveillance VII.H2-2 3.3.1-18 E

housing boundary and preventive (A-27) maintenance Turbocharger Pressure Carbon steel Lube oil (int)

Loss of material Oil analysis VII.H2-20 3.3.1-14 B, 316 housing boundary LAP-301 Tur-behargef Ue-Atr.a..f.

Carbon steel Air- *n Foing

.PeiOdi.

S

r.Veillanc G

houing and pf~evefitve Tu-echargef Heat tfafsfer-Garbhn-stee Trfeated water- (int)

Fouling Water-ehefnistry V11.142 23 3..147-B heusing control closead (A-25)

T,,r-hAg, Pressure C-be-ste"-

Air indo*o- (et) Loss of m.ateria External surfaces V4 1

1 A

Turbocharger Pressure Carbon steel Air - indoor (int)

Loss of material External surfaces V.A-I19 3.2.1-32 E

housing boundary monitoring (E-29)

Turboeha.ger.

Pressur-e rbeu-s, steel Treated, water. (int)

LOss of material W147840r-e

,isrY 341.42-3 33.147 B

hEUSing b+undary conol closed (A-25) eee4iftg-waw~

Valve body Pressure Carbon steel Air - indoor (ext)

Loss of material External surfaces VII.I-8 3.3.1-58 A

boundary monitoring (A-77)

Valve bady G-Ae-hre

@a qeusee Conmdensation (int) os of mnaterwial Periodic surveillance V47M-24 W4-~

ýý1 33 i7i boundary and preventive (A 23)

NL-08-074 Docket Nos. 50-247 & 50-286 Page 14 of 16 Table 3.32-16-1P2: SBOI Annendix R Diesel Generator System Table ~~~~~

~

~

~

NFIG TableIP:SO ppni iee eeatrSse Aging Effect Management NUREG-Notes Component Intended Material Environment Requiring Table 1 Notes Tye ucton Mteia nvromnt ReurigPrograms 10Vo.2 Item Type Function Management Item 3*.lye b.dy Pressure CarboEn SteeI

,e Oil*;40; Loss of material Oilnalyss 4411.42 20 3.-1 14 B,346 Valve body Pressure Carbon steel Treated water (int)

Loss of material Water chemistry VII.H2-23 3.3.1-47 B

boundary control - closed (A-25) cooling water Valve body Pressure Copper alloy Air - indoor (ext)

None None V.F-3 3.2.1-53 C

boundary (EP-10)

Valve body Pressure Copper alloy Lube oil (int)

Loss of material Oil analysis VII.H2-10 3.3.1-26 B, 316 boundary (AP-47)

Valve body Pressure Copper alloy Treated water (int)

Loss of material Water chemistry VII.H2-8 3.3.1-51 B

boundary control - closed (AP-12) cooling water Valve body Pressure Copper alloy Air - indoor (ext)

None None V.F-3 3.2.1-53 C

boundary

> 15% Zn MEJ-lO Valve body Pressure Copper alloy Lube oil (int)

Loss of material Oil analysis VII.H2-10 3.3.1-26 B, 316 boundary

> 15% Zn LAP-47j Valve body Pressure Stainless steel Air - indoor (ext)

None None VII.J-15 3.3.1-94 A

boundary (AP-17)

Valve body Pressure Stainless steel Lube oil (int)

Loss of material Oil analysis VII.H2-17 3.3.1-33 B, 316 boundary (AP-59)

NL-08-074 Docket Nos. 50-247 & 50-286 Page 15 of 16 A.2.1.16, last item of the first bullet is changed to read as follows.

SBO/Appendix R diesel jaGket-cooling water heat exchangers A.2.1.28, seventeenth and eighteenth bullets are changed to read as follows.

0 0

SBO/Appendix R diesel turbochargers and aftercoolers SBO/Appendix R dieseljaGket-cooling water heat exchangers B.1.9, DIESEL FUEL MONITORING, Enhancement 5 is changed to read as follows.

Attributes Affected Enhancements

5. Monitoring and Trending IP2: Revise appropriate procedures to change the GT1 gas turbine fuel oil storage tanks, SBO/Appendix R diesel generator day tank, and diesel fire pump fuel oil storage tank analysis for water and particulates to a quarterly frequency.

IP3: Revise appropriate procedures to change the Appendix R diesel generator fuel oil day tank and diesel fire pump fuel oil storage tank analysis for water and particulates to a quarterly frequency.

B.1.17, HEAT EXCHANGER MONITORING, Scope of Program, Enhancement, last bullet, is changed to read as followings.

SBO/Appendix R diesel jaEk-et-cooling water heat exchangers (IP2 only)

B.1.17, HEAT EXCHANGER MONITORING, Enhancement. 1. Scope of Program, last bullet, is changed to read as follows.

SBO/Appendix R diesel jaGket-cooling water heat exchangers (IP2 only)

NL-08-074 Docket Nos. 50-247 & 50-286 Page 16 of 16 B.1.29, PERIODIC SURVEILANCE AND PREVENTIVE MAINTENANCE, Program Description, IP2 SBO/Appendix R Diesel Generator, is changed to read as follows.

IP2 SBO/Appendix R Diesel Generator Use visual or other NDE techniques to inspect internal surfaces of a representative sample of diesel exhaust gas piping, piping elements, and components to manage cracking and loss of material on internal surfaces.

Use visual or other NDE techniques to inspect the internal surface condition of the engine turbocharger and aftercooler housing including external surfaces of tubes and fins to manage loss of material and fouling.

Use visual or other NDE techniques to inspect the internal surfaces of the diesel jaeket-coolinA water heat exchangers carbon steel bonnets and stainless steel tubes exposed to treated water (city water).

ENCLOSURE 1 TO NL-08-074 Drawing LRA-400881-0 ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 & 50-286

LEGEND RaR~rR,~ C"

(~C )

2) 0 0

(D)

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'eon 4

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JFI F IC\\26, 21n I

I To-s~'Te' I-1"*,,

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. I; si

~

u.

usaaD

-L.

GC 4/15/OS THIS LRA DRAWING IS BASED ON AN UNAPPROVED SITE DRAWING i

LRA-400881-O

ENCLOSURE 2 TO NL-08-074 Drawina LRA-400882-0 ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 & 50-286

-EGLND NOWES I,.I,*',*,

c-owom s0 1TO To 0

W Y IIIATER SYSTE Sý**;JI-

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la=--

11c.

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WZ II SET -m POINT1 FNFRCY CFNTFR U EpDIES N

SRf OEL CKOUT Af'%

SYSTEM THIS LRA DRAWING IS BASED ON AN UNAPPROVED SITE DRAWING

ENCLOSURE 3 TO NL-08-074 1P2 and 1P3 UFSAR License Basis Document Changes (supplemental information)

IP2 UFSAR - 11 pages IP3 UFSAR - 11 pages Changes are shown as strikethroughs for d4eetiGne and bold underlines for additions ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NOS. 2 & 3 DOCKET NOS. 50-247 & 50-286

IP2 FSAR UPDATE Electric power from the transmission network to the onsite electric distribution system shall be supplied by two physically independent circuits (not necessarily on separate rights of way) designed and located so as to minimize to the extent' practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions. A switchyard common to both circuits is acceptable. Each of these circuits shall be designed to be available in sufficient time following a loss of all onsite alternating current power supplies and the other offsite electric power circuit, to assure that specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded. One of these circuits shall be designed to be available within a few seconds following a loss-of-coolant accident to assure that the core cooling, containment integrity, and other vital safety functions are maintained.

Provisions shall be included to minimize the probability of losing electric power from any of the remaining supplies as a result of, or coincident with, the loss of power generated by the nuclear power unit, the loss of power from the transmission network, or the loss of power from the onsite electric power supplies.

Independent alternate power systems are provided with adequate capacity and testability to supply the required engineered safety features and protection systems.

The plant is supplied with normal, standby, and emergency power sources as follows:

1.

The normal source of auxiliary power for 6.9-kV buses 1, 2, 3, and 4 during plant operation is the unit auxiliary transformer, which is connected to the main generator via the iso-phase bus.

2.

The normal source of auxiliary power for 6.9-kV buses 5 and 6 and standby power required during plant startup, shutdown, and after reactor trip is the station auxiliary transformer, which is supplied from the Con Edison 138-kV system by either of two separate overhead lines from the Buchanan substation approximately 0.5 mile from the plant. Alternate feeds from the Buchanan 13.8-kV system are also available for immediate manual connection to the auxiliary buses. In addition, thr..

gas turbinob i..ith blac,*6tat (no auxiliary, p.w..)

capability arc available. There gac turbinos may also be ucod to "bootstrap" the unit back to p.w..

operatieo folloGWig a lo66 Of the Cn Edison grid.

The capacitios of thoso gas turbino gcnReaters roquiro that the station load be roducod to a mi*imum du'rng sta'tup.

3.

Three diesel-generator sets supply emergency power to the engineered safety features buses in the event of a loss of AC auxiliary power. There are no automatic bus ties associated with these buses.

The threc gas turbines d'i.....d ion iteom 2 may ase seroe to supply. m

.rgno*y

,hutdwn* pw;'r.The SBO / Appendix R emergency diesel-generator is installed in Unit 1 Turbine Building and is used to supplv Power for ApDendix R fires and a Station Blackout.

4.

Power for vital instrumentation and controls and for emergency lighting is supplied from the four 125-V DC systems.

The station batteries supply 3 of 30 Revision 20

IP2 FSAR UPDATE Failure of a single inverter or its static transfer to switch will not cause the loss of a basic protective system or prevent the actuation of the minimum safeguards devices.

Several sources of offsite power are available to Indian Point Unit 2. These consist of two 138-kV overhead supplies from the Buchanan 138-kV substation, and three separate underground feeders from the Buchanan 13.8-kV substation, and throo 13.8 kV gac tubincc (*n. of which ic loGa4 ed onsite). The 13.8-kV line is rated 19.8 MVA at 13-kV. The 13.8/6.9-kV transformer is rated 20 MVA. The maximum engineered safety feature and safe shutdown loads are 9.2 MVA.

No safety or emergency power is required from these sources for the retired Indian Point Unit 1.

The Buchanan 138-kV substation supply to Indian Point Unit 2 has two connections to the Millwood 138-kV substation, a connection to the Peekskill Refuse Burning Generating Station and a connection via auto-transformer to the Buchanan North 345-kV substation. The Indian Point Unit 2 345-kV connection to the system goes to the Buchanan North 345-kV substation, which has connections to Ramapo and Eastview 345-kV substations. System stability. studies show that the system is stable for the loss of any generating unit including Indian Point Unit 2.

Each 138-kV overhead tie line can provide offsite power to Indian Point 2 via the station auxiliary transformer. The loss of this transformer would interrupt the 138-kV supply to the station. For this reason, an alternate 13.8/6.9-kV supply is provided.

An additional sources of offsite power from the 13.8-kV distribution system at Buchanan and ae i ndependent powor upply fromA the ocito gac turbio (Un.it 1) inctallatiOn are is available to 6.9-kV buses 5 and 6 through supply breakers GT-25 and GT-26. The transfer from the normal to the reserve supply (or vice versa) must be accomplished manually.

T.hree (3) gac bi.

gonerateos aro directly available to the Indian Point cite. One gas tubiino generator 6c mere than adequate to pro.i ;d

.A additional contingenc. of backup eletrca POWor for mnaintaining the plant in a ca;fe htoncniin Gar tur;bine Unit 1 i6 !ocated adjacent to the IJnit 1 turbine building. The p9citien indication and GGnr#9lc for broa;_korc_ G-4 and GT--26 are located on a panel1 in the CoA-ntral Con-trol ROOM-.

Gas turbino Units 2 and 3 aro Iloated at the Buchanan cubctati9n. EithII of these gac turbineI can cupplY poWer to the Un~it 2 auxilia~y Gloctrical system through the Buchanan 13.8 04 dictribution cyctomA GOnnectiOnc or through the 138 WY tie linec.

Each of these circuits is designed to be available in sufficient time following a loss of all onsite AC power supplies and other offsite electric power circuits, to ensure that specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded. The 138-kV system is designed to be available instantaneously following a loss-of-coolant accident to ensure that core cooling, containment integrity, and other vital safety functions are maintained.

This is accomplished by a "dead-fast" transfer scheme that uses stored energy breakers to transfer the auxiliaries on the four 6.9-kV buses supplied by the unit auxiliary transformer to the station auxiliary transformer, which is supplied from the 138-kV system.

However, when buses 5 and 6 are supplied from the alternate 13.8-kV supply, the "dead fast" transfer scheme is defeated by manual action to protect the 13.8-kV-6.9-kV transformer.

The diversity and redundancy inherent in the combination of eRsite/offsite electrical systems minimize the probability of losing electric power from any of the remaining sources as a result 6 of 30 Revision 20

IP2 FSAR UPDATE

4.

Letter from Con Edison to the Nuclear Regulatory Commission,

Subject:

Station Blackout Rule, dated April 14,1989.

5.

Letter from Con Edison to the Nuclear Regulatory Commission,

Subject:

Station Blackout Rule, dated March 27,1990.

6.

Letter from Con Edison to the Nuclear Regulatory Commission,

Subject:

Station Blackout Rule, dated October 22, 1993.

7.

Letter from Con Edison to the Nuclear Regulatory Commission,

Subject:

Station Blackout Rule, dated November 30,1993.

8.

Letter from Francis J. Williams, U.S. Nuclear Regulatory Commission, to Stephen B. Bram, Con Edison,

Subject:

Safety Evaluation of the Indian Point Nuclear Generating Unit No.2, Response to the Station Blackout Rule (TAC No.

M68556), dated November 21, 1991.

9.

Letter from Con Edison to the Nuclear Regulatory Commission,

Subject:

Station Blackout Rule, dated December 23, 1991.

8.2 ELECTRICAL SYSTEM DESIGN 8.2.1 Network Interconnections Con Edison's external transmission system provides two basic functions for the nuclear generating station: (1) it provides auxiliary power as required for startup and normal shutdown and (2) it transmits the output power of the station.

Electrical energy generated at 22-kV is raised to 345-kV by the two main transformers. Power is delivered to the system via a 345-kV overhead tie line routed between the main transformers and the 345-kV North Ring Bus at Buchanan Substation. The North Ring Bus is configured with three circuit breakers rated 362-kV, 3000A, 40/63kA.

Two of these breakers have synchronizing capability to connect the main generator to the system. The North Ring Bus is also connected to Ramapo and Eastview Substations via overhead transmission circuits and to the Buchanan 138-kV Substation via a 335/138-kV auto-transformer.

The electrical one-line diagram for the Indian Point Station is presented in Plant Drawing 250907 [Formerly UFSAR Figure 8.2-1].

Standby power is supplied to the station from the Buchanan 138-kV Substation, which has two connections to the Millwood 138-kV Substation, one connection to the Peekskill Refuse Burner, and one connection to the Buchanan 345-kV Substation via an auto-transformer.

in addition, gas t,,bino p.w.r can be pr.vided to Indian PGint UJnit 2 from any of the throo gas turbinoc.

Several power flow paths exist to connect-gas turbine pc-wer to the plant, cithor thru vaFriuc Switching arrengcmentc of 13.8 kV and 6.0 k0 underground feeder, or thru mb.*,Ination. of 13.8 kV undorground feoders, traneform.tione up through the Buchanan 138 kV, aRd th.u either of the two 138 kV overhead feedo*r.

,MaXimu' flexibility ef routing ic pr*vided by intcr ties at the Buchanan cu*btation (138 kV and 13.8-kV buses) and at the IndiaRn Point sit (138 kYV site...

c*hyard and ga. turbine

.ubstatien 6.0 kY bus tee). One of thece gar. turbine generatrem is located at the Indian Point site and two arc l'oated at the Buchanan Substation.through 13.8/6.9 kV autotransformers to Buses 1 and 6.

9 of 30 Revision 20

IP2 FSAR UPDATE A single-line diagram showing the connections of the main generator to the power system grid and standby power source is shown in Pl Drawing 250907 [For*erly:UFSAR Figure 8.2-2.

8.2.1.1 Reliability Assurance Twohree external sources of standby power are available to Indian Point Unit 2. They are the 1 38-kV tie from the Buchanan 345-kV substation, and the 138-kV Buchanan-Millwood tiesaRd the gasc turbin, gnFratoFr.

Loss of any two-of these sources will not affect the other-third.

Substantial flexibility and alternate paths exist within each source.

The 138-kV supply from the Buchanan substation with its connections to the Con Edison 345-kV system provides a dependable source of station auxiliary power. Upon loss of 345/138-kV auto-transformer supply at Buchanan, two 138-kV ties are designed to provide additional auxiliary power from the Millwood 138-kV substation.

A further guarantee of reliable auxiliary power, independent of transmission system connections, is provided by the throo gac turbin g...ratre.,

ono inrtallod at the plant site and two (2) at 9 I.hanan. SBO / Appendix R Diesel for the Appendix R fire or a loss of all AC (station blackout).

The SBO M

Appendix R diesel, associated switchgear and breakers minimum operating requirements are specified in the TRM. The minimum quantity of fuel for the SBO / Appendix R Diesel to operate for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> shall be available at all times the SBO / Appendix R Diesel is considered operable. Support systems for cooling include the City Water Storage Tank and the Service Water System (first the city water and then a switch to SW).

If these requirements cannot be met, then the diesel is considered inoperable and the TRM requirments are followed. The gasc trbinec aRn p.OVid an alto.at. bacup p,9w**,

r courcc in coae Of 1c6 of oncito omr~egoncY powor and concurront 19s6 of offeito powor- _ac_

w.oAl ais required auxiliary powor for altornato i;afo rhutdoWn; 9quiPM8Rt.' Minimumn oporating condi.tiGne for tho gar, turInOce aro 6pocifid in thel Unit 2 TocGhnical RoqIUiromontc IManual.[TRlM].

The fuel supply-f4e gas t'e-kbrb consists of two onsite 30,000-gal fuel oil tanks and a 200,000-gal storage tank located at the Buchanan substation site. A minimum amount of 94,879 gal of fuel is maintained available and dedicated for the SBO / Appendix R Diesel req-4red 4-gas tuWI-bRe.

This minimum fuel inventory ensures that ene asc t'-rbine the SBO I Appendix R Diesel will be capable of supplying the maximum electrical load for the Indian Point Unit 2 alternate safe shutdown power supply system (i.e., 1600kW) for at least 3 days. Commercial oil supplies and trucking facilities exist to ensure deliveries of additional fuel within one day's notice.

In the event of the loss of the Indian Point Unit 2 138-kV supply (the primary preferred offsite supply), the Indian Point Unit 2 13.8/6.9-kV supply is manually connected to 6.9-kV buses 5 and

6. The capacity of this supply is limited and is not capable of supplying full plant load. However, the 13.8-6.9-kV supply is capable of supplying the normal load on buses 5 and 6 and is also capable of supplying all 480-V safeguards and safe shutdown loads. The "dead-fast" transfer of 6.9-kV buses 1, 2, 3, and 4 is prevented by manual action when buses 5 and 6 are supplied from the 13.8/6.9-kV supply.

8.2.2 Station Distribution System The auxiliary electrical system is designed to provide a simple arrangement of buses requiring a minimum of switching-to restore power to a bus in the event that the normal supply is lost.

10 of 30 Revision 20

IP2 FSAR UPDATE In 1989, the NRC approved changes to the design basis with respect to dynamic effects of postulated primary loop ruptures, as discussed in Section 4.1.2.4.

In those areas where the compressed instrument air system is near the essential 480-V switchgear, the following provisions have been incorporated to shield this essential switchgear and cabling from potential missiles or pipe whip:

1.

The compressed instrument air lines in the vicinity of the switchgear are supported at the piping bends. This will resist any step loading of PA (which could occur in the event of an instantaneous circumferential rupture) without occurrence of a "plastic hinge." The possibility of pipe whip is eliminated.

2.

A guard cover is supplied around the air compressor flywheel.

This cover is designed to absorb the translational kinetic energy associated with a compressor flywheel missile.

3.

A guard barrier is supplied adjacent to the compression chamber of the air compressor. This barrier is designed to absorb the kinetic energy associated with a compression chamber segment.

These provisions ensure that no missile or whipping pipe originating from postulated failures in the compressed instrument air system will strike the essential switchgear.

8.2.3 Emergency Power 8.2.3.1 Source Descriptions The-three sources of offsite emergency power are: (1) the Con Edison 345-kV system and (2)

Con Edison's 138-kV system and (3) the lioncO'*,

gas turbin*..

The emergency diesel-generator sets provide three sources of onsite emergency power. Each set is an Alco Model 16-251-E engine coupled to a Westinghouse 900 rpm, 3-phase, 60-cycle, 480-V generator. The units have a capability of 1750 kW (continuous), 2300 kW for 1/2 hour in any 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period, and 2100 kW for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> in any 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> period. There is a sequential limitation whereby it is unacceptable to operate EDG's for two hours at 2100 kW followed by operating at 2300 kW for a half hour. Any other combination of the above ratings is acceptable.

Any two units, backups to the normal standby AC power supply, are capable of sequentially starting and supplying the power requirement of at least one complete set of safeguards equipment.

The units are installed in a seismic Class I structure located near the Primary Auxiliary Building.

Each emergency diesel is automatically started by two redundant air motors, each unit having a complete 53-ft3 air storage tank and compressor system powered by a 480-V motor. The piping and the electrical services are arranged so that manual transfer between units is possible. The capability exists to cross-connect a single EDG air compressor to more than one (1) EDG air receiver, via manual air tie valves. However, to ensure that the operability of two (2) of the three (3) EDGs is maintained for minimum safeguards in the event of a single failure, administrative controls are in-place to require an operator to be stationed within the EDG Building, whenever any of the starting air tie valves are opened. Each air receiver has sufficient storage for four normal starts. However, the diesel will consume only enough air for one automatic start during 19 of 30 Revision 20

IP2 FSAR UPDATE manner, transfer pump 22 receives an automatic starting signal on low level in the day tank for diesel 22 and is backed up by transfer pump 23. Transfer pump 23 starts on low level in the day tank for diesel generator 23 and is backed up by transfer pump 21.

Each diesel oil transfer pump stops automatically when 15.5-in. of oil remains in the associated underground tank which equates to a maximum of approximately 7000-gal of available fuel oil per tank.

A minimum fuel storage of 19,000 gal (i.e., approximately 6340 gal per tank) is maintained in the three underground storage tanks.

The 19,000 gal of storage ensures that two diesels can operate for at least 73 hours8.449074e-4 days <br />0.0203 hours <br />1.207011e-4 weeks <br />2.77765e-5 months <br /> at the maximum load profile permitted by the diesels' ratings. If one of the three storage tanks is not available, there is sufficient fuel oil to run two diesels at the maximum load profile for at least 45 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br />. Similarly, if three diesels are available, there is sufficient fuel oil in the three storage tanks for at least 45 hours5.208333e-4 days <br />0.0125 hours <br />7.440476e-5 weeks <br />1.71225e-5 months <br /> of operation at the maximum load profile. These values are based on the use of No. 2 diesel fuel oil at the lowest density of 6.87 lb/gal and engine fuel oil consumption rates based on operating at each load rating. For heavier oil, the time would be increased proportionally to the ratio of 6.87 lb/gal and the actual fuel density. An upper limit of 7.39 lb/gal is common for No. 2 diesel oil.

Additional fuel oil suitable for the diesel engines is stored on the site fer gar tu*binc GT 1 and at Buchanan substation. for gas turbinoc GT 2 and GT 3. A minimum additional storage of 29,000 gal is maintained in the storage tanks dedicated for diesel-generator use.

This storage is sufficient for operation of two diesels for at least 111 hours0.00128 days <br />0.0308 hours <br />1.835317e-4 weeks <br />4.22355e-5 months <br /> at the maximum load profile permitted by the diesels' ratings.

As previously mentioned (Section 8.2.1), commercial oil supplies and trucking facilities exist to ensure deliveries on one day's notice.

The basis for the minimum total required fuel oil quantity of 48,000 gallons is to provide for operation of two diesel generators for 7 days. The specified minimum quantity of fuel oil is based on operation of two diesel generators for 7 days at the maximum load profile permitted by the diesel generator rating. Each diesel is rated for operation for 0.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> of operation out of any 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at 2300 kW plus 2.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> of operation out of any 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> at 2100 kW with the remaining 21.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> of operation of any twenty four hours at 1750 kW. Operation of the diesel generators at the maximum load profile ratings bounds the postulated accident load profile. If one EDG storage tank or transfer pump is unavailable, the remaining tanks or pumps with the additional 29,000 gallons of fuel oil can operate two diesels at the maximum load profile permitted by the diesel generator rating for at least 160 hours0.00185 days <br />0.0444 hours <br />2.645503e-4 weeks <br />6.088e-5 months <br />.

8.2.3.3 Emergency Diesel Generator Separation The emergency diesel generators are located in a sheet metal, steel-framed building immediately South of the Primary Auxiliary Building.

The diesel generators are arranged parallel to each other on 13-ft centers, with approximately 10 ft of clear space between engine components. The engine foundations are surrounded by a 1 foot-high' concrete curb containing sufficient volume to hold all the lube-oil or fuel released from a single engine in the event of an inadvertent spill or line break.

Diesel generator separation and fire protection features necessary to meet the criteria of 10 CFR 50.48 are described in the document under separate cover entitled, ":

41r _&07d n.aysis." A control panel, which contains relays and metering equipment for all three diesel generators is located on the west end of the building. The panels are compartmentalized with controls for each engine separated from each other. The compartmentalized design minimizes 22 of 30 Revision 20

IP2 FSAR UPDATE Figure 8.2-10 Single Line Diagram - 480-V Motor Control Centers 28A and 211, Replaced with Plant Drawing 208241 Figure 8.2-11 Single Line Diagram - 480-V Motor Control Centers 26A and 26B, Replaced with Plant Drawing 9321-3006 Figure 8.2-11 a Single Line Diagram - 480-V Motor Control Center 26C, Replaced with Plant Drawing 248513 Figure 8.2-12 Single Line Diagram - 480-V Motor Control Centers 26AA and 26BB and 120-V AC Panels No. 1 and 2, Replaced with Plant Drawing 208500 Figure 8.2-13 Single Line Diagram - 118-VAC Instrument Buses No. 21 thru 24, Replaced with Plant Drawing 208502 Figure 8.2-14 Single Line Diagram - 118-VAC Instrument Buses No. 21A thru 24A, Replaced with Plant Drawing 208503 Figure 8.2-15 Single Line Diagram - DC System Distribution Panels No. 21, 21A, 21 B, 22, and 22A, Replaced with Plant Drawing 208501 Figure 8.2-16 Single Line Diagram - DC System Power Panels No. 21 thru 24, Replaced with Plant Drawing 9321-3008 Figure 8.2-17 Single Line Diagram of Unit Safeguard Channeling and Control Train Development, Replaced with Plant Drawing 208376 Figure 8.2-18 Cable Tray Separations, Functions, and Routing, Replaced with Plant Drawing 208761 8.3 ALTERNATE SHUTDOWN SYSTEM The Indian Point Unit 2 alternate safe shutdown system provides the necessary functions to maintain the plant in a safe shutdown condition following a fire that damages the capability to power and control essential equipment from normal and emergency Indian Point Unit 2 sources.

In the unlikely event of a major fire or other external event affecting redundant cabling or equipment in certain areas, electrical power could be disrupted to safe shutdown components and systems. However, following the unlikely loss of normal and preferred alternate power, additional independent and separate power supplies from the Indian Point Unit 1 440-V switchgear are provided for a number of safe shutdown components.

An independent SBO/APP, R diesel-aenerator is provided to oower the Unit 1 440-V switchaear in the unlikely event of loss of offsite power to Unit 1 switchaear. In addition, there is provision to cross-connect the Unit 3 SBO / Appendix R DG to the Unit 2 alternative shutdown loads: and Unit 2 SBO/APP. R DG to Unit 3 alternative shutdown loads.

The Indian Point 2 SBO/App.

R diesel generator set is manufactured by Cummins Power Generation. with a rating of 2700 kW (Standby Rating). 13.8 kV, 3 Phase. 60 Hertz, 1800 RPM. for operation on diesel fuel. The output of the generator is connected to SBO/APP. R 13.8 kV Switchoear bus via circuit breaker SBO/ASS. located at DG Breaker Switchgear. The SBO/APP. R 13.8 kV Switchgear section has two feeder circuit breakers. ASS and SBOH.

The ASS breaker feeds the existing Unit No. 1. 13.8 kV L&P Bus Section 3 in order to provide power to Alternate Safe Shutdown System loads. The SBOH breaker feeds a 13.8 kV - 6.9 kV, 3750 KVA SBO transformer, that in turn feeds the 6.9 kV section of the SBO/APP Switchgear via circuit breaker SBOL. This breaker then feeds power to the plant 6.9 kV electrical distribution system via breakers GT-25 and GT-26.

In addition, there is provision to cross-connect the Unit 3 SBO /

Appendix R DG to the Unit 2 alternative shutdown loads: and Unit 2 SBO/APP. R DG to Unit 3 alternative shutdown loads.

28 of 30 Revision 20

IP2 FSAR UPDATE The SBO/ADp.

R diesel generator and associated switchaear. fuel sUDDIy and breakers shall be operable and tested in accordance with the TRM.

A detailed description of the alternate safe shutdown system including its functions, components, and operation is provided in the document under separate cover entitled, "iP2i10 CFR 50, Appedix R Safe-Shutdown Separation Analysis."

8.3 FIGURES Figure No.

Title Figure 8.3-1 Delet6d 8.4 MINIMUM OPERATING CONDITIONS The electrical system is designed such that no single contingency can inactivate enough safeguards equipment to jeopardize plant safety. The minimum operating conditions define those conditions of electrical power availability necessary (1) to provide for safe reactor operation and (2) to provide for the continuing availability of engineered safety features. The facility Technical Specifications, Section 3.8, include minimum operating conditions covering the following plant conditions:

1.

Minimum electrical conditions for reactor criticality.

2.

Minimum electrical conditions during power operation.

8.5 TESTS AND INSPECTIONS Emergency Diesel generators are tested in accordance with technical specification requirements.

The tests specified are designed to demonstrate that the emergency diesel generators will provide power for the operation of equipment.

They also ensure that the emergency generator system controls and the control systems for safeguards equipment will function automatically in the event of a loss of all normal 480-V AC station service power.

The testing frequency specified is often enough to identify and correct deficiencies in systems under test before they can result in a system failure. The fuel supply and starting circuits and controls are continuously monitored and any faults are alarm indicated. An abnormal condition in these systems would be signaled without having to place the emergency diesel generators on test.

The Emergency Diesel Generators will be inspected in accordance with a licensee controlled maintenance program. The maintenance program will require inspection in accordance with the manufacturer's recommendation for this class of standby service. Changes to the maintenance program will be controlled under Station batteries will deteriorate with time, but precipitous failure is. extremely unlikely. The surveillance specified is that which has been demonstrated over the years to rovide an indication of a cell becoming unserviceable long before it fails. The periodic M

E wwill ensure that the ampere-hour capability of the batteries is maintained.

The 'refueling interval' load test for each battery, together with the visual inspection of the plates, will assure the continued integrity of the batteries. The batteries are of the type that can 29 of 30 Revision 20

IP2 FSAR UPDATE be visually inspected, and this method of assuring the continued integrity of the battery is proven standard power plant practice.

At monthly intor"alc, at loact ono gas turbino The SBO I Appendix R Diesel and support systems shall be tested and have surveillances in accordance with the TRM. eta.ted and Sy.chron...izcd to tho powor disribution c.yct. m for a minimum ef thit;*

(30) m-inutoc with a mninimum oloctric output of 2000kM. At wcckly iRntralcs, tho mninimum gas tu~bino fuel volumo 01,870 gallons shall be VWrifiod to bo available and shall bo documontcd in tho plant log.

These tests and surveillances are designed to assure that the SBO / Appendix R diesel at l**st ono gas tuFrbno will be available to provide power for operation of equipment, if required.

So..

tho Indian Point 2 altornato safo shutdown powor s c.......ycm demands a maxu

.m elo.trical load of apprOXim*atcly 1600 kM, tho rfquirod minimum,," tost load will dcons.tratc adoquate capability.

in addition, the roquirod minimum gas tutbino fuel oil storago volumo of 01,870 gallons will conservatively assuro at loast throo (3) days of oporation of a gas turbino gonor~ator.

Tho specifiod tost frcqucncios for tho gas turbino gcnreatoFr.s) and assosiatod fuol Supply will 19o adoquato to identif' and sorroct any mosehanfical or eloctrical doficioncy bfefoe it can result in -a comoncenet mnalfunction or failuro.

30 of 30 Revision 20

IP2 FSAR UPDATE leak to the outside atmosphere. Pump leakage is piped to the drain header for disposal. The pump design prevents lubricating oil from contaminating the charging flow, and the integral discharge valves act as check valves.

Each pump is designed to provide the normal charging flow and the reactor coolant pump seal water supply during normal seal leakage. Each pump is designed to provide flow against a pressure equal to the sum of the reactor coolant system normal maximum pressure (existing when the pressurizer power-operated relief valve is operating) and the piping, valve and equipment pressure losses at the charging flows. During normal operation, 8 gpm seal injection enters each reactor coolant pump in the thermal barrier region where the flow splits, with 3 gpm flowing upward through the controlled leakage seal package and returning to the chemical and volume control system.

The remaining 5 gpm passes through the thermal barrier heat exchanger and into the reactor coolant system where it constitutes a portion of the reactor coolant system water makeup.

In the event that normal seal cooling is lost, the component cooling water system provides adequate seal cooling by supplying flow to the thermal barrier heat exchanger.

Seal injection flow is indicated locally and in the central control room.

An alternate power supply is provided for one of the charging pumps from the 13.8-kV normal offsite power through Unit 1 switchgear. If normal offsite power is not available, this pump can be energized using any of the thrz. available gas turbine.the SBO / Appendix R diesel.

Any one of the three charging pumps can be used to hydrotest the reactor coolant system.

A low-pressure tank (dampener) is installed in the suction line, and a high-pressure tank is installed in the discharge line on each charging pump in order to eliminate pulsation that could potentially cause cavitation at the charging pump suction or root weld cracks on the discharge piping.

9.2.2.4.10 Chemical Mixinq Tank The primary use of the stainless steel chemical mixing tank is to prepare caustic solutions for pH control and hydrazine for oxygen scavenging. The capacity of the chemical mixing tank is more than sufficient to prepare a solution of pH control chemical for the reactor coolant system.

9.2.2.4.11 Excess Letdown Heat Exchanger The excess letdown heat exchanger cools reactor coolant letdown flow if letdown through the normal letdown path is blocked.

The letdown stream flows through the tube side and component cooling water is circulated through the shell side. All surfaces in contact with reactor coolant are austenitic stainless steel and the shell is carbon steel. All tube joints are welded.

The unit is designed to withstand 2000 step changes in the tube fluid temperature from 80°F to the cold-leg temperature.

9.2.2.4.12 Seal-Water Heat Exchanger The seal-water heat exchanger removes heat from two sources; reactor coolant pump seal-water returning to the volume control tank and reactor coolant discharge from the excess letdown heat exchanger. Reactor coolant flows through the tubes and component cooling water Chapter 9, Page 17 of 100 Revision 20, 2006

IP2 FSAR UPDATE An alternate power supply is also provided for one of the component cooling water pumps from the 13.8-kV normal offsite power through Unit 1 switchgear. If normal offsite power is not available, this pump can be energized using anY of the thr..

available ga turbncthe SBO /

Appendix R diesel. During the recirculation phase following a loss-of-coolant accident, one of the three component cooling water pumps is required to deliver flow to the shell side of one of the residual heat exchangers.

9.3.3.1.2 Residual Heat Removal Loop Two pumps and two heat exchangers are utilized to remove residual and sensible heat during plant cooldown. If one of the pumps and/or one of the heat exchangers is not operable, safe operation is governed by Technical Specifications and safe shutdown of the plant is not affected; however, the time for cooldown is extended. The function of this equipment following a loss-of-coolant accident is discussed in Section 6.2.

Alternate power can be supplied to one residual heat removal pump from the 13.8-kV normal outside power through Unit 1 switchgear.

The time to cool down using the safe shutdown components (1 RHR pump and heat exchanger, 1 component cooling pump, and, 1 service water pump supplying flow to non-essential header) has been determined' []. Conditions assumed were an initial core power of 102% of 3216 MW and service water temperature of 95 0F. The analysis shows that the RCS can be brought to the cold shutdown mode (temperature less than 2000F) within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

9.3.3.1.3 Spent Fuel Pit Cooling Loop This manually controlled loop may be shut down safely for time periods, as shown in Section 9.3.3.2.3, for maintenance or replacement of malfunctioning components.

9.3.3.2 Leakage Provisions 9.3.3.2.1 Component Cooling Loop Water leakage from piping, valves, and equipment in the system inside the containment is not considered to be generally detrimental unless the leakage exceeds the makeup capability. With respect to water leakage from piping, valves, and equipment outside the containment, welded construction is used where possible to minimize the possibility of leakage. The component cooling water could become contaminated with radioactive water due to a leak in any heat exchanger tube in the chemical and volume control, the sampling, or the auxiliary coolant systems, or a leak in the thermal barrier cooling coil for the reactor coolant pumps.

Tube or coil leaks in components being cooled would be detected during normal plant operations by the leak detection system described in Sections 4.2.7 and 6.7. Such leaks are also detected at any time by a radiation monitor that samples the component cooling pump discharge downstream of the component cooling heat exchangers.

Leakage from the component cooling loop can be detected by a falling level in the component cooling surge tank. The rate of water level fall and the area of the water surface in the tank permit determination of the leakage rate. To assure accurate determinations, the operator would check that temperatures are stable.

Chapter 9, Page 46 of 100 Revision 20, 2006

IP3 FSAR UPDATE Sharing of Structures, Systems and Components (Criterion 5)

Criterion:

Structures, systems and components important to safety shall not be shared among nuclear power units unless it can be shown that such sharing will not significantly impair their ability to perform their safety functions, including, in the event of an accident in one unit, an orderly shutdown and cooldown of the remaining units.

The only structure important to safety that is shared by the nuclear units at the site is the cooling water discharge canal which carries the safety related Service Water System discharge to the river. Since this channel is of sufficient capacity to handle the discharge flow from both operating units, sharing of this structure will in no way impair the ability of safety related systems in either of the nuclear units to perform their safety functions.

There are no safety related systems shared by the nuclear units at the site. Ho-wcvr, thcre arc thrce gas turbino gnereators provided which arc 6harcd by the two opcrating units and which cian b used to supply the safeguard pe ruiremtS. Two of these aCoe loated near the Buchanka Subtation, while the thrrd iq at. tfh Indian Point site. The gas tubines are cornected to the distfibutir eystemA at 13.8kV.

The 13.8 kV feeders and the gas turbinep are connected te the 6.9 kV buses via autetrapnsfirmors. while each of the t3.8 kV feeders is normnally assigned to one unit, interties at the subctation perm~it the cross feeding fo0m any line to any urit. (Sec Sections 8.1 and 8.2)

The city water supply system provides a backup source of water to the, Condensate Water Storage Tank for the Auxiliary Feedwater System of Indian Point 3.

The Fire Protection Systems formerly shared between Indian Point 1, 2 and 3 have been separated to provide independent fire protection capability.

Details of the system modification are addressed in Section 9.6.

The only components important to safety that are shared by the two operating nuclear units (Indian Point 2 and 3) are the backup fuel oil storage tanks for the emergency diesel generators.

The fuel oil storage tanks dedicated to Indian Point 3 have a capacity sufficient to assure continuous operation of two of the three Indian Point 3 diesels at minimum safeguards load for a total of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />.

The additional fuel oil required for continuous operation for a minimum of seven days can be transported by truck from the 200,000 gallon fuel oil storage tank at the Buchanan Substation located immediately across Broadway and/or from other local oil supplies (Section 8.2).

1.3.2 Protection by Multiple Fission Product Barriers (Criteria 10 to 19)

Reactor Design (Criterion 10)

Criterion:

The reactor core and associated coolant, control, and protection systems shall be designed with appropriate margin to assure that specified acceptable fuel design limits are not exceeded during any condition of normal operation, including the effects of anticipated operational occurrences.

Chapter 1, Page 19 of 118 Revision 02, 2007

IP3 FSAR UPDATE Electric power from the transmission network to the onsite electric distribution system shall be supplied by two physically independent circuits (not necessarily on separate rights of way) designed and located so as to minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions. A switchyard common to both circuits is acceptable.

Each of these circuits shall be designed to be available in sufficient time following a loss of all onsite alternating current power supplies and the other offsite electric power circuit, to assure that specified acceptable fuel design limit and design limit and design conditions of the reactor coolant pressure boundary are not exceeded. One of these circuits shall be designed to be available within a few seconds following a Loss-of-Coolant Accident to assure that the core cooling, containment integrity, and other vital safety functions are maintained.

Provisions shall be included to minimize the probability of losing electric power from any of the remaining supplies as a result of, or coincident with, the loss of power generated by the nuclear power unit, the loss of power from the transmission network, or the loss of power from the onsite electric power supplies.

Independent alternate power systems are provided with adequate capacity and testability to supply the required Engineered Safety Features and protection systems.

The plant is supplied with normal, standby (offsite) and emergency (onsite) power sources as follows:

1. The normal source of auxiliary power during plant operation is supplied from both the plant's generator and offsite power.

2. Offsite power is supplied from Buchanan Substation (approximately 3/4 mile from the plant) by 138kV and 345 kV feeders, and two underground 13.8 kV feeders.

The Buchanan Substation has two 345kV and two 138 kV circuits to Millwood Substation and a 345kV circuit to Ladentown Substation which interconnects with the PJM system.

Millwood Substation has ties to Pleasant Valley Substation which is the interconnection point between Consolidated Edison Co. and Niagara Mohawk and Connecticut Light and Power system. In addition, there is 1 25.4 MW and 1 16.9 MW, combut*ion tubino gencrator at Buchanan Substation 9onnctcd to the 13.8kV fcodcrs from Buc1hanan Substation and a 21 MW combustion turbine gncR.ator. Iocatcd at the Indian Point s.to.

The 138kV feeders are connected to the 6.9 kV buses through the station auxiliary transformer, the 13.8 kV feeders and combution tu-rblnoc are connected to the 6.9 kV buses through autotransformers. The 480 volt engineered safety features buses are connected to the 6.9 kV buses through station auxiliary transformers.

3. Three diesel generators are each connected to their respective engineered safety features buses to supply emergency shutdown power in the event of loss of all other AC auxiliary power. There are no automatic ties between the buses associated with each diesel generator. Each diesel will be started automatically on a safety injection signal or upon the occurrence of under voltage on its associated 480 volt bus. Any two diesels have adequate capacity to supply the engineered safety features for the hypothetical accident concurrent with loss of outside power. This capacity is adequate to provide a safe and orderly plant shutdown in the event of loss of outside electrical power. The Chapter 1, Page 31 of 118 Revision 02, 2007

IP3 FSAR UPDATE consideration of the most severe of these natural phenomena that have been officially recorded for the site and the surrounding area and (b) an appropriate margin for withstanding forces greater than those recorded to reflect uncertainties about the historical data and their suitability as a basis for design. (GDC 2 of 7/11/67)

All electrical systems and components vital to plant safety, including the emergency diesel generators, are designed as Class I so that their integrity is not impaired by the maximum potential earthquake, wind, storms, floods or disturbances on the external electrical system.

Power, control and instrument cabling, motors and other electrical equipment required for operation of the engineered safety features are suitably protected against the effects of either a nuclear system accident or of severe external environment phenomena in order to assure a high degree of confidence in the operability of such components in the event that their use is required.

Emergency Power Criterion: An emergency power source shall be provided and designed with adequate independency, redundancy, capacity, and testability to permit the functioning of the engineered safety features and protection systems required to avoid undue risk to the health and safety of the public., This power source shall provide this capacity assuming a failure of a single component. (GDC 39 and GDC 24 of 7/11/67)

Independent alternate power systems are provided with adequate capacity and testability to supply the required engineered safety features and protection systems.

The plant is supplied with normal, standby and emergency power sources as follows:

1) The normal sources of auxiliary power during plant operation are both the generator and offsite power.

2) Offsite power is supplied from Buchanan Substation (approximately 3/4 mile from the plant) by 138kV and 345kV feeders, and two underground 13.8kV feeders.

The Buchanan Substation has two 345kV and two 138kV circuits to Millwood Substation and a 345Kv circuit to Ladentown Substation which interconnects with the PJM system.

Millwood Substation has ties to Pleasant Valley Substation which is the interconnection point between Consolidated Edison Company, Niagara Mohawk and Connecticut Light and Power systems. In addition, tho..

ar, 1 25.4 MW and 1 16.9 MW.. comFbustionR turbine gnereatorFs at Buc~hanan S-ubstationA and a 21M' combustion turbine generator located at the Indian Point site.

138Kv feeders are connected to the 6.9 KV buses through the station auxiliary transformer, and 13.8 kV feeders and combu'stin tu'rbins are connected to the 6.9kV buses through autotransformers. 480 volt engineered safety features are connected to the 6.9kV buses through station auxiliary transformers.

3) Three diesel generators are each connected to their respective engineered safety features buses to supply emergency shutdown power in the event of loss of all other AC auxiliary power. There are no automatic ties between the buses associated with each diesel generator.

Each diesel will be started automatically on a safety injection signal or upon the occurrence of under voltage on its associated 480 volt bus. Any two diesels have Chapter 8, Page 2 of 30 Revision 02, 2007

IP3 FSAR UPDATE adequate capacity to supply the engineered safety features for the hypothetical accident concurrent with loss of outside power. This capacity is adequate to provide a sage and orderly plant shutdown in the event of loss of outside electrical power.

The diesel generator units are capable of being started and sequence load begun within 10 seconds after the initial signal.

The three diesel-generators are located adjacent to the control building and are connected to three (3) of the four (4) separate 480 volt auxiliary system buses. The fourth 480 volt bus is automatically connected to the third bus during diesel generator operation, and the two buses are operated as a unit from a single diesel generator for this mode of operation only.

4) Emergency power supply for vital instruments, control, and emergency lighting is from the four 125 volt DC station batteries.

5) A 2500 KW diesel generator capable of providing on-site power for safe shutdown loads has been installed in compliance with 10 CFR 50 Appendix "R"; also support compliance with SBO requirements.

8.2 ELECTRICAL SYSTEM DESIGN 8.2.1 Network Interconnection The offsite transmission system provides two basic functions for the station; namely, it provides auxiliary power as required for startup and normal shutdown and transmits the output of the station.

Electrical energy generated at 22 kV is raised to 345 kV by the two main generator transformers and delivered to the Buchanan 345 kV Switching Station via 345 kV, 3000 Amp, 25,000 MVA synchronizing circuit breakers. The Buchanan Substation has two 345 kV and two 138 kV circuits to Millwood Substation and a 345 kV circuit to Ladentown Substation which interconnects with the PMJ system. Millwood Substation has ties to Pleasant Valley Substation which is the interconnection point between Consolidated Edison Company and Niagara Mohawk and Connecticut Light and Power System. The Buchanan 138 kV Substation has connections to Lovett Station.

Offsite (standby) power is supplied from Buchanan Substation (approximately 3/ mile from the plant) by 138 kV and 345 kV feeders, and two underground 13.8 kV feeders. In addition, thoro i s 1 25.4 MW and 1 16.9 MWV combustion turbin genreators at Buchanan substation connocteGd to the 13.8 W fedcrs and a 21 MW comb^u tion tu*Rbnc gencrateFr !cated at the. Idian Point Site.-The 13.8 kV feeders are connected to the 6.9 kV buses through autotransformers. The 480 volt engineered safety feature buses are connected to the 6.9 kV buses through station auxiliary transformers.

Sinqle-Line Diagram A single-line diagram, showing the connections of the main generator to the power system grid and to standby power source is shown on Plant Drawing 9321 -F-33853 [Formerly Figure 8.2-11.

Chapter 8, Page 3 of 30 Revision 02, 2007

IP3 FSAR UPDATE Reliability Insurance There are four independent sources of emergency power available to Indian Point 3. They are the 138 kV and 345 kV ties from Buchanan and the two 13.8 kV feeders from Buchanan.--I addition, thor aro throo combustion turbine generators, one located On tho Indian Point site aRd the others connected to 13.8 WY feeders at Buchanan, providing a completely independent supply from the rest of the Offito transGm.....ion system. The 138 kV supply from the Buchanan bus with its connections to the Consolidated Edison Company system and Orange & Rockland County provide a dependable source of station auxiliary power.

An analysis of the 1971 system demonstrated that the interconnected power system remained stable for the loss of the largest unit, Ravenswood No. 3 (1000 Mwe). Since the transmission system is as strong after the installation of Indian Point 3, and since Indian Point 3 is not as large capacity wise, this analysis can be applied to confirm the stability of the interconnected system for the sudden loss of the largest unit.

In addition, a 2500 kw self-contained diesel generator is available to provide on-site power for safe shutdown loads having alternate feed capability.

8.2.2 Station Distribution System The Auxiliary Electrical System was designed to provide a simple arrangement of buses requiring the minimum of switching to restore power to a bus in the event that the normal supply to that bus is lost.

The relays that are used for bus clearing and sequencing of safeguards components on the four 480 volt buses have been physically located in the 480 volt switchgear and the circuitry has been developed on an individual, independent bus scheme. That is, each bus has its own set of bus clearing and load sequencing relays physically located within its own line-up, independent of the other bus sections. Diesel generator No. 31 is connected to bus No. 2A and bus No. 2A is then connected to bus No. 3A in the event of a diesel requirement. Buses No. 2A and 3A together form one of the three 480 volt safeguards power trains with buses No. 5A and 6A used for the remaining two power trains.

In addition, Indian Point 3 has a five-battery DC System. Each of the three 480 volt safeguards power trains and associated circuitry receives its DC control power from its own individual battery (Nos. 31, 32 and 33). Battery No. 36 feeds power panel No. 36. Battery No. 34 feeds instrument bus No. 34.

Batteries 31, 32, 33, and 34 are safety batteries which supply DC power to safe shutdown systems. Battery 36 is a non-safety battery which supplies DC power to non-essential loads.

Single Line Diagrams The basic components of the station's electrical system are shown on the electrical one line diagrams, Plant Drawings 617F645, 617F643, 617F644, 9321 -F-30063, -30083, 9321 -H-36933, and 9321-F-39893 [Formerly Figures 8.2-2 through 8.2-6, 8.2-8 and 8.2-9], which include the 6900 volt, the 480 volt, the 120 volt AC instrument, and the 125 volt DC bus systems.

Unit Auxiliary, Station Auxiliary and Station Service Transformers Unit Auxiliary Transformer Chapter 8, Page 4 of 30 Revision 02, 2007

1P3 FSAR UPDATE The unit auxiliary transformer is a three phase, two winding, forced oil/air type.

During unit operation, it transforms 22 kV power from the main generator bus to 6.9 kV and, through appropriate switching, supplies four of the six 6900 volt auxiliary buses.

These four buses supply virtually all of the unit 6900 volt auxiliaries and approximately 50% of the 480 volt auxiliaries.

Station Auxiliary Transformer The station auxiliary transformer is a three phase, two winding forced oil/air type. It transforms 138 kV power from the offsite network to 6.9 kV and, through appropriate switching, supplies the remaining two of the six 6900 volt auxiliary buses. During unit operation it supplies the 6900 and 480 volt auxiliary loads that are not supplied by the Unit Auxiliary Transformer.

When the Unit Auxiliary Transformer is not available, such as during unit trip, unit downtime, or startup, the four buses normally supplied by this transformer are reconnected to the two remaining buses, and the Station Auxiliary Transformer supplies all auxiliary loads.

Station Service Transformers The seven station service transformers are three phase, two winding, air insulated, dry type.

Insulation material is fire resistant and non-explosive.

Solid insulation in the transformers consists of inorganic materials such as porcelain, mica, glass or asbestos, in combination with a sufficient quantity of high temperature binder to impart the necessary mechanical strength to the insulation structure. This insulation is defined by ASA standards as Group Ill material. The Station Service Transformers transform 6.9 kV power form the 6900 volt buses to 480 volts to supply low voltage auxiliary loads.

The above transformers were designed and constructed in accordance with the applicable standards of ASA, lEE and NEMA. During normal operation and auto engineered safeguards loading, these transformers will not be loaded beyond their rating.

However, during peak accident loading scenarios, these transformers are allowed to be loaded up to 3600 amps, for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. This short time overload capability is necessary to support the 480V buses 2A, 3A, 5A, and 6A loading requirements during the manual recovery phase of a design basis accident. Manufacturer shop tests of the transformers were conducted in accordance with the latest revision of American Standard Test Code C 57.12.90. This series of tests consisted of the following:

1) Resistance measurements of all windings,

2) Ratio tests,

3) Polarity and phase relation tests,

4) No-load losses,

5) Exciting current,

6) Impedance and load loss,

7) Temperature test,

8) Applied potential tests, and

9) Induced potential tests.

6900 Volt System The 6900 volt system is divided into seven buses. These buses supply 6900 volt auxiliaries directly and 480 volt auxiliaries via the station service transformers. Two buses, numbers 5 and 6, are connected to the 138 kV system via bus main breakers and the Station Auxiliary Transformer.

An alternate connection is available to the 13.8 kV IP2 SBO / Appendix R Chapter 8, Page 5 of 30 Revision 02, 2007

IP3 FSAR UPDATE dieselgas-t'rbWne and/or the 13.8 kV off-site power network via a step-down auto transformer.

Buses No. 1, 2, 3, and 4 are connected to the generator leads via bus main breakers and the Unit Auxiliary Transformer. Buses No. 1 and 2 can be tied to Bus No. 5 and Buses No. 3 and 4 can be tied to Bus No. 6 via bus tie breakers to provide auxiliary power during unit down time.

These bus tie connections are automatically initiated, in the event of unit trip, to assist continuity of service. BUS 3NBY01 is connected to the 13.8 kV off-site power network via a step-down auto transformer.

480 Volt System The 480 volt system consists of seven buses, each supplied from a 6900 volt bus via a station service transformer. Four of these Buses, No. 2A, 3A, 5A and 6A, supplied from Buses No. 2, 3, 5, and 6 respectively, comprise the safety related 480 volt system. The required safeguards equipment circuits are dispersed among these buses. These buses are provided with diesel generator back-up in the event of voltage failure, and are protected against a sustained undervoltage condition, which could cause mis-operation of, or damage to, safeguards equipment. 480V Buses 2A, 3A, 5A and 6A are each rated 3200 amps continuous. However, during peak accident loading scenarios, these buses can be loaded up to 3600 amps for up to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, based on a maximum ambient switchgear room temperature of 400C. For Buses 2A and 3A, this short time limit applies to the combined loading, when these buses are tied together and powered from a single station service transformer. (Buses 2A and 3A are considered a single safeguards bus.)

480 Buses 2A, 3A, 5A and 6A load breakers are rated to interrupt up to 50kA short circuit current.

Maximum short circuit current at the 480V load breakers during emergency diesel generator testing parallel to the system, was initially and conservatively calculated to be slightly greater than 50kA.

However, taking into account cable and raceway construction, and establishment of "safe zone" areas during diesel testing (CAT I areas), the maximum fault current was analyzed to be less than the 50kA rating which would allow the breaker to safely interrupt a fault if it occurs.

The three remaining 480 volt buses, Buses No. 312, 313, and 3NGY01 are supplied from 6900 volt Buses No. 1, 3 and 3NBY01 respectively, and supply auxiliary power to additional plant facilities installed subsequent to the initial installation.

A tie breaker between Buses 312 and 313 permit one bus to serve as a backup for the other.

Interlocking prevents the cross connecting of the two 6.9 kV sources to Buses 312 and 313 through the 480 volt system. The interlock can be defeated temporarily for performing a live transfer of 480 volt buses 312 and 313 when both 6.9 kV supply buses are fed from the same 6.9 kV power source.

The 480 volt feeders for the Fire Protection System are from the 480 Volt Buses No. 312 and 313 to the 480 volt Motor Control Center G and H, respectively. Buses No. 312 and 313 are located in the Turbine Hall and Motor Control Centers G and H are located in the Fire Pump House. The motor driven fire pump normal feed is Bus No. 312 and the emergency feed is 480 volt Bus No. 5A.

These feeders run through the manual transfer switch which is used to manually transfer the feeders to the motor driven fire pump from the normal feed to the emergency feed and from the emergency feed to normal feed.

The electrical feeds to the remaining equipment installed as part of the additional facilities program are supplied through individual breakers. A provision also exists to cross-connect the Unit 2 SBO/App. R DG to the Unit 3 alternative shutdown loads; and the Unit 3 Appendix R DG to the Unit 2 alternative shutdown loads.

Chapter 8, Page 6 of 30 Revision 02, 2007

IP3 FSAR UPDATE runs, PVC heavy wall conduit encased in a concrete envelope provides maximum protection.

When cable is run in a tray, peaked covers are used in areas where physical damage to cables may result from falling objects or liquids. In addition, covers are provided on horizontal cable trays which are exposed to the sun.

Fire protection measures to prevent propagation of flame are discussed in Section 9.6-2. Fire detection is provided for areas where there are large groupings of cables in stacked cable trays.

The plant has a protective signaling system that transmits fire alarm and supervisory signals to the Control Room where audible and visual alarms are provided. The system includes signals for actuation of fire detectors, and automatic sprinkler, water spray, foam and C02 systems.

Electrical supervisory signals are received from tamper switches on fire water system control valves.

Cables and wireways are marked by means of metal tags attached at each end. These tags are embossed to conform with the identification given in the Conduit and Cable Schedule. At each multiple conductor cable termination, a plastic covering is attached which as been premarked to indicate the terminal designation of each conductor.

In addition, cable trays are marked at frequent intervals to indicate the channel number and voltage level of the tray. Color coding is discussed in Section 7.2.

In areas where missile protection could not be provided (such as near the Reactor Coolant System) redundant instrument impulse lines and cables were run by separate routes. These lines were kept as far apart as physically possible, or were protected by heavy (1/4") metal plates interposed where inherent missile protection could not be provided by spacing.

8.2.3 Emergency Power Sources Description Standby power required during plant startup, shutdown and after turbine trip is supplied from one 345kV feeder and one 138 kV feeder from the Buchanan Substation (approximately 3/4 mile from the plant) which as connections to the Millwood Substation and the Lovett Station of the Orange and Rockland system. These connections are made through the station auxiliary transformer.

In addition, there are two underground 13.8 kV feeders from the Buchanan Substation. There-ie also 1 25.4 MWV and 1 16.9 MWIV comrbuMton turbinc gonreatOr at Buchanan conncctcd to thes 13.8 k4 undcr~ground fccdcrs, and a 21 MW com~bustion turbino genor-ator leocatcd on the Indaian PEOit so The 13.8 kV feeders are connected to the 6.9 kV buses via autotransformers. If these sources should fail, the on-site sources of emergency power are three emergency diesel generator sets, each consisting of an Alco model 16-251-E engine coupled to a Westinghouse 2188 KVA, 0.8 power factor, 900 rpm, 3 phase, 60 cycle, 480 Volt generator. Each unit has a 2000 hour0.0231 days <br />0.556 hours <br />0.00331 weeks <br />7.61e-4 months <br /> and a 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> rating of 1950 kW and a 1750 kW continuous rating. There is also a vendor stated maximum 1/22 hour rating of 2000 kW. This is not an operational limit but an area of additional margin for handling power surges and spikes which may occur during testing. In addition, an alternate on-site source of power for safe shutdown loads is available from the Appendix "R" Diesel Generator which consists of an ALCO model 251 engine coupled to a KATO model 8P103600 3125 KVA, 0.8 power factor, 900 rpm, 3 phase, 60 cycle, 6900 volt Generator.

Chapter 8, Page 11 of 30 Revision 02, 2007

IP3 FSAR UPDATE immediately across Broadway. These tanks contain fuel oil for operation of combustion turbines that is compatiblc for use with the

• dicslthe Unit 2 SBO / Appendix R diesel. Each tank has a level indicator and a capacity check is made weekly. The maximum consumption of the 1P2 SBO / Appendix R diesel generator over a three day operating period is 12,500 gallons.When the9 Gcmbution turbines are boing operated, the dispatcher Will bep-...n"tifed to start oil deliveries and to keep the tanks filled. The gas turbinoS conRsume approximately 200 gallons per turbino po. hour. A truck with hose connections compatible with the underground storage tanks will be provided. If the diesels require the reserves in these tanks, the contents of these tanks would be transported by truck to the underground diesel storage tanks. Additional supplies of diesel oil are available locally.

Under normal conditions, 25,000 gallons can be delivered on a one or two-day notice. Additional supplies are also maintained in the region (about 40 miles from the plant) and are available for use during emergencies, subject to extreme cold weather conditions (increased domestic heating usage) and available transportation.

All components of the emergency diesel fuel oil supply system are seismic Class I and as such were designed in accordance with the criteria of Section 16.1. In addition, all components of the diesel fuel oil supply system are tornado protected and as such are able to withstand the design tornado and the tornado driven missiles delineated in Section 16.2. These components are also protected against the turbine missiles described in Appendix 14A of Chapter 14. The power supply and control system for the diesel fuel oil transfer system were designed in accordance with IEEE-279, meeting fully the single failure criteria specified therein.

Fuel oil for the emergency diesel generators is stored in three buried storage tanks. Each tank is equipped with a single vertical fuel oil transfer pump that discharges oil into either of two headers according to the manual valving arrangement selected. Both of these headers connect to a 175-gallon day tank mounted on each of the three diesel engines.

Decrease in level in any qne of the three day tanks to the 65 percent level automatically starts its associated fuel oil transfer pump (local manual controls are also available). The fuel oil transfer pumps are powered from motor control centers 36C, 36D, and 36E. Since each pump is capable of supplying fuel oil to all three diesels, this arrangement assures the availability of fuel oil to each diesel.

Each day tank is provided with AC normal level and low level indicating lights. In addition, each day tank has a DC low-low alarm on its respective diesel generator control panel which also annunciates a common Diesel Generator Trouble Alarm on the supervisory panels in the Control Room.

Diesel-Generator Separation The emergency diesel generators are located in a tornado-proof reinforced concrete building immediately adjacent to the Control Building.

The diesel generators are arranged on 13'-0" centers, parallel to each other with approximately 10'-0" between engine components.

The structure is provided with internal walls to separate the three diesel generators and their associated cabling and control panels from each other for fire protection.

Fire protection and detection systems for the diesel generators are discussed in Section 9.6.2.

Each control panel contains relays and metering equipment for its diesel generator. In the event of an electrical fire the event is annunciated in the main control room. With the compartmentalized diesel generator separation design, and the fire protection systems Chapter 8, Page 15 of 30 Revision 02, 2007

IP3 FSAR UPDATE Charging pumps and volume control tank with associate piping. Boric Acid transfer pumps and tanks and associated piping. Letdown station. Non-regenerative heat exchanger and associated equipment. Component Cooling and Service Water Systems. Periodic operation of one reactor coolant pump for pressurizer homogenization; the auxiliary spray/heaters could be used if necessary. Compressed air for valve operation - manual could be adopted if necessary.

The vital items of this equipment are housed within the containment and the reinforced concrete auxiliary building. The Service Water System is protected by means of redundancy. In order to guarantee the operation of the system the 480 volt system must again be assured.

It is worthy of note that with the reactor held at hot shutdown conditions, boration of the plant is not required immediately after shutdown. The xenon transient does not decay to the equilibrium level until at least 9 hours1.041667e-4 days <br />0.0025 hours <br />1.488095e-5 weeks <br />3.4245e-6 months <br /> after shutdown and a further period would elapse before the reactivity shutdown margin provided by the full length control rods have been cancelled. This delay would provide useful time for emergency measures although the essential systems are considered to be adequately protected within the auxiliary building and Containment Building. For loss of CCW due to a missile strike in the Fuel Storage Building, city water is available for hook-up (IPN-02-040).

c) Pressurizer Pressure Level Control Following a reactor trip, the primary coolant temperature will automatically reduce to the no load temperature condition as dictated by the steam generator conditions. This reduction in the primary water temperature reduces the primary water volume and if continued pressure control is to be maintained primary water makeup is required. The pressurizer pressure level is controlled in normal circumstances by the Chemical and Volume Control System. This requirement implies the charging pump duty referred to for boration plus a guaranteed borated water supply. The facility for boration is safety protected within the Primary Auxiliary Building; it is only necessary to supply water for makeup. Water may readily be obtained from separate sources: that in the volume control tank, boric acid tanks, monitor tanks, primary storage tank, and refueling water storage tank.

Similarly to the two previous service requirements, the 480 volt system must be assured with the additional electrical load of the pressurizer heaters. Vital instruments and controls are provided both locally and in the Control Room.

d) Ventilation The most essential ventilation requirements apply to the containment since in order to guarantee the satisfactory operation of the instrumentation and control systems the containment air temperature must be controlled to a tolerable level. This system again requires the satisfactory operation of the Service Water and Electrical Systems.

e) Electrical Systems Protection from tornado is provided for the 480 volt switchgear and supply redundancy is provided by the diesel generators, gas tur*b...

g,* e.ater, the two above-ground Chapter 16, Page 43 of 62 Revision 02, 2007

IP3 FSAR UPDATE incoming lines and the one below ground incoming line. The 6.9kV is fed by-eithe-the gas tubinc gne,*ator or by an underground 13.8 kV feeder from the Buchanan substation. The Buchanan substation consists of four buses.

Shutdown to Cold Condition Plant cooldown is not an immediate requirement following major damage due to a tornado. For a cooldown, the basic services required are:

a)

Residual Heat Removal b)

Reactivity Control c)

Pressurizer Pressure Level Control d)

Ventilation e)

Electrical Systems A cooldown would not be attempted until full equipment facilities had been guaranteed.

Tornado missile damage to a small bore pipe in the Containment Cooling Loop in the Fuel Storage Building (FSB) would require isolation and repair or isolation of piping.

Prior to establishing Residual Heat Removal during plant cooldown the CCW System would have to be refilled using operator action.

The Primary Water Storage Tank is available to replace lost water inventory.

Criterion III Following a Loss-of-Coolant Accident the residual heat is removed through internal recirculation conditions with the facility for external recirculation if required. The duty implies the continued operation of the Auxiliary Feedwater System together with the associated electrical and service water supplies. The recirculation systems are protected by the tornado proof containment and auxiliary buildings. The Electrical and Service Water Systems are assured by redundancy as previously discussed.

References:

(1) "Design of Protective Structures" by Arsham Amirikian, Navy Docks P-51, Bureau of Yards and Docks Department of the Navy, Washington, D.C., August 1950.

(2) TM5-855-1, Department of the Army Technical Manual, "Fundamentals of Protective Design (Non-Nuclear)," 1965.

16.3 DEMONSTRATION OF ADEQUACY OF SELECTED SEISMIC CLASS I ITEMS 16.3.1 Design of Seismic Class I Structures A multi degree-of-freedom modal analysis was performed on all Class I building structures for Indian Point 3. The results indicate that all except the containment structure are rigid.

16.3.2 Analysis of Seismic Class I Eguipment Other Than Reactor Coolant Pressure Boundary*

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