Text

TS Bases Control Program
	ML031080411
Person / Time
Site:	Crystal River
Issue date:	04/10/2003
From:	Taylor D; Progress Energy Florida
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	3F0403-04
	Download: ML031080411 (39)
	v • d • e

Progress Energy Docket No. 50-302 Operating License No DPR-72 Ref: ITS 5.6.2.17 April 10, 2003 3F0403-04 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555-0001

Subject:

Crystal River Unit 3 - Technical Specifications Bases Control Program

Dear Sir:

Progress Energy Florida, Inc. hereby submits the changes that were made to the Crystal River Unit 3 (CR-3) Improved Technical Specifications (ITS) Bases as required by ITS 5.6.2.17. The attachments provide revisions to the CR-3 ITS Bases that will update NRC copies of the ITS.

Attachment A provides the instructions for updating the CR-3 ITS.

Attachment B provides the ITS and Bases List of Effective Pages.

Attachment C provides the replacement pages for the CR-3 ITS Bases.

If you have any questions regarding this submittal, please contact Mr. Sid Powell, Supervisor, Licensing and Regulatory Programs at (352) 563-4883.

Sincerely, D. L. Taylor Manager, Support Services DLT/ff Attachments:

A.

Instructions for Updating the Crystal River Unit 3 ITS and Bases B.

ITS and Bases List of Effective Pages C.

Replacement ITS Bases Pages xc:

Regional Administrator, Region II (w/o Attachment C)

Senior Resident Inspector (w/o Attachment C)

NRR Project Manager (w/o Attachment C)

Progress Energy Florida, Inc Crystal River Nuclear Plant 15760 W Powerline Street Crystal River, FL 34428

PROGRESS ENERGY FLORIDA, INC.

CRYSTAL RIVER UNIT 3 DOCKET NUMBER 50-302/LICENSE NUMBER DPR-72 ATTACHMENT A INSTRUCTIONS FOR UPDATING THE CRYSTAL RIVER UNIT 3 ITS AND BASES

r INSTRUCTIONS FOR UPDATING THE CRYSTAL RIVER UNIT 3 IMPROVED TECHNICAL SPECIFICATIONS 4/10/03 Page(s) to be Removed Revision Page(s)

Pages(s)

ITS LOEPages (1-5)

ITS Bases LOEPages (1-8)

B 3.0-17 / B 3.0-18 B 3.0-19 B 3.3-15 / B 3.3-16 B 3.3-69 / B 3.3-70 B 3.3-71 /B 3.3-72 B 3.3-125 / B 3.3-125A B 3.4-1/B 3.4-2 B 3.7-95 / B 3.7-96 B 3.7-97 B 3.8-36 / B 3.8-37 B 3.8-38 3/27/02 3/27/02 28/28 28 22/22 202 / 202 202 / 157 22/ 178 149/22 182/ 182 182 163/ 149 149 Page(s) to be Added Revisio]

ITS LOEPages (1-5) 2/24/03 ITS Bases LOEPages (1-8) 2/24/03 B 3.0-17 / B 3.0-18 203 / 2C B 3.0-19 203 B 3.3-15 / B 3.3-16 40 / 22 B 3.3-69 / B 3.3-70 202/ 39 B 3.3-71 /B 3.3-72 206/15 B 3.3-125 / B 3.3-125A 22/39 B 3.4-1 / B 3.4-2 149 / 2C B 3.7-95 / B 3.7-96 39 / 39 B 3.7-97 / B 3.7-98 39 / 39 B 3.8-36 / B 3.8-37 39 / 39 B 3.8-38 / B 3.8-38A 39 / 39 n

13 57 04

PROGRESS ENERGY FLORIDA, INC.

CRYSTAL RIVER UNIT 3 DOCKET NUMBER 50-302/LICENSE NUMBER DPR-72 ATTACHMENT B ITS AND BASES LIST OF EFFECTIVE PAGES

CRYSTAL RIVER UNIT 3 IMPROVED TECHNICAL SPECIFICATIONS ITS LOEPage 1 of 5 2124/03 List of Effective Pages (Through Amendment 206)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page ii iii iv v

Vi vii 1.1-1 1.1-2 1.1-3 1.1-4 1.1-5 1.1-6 1.1-7 1.1-8 1.2-1 1.2-2 1.2-3 1.3-1 1.3-2 1.3-3 1.3-4 1.3-5 1.3-6 1.3-7 1.3-8 1.3-9 1.3-10 1.3-11 1.3-12 1.4-1 1.4-2 1.4-3 1.4-4 2.0-1 2.0-2 2.0-3 3.0-1 3.0-2 3.0-3 Amendment 182 161 182 182 182 182 182 149 149 149 205 149 205 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 201 149 149 149 149 Page 3.0-4 3.0-5 3.1-1 3.1-2 3.1-3 3.1-4 3.1-5 3.1-6 3.1-7 3.1-8 3.1-9 3.1-10 3.1-11 3.1-12 3.1-13 3.1-14 3.1-15 3.1-16 3.1-17 3.1-18 3.1-19 3.1-20 3.1-21 3.2-1 3.2-2 3.2-3 3.2-4 3.2-5 3.2-6 3.2-7 3.2-8 3.2-9 3.2-10 3.2-11 3.2-12 3.2-13 3.3-1 3.3-2 3.3-3 3.3-4 Amendment 203 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 152

CRYSTAL RIVER UNIT 3 ITS LOEPage 2 of 5 2/24/03 IMPROVED TECHNICAL SPECIFICATIONS List of Effective Pages (Through Amendment 206)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page 3.3-5 3.3-6 3.3-7 3.3-8 3.3-9 3.3-10 3.3-11 3.3-12 3.3-13 3.3-14 3.3-15 3.3-16 3.3-17 3.3-18 3.3-19 3.3-20 3.3-21 3.3-22 3.3-23 3.3-24 3.3-25 3.3-26 3.3-27 3.3-28 3.3-29 3.3-30 3.3-31 3.3-32 3.3-33 3.3-34 3.3-35 3.3-36 3.3-37 3.3-38 3.3-39 3.3-40 3.3-41 3.3-42 3.3-43 3.3-44 Amendment 204 149 149 149 149 149 149 149 178 152 178 149 152 149 155 206 206 149 152 149 152 149 194 194 194 149 149 149 149 149 149 199 199 149 149 177 177 149 152 196 Page Amendment 3.4-1 3.4-2 3.4-3 3.4-4 3.4-5 3.4-6 3.4-7 3.4-8 3.4-9 3.4-10 3.4-11 3.4-12 3.4-13 3.4-14 3.4-15 3.4-16 3.4-17 3.4-18 3.4-19 3.4-20 3.4-21 3.4-21A 3.4-21B 3.4-21 C 3.4-21 D 3.4-22 3.4-23 3.4-24 3.4-25 3.4-26 3.4-27 3.4-28 3.4-29 3.4-30 3.4-31 3.4-32 3.4-33 3.5-1 3.5-2 3.5-3 149 204 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 183 183 183 183 183 158 149 149 149 149 149 149 195 149 149 149 149 149 149 149

CRYSTAL RIVER UNIT 3 ITS LOEPage 3 of 5 2/24/03 IMPROVED TECHNICAL SPECIFICATIONS List of Effective Pages (Through Amendment 206)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page 3.5-4 3.5-5 3.5-6 3.5-7 3.5-8 3.5-9 3.5-10 3.6-1 3.6-2 3.6-3 3.6-4 3.6-5 3.6-6 3.6-7 3.6-8 3.6-9 3.6-10 3.6-11 3.6-12 3.6-13 3.6-14 3.6-15 3.6-16 3.6-17 3.6-18 3.6-19 3.6-20 3.6-21 3.7-1 3.7-2 3.7-3 3.7-4 3.7-5 3.7-6 3.7-7 3.7-8 3.7-9 3.7-10 3.7-11 3.7-12 Amendment 182 178 149 161 149 149 149 149 191 156 149 149 149 156 156 149 156 156 156 156 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 182 182 182 182 Page 3.7-13 3.7-14 3.7-15 3.7-16 3.7-17 3.7-18 3.7-19 3.7-20 3.7-21 3.7-22 3.7-23 3.7-24 3.7-25 3.7-26 3.7-27 3.7-28 3.7-29 3.7-30 3.7-31 3.7-32 3.7-33 3.7-34 3.7-35 3.7-36 3.7-37 3.7-38 3.7-39 3.7-40 3.8-1 3.8-2 3.8-3 3.8-4 3.8-5 3.8-6 3.8-7 3.8-8 3.8-9 3.8-10 3.8-11 3.8-12 Amendment 149 149 182 182 182 182 182 182 182 182 149 199 199 199 149 193 149 193 193 193 193 149 149 149 200 199 192 192 149 182 182 182 149 163 149 149 149 163 149 149

CRYSTAL RIVER UNIT 3 IMPROVED TECHNICAL SPECIFICATIONS ITS LOEPage 4 of 5 2/24/03 List of Effective Pages (Through Amendment 206)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page 3.8-13 3.8-14 3.8-15 3.8-16 3.8-17 3.8-18 3.8-19 3.8-20 3.8-21 3.8-22 3.8-23 3.8-24 3.8-25 3.8-26 3.8-27 3.8-28 3.8-29 3.8-30 3.8-31 3.8-32 3.8-33 3.8-34 3.9-1 3.9-2 3.9-3 3.9-4 3.9-5 3.9-6 3.9-7 3.9-8 3.9-9 3.9-10 3.9-11 3.9-12 4.0-1 4.0-2 4.0-3 5.0-1 5.0-2 5.0-3 Amendment 149 163 163 163 149 149 149 149 149 149 149 149 149 149 149 149 149 149 182 182 149 149 149 149 152 184 149 149 149 149 149 149 149 149 151 193 193 201 201 149 Paqe 5.0-4 5.0-5 5.0-6 5.0-7 5.0-8 5.0-9 5.0-10 5.0-11 5.0-12 5.0-13 5.0-14 5.0-14A 5.0-15 5.0-16 5.0-17 5.0-17A 5.0-18 5.0-19 5.0-20 5.0-21 5.0-22 5.0-23 5.0-23A 5.0-23B 5.0-24 5.0-25 5.0-26 5.0-27 5.0-28 5.0-29 5.0-30 5.0-31 Appendix B -Part II 1-1 2-1 3-1 149 149 149 149 149 201 149 191 149 149 188 188 198 180 198 198 199 199 199 185 201 204 199 199 149 180 180 149 149 191 201 149 Amendment 190 190 190

CRYSTAL RIVER UNIT 3 IMPROVED TECHNICAL SPECIFICATIONS ITS LOEPage 5 of 5 2/24/03 List of Effective Pages (Through Amendment 206)

Amendment Nos. 159, 164, 166, 171, 173, 161, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page Amendment Page Amendment 3-2 4-1 4-2 190 190 190

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 1 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 License, only, and did not effect changes to the ITS LCOs or Bases.

Operating Page B 2.0-1 B 2.0-2 B 2.0-3 B 2.0-4 B 2.0-5 B 2.0-6 B 2.0-7 B 2.0-8 B 2.0-9 B 2.0-10 B 3.0-1 B 3.0-2 B 3.0-3 B 3.0-4 B 3.0-5 B 3.0-6 B 3.0-7 B 3.0-8 B 3.0-9 B 3.0-10 B 3.0-11 B 3.0-12 B 3.0-13 B 3.0-14 B 3.0-15 B 3.0-16 B 3.0-17 B 3.0-18 B 3.0-19 B 3.1-1 B 3.1-2 B 3.1-3 B 3.1-4 B 3.1-5 B 3.1-6 B 3.1-7 B 3.1-8 B 3.1-9 B 3.1-10 B 3.1-11 B 3.1-12 B 3.1-13 B 3.1-14 B 3.1-15 Revision 34 34 34 34 201 201 34 34 37 37 149 149 149 149 149 149 149 149 149 149 149 149 28 28 28 28 203 203 203 149 149 22 17 149 149 149 149 149 149 149 149 149 149 149 Page Revision B 3.1-16 B 3.1-17 B 3.1-18 B 3.1-19 B 3.1-20 B 3.1-21 B 3.1-22 B 3.1-23 B 3.1-24 B 3.1-25 B 3.1-26 B 3.1-27 B 3.1-28 B 3.1-29 B 3.1-30 B 3.1-31 B 3.1-32 B 3.1-33 B 3.1-34 B 3.1-35 B 3.1-36 B 3.1-37 B 3.1-38 B 3.1-39 B 3.1-40 B 3.1-41 B 3.1-42 B 3.1-43 B 3.1-44 B 3.1-45 B 3.1-46 B 3.1-47 B 3.1-48 B 3.1-49 B 3.1-50 B 3.1-51 B 3.1-52 B 3.2-1 B 3.2-2 B 3.2-3 B 3.2-4 B 3.2-5 B 3.2-6 B 3.2-7 23 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 35 35 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 22 149 149 149

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 2 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page B 3.2-8 B 3.2-9 B 3.2-10 B 3.2-11 B 3.2-12 B 3.2-13 B 3.2-14 B 3.2-15 B 3.2-16 B 3.2-17 B 3.2-18 B 3.2-19 B 3.2-20 B 3.2-21 B 3.2-22 B 3.2-23 B 3.2-24 B 3.2-25 B 3.2-26 B 3.2-27 B 3.2-28 B 3.2-29 B 3.2-30 B 3.2-31 B 3.2-32 B 3.2-33 B 3.2-34 B 3.2-35 B 3.2-36 B 3.2-37 B 3.2-38 B 3.2-39 B 3.2-40 B 3.2-41 B 3.2-42 B 3.2-43 B 3.2-44 B 3.3-1 B 3.3-2 B 3.3-3 B 3.3-4 B 3.3-5 B 3.3-6 B 3.3-7 Revi si on 149 149 149 149 22 22 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 149 23 37 07 07 07 07 07 07 Page Revision B 3.3-8 B 3.3-9 B 3.3-10 B 3.3-11 B 3.3-12 B 3.3-13 B 3.3-14 B 3.3-15 B 3.3-16 B 3.3-17 B 3.3-18 B 3.3-19 B 3.3-20 B 3.3-21 B 3.3-22 B 3.3-23 B 3.3-24 B 3.3-25 B 3.3-26 B 3.3-27 B 3.3-28 B 3.3-29 B 3.3-30 B 3.3-31 B 3.3-32 B 3.3-33 B 3.3-34 B 3.3-35 B 3.3-36 B 3.3-37 B 3.3-38 B 3.3-39 B 3.3-40 B 3.3-41 B 3.3-42 B 3.3-43 B 3.3-44 B 3.3-45 B 3.3-46 B 3.3-47 B 3.3-48 B 3.3-49 B 3.3-50 B 3.3-51 178 178 07 07 30 07 22 40 22 22 22 07 178 178 07 20 31 07 07 23 07 26 23 149 149 149 149 149 149 149 149 149 149 149 149 149 182 11 178 178 22 23 11 178

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 3 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page Revi si on Page Revi sion B 3.3-52 178 B 3.3-96 31 B 3.3-53 27 B 3.3-97 194 B 3.3-54 178 B 3.3-98 23 B 3.3-55 1 1 B 3.3-99 23 B 3.3-56 23 B 3.3-1 00 149 B 3.3-57 07 B 3.3-1 01 1 7 B 3.3-58 1 6 B 3.3-102 149 B 3.3-59 23 B 3.3-1 03 149 B 3.3-60 23 B 3.3-1 04 149 B 3.3-61 149 B 3.3-1 05 149 B 3.3-62 1 6 B 3.3-106 17 B 3.3-63 37 B 3.3-1 07 17 B 3.3-64 149 B 3.3-108 149 B 3.3-65 149 B 3.3-1 09 149 B 3.3-66 149 B 3.3-1 10 149 B 3.3-67 149 B 3.3-111 17 B 3.3-68 149 B 3.3-112 149 B 3.3-69 202 B 3.3-113 35 B 3.3-70 39 B 3.3-114 1 7 B 3.3-71 206 B 3.3-115 149 B 3.3-72 157 B 3.3-116 37 B 3.3-73 1 7 B 3.3-117 1 7 B 3.3-74 07 B 3.3-118 37 B 3.3-75 07 B 3.3-119 199 B 3.3-76 24 B 3.3-120 199 B 3.3-77 24 B 3.3-121 199 B 3.3-78 07 B 3.3-122 199 B 3.3-79 07 B 3.3-1 23 199 B 3.3-80 24 B 3.3-1 24 22 B 3.3-81 23 B 3.3-125 22 B 3.3-82 07 B 3.3-125A 39 B 3.3-83 25 B 3.3-125B 35 B 3.3-84 07 B 3.3-126 22 B 3.3-85 1 7 B 3.3-1 27 22 B 3.3-86 17 B 3.3-1 28 22 B 3.3-87 07 B 3.3-1 29 178 B 3.3-88 07 B 3.3-130 178 B 3.3-89 07 B 3.3-1 31 22 B 3.3-90 17 B 3.3-1 32 22 B 3.3-91 1 7 B 3.3-1 33 22 B 3.3-92 1 7 B 3.3-134 22 B 3.3-93 20 B 3.3-1 35 22 B 3.3-94 23 B 3.3-1 36 22 B 3.3-95 07 B 3.3-1 37 174

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 4 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 License, only, and did not effect changes to the ITS LCOs or Bases.

Operating Page Revision Page Revision B 3.3-138 B 3.3-138A B 3.3-138B B 3.3-138C B 3.3-138D B 3.3-139 B 3.3-140 B 3.3-141 B 3.3-142 B 3.3-143 B 3.3-144 B 3.3-145 B 3.3-146 B 3.3-147 B 3.3-148 B 3.3-149 B 3.3-150 B 3.4-1 B 3.4-2 B 3.4-3 B 3.4-4 B 3.4-5 B 3.4-6 B 3.4-7 B 3.4-8 B 3.4-9 B 3.4-10 B 3.4-11 B 3.4-12 B 3.4-13 B 3.4-14 B 3.4-15 B 3.4-16 B 3.4-17 B 3.4-18 B 3.4-19 B 3.4-20 B 3.4-21 B 3.4-22 B 3.4-23 B 3.4-24 B 3.4-25 B 3.4-26 B 3.4-27 174 174 174 177 177 11 11 11 11 23 23 07 196 07 07 23 196 149 204 149 149 149 149 149 149 149 149 183 149 149 149 149 183 149 149 149 149 149 149 14 149 149 149 22 B 3.4-28 B 3.4-29 B 3.4-30 B 3.4-31 B 3.4-32 B 3.4-33 B 3.4-34 B 3.4-35 B 3.4-36 B 3.4-37 B 3.4-38 B 3.4-39 B 3.4-40 B 3.4-41 B 3.4-42 B 3.4-43 B 3.4-44 B 3.4-45 B 3.4-46 B 3.4-47 B 3.4-48 B 3.4-49 B 3.4-50 B 3.4-51 B 3.4-52 B 3.4-52A B 3.4-52B B 3.4-52C B 3.4-52D B 3.4-52E B 3.4-52F B 3.4-52G B 3.4-52H B 3.4-521 B 3.4-52J B 3.4-52K B 3.4-52L B 3.4-53 B 3.4-54 B 3.4-55 B 3.4-55A B 3.4-55B B 3.4-56 B 3.4-57 22 22 14 22 22 149 149 149 149 29 29 29 29 29 29 161 149 161 149 149 149 149 149 149 161 161 183 183 183 183 183 183 183 183 183 183 183 10 37 158 10 10 10 30

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 5 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 License, only, and did not effect changes to the ITS LCOs or Bases.

Operating Page B 3.4-58 B 3.4-59 B 3.4-60 B 3.4-61 B 3.4-62 B 3.4-63 B 3.4-64 B 3.4-65 B 3.4-66 B 3.4-67 B 3.4-68 B 3.4-69 B 3.4-70 B 3.4-71 B 3.4-72 B 3.4-73 B 3.4-74 B 3.5-1 B 3.5-2 B 3.5-3 B 3.5-4 B 3.5-5 B 3.5-6 B 3.5-7 B 3.5-8 B 3.5-9 B 3.5-10 B 3.5-11 B 3.5-12 B 3.5-13 B 3.5-14 B 3.5-15 B 3.5-16 B 3.5-17 B 3.5-18 B 3.5-19 B 3.5-20 B 3.5-21 B 3.5-22 B 3.5-23 B 3.5-24 B 3.5-25 B 3.5-26 B 3.5-27 Revi si on 149 149 149 149 149 33 33 179 149 149 149 149 195 37 37 37 37 149 149 17 17 149 149 149 17 182 37 06 22 37 06 25 24 24 182 22 149 161 161 149 23 149 149 149 Page Revision B 3.5-28 B 3.5-29 B 3.5-30 B 3.6-1 B 3.6-2 B 3.6-3 B 3.6-4 B 3.6-5 B 3.6-6 B 3.6-7 B 3.6-8 B 3.6-9 B 3.6-10 B 3.6-11 B 3.6-12 B 3.6-13 B 3.6-14 B 3.6-14A B 3.6-15 B 3.6-16 B 3.6-17 B 3.6-18 B 3.6-19 B 3.6-20 B 3.6-21 B 3.6-22 B 3.6-23 B 3.6-24 B 3.6-25 B 3.6-26 B 3.6-27 B 3.6-28 B 3.6-29 B 3.6-30 B 3.6-31 B 3.6-32 B 3.6-33 B 3.6-34 B 3.6-35 B 3.6-36 B 3.6-37 B 3.6-38 B 3.6-39 B 3.6-40 149 149 22 156 37 156 191 37 156 37 156 26 01 01 01 156 156 37 11 156 37 156 38 26 156 11 11 156 156 11 156 37 30 01 01 149 149 149 23 23 165 34 34 17

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 6 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 License, only, and did not effect changes to the ITS LCOs or Bases.

Operating Page Revision Page Revi si on B 3.6-41 B 3.6-42 B 3.6-43 B 3.6-44 B 3.6-45 B 3.6-46 B 3.6-47 B 3.6-48 B 3.6-49 B 3.7-1 B 3.7-2 B 3.7-3 B 3.7-4 B 3.7-5 B 3.7-6 B 3.7-7 B 3.7-8 B 3.7-9 B 3.7-10 B 3.7-11 B 3.7-12 B 3.7-13 B 3.7-14 B 3.7-15 B 3.7-16 B 3.7-17 B 3.7-18 B 3.7-18A B 3.7-18B B 3.7-19 B 3.7-20 B 3.7-21 B 3.7-22 B 3.7-23 B 3.7-23A B 3.7-23B B 3.7-24 B 3.7-25 B 3.7-26 B 3.7-27 B 3.7-28 B 3.7-29 B 3.7-30 B 3.7-31 23 24 34 34 165 149 37 149 149 149 149 149 149 149 149 17 37 37 18 149 37 17 17 17 01 01 17 23 01 37 12 12 37 22 182 182 182 182 26 26 24 149 149 22 B 3.7-32 B 3.7-33 B 3.7-34 B 3.7-35 B 3.7-36 B 3.7-37 B 3.7-38 B 3.7-39 B 3.7-40 B 3.7-41 B 3.7-42 B 3.7-43 B 3.7-44 B 3.7-45 B 3.7-46 B 3.7-47 B 3.7-48 B 3.7-49 B 3.7-50 B 3.7-51 B 3.7-52 B 3.7-53 B 3.7-54 B 3.7-55 B 3.7-56 B 3.7-57 B 3.7-58 B 3.7-59 B 3.7-60 B 3.7-61 B 3.7-62 B 3.7-63 B 3.7-64 B 3.7-65 B 3.7-65A B 3.7-65B B 3.7-66 B 3.7-67 B 3.7-68 B 3.7-69 B 3.7-70 B 3.7-71 B 3.7-72 B 3.7-73 24 16 149 149 149 149 24 24 22 182 182 182 24 24 149 182 182 24 22 149 182 163 24 24 17 149 38 149 199 199 199 199 199 199 199 199 37 25 37 193 23 193 193 37

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 7 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page B 3.7-74 B 3.7-75 B 3.7-76 B 3.7-77 B 3.7-78 B 3.7-79 B 3.7-80 B 3.7-81 B 3.7-82 B 3.7-83 B 3.7-84 B 3.7-85 B 3.7-86 B 3.7-87 B 3.7-88 B 3.7-89 B 3.7-90 B 3.7-91 B 3.7-92 B 3.7-93 B 3.7-94 B 3.7-95 B 3.7-96 B 3.7-97 B 3.7-98 B 3.8-1 B 3.8-2 B 3.8-3 B 3.8-3A B 3.8-3B B 3.8-4 B 3.8-5 B 3.8-6 B 3.8-7 B 3.8-8 B 3.8-9 B 3.8-10 B 3.8-11 B 3.8-12 B 3.8-13 B 3.8-14 B 3.8-15 B 3.8-16 B 3.8-17 Revision 193 193 37 25 37 37 37 17 17 149 149 182 199 200 182 182 192 25 192 25 192 39 39 39 39 149 17 163 163 163 17 160 149 26 182 182 26 182 182 182 182 182 149 149 Page B 3.8-18 B 3.8-19 B 3.8-20 B 3.8-21 B 3.8-22 B 3.8-23 B 3.8-24 B 3.8-25 B 3.8-26 B 3.8-27 B 3.8-28 B 3.8-29 B 3.8-30 B 3.8-31 B 3.8-32 B 3.8-33 B 3.8-33A B 3.8-33B B 3.8-34 B 3.8-35 B 3.8-36 B 3.8-37 B 3.8-38 B 3.8-38A B 3.8-39 B 3.8-40 B 3.8-41 B 3.8-42 B 3.8-43 B 3.8-44 B 3.8-45 B 3.8-46 B 3.8-47 B 3.8-48 B 3.8-49 B 3.8-50 B 3.8-51 B 3.8-52 B 3.8-53 B 3.8-54 B 3.8-55 B 3.8-56 B 3.8-57 B 3.8-58 163 22 15 149 163 22 149 17 160 149 149 157 182 182 182 37 163 163 163 163 39 39 39 39 34 34 34 34 08 23 23 08 34 34 149 149 149 149 149 149 149 149 149 149 Revi si on

CRYSTAL RIVER UNIT 3 ITS Bases LOEPage 8 of 8 2/24/03 IMPROVED TECHNICAL SPECIFICATION BASES List of Effective Pages (Through Amendment 206 and ITS Bases Revision 40)

Amendment Nos. 159, 164, 166, 171, 173, 181, 189 and 190 amended the CR-3 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page B 3.8-59 B 3.8-60 B 3.8-61 B 3.8-62 B 3.8-63 B 3.8-64 B 3.8-65 B 3.8-66 B 3.8-67 B 3.8-68 B 3.8-69 B 3.8-70 B 3.8-71 B 3.8-72 B 3.8-73 B 3.8-74 B 3.8-75 B 3.8-76 B 3.8-77 B 3.8-78 B 3.8-79 B 3.8-80 B 3.9-1 B 3.9-2 B 3.9-3 B 3.9-4 B 3.9-5 B 3.9-6 B 3.9-7 B 3.9-8 B 3.9-9 B 3.9-10 B 3.9-11 B 3.9-12 B 3.9-13 B 3.9-14 B 3.9-15 B 3.9-16 B 3.9-17 B 3.9-18 B 3.9-19 B 3.9-20 B 3.9-21 B 3.9-22 Revi si on 17 149 149 149 149 149 149 149 149 149 182 26 182 26 26 182 149 149 149 149 149 149 149 149 149 149 33 33 07 33 184 37 37 184 184 149 149 149 149 149 149 149 149 149 Page Revi si on B 3.9-23 B 3.9-24 B 3.9-25 37 37 37

PROGRESS ENERGY FLORIDA, INC.

CRYSTAL RIVER UNIT 3 DOCKET NUMBER 50-302/LICENSE NUMBER DPR-72 ATTACHMENT C REPLACEMENT ITS BASES PAGES

SR Applicability B 3.0 I

BASES SR 3.0.2 (continued) 25% extension applies to each performance after the initial performance. The initial performance of the Required Action, whether it is a particular Surveillance or some other remedial action, is considered a single action with a single Completion Time.

One reason for not allowing the 25% extension to this Completion Time is that such an action usually verifies that no loss of function has occurred by checking the status of redundant or diverse components or accomplishes the function of the inoperable equipment in an alternative manner. -

The provisions of SR 3.0.2 are not intended to be used repeatedly merely as an operational convenience to extend Surveillance intervals or periodic Completion Time intervals beyond those specified.

SR 3.0.3 SR 3.0.3 establishes the flexibility to defer declaring affected equipment inoperable or an affected variable outside the specified limits when a Surveillance has not been completed within the specified Frequency. A delay period of up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified

-Frequency, whichever is greater, applies from the point in time that it is discovered that the Surveillance has not been performed in-accordance with SR 3.0.2, and not at the time that the specified Frequency was not met.

I This delay period-provides an adequate time limit to complete Surveillances that have been missed.

This delay period permits the completion of a Surveillance before complying with Required Actions or other remedial measures that might preclude completion of the Surveillance. The basis for this delay period includes-consideration of unit conditions, adequate planning, availability of personnel, the time required to-perform the Surveillance, the safety significance of the delay in completing the required Surveillance, and the recognition that the most probable result of any particular Surveillance being performed is the verification of conformance with the SRs.

When a Surveillance with a Frequency based not on time intervals, but upon specified unit conditions, operating situations, or requirements of regulations (e.g., prior to entering MODE 1 after each fuel loading, or in accordance with 10 CFR 50, Appendix J, as modified by approved exemptions, etc.) is discovered to not have been performed when specified, SR 3.0.3 allows for the full delay period of up to the specified Frequenc to perform the Surveillance.

However, since there is not a time interval specified, the missed Surveillance should be performed at the first reasonable opportunity.

(continued)

Crystal River Unit 3 B 3.0-17 Amendment No.

203

SR Applicability B 3.0 BASES SR 3.0.3 SR 3.0.3 provides a time limit for, and allowances for the (continued) performance of, Surveillances that become applicable as a consequence of MODE changes imposed by Required Actions.

Failure to comply with specified Frequencies for SRs is expected to be an infrequent occurrence.

Use of the delay period established by SR 3.0.3 is a flexibility which is not intended to be used as an operational convenience to extend Surveillance intervals. While up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or the limit of the specified Frequency is provided to perform the missed Surveillance, it is expected that the missed Surveillance will be performed at the first reasonable opportunity. The determination of the first reasonable opportunity should include consideration of the impact on pant risk (from delaying the Surveillance as well as any plant configuration changes required or shutting the plant down to perform the Surveillance) and impact on any analysis assumptions, in addition to unit conditions, planning, availability of personnel and the time required to perform the Surveillance. This risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementing guidance, NRC Regulatory Guide 1.182, "Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants." This Regulatory Guide addresses consideration of temporary and aggregate risk impacts, determination of risk management action thresholds,-aWd risk management action up to and including plant shutdown. The missed Surveillance should be treated as an emergent condition as discussed in Regulatory Guide 1.182. The risk evaluation may use quantitative, qualitative, or blended methods. The degree and depth and rigor of the evaluation should be commensurate with the importance of the component. Missed Surveillances for important components should be analyzed quantitatively. If the results of the risk evaluation determine the risk increase is significant, this evaluation should be used to determine the safest course of action. All missed Surveillances will be placed in the licensee's Corrective Action Program. Refer to the Master Surveillance Plan for additional guidance for missed surveillances.

If a Surveillance is not completed within the allowed delay period, then the equipment is considered inoperable or the variable is considered outside the specified limits and the Completion Times of the Required Actions for the applicable Specification Conditions beain immediately upon expiration of the delay period. If a Surveillance is failed within the delay period, then the equipment is inoperable, or the variable is outside the specified limits and the Completion Times of the Required Actions for the applicable Specification Conditions begin immediately upon the failure of the Surveillance.

Completion of the Surveillance within the delay period allowed by this Specification, or within the Completion Time of the ACTIONS, restores compliance with SR 3.0.1.

(continued)

Crystal River Unit 3 B 3.0-18 Amendment No. 203

-1,

., I,

) -

SR Applicability B 3.0 BASES SR 3.0.4 SR 3.0.4 establishes the requirement that all applicable SRs must be met.'before-entry~i'nto a'MODE or other specified condition in the'Appifca bility>:,'*.

This Specification' ensu'resthat'system and component OPERABILITY requirehients1-and variablevlimits are met before entry into MODES or other.spec'ifie'd'conditions in the Applicability for,'jhich `these' sysifehs and components ensure safe operation of:Ehe',dnit-. iThis Specification applies to changes in MODES 6r:.other specified conditions in the Applicability,.associated_'ith'unit shutdown as well as startup.

However,iJn` certain circumstances, failing to meet an SR will not result in SR' 3.0.4 restricting a MODE change or other specified cobndition 'chanoe.- When a system, subsystem, train,, component,: device, or variable is

-inoperable or2'outside its specified limits, the associated SR(s),are not required o, be performed (per SR 3.0.1).

Surveillances-,do-not have to be performed on inoperable equipment. When 'equipment is inoperable, SR 3.0.4 does not apply-to'the -associated SR(s) since the requirement for the SR(s) to be performed is-removed.,.

i Therefore, failing ;to perform the Surveillance(s) within the specifdFrequencyd does'not'result in an SR 3.0.4 restricti'6ri to charnging MODES"or other specified conditions of the AipIlcabil'ty,.~'HoweverV'since the LCO is not met in this instance,'-LCGa-3.O;4 1will' gov'ern any restrictions that

-may (or may not)',pp1'y;to'iODE or other specified condition

,changes.

a'a-The.provisions bfSR,3.0.4 shall not-prevent entry into

-.MODES or other pecified con'ditionsin the Applicability that'are rrequired to'comply with.ACTIONS.

The preciseirequirements forperformance of SRs are

- ->specified such that exceptions to -SR 3.0.4 are not

-- necessary. '-The specific 'time frames and conditions

- - necessary for meeting the-SRs,-inaccordance with the requirements of SR 3.0.4 are specified in the Frequency, in

-K. -'

a,; -thecSurveillanceFor both.- This allows performance of x r.,Surveillances when.the. prerequisite condition(s) specified

' -iin a, Surveillance.procedureirequire entry into the MODE or

~f'6therX'specified condition in the'Applicability of the assbciated:-Specification priori to the performance or completion of:a Surveillance.

A Surveillance that could not be'performed until after-entering the Specification Applicability w6old-:have its Frequency specified such that it is not "due" buftil"the specific conditions needed are met.

Alternately.'the Surveillance may be stated in the form of a Note, as not required to be performed until a particular event, condition, or time has been reached. The SRs are anhotated'consistent with the requirements of Section 1.4, Frequency.

Crystal River Unit 3 B 3.0-19 Amendment No.

203

RPS Instrumentation B 3.3.1 BASES APPLICABLE

6.

Reactor Building High Pressure (continued)

SAFETY ANALYSES, LCO, and The Allowable Value for RB High Pressure trip is at APPLICABILITY the lowest value consistent with avoiding spurious trips during normal operation. The electronic components of the RB High Pressure trip are located in an area outside the RB and are not exposed to high temperature steam environments during a LOCA.

However, the components would be potentially exposed to high radiation levels. Therefore, the determination of the setpoint Allowable Value accounts for errors induced by the high radiation.

7.

Reactor Coolant Pump Power Monitors The Reactor Coolant Pump Power Monitor (RCPPM) tri provides protection for changes in the reactor coolant flow due to the loss of multiple RCPs. Because the flow reduction lags loss of power indications due to the inertia of the RCPs, the trip initiates protective action earlier than a trip based on a measured flow signal.

The trip also prevents single loop operation (operation with both pumps in an RCS loop tripped).

Under these conditions, core flow and core fluid mixing are insufficient for adequate heat transfer.

The RCPPM trip has been credited in the accident analysis calculations for the loss of four RCPs. The monitors were added as part of a previous power level upgrade (2452 to 2544 MWth ) to provide DNB protection at greater than 2475 MWth. Analyses has shown this trip Function is not necessary when conditions are such that THERMAL POWER is less than 2475 MWth and four RCPs are in operation (Ref. 8).

The Allowable Value for the Reactor Coolant Pump to Power trip setpoint is selected to prevent normal power operation unless at least three RCPs are operating. RCP status is monitored by two power transducers on each pump. The allowable values for the Reactor Coolant Pump Power Monitors are selected to trip the reactor if more than one RCP is drawing 2

Ž 14,400-kW or-< 1152 kW. The overpower setpoint is selected low enough to detect locked rotor conditions (although credit is not allowed for this capability) but high enough to avoid a spurious trip due to the current associated with start of an RCP. The underpower Allowable Value is selected to reliably trip on loss-of voltage to the RCPs. The RCPPM setpoints do not account for instrumentation errors

-caused by harsh environments because the trip Function is not required to respond to events that could create harsh environments around the equipment.

(conti nued)

Crystal River Unit 3 B 3.3-15 Revision No.

40

RPS Instrumentation B 3.3.1 BASES APPLICABLE

7.

Reactor Coolant Pump Power Monitors (continued)

SAFETY ANALYSES, LCO, and There are two pump power monitors provided for each APPLICABILITY RCP.

Both monitors are required to satisfy the (continued) instrumentation'channel requirements of this LCO.

The RPS RCPPMs act as the sensors for the EFIC (Emergency Feedwater Initiation and Control System)

RCP Status function by providing a loss of RCP indication to each EFIC channel. When a minimum of two EFIC channels recognize a loss of all RCPs, EFIC will automatically actuate EFW (Emergency Feedwater System) and control level to natural circulation level in the OTSG (Once'Through Steam Generator).

8.

Nuclear Overpower RCS Flow and Measured AXIAL POWER IMBALANCE The Nuclear Overpower RCS Flow and Measured AXIAL POWER IMBALANCE trip provides steady state protection for the powerjimba-lancq SLs. A reactor trip is initiated when neutron power AXIAL POWER IMBALANCE, and reactor coolant flow conditions indicate an approach to DNB or fuel centerline melt limits.

This trip supplements the protection provided by the Reactor Coolant Pump Power trip, through the power to flow ratio, for loss of reactor coolant flow events.

The power to flow ratio provides direct protection for the DNBR'SL for the loss of a single RCP and for locked RCP rotor accidents. The imbalance portion of the trip is credited for steady state protection only.

The power to flow ratio of the Nuclear Overpower RCS Flow and Measured AXIAL POWER IMBALANCE trip also provides steady state protection to prevent reactor power from exceeding the-allowable power during three pump operation. Thus, the power to flow ratio prevents overpower conditions similar to the Nuclear Overpower trip. This protection ensures that during reduced flow conditions the core power is maintained below that required to initiate DNB.

(continued)

Crystal River Unit 3 B 3.3-16 Revision No. 22

EDG LOPS B 3.3.8 BASES LCO (continued)

FLURs The FLURs instrumentation associated with each ES.4160 V bus is required to be OPERABLE:.upon. a loss of voltage. For each voltage value, theaassociated channel responsetime is based on the physical characteristics of the loss of voltage sensing relays.iThe. loss of voltage channels respond to a complete loss of'ES bus voltage, providing automatic starting and loading'of the associated EDG. However, their response time is not critical to the overall ES equipment response time following an actuation, since the SLURs instrumentation-will also respond to the complete loss of

'voltage, and will'do-so earlier than the loss of voltage instrumentation. Upon a complete loss of voltage from full voltage to O.OV, -thq loss of voltage relays will respond in 7.8 seconds with a tolerance of 7% or +/- 0.55 seconds.

APPLICABILITY The EDG LOPS actuation Function for each EDG shall be OPERABLE in MODES 1,

,2, 3, and 4 to provide protection for equipment'powered from the Class lE AC Electrical Power Distribution System in these MODES. The ability to start the EDG or -'a:degraded`o'r loss rof voltage condition is also required'fdorthe".EDG'r'equired.'to be OPERABLE by LCO 3.8.2, "AC Sources-Shutdown." -

ACTIONS A Note has'been added to the.ACTIONS indicating that separate Condition entry-is allowed for each Function. Since the required channels are specified on a per EDG basis, the Condition may be entered-separately for each EDG.

i

-vat P

A.1

-^-

A loss of one channel of loss of voltage CFLUR) Function rpsults in a loss'6f redundancy for that Function, e.g., the two remaining operable 'channels are'still capable of providing an EDG start signal assuming no additional single fai'lures.* With one channel of loss of voltage Function inoperable, the channel must-be restored to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .,',The 72 hour-Completion Time is reasonable to evaluate and-take action to correct the degraded condition in an-orderly manner, and is consistent with the allowed outage time for a loss of redundancy condition for other safety systems.

(continued)

Crystal River Unit 3 B 3.3-69 Amendment No. 202

EDG LOPS EDG LOPS B 3.3.8 BASES ACTIONS B.1

-A loss of one or more channels of degraded voltage (SLUR)

Function, results in a loss of safety Function.

With up to two channels of degraded voltage Function (SLUR) per EDG

-inoperable, the channel(s) must be tripped within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Since there is no installed trip for the SLUR relays, a more liberal reading of the requirements is that the function of the relay must be accomplished and maintained. This involves jumpering the relay or taking other action such that the function is accomplished. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time is reasonable to evaluate and to take action to correct the degraded condition in an orderly manner and takes into account-the low probability of an event requiring this instrumentation occurring during this interval.

C.1 Condition C applies when; two or more undervoltage or all three degraded voltage channels associated with a single ES 4160 V bus are inoperable.

With two or more FLUR channels or three SLUR channels inoperable, the logic is not capable of providing an automatic EDG LOPS signal for valid loss of voltage or degraded"voltage conditions.

Tripping the inoperable channels'is not a viable'Action for'this Condition since

'doing so would result in an EDG start.

In addition, it is unlikely that repair/restoration of multiple failed channels could be accomplished in an acceptable time frame for a condition representing a loss of the affected Function.

Therefore, Required Action C.1 requires that the EDG associated with the inoperable FLUR or SLUR be declared inoperable.

Depending on MODE, the Actions specified in LCO 3.8.1, "AC Sources-Operating," or LCO 3.8.2, are required to be entered immediately.

(continued)

Crystal River Unit 3 B 3.3-70 Revision No. 39

EDG LOPS B 3.3.8 BASES ACTIONS D.1 and D.2 (continued)

If the inoperable channel cannot be restored to OPERABLE status within-the associated Completion Time, the plant must be placed in at least MODEK3,within-.6hours and in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .* sThe all6wed^Completion Times are reasonable, basedron operating experience, to reach the required MODES from full-power conditions in an orderly manner and without challenging plant systems.

E.1 Condition E-is. the-default'Condition should Required Action A.1 or B.1 not 'be met within the associated Completion Time.

Required Action E.1 ensures that Required Actions for affected diesel generator inoperabilities are initiated.

Depending on MODE, the Actions-specified in LCO 3.8.1, "AC Sources-Operating," or LCO 3.8.2, are required to be entered immediately.'

SURVEILLANCE SR 3.3.8.1.

REQUIREMENTS A CHANNEL FUNCTIONAL TEST isperformed' on each required EDG LOPS channel to ens'ure the entire channel will perform the intended functioni.- This test ensures functionality of each

'channel to output relays.

The Frequency of 31 days is considered reasonable based on lthe'reliability of the.components 'nd on operating experience.

r NA6~e has'been added -to allow performance of the SR without taking the ACTIONS for inoperable instrumentation channels although during this'time period the relay instrumentation cannot initiate a diesel start. This allowance is based on the assumption that the EDG is maintained inoperable during this functional test and the appropriate actions for the inoperable EDG are entered.

(conti nued)

Crystal River Unit 3 B 3.3-71 Amendment No.

206

EDG LOPS B 3.3.8 BASES (continued)

SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.8.2 A CHANNEL CALIBRATION is a complete check of the instrument channel, including the sensor. The setpoints and the response to a loss of voltage and a degraded voltage test-shall include a single point verification that the trip occurs within the required delay time, as shown in Reference 2.

The 18 month Frequency is based on operating experience and industry-accepted practice.

A Note has been added indicating the voltage sensing device (bus potential transformer) may be excluded from testing since these transformers are passive, inherently stable devices which cannot be calibrated.

In the event of transformer failure, the corresponding degraded voltage or loss of voltage relays would trip on low voltage, actuating the associated channel (i.e., the channels fail in the safe condition).

In addition, annunciation of failure of a single transformer or associated circuits would be provided via the channel monitor relay, identifying to the operator a failure within the loss of voltage or degraded voltage channels.

REFERENCES

1.

FSAR, Chapter 14.

2.

FSAR, Section 8.3.

Crystal River Unit 3 B 3. 3-72 Amendment No. 157

PAM Inst rumentati on PAM Instrumentation B 3.3.17 BASES I __

APPLICABLE PAM instrumentation that-is determined to display a SAFETY-ANALYSES Regulatory Guide 1.97 Type A variable, satisfies Criterion 3 (continued) of the NRC Policy Statement.'Category 1, no'n-Type At instrumentation does not meet any of the criterion in the NRC Policy Statement. H6oweVer,-itis retained in Technical Specifications because itris, considered important to reducing risk to the public.'

LCO LCO 3.3.17 requires redundant channels-be OPERABLE to ensure no single failure prevents the'operators from being presented with the information necessary to determine the status of'the'unit and to bring the unit to, and maintain it in, a safe -condition following that-accident. The provision of two channels also allows for relative comparison of the channels (a CHANNELCHECK type of qualitative assessment) during the post accident phase to confirm the validity of displayed'information.' '

e cf t

An-exception to the two channel requirement is containment

'isolation valve. position. In this case, the important information is t eistatus' of the containment penetration.

The LCO requires'one position'indicator for each automatic containment isolation valve.'This is sufficient to redundantly verifyfthe isolation status of each isolable penetrati'o'neither via indicated 'status-of the automatic valve and prior'kndwledge of'the passive valve or via system boundary status". If,-a'normally active containment isolation valve is known to.be' closed-and deactivated, position indication is not needed to determine status. Therefore, the position indication for valves in this state is not required to 'be OPERABLE.'

Another exception'to the redundant channel requirement pertains to the reactor coolant inventory and pressurizer level variables. iVarious SSCs have been identified that are not p'rotected from the jet impingement and/or pipe whip effects of certain LOCAs. Among these are several-

'components"associated

'with RG 1.97-Post Accident Monitoring Instruments providing pressurizer level indication, and hot leg and reactor vessel level indication for assessing reactor coolant inventory. The subject instruments would be rendered non-functional as a result of the failure of the target SSCs.

Therefore, a consequential failure of these instruments due to a LOCA along with a single failure in the redundant train.would not satisfy RG 1.97 Category 1 redundancy requirements. However, the failure of these instruments due to the effects of a LOCA does not violate the LCO requirements for operability on the basis that an instrument need not be declared inoperable during normal operation if the instrument has no accident mitigation function for the specific LOCA causing its failure.

Details on the basis for this assessment are provided in the discussion for reactor coolant inventory and pressurizer level (Items 4 and 13, respectively).

(conti nued)

Crystal River Unit 3 B 3.3-125 Revision No. 22

PAM Instrumentation B 3.3.17 BASES The following table identifies the specific instrument tag numbers for PAM instrumentation identified in Table 3.3.17-1.

FUNCTION CHANNEL A CHANNEL B

1.

Wide Range Neutron Flux NI-15-NI-1 or NI-15-NIR NI-14-NI-1

2.

RCS Hot Leg Temperature RC-4A-TI4-1 RC-48-TIR1

3.

RCS Pressure(Wide Range)

RC-158-PI2 or RC-158-PIR RC-159-PI2

4.

Reactor Coolant RC-163A-LR1 (Hot leg level) and RC-163B-LR1 (Hot leg level) and Inventory RC-164A-LR1 (Vessel Head level)

RC-164B-LR1 (Vessel Head level)

5.

Borated Water Storage DH-7-LI or DH-7-LIR1 DH-37-LI Tank Level

6.

High Pressure Injection Al:

MU-23-FI8-1 Al:

MU-23-FI12 Flow A2:

MU-23-FIIO A2:

MU-23-FI6-1 B1:

MU-23-FI9 B1:

MU-23-FIS-1 B2:

MU-23-FI7-1 B2:

MU-23-FI11

7.

Containment Sump Water WD-303-LI or WD-303-LR WD-304-LI or WD-304-LR Level (Flood Level)

8. Containment Pressure BS-16-PI BS-17-PI (Expected Post-Accident Range)

9.

Containment Pressure BS-90-PI or BS-90-PR BS-91-PI or BS-91-PR (Wide Range)

10. Containment Isolation ES Light Matrix "A": AHV-lB/lC; ES Light Matrix "B": AHV-IA/lD; Valve Position CAV-1/3/4/5/126; CAV-2/6/7/431; CFV-11/12/15/16; LRV-70/72; MUV-CFV-29/42; LRV-71/73; MUV-258 thru -261/567;WDV-3/60/94/

18/27/49/253; WDV-4/61/62/405; 406; WSV-3/5 WSV-4/6 ES Light Matrix "AB": CFV-25 thru-28; CIV-34/35/40/41; DWV-160; MSV-130/148; SWV-47 thru 50/79 thrn 86/109/110

11. Containment Area RM-G29-RI or RM-G29-RIR RM-G30-RI Radiation (High Range)

12. Containment Hydrogen WS-11-CR WS-10-CR Concentration

13. Pressurizer Level RC-1-LIR-1 RC-1-LIR-3

14. Steam Cenerator Water OTSG A: SP-25-LI1 or OTSG A:

SP-26-LI1 Level (Startup Range)

SP-25-LIR OTSG B:

SP-30-LI1 OTSG B:

SP-29-LI1 OR SP-29-LIR (continued)

Crystal River Unit 3 B 3.3-125A Revision No. 39

RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.1 RCS Pressure, Temperature,-and Flow Departure from Nucleate Boiling (DNB) Limits BASES

.j

-I.

BACKGROUND These Bases address requirements-for maintaining RCS pressure, temperature, and flow rate Within-the limits assumed in the safety analyses. The analyses of normal operating conditions, including anticipated operational occurrences assume initial conditions within the normal steady state envelopei.-'The limits placed on DNB related parameters ensure-that-these parameters will not be less conservative than-were-assumed in the-analyses and thereby provide assurance that the minimum departure from nucleate boiling ratio (DNBR) will meet the required criteria for each of the transients analyzed.

I,

0 The RCS'pressure limit is consistent with operation within the nominal operating enVelope and is above the value used as the initial pressure in the analyses. - A pressure greater than the Tminimui specified will produce a higher DNBR. A pressure lower than the minimum specified will cause the plant to approach-the DNB limit.

The RCS coolant hotileg-temperature limit is consistent with full powi'er operation-within'the nominal operating envelope and is lower than the -initialhot leg temperature in the

'analyses. -A hot leg-temperature lower than that specified will produce a higher DNBR.' -A temperature higher than that i--

specified will cause the plant to approach the DNB limit.

, The RCS flow rate is a function of the number of RCPs in operation and is not expected'to vary during operation.

The minimum RCS flow rate limit corresponds to that assumed for

--the-,DNBR analyses-.- A-higher RCS flow rate will produce a higher DNBR.

A lower RCS flow will cause the plant to

.approach the DNBiimnit.

APPLICABLE The requirements of LCO 3.4.1 represent the initial SAFETY ANALYSES conditions for DNB limited transients analyzed in the plant safety analyses (Ref. 1).

The safety analyses have shown (continued)

Crystal River Unit 3 a B 3. 4-1 Amendment No.

149

RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES APPLICABLE that transients initiated from the limits of this LCO will SAFETY ANALYSES meet the event-specific DNBR acceptance criterion. This is (continued) the acceptance-limit for the RCS DNBR parameters. The transients analyzed for include loss of coolant flow events and dropped or stuck control rod events.

A key assumption for the analysis of these events is that the core power distribution is within the limits of LCO 3.2.1, "Regulating Rod Insertion Limits," LCO 3.2.2, "APSR Insertion Limits,"

LCO 3.2.3, "AXIAL POWER IMBALANCE OPERATING LIMITS," and

'LCO 3.2.4, "QUADRANT POWER TILT."

For full power conditions, limits are set on loop parameters' to meet the'DNBR criterion. The minimum core outlet pressure is the limit value in the reactor coolant loop as measured at the hot leg pressure tap.

The maximum hot leg temperature specified is the limit value as measured at the hot'leg resistance temperature detector.

The minimum volumetric flow rate corresponds to the mass flow rate for four' RCP operation at full power.

Additionally, analyses have been performed to establish the pressure, temperature, and flow rate requirements for three pump operation.

The flow limits for three pump operation are approximately 25% lower" than the four pump limits. To meet the DNBR criterion,' a corresponding maximum power limit of less than the top of the "doghouse" (Power-Imbalance-Flow trip setpoint contained in the COLR) is required in combination with thie 3 pump limits (see Bases for LCO 3.3.1, "RPS Instrumentation").

RCS DNB limits satisfy Criterion 2 of the NRC Policy Statement.

LCO Limits on RCS loop (hot leg) pressure, RCS hot leg temperature, and RCS total flow rate ensure that the core (conti nued)

Crystal River Unit 3 B 3.4-2 Amendment No. 204

Diesel Driven EFW Pump Fuel Oil, Lube Oil and Starting Air I IB 3.7.19 BASES SURVEILLANCE REQUIREMENTS SR 3.7.19.3 (continued)

Ho new fuel to the storage, tank(s),-but-in no case is the time between receipt of newfuel and conducting the tests to exceed 31 days. Receipt of.fuel oil without testing results may be authorized by the Emergency-Coordinator, provided the vendor's.certificate'of conformance is in accordance with procurement specifications. In this case, fuel oil samples should be,-taken from the delivery, with test results to be documented within 31 days. The tests, limits, and applicable ASTM Standards are as follows:

a.

Sample the newfuel in accordance with ASTM D4057-88 (Ref. 6),

b~.

Verifyin'accordance with the tests specified in ASTM D975-70,' (Refi. 7) that the new fuel oil sample has:

.4 A

4,

1.

A maxiimummof 0.05% by volume water and sediment per ASTM D2709-82 (Ref. -11);

l OR. -

j 1

I

)

Yd I

_ 1, A-maximum-of 0.05% by volume water and sediment I

per ASTM D1796-83 (Ref.,512);

-2.

II -

'4 -

A Saybolt viscosity-at 1000F of 2 32.6 SUS and <

.40.1 SUS~per ASTM'-D888,81-(Ref. 13)

OR A Kinematic viscosity at 400C of > 1.9 mm/s and S 4.1 mm/s per ASTM D445-88 (Ref. 14); conversion to SUS units is-required, and can be made using

-ASTMED2161-93 (Ref. 15);

.. I I

.. I

..-.I,

-3. A flash point of 2 1250F per ASTM D93-94 Procedure "A", Manual or Automated Method 16);

(Ref.

c.

Verify in-accordance with the test specified in ASTM D287-92-(Ref. 17) that the new fuel has an API specific gravity of > 28 and < 38; OR (continued)

Crystal River Unit 3 B 3.7-95 Revision No. 39

Diesel Driven EFW Pump Fuel Oil, Lube Oil and Starting Air B 3.7.19 BASES SURVEILLANCE SR 3.7.19.3 (continued)

REQUIREMENTS Verify in accordance with the test specified in ASTM D1298-85 (Ref. 18) that the new fuel has an API specific gravity of,> 28 and < 38;

.t

d.

Verify in accordance with the test specified in ASTM D4176-91 (Ref. 19) and ASTM D1500-91 (Ref. 20) that the new fuel oil has a clear and bright appearance with proper color; OR Verify in accordance with the test specified in ASTM D2276-91 (gravimetric method) (Ref. 21) that the new fuel oil has a total particulate contamination of < 10 mg/L.

Failure to meet any' of the above limits is cause for rejecting the new fuel oil, but does not represent a failure to meet the'LCO concern since the fuel oil is not added to the storage tank.

Within 31 days following the initial new fuel oil sample, the fuel oil is analyzed to establish that the other properties specified in Table 1 of ASTM D975-00, (Ref. 7),

are met for new fuel oil when tested in accordance with ASTM D975-00, (Ref.-7), 'except that a calculated Cetane Index,'per ASTM D4737-90 (Ref. 9), is determined to estimate the actual Cetane Number. Also, Cloud Point is to be determined using ASTM D2500-91 (Ref. 8). If the Cetane Index is not met, then a sample of fuel is tested in accordance with ASTM D613-93 (Ref. 10) to determine Cetane Number. The 31 day period is acceptable because the fuel oil properties of interest, even if they were not within stated limits, would not have an immediate effect on DD-EFW Pump operation. This Surveillance ensures the availability of high quality fuel oil for the DD-EFW Pump diesel engine.

Fuel oil degradation during long-term storage is typically detected as an increase in particulate, due mostly to oxidation. The presence of particulate does not mean the fuel oil will not burn properly in a diesel engine.

However, the particulate can cause fouling of filters and fuel oil injection equipment which can cause engine failure.

(continued)

Crystal River Unit 3 B 3.7-96 Revision No. 39

Diesel Driven EFW Pump Fuel Oil, Lube Oil and Starting Air B 3.7.19 BASES SURVEILLANCE REQUIREMENTS SR 3.7.19.3 (continued)

Particulate concentrationsshould be determined in accordance with ASTM-D2276-91, Method A (Ref.

21). This method involves a gravimetric'-determination of total particulate concentration in the fuel oil. It is acceptable to obtain a field sample'for subsequent laboratory testing in lieu of field testingg.

The Frequency of this SR'takes into consideration fuel oil degradation trends that indicate that particulate concentration is unlikely to change significantly between tests.

I

~.

SR 3.7.19.4 This Surveillance ensures that, without the aid of the re-fill 'c6mpressro'r,-"sufficient,air start capacity for the DD-EFW,Pump0dieselengine is available. The design requirementsproVid6 for a,niinimum of six engine start cycles with6bt'recharging. The pressure specified in this SR reflects thejowest value at which the six starts can be accomplished.;,

The 31 day,Frequency takes into account the capacity, capabilityu-andothe'r indications available in the control room for DD-EFW Pump start readiness, including alarms, to

.,alert the operator'to below 'normal-air start pressure. In addition, the system design includes-a feature to

'automatically start the air compressors on low air

, pressure.

' ^

I I

, I

. I.

I I

(continued)

Crystal River Unit 3 S 3.7-97 Revision No. 39

Diesel Driven EFW Pump Fuel Oil, Lube Oil and Starting Air B 3.7.19 BASES REFERENCES 1.,

FSAR,-Section" 10.5.

2. ~Regulatory Guide 1.137.

3.

ANSI N195-1976, Appendix B.

4.

FSAR, Chapter 6.

5.

FSAR, Chapter;14.

6.

ASTM Standard, D4057-88.

7.

ASTM Standard, D975-00.

8.

ASTM Standard, D2500-91.

9.

ASTM Standard, D4737-90.

10.

ASTM Standard, D613-93.

11.

ASTM Standard, D2709-82>

12.

ASTM Standard, D1796-83.'

13.

ASTM Standard, D88-81.

14.

ASTM Standard, D445-88.-

15.

ASTM Standard, D2161-93.

16.

ASTM Standard, D93-94.

17.

ASTM Standard, D287-92.

18.

ASTM Standard, D1298-85.

19.

ASTM Standard, D4176-91.

20.

ASTM Standard, D1500-91.

21.

ASTM Standard, D2276-91.

22.

ASTM Standard, D2274-88.

Crystal River Unit 3 B 3.7-98 Revision No. 39

i, Diesel Fuel Oil, Lube Oil, and Starting Air I

B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.3.2 This Surveillance ensures that sufficient lube-oil inventory is available-'to'sup'pdr-t at least 7 days of operation of a single EDG at the upper limit of its 200-hour rating. The 280 gallon-requirement is based on the EDG manufacturer consumption values for the run time of the EDG.

The specified volume-includes-the lube oil contained in the sump as well as the onsite'stored stock. As such, implicit in this SR is the requirement to verify the capability to transfer the lube oil from its storage location to the EDG.

When determining compliance with this requirement, both EDGs may take credit for the same volume of onsite stored lube oil.

A 31 day Frequencytis adequate to ensure that a sufficient lube oil supply, is onsite, since EDG-starts and run time are closely monitored by the plant-staff.

SR 3.8.3.3 The tests'listed"belobw-are a means of determining whether new fuel oil is of the appropriate grade and has not been contaminated with substances that would have an immediate, detrimental impact on diesel engine combustion. If results from thesel-tests;arezwithin acceptable limits, the fuel oil may be'added to the storage tanks without concern for contaminating'the entire volume of fuel oil in the storage tanks. These tests are 'to be conducted prior to adding the new fuel to 'the storage tank(s), but in no case is the time between receipt'of new fuel and conducting the tests to exceed 31 days.. Receipt.of fuel oil without testing results may be authorized bytheEm&rgency Coordinator, provided

-the -vendor's certificate of conformance is in accordance with procurement specifications'. In this case, fuel oil

-samples -should be taken from the delivery, with test

-results to be documented within 31-days. The tests, limits, and applicable ASTM Standards are as follows:

a.

Sample the new fuel in accordance with ASTM D4057-88 (Ref. 6);

b.

Verify in accordance with thetests specified in ASTM D975-OO(Ref. 7) that the new fuel oil sample has:

1. - A maximum of 0.05% by volume water and per ASTM D2709-82,(Ref. 10);

OR A maximum of 0.05% by volume water and per ASTM D1796-83,(Ref. 11);

sediment sediment

2.

A Saybolt viscosity at 100OF of Ž 32.6 SUS and <

40.1 SUS per ASTM D88-81 (Ref. 12)

(continued)

B 3.8-36 Revision No. 39 Crystal River Unit 3

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.3 (continued)

REQUIREMENTS OR A Kinematic viscosity at 400C of > 1.9 mm/s and <

4,1 mm/s per ASTM D445-88 (Ref. 13); conversion to SUS units is required, and can be made using ASTM D2161-93 (Ref. 14);

3.

A flash point of 2 1250F per ASTM D93-94 Procedure "A", Manual or Automated Method (Ref.

15);

c.

Verify in accordance with the test specified in ASTM D287-92 (Ref. 16) that the new fuel has an API specific gravity of > 28 and < 38; OR Verify in accordance with the test specified in ASTM D1298-85 (Ref. 17) that the new fuel has an API specific gravity of > 28 and < 38;

d.

Verify in accordance with the test specified in ASTM

,D4176-91 (Ref.,18) and ASTM D1500-91 (Ref. 19) that the new fuel oil has a clear and bright appearance with proper color; OR Verify in accordance with the test specified in.ASTM D2276-91 (gravimetric method) (Ref. 20) that the new fuel oil has a total particulate contamination of < 10 mg/L.

Failure to meet any of the above limits is cause for rejecting the new fuel oil, but does not represent a failure to meet the LCO concern since the fuel oil is not added to the storage tanks.

Within 31 days following the initial new fuel oil sample the fuel oil is analyzed to establish that the other properties specified in Table 1 of ASTM D975-00, (Ref. 7) are met for new fuel oil when tested in accordance with ASTM D975-00, (Ref. 7), except that a calculated Cetane Index, per ASTM D4737-90 (Ref.- 22),- is determined to estimate the actual Cetane Number. Also, Cloud Point is to be determined using ASTM D2500-91 (Ref. 21). If the Cetane Index is not met, then a sample of fuel is tested in accordance with ASTM D613-93 (Ref. 23) to determine Cetane Number. The 31 day period is acceptable because the fuel oil properties of interest, even if they were not within stated limits, would not have an immediate effect on EDG operation. This Surveillance ensures the availability of high quality fuel oil for the EDGs.

(continued)

Crysal iverUni 3 B3.837 Rvison N. 3 Crystal River Unit 3 3 3.8-37 Revision No. 39

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE SR 3.8.3.3 (continued)

REQUIREMENTS Fuel oil degradation during long-term storage is typically detected as an increase In particulate, due mostly to oxidation. The presence'of particulate does not mean the fuel oil will not burn properly in a diesel engine.

However, the particulate can cause fouling of filters and fuel oil injection-.equipment which can cause engine failure.

Particulate concentrations should be determined in accordance with ASTM D2276-91, Method A (Ref. 20). This method involyes a gravimetric--determ'ination of total particulate concentration in the fuel oil. It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing. Because the total stored fuel oil volume is.contained in two isolated tanks, each tank must be considered'and tested separately,.

The Frequency of this SR takes-into consideration fuel oil

- degradation trendsethat indicate that' particulate concentration ig-'unlikely to change significantly between tests.

SR 3.8.3.4

'This Surveillanceensures that,',without the aid of the re-fill compressor, su fficieft air start capacity for each EDG is available. The design requirements provide for a minimum

- of six engine start'cycles without 'recharging. The pressure specified in this SR reflects the lowest value at which the six starts can be'accomplished,'with substantial margin The-31 day Frequenc'y takes into account the capacity, capability, redundancy, and diversity of the AC sources and o-'

'othr'r>

indications available in the control room, including alarms,"-to'alert the operator to below normal air start pIredsdre. Xn-addition','the system design includes a feature to automatically-start the air.-compressors on low air pressure.

(continued)

Crystal River Unit 3

'B 3.8-38 Revision No. 39

Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES REFERENCES

1.

FSAR, Section 8.2.3.1.

2.

Regulatory Guide 1.137.

3.

ANSI N195-1976, Appendix B.

4.

FSAR, Chapter 6.

5.

FSAR, Chapter 14.

6.

ASTM Standard, D4057-88.

7.

ASTM Standard, D975-00.

8.

ASME, Boiler and Pressure Vessel Code,Section XI.

9.

Correspondence, G/CI to FPC, FCS-6541, dated May 25, 1985.

10.

11.

12.

13.

14.

15.

16.

17.

18.

19.

20.

21.

22.

23.

24.

ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM ASTM

Standard, Standard,

Standard, D2709-82.

D1796-83.

D88-81.

D445-88.

D2161-93.

D93-94.

D287-92.

D1298-85.

D4176-91.

D1500-91.

D2276-91.

D2500-91.

D4737-90.

D613-93.

D2274-88.

(continued)

Revision No. 39 Crystal River Unit 3 B 3.8-38A

3F0403-04, TS Bases Control Program

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