3F0403-04, TS Bases Control Program

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TS Bases Control Program
ML031080411
Person / Time
Site: Crystal River Duke Energy icon.png
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


Text

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, FL34428

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 Page(s) to be Added Page(s) Revision Pages(s) Revisio]n ITS LOEPages (1-5) 3/27/02 ITS LOEPages (1-5) 2/24/03 ITS Bases LOEPages (1-8) 3/27/02 ITS Bases LOEPages (1-8) 2/24/03 B 3.0-17 / B 3.0-18 28/28 B 3.0-17 / B 3.0-18 203 / 2C13 B 3.0-19 28 B 3.0-19 203 B 3.3-15 / B 3.3-16 22/22 B 3.3-15 / B 3.3-16 40 / 22 B 3.3-69 / B 3.3-70 202 / 202 B 3.3-69 / B 3.3-70 202/ 39 B 3.3-71 /B 3.3-72 202 / 157 B 3.3-71 /B 3.3-72 206/1557 B 3.3-125 / B 3.3-125A 22/ 178 B 3.3-125 / B 3.3-125A 22/39 B 3.4-1/B 3.4-2 149/22 B 3.4-1 / B 3.4-2 149 / 2C04 B 3.7-95 / B 3.7-96 182/ 182 B 3.7-95 / B 3.7-96 39 / 39 B 3.7-97 182 B 3.7-97 / B 3.7-98 39 / 39 B 3.8-36 / B 3.8-37 163/ 149 B 3.8-36 / B 3.8-37 39 / 39 B 3.8-38 149 B 3.8-38 / B 3.8-38A 39 / 39

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 ITS LOEPage 1 of 5 2124/03 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 Amendment Page Amendment 182 3.0-4 203 ii 161 3.0-5 149 iii 182 3.1-1 149 iv 182 3.1-2 149 v 182 3.1-3 149 Vi 182 3.1-4 149 vii 182 3.1-5 149 1.1-1 149 3.1-6 149 1.1-2 149 3.1-7 149 1.1-3 149 3.1-8 149 1.1-4 205 3.1-9 149 1.1-5 149 3.1-10 149 1.1-6 205 3.1-11 149 1.1-7 149 3.1-12 149 1.1-8 149 3.1-13 149 1.2-1 149 3.1-14 149 1.2-2 149 3.1-15 149 1.2-3 149 3.1-16 149 1.3-1 149 3.1-17 149 1.3-2 149 3.1-18 149 1.3-3 149 3.1-19 149 1.3-4 149 3.1-20 149 1.3-5 149 3.1-21 149 1.3-6 149 3.2-1 149 1.3-7 149 3.2-2 149 1.3-8 149 3.2-3 149 1.3-9 149 3.2-4 149 1.3-10 149 3.2-5 149 1.3-11 149 3.2-6 149 1.3-12 149 3.2-7 149 1.4-1 149 3.2-8 149 1.4-2 149 3.2-9 149 1.4-3 149 3.2-10 149 1.4-4 149 3.2-11 149 2.0-1 149 3.2-12 149 2.0-2 201 3.2-13 149 2.0-3 149 3.3-1 149 3.0-1 149 3.3-2 149 3.0-2 149 3.3-3 149 3.0-3 149 3.3-4 152

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

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

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

CRYSTAL RIVER UNIT 3 ITS LOEPage 5 of 5 2/24/03 IMPROVED TECHNICAL SPECIFICATIONS 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 3-2 190 4-1 190 4-2 190

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 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

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

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

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 11 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 17 B 3.3-58 16 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 16 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 17 B 3.3-71 206 B 3.3-115 149 B 3.3-72 157 B 3.3-116 37 B 3.3-73 17 B 3.3-117 17 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 17 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 17 B 3.3-1 33 22 B 3.3-92 17 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 Operating License, only, and did not effect changesto the ITS LCOs or Bases.

Page Revision Page Revision B 3.3-138 174 B 3.4-28 22 B 3.3-138A 174 B 3.4-29 22 B 3.3-138B 174 B 3.4-30 14 B 3.3-138C 177 B 3.4-31 22 B 3.3-138D 177 B 3.4-32 22 B 3.3-139 11 B 3.4-33 149 B 3.3-140 11 B 3.4-34 149 B 3.3-141 11 B 3.4-35 149 B 3.3-142 11 B 3.4-36 149 B 3.3-143 23 B 3.4-37 29 B 3.3-144 23 B 3.4-38 29 B 3.3-145 07 B 3.4-39 29 B 3.3-146 196 B 3.4-40 29 B 3.3-147 07 B 3.4-41 29 B 3.3-148 07 B 3.4-42 29 B 3.3-149 23 B 3.4-43 161 B 3.3-150 196 B 3.4-44 149 B 3.4-1 149 B 3.4-45 161 B 3.4-2 204 B 3.4-46 149 B 3.4-3 149 B 3.4-47 149 B 3.4-4 149 B 3.4-48 149 B 3.4-5 149 B 3.4-49 149 B 3.4-6 149 B 3.4-50 149 B 3.4-7 149 B 3.4-51 149 B 3.4-8 149 B 3.4-52 161 B 3.4-9 149 B 3.4-52A 161 B 3.4-10 149 B 3.4-52B 183 B 3.4-11 183 B 3.4-52C 183 B 3.4-12 149 B 3.4-52D 183 B 3.4-13 149 B 3.4-52E 183 B 3.4-14 149 B 3.4-52F 183 B 3.4-15 149 B 3.4-52G 183 B 3.4-16 183 B 3.4-52H 183 B 3.4-17 149 B 3.4-521 183 B 3.4-18 149 B 3.4-52J 183 B 3.4-19 149 B 3.4-52K 183 B 3.4-20 149 B 3.4-52L 183 B 3.4-21 149 B 3.4-53 10 B 3.4-22 149 B 3.4-54 37 B 3.4-23 14 B 3.4-55 158 B 3.4-24 149 B 3.4-55A 10 B 3.4-25 149 B 3.4-55B 10 B 3.4-26 149 B 3.4-56 10 B 3.4-27 22 B 3.4-57 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 Operating License, only, and did not effect changes to the ITS LCOs or Bases.

Page Revi si on Page Revision B 3.4-58 149 B 3.5-28 149 B 3.4-59 149 B 3.5-29 149 B 3.4-60 149 B 3.5-30 22 B 3.4-61 149 B 3.6-1 156 B 3.4-62 149 B 3.6-2 37 B 3.4-63 33 B 3.6-3 156 B 3.4-64 33 B 3.6-4 191 B 3.4-65 179 B 3.6-5 37 B 3.4-66 149 B 3.6-6 156 B 3.4-67 149 B 3.6-7 37 B 3.4-68 149 B 3.6-8 156 B 3.4-69 149 B 3.6-9 26 B 3.4-70 195 B 3.6-10 01 B 3.4-71 37 B 3.6-11 01 B 3.4-72 37 B 3.6-12 01 B 3.4-73 37 B 3.6-13 156 B 3.4-74 37 B 3.6-14 156 B 3.5-1 149 B 3.6-14A 37 B 3.5-2 149 B 3.6-15 11 B 3.5-3 17 B 3.6-16 156 B 3.5-4 17 B 3.6-17 37 B 3.5-5 149 B 3.6-18 156 B 3.5-6 149 B 3.6-19 38 B 3.5-7 149 B 3.6-20 26 B 3.5-8 17 B 3.6-21 156 B 3.5-9 182 B 3.6-22 11 B 3.5-10 37 B 3.6-23 11 B 3.5-11 06 B 3.6-24 156 B 3.5-12 22 B 3.6-25 156 B 3.5-13 37 B 3.6-26 11 B 3.5-14 06 B 3.6-27 156 B 3.5-15 25 B 3.6-28 37 B 3.5-16 24 B 3.6-29 30 B 3.5-17 24 B 3.6-30 01 B 3.5-18 182 B 3.6-31 01 B 3.5-19 22 B 3.6-32 149 B 3.5-20 149 B 3.6-33 149 B 3.5-21 161 B 3.6-34 149 B 3.5-22 161 B 3.6-35 23 B 3.5-23 149 B 3.6-36 23 B 3.5-24 23 B 3.6-37 165 B 3.5-25 149 B 3.6-38 34 B 3.5-26 149 B 3.6-39 34 B 3.5-27 149 B 3.6-40 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 Operating License, only, and did not effect changesto the ITS LCOs or Bases.

Page Revision Page Revi si on B 3.6-41 23 B 3.7-32 24 B 3.6-42 24 B 3.7-33 16 B 3.6-43 34 B 3.7-34 149 B 3.6-44 34 B 3.7-35 149 B 3.6-45 165 B 3.7-36 149 B 3.6-46 149 B 3.7-37 149 B 3.6-47 37 B 3.7-38 24 B 3.6-48 149 B 3.7-39 24 B 3.6-49 149 B 3.7-40 22 B 3.7-1 149 B 3.7-41 182 B 3.7-2 149 B 3.7-42 182 B 3.7-3 149 B 3.7-43 182 B 3.7-4 149 B 3.7-44 24 B 3.7-5 149 B 3.7-45 24 B 3.7-6 149 B 3.7-46 149 B 3.7-7 17 B 3.7-47 182 B 3.7-8 37 B 3.7-48 182 B 3.7-9 37 B 3.7-49 24 B 3.7-10 18 B 3.7-50 22 B 3.7-11 149 B 3.7-51 149 B 3.7-12 37 B 3.7-52 182 B 3.7-13 17 B 3.7-53 163 B 3.7-14 17 B 3.7-54 24 B 3.7-15 17 B 3.7-55 24 B 3.7-16 01 B 3.7-56 17 B 3.7-17 01 B 3.7-57 149 B 3.7-18 17 B 3.7-58 38 B 3.7-18A 23 B 3.7-59 149 B 3.7-18B 01 B 3.7-60 199 B 3.7-19 37 B 3.7-61 199 B 3.7-20 12 B 3.7-62 199 B 3.7-21 12 B 3.7-63 199 B 3.7-22 37 B 3.7-64 199 B 3.7-23 22 B 3.7-65 199 B 3.7-23A 182 B 3.7-65A 199 B 3.7-23B 182 B 3.7-65B 199 B 3.7-24 182 B 3.7-66 37 B 3.7-25 182 B 3.7-67 25 B 3.7-26 26 B 3.7-68 37 B 3.7-27 26 B 3.7-69 193 B 3.7-28 24 B 3.7-70 23 B 3.7-29 149 B 3.7-71 193 B 3.7-30 149 B 3.7-72 193 B 3.7-31 22 B 3.7-73 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 Revision Page Revi si on B 3.7-74 193 B 3.8-18 163 B 3.7-75 193 B 3.8-19 22 B 3.7-76 37 B 3.8-20 15 B 3.7-77 25 B 3.8-21 149 B 3.7-78 37 B 3.8-22 163 B 3.7-79 37 B 3.8-23 22 B 3.7-80 37 B 3.8-24 149 B 3.7-81 17 B 3.8-25 17 B 3.7-82 17 B 3.8-26 160 B 3.7-83 149 B 3.8-27 149 B 3.7-84 149 B 3.8-28 149 B 3.7-85 182 B 3.8-29 157 B 3.7-86 199 B 3.8-30 182 B 3.7-87 200 B 3.8-31 182 B 3.7-88 182 B 3.8-32 182 B 3.7-89 182 B 3.8-33 37 B 3.7-90 192 B 3.8-33A 163 B 3.7-91 25 B 3.8-33B 163 B 3.7-92 192 B 3.8-34 163 B 3.7-93 25 B 3.8-35 163 B 3.7-94 192 B 3.8-36 39 B 3.7-95 39 B 3.8-37 39 B 3.7-96 39 B 3.8-38 39 B 3.7-97 39 B 3.8-38A 39 B 3.7-98 39 B 3.8-39 34 B 3.8-1 149 B 3.8-40 34 B 3.8-2 17 B 3.8-41 34 B 3.8-3 163 B 3.8-42 34 B 3.8-3A 163 B 3.8-43 08 B 3.8-3B 163 B 3.8-44 23 B 3.8-4 17 B 3.8-45 23 B 3.8-5 160 B 3.8-46 08 B 3.8-6 149 B 3.8-47 34 B 3.8-7 26 B 3.8-48 34 B 3.8-8 182 B 3.8-49 149 B 3.8-9 182 B 3.8-50 149 B 3.8-10 26 B 3.8-51 149 B 3.8-11 182 B 3.8-52 149 B 3.8-12 182 B 3.8-53 149 B 3.8-13 182 B 3.8-54 149 B 3.8-14 182 B 3.8-55 149 B 3.8-15 182 B 3.8-56 149 B 3.8-16 149 B 3.8-57 149 B 3.8-17 149 B 3.8-58 149

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

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 25% extension applies to each performance after the initial (continued) 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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or up to the limit of the specified

-Frequency, whichever is greater, applies from the point in I 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.

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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 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 gov'ern any restrictions that 1will'

-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

Ž 14,400-kW or-< 1152 kW. The overpower setpoint is 2

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 FLURs -' " *

(continued)

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 <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.,',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

LOPS EDG 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 <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

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 <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> 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 <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.* 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 SR 3.3.8.2 REQUIREMENTS (continued) 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

on PAM Inst rumentati 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 IIB 3.7.19 BASES SURVEILLANCE SR 3.7.19.3 (continued) Ho .

REQUIREMENTS 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);

-. 1

  • ._ l .-* , *' ,. , I ) Yd I OR.- j

_ 1, A-maximum-of 0.05% by volume water and sediment I per ASTM D1796-83 (Ref.,512);

II -  ; , '4 -

-2. A Saybolt viscosity-at 100 0F 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

..I I .. I to SUS units is-required, and can be made using

..- .I ,

-ASTMED2161-93 (Ref. 15);

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

16); -

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 SR 3.7.19.3 (continued) ,

REQUIREMENTS Particulate concentrationsshould be determined in accordance with ASTM-D2276-91, Method A (Ref. 21). This I 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.

. . ~. .

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 SR 3.8.3.2 REQUIREMENTS (continued) 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 sediment per ASTM D2709-82,(Ref. 10);

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

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

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

(continued)

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

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 1250 F 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)

Rvison N. 3 iverUni 3 Crysal B3.837 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. ASTM Standard, D2709-82.
11. ASTM Standard, D1796-83.
12. ASTM Standard, D88-81.
13. ASTM Standard, D445-88.
14. ASTM Standard, D2161-93.
15. ASTM Standard, D93-94.
16. ASTM Standard, D287-92.
17. ASTM Standard, D1298-85.
18. ASTM Standard, D4176-91.
19. ASTM Standard, D1500-91.
20. ASTM Standard, D2276-91.
21. ASTM Standard, D2500-91.
22. ASTM Standard, D4737-90.
23. ASTM Standard, D613-93.
24. ASTM Standard, D2274-88.

(continued)

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

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