Text

Revisions to the Technical Requirements Manual and the Technical Specifications Bases
	ML051020266
Person / Time
Site:	River Bend
Issue date:	04/08/2005
From:	King R; Entergy Operations
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	G9.25.1.5, G9.41.1, G9.5, RBF1-05-0062, RBG-46419
	Download: ML051020266 (62)
	v • d • e

Entergy Operations, Inc.

River Bend Station 5485 U.S. Highway 61 P. 0. Box 220 St. Francisville, LA 70775 Entergy Tel 225 336 6225 Fax 225 635 5068 Rick J. King Director Nuclear Safety Assurance April 8, 2005 U. S. Nuclear Regulatory Commission Document Control Desk Washington, D. C. 20555

Subject:

River Bend Station - Unit 1 Docket No. 50-458 License No. NPF-47 Revisions to the Technical Requirements Manual and the Technical Specifications Bases File Nos.:

G9.5, G9.25.1.5, G9.41.1 RBG-46419 RBF1-05-0062 Gentlemen:

Pursuant to 10CFR50.71(e), Entergy Operations, Inc., (EOI) herein submits changes to the River Bend Station (RBS) Technical Requirements Manual (TRM). The revised pages cover changes made from the period October 2, 2003 through April 8, 2005. This includes TRM revisions 91 through 100. A list of effective pages is included to identify the current pages of the TRM through revision 100.

Pursuant to RBS Technical Specification 5.5.11, revised pages for the Technical Specification Bases pages are included. The revised pages cover changes made from October 2, 2003, through April 8, 2005. This includes Bases revisions 117 through 122. A list of effective pages is included to identify the current pages of the Bases through revision 122.

As required by 10CFR50.71(e), the below affirmation certifies that the information in this submittal accurately reflects changes made since the previous submittal, necessary to represent information and analyses submitted or prepared pursuant to NRC requirements.

ooOC

RBG-46419 RBF1-05-0062 Page 2 of 2 Should you have any questions, please contact Mr. David Lorfing at 225-381-4517.

I declare under penalty of perjury that the foregoing is true and correct.

Executed on April 8, 2005.

Sincerely, R. J. King Director - Nuclear Safety Assurance R.K/DHW

Enclosures:

(1) Technical Requirements Manual Revision Package (2) Technical Specifications Bases Revision Package cc:

U. S. Nuclear Regulatory Commission Region IV 611 Ryan Plaza Drive, Suite 400 Arlington, TX 76011 (w/o enclosures)

U. S. Nuclear Regulatory Commission Senior Resident Inspector P. 0. Box 1150 St. Francisville, LA 70775 River Bend Station RBG-46419 Technical Requirements Manual Change Package

TECHNICAL REQUIREMENTS MANUAL LIST OF EFFECTIVE PAGES PAGE NUMBER I REV PAGE NUMBER I REV PAGE NUMBER I REV 4-4-

i ii iii iv V

vi TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 1-1 1-2 1-3 1-4 3.0-1 3.0-2 3.0-3 3.0-4 3.1-1 3.1-2 3.1-3 3.1-4 3.2-1 3.3-1 3.3-2 3.3-3 3.3-4 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 (10i)

(17i)

(17ii)

(25i)

(6i)

(9i)

(9ii)

(9iii)

(15i)

(15ii)

(17i)

(17ii)

(17iii)

(18i)

(18ii)

(24i)

(24ii)

(24iii)

(24iv)

(28i)

(31i)

(37i)

(43i)

(43ii)

(43iii)

(43iv)

(43v)

(43vi)

(43vii)

(47i)

(52i) 77 100 98 5

77 77 77 77 77 77 77 S

92 5

5 84 90 5

74 S

48 72 78 5

5 5

18 18 61 86 5

21 49 5

78 72 5

9 9

9 77 S

9 5

TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 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 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.3-56 3.3-57 3.3-58 3.3-59 3.3-60 3.3-61 3.3-62 3.3-63 3.3-64 3.3-65 3.3-66 3.3-67 3.3-68 3.3-69 3.3-70 3.3-71 3.3-72 3.3-73 (52ii)

(52iii)

(52iv)

(52v)

(57i)

(57ii)

(57iii)

(57iv)

(57v)

(57vi)

(57vii)

(57viii)

(60i)

(60ii)

(61i)

(61ii)

(65i)

(67i)

(67ii)

(67iii)

(71i)

(71ii)

(71iii)

(7liv)

(71v)

(71vi)

(71vii)

(71viii)

(71ix)

(71x)

(71xi)

(71xii)

(71xiii)

(71xiv)

(7 1xv)

(71xvi)

(7 1xvi i)

(71xviii)

(71xix)

(71xx)

(7 lxxi)

(71xxii)

(71xxiii)

(7lxxiv)

(71xxv)

(71xxvi) 5 5

5 5

80 97 40 13 13 87 16 28 62 62 62 98 9

72 75 75 85 91 5

38 38 77 77 5

79 5

40 5

40 40 81 S

5 67 96 51 51 78 75 90 26 5

TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.3-74 3.3-75 3.3-76 3.3-77 3.3-78 3.3-79 3.3-80 3.3-81 3.3-82 3.3-83 3.3-84 3.3-85 3.3-86 3.3-87 3.3-88 3.3-89 3.3-90 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 3.5-1 3.5-2 3.5-3 3.5-4 3.6-1 3.6-2 3.6-3

3. 6-3a

3. 6-4 3.6-5 3.6-6 (74i)

(77i)

(77ii)

(77iii)

(77iv)

(77v)

(77vi)

(77vii)

(77viii)

(77ix)

(77x)

(77xi)

(77xii)

(77xiii)

(40i)

(4i)

(Si)

(5ii)

(13i)

(16i)

(16ii)

(16iii)

(19i)

(32i)

(32ii)

(32iii)

(33i)

(33ii)

(33iii)

(33iv)

(33v)

(Si)

(5ii)

(12i)

(12ii)

(2i)

(2ii)

(8i)

(8ii)

(8iii)

(20i)

(20ii) 91 90 5

44 44 44 5

5 5

5 77 5

86 90 100 5

48 86 5

5 49 75 75 S

89 71 5

5 5

39 5

5 5

5 77 77 11 69 73 13 73 11 77 I

TR 3.3-26 TR 3.3-27 RIVER BEND TR-a Revision 100

TECHNICAL REQUIREMENTS MANUAL LIST OF EFFECTIVE PAGES PAGE NUMBER l REV PAGE NUMBER l REV PAGE NUMBER l REV TR 3.6-7 (20iii) 57 TR 3.7-28 (lSxxi) 58 TR 3.11-6 18 TR 3.6-8 (20iv) 68 TR 3.7-29 (lSxxii) 95 TR 3.11-7 14 TR 3.6-9 (20v) 69 TR 3.7-30 (lSxXiii) 5 TR 3.11-8 5

TR 3.6-10 (20vi) 93 TR 3.7-31 (15xxiv) 5 TR 3.11-9 5

TR 3.6-11 (20vii) 69 TR 3.7-32 (15xxv) 18 TR 3.11-10 75 TR 3.6-12 (22i) 12 TR 3.7-33 (15xxvi) 5 TR 3.11-11 5

TR 3.6-13 (28i) 90 TR 3.7-34 (15xxvii) 5 TR 3.11-12 5

TR 3.6-14 (28ii) 35 TR 3.7-35 (1sxxviii) 5 TR 3.11-13 5

TR 3.6-15 (30i) 5 TR 3.8-1 (15i) 76 TR 3.11-14 5

TR 3.6-16 (35i) 77 TR 3.8-2 (lSii) 65 TR 3.11-15 5

TR 3.6-17 (36i) 77 TR 3.8-3 (15iii) 76 TR 3.11-16 5

TR 3.6-18 (40i) 100 TR 3.8-4 (19i) 5 TR 3.11-17 5

TR 3.6-19 (50i) 62 TR 3.8-5 (20i) 76 TR 3.12-1 5

TR 3.6-20 (52i) 63 TR 3.8-6 (23i) 64 TR 3.12-2 5

TR 3.6-21 (54i) 98 TR 3.8-7 (27i) 55 TR 3.12-3 77 TR 3.8-8 (42i) 81 TR 3.12-4 77 TR 3.6-23 (59i) 5 TR 3.8-9 (42ii) 81 TR 3.12-5 59 TR 3.6-24 (61i) 18 TR 3.8-10 (42iii) 81 TR 3.12-6 41 TR 3.6-25 (70i) 96 TR 3.8-11 (42iv) 81 TR 3.12-7 41 TR 3.6-26 (70ii) 96 TR 3.8-12 (42v) 5 TR 3.12-8 5

TR 3.6-27 (72i) 5 TR 3.8-13 (42vi) 95 TR 3.12-9 5

TR 3.7-1 (4i) 5 TR 3.8-14 (42vii) 95 TR 3.12-10 41 TR 3.7-2 (4ii) 5 TR 3.8-15 (42viii) 95 TR 3.12-11 41 TR 3.7-3 (4iii) 5 TR 3.8-16 (42ix) 95 TR 3.12-12 77 TR 3.7-4 (4iv) 5 TR 3.8-17 (42x) 95 TR 5-1 87 TR 3.7-5 (8i) 90 TR 3.8-18 (42xi) 30 TR 5-2 5

TR 3.7-6 (Ili) 26 TR 3.8-19 (42xii) 5 TR 5-3 5

TR 3.7-7 (14i) 5 TR 3.8-20 (42xiii) 5 TR 5-4 53 TR 3.7-8 (15i) 94 TR 3.8-21 (42xiv) 5 TR 5-5 65 TR 3.7-9 (15ii) 5 TR 3.8-22 (42xv) 30 TR 5-6 94 TR 3.7-10 (lSiii) 5 TR 3.8-23 (42xvi) 88 TR 5-7 23 TR 3.7-11 (lSiv) 93 TR 3.9-1 (7i) 84 TR 5-8 5

TR 3.7-12 (lSv)

S TR 3.9-2 (7ii) 72 TR 5-9 5

TR 3.7-13 (lSvi)

S TR 3.9-3 (13i) 85 TR 5-10 5

TR 3.7-14 (lSvii) 15 TR 3.9-4 (13ii) 5 TR 5-11 77 TR 3.7-15 (lSviii) 5 TR 3.9-5 (13iii) 70 TR 5-12 5

TR 3.7-16 (lSix) 5 TR 3.9-6 (13iv) 5 TR 5-13 94 TR 3.7-17 (lSx) 58 TR 3.9-7 (13v)

S TR 5-14 33 TR 3.7-18 (15xi) 5 TR 3.9-8 (13vi) 5 TR 5-15 53 TR 3.7-19 (15xii) 79 TR 3.9-9 (13vii) 54 TR 5-16 53 TR 3.7-20 (15xiii) 5 TR 3.9-10 (13viii) 56 TR 5-17 87 TR 3.7-21 (15xiv) 15 TR 3.9-11 (13ix) 99 TR S-18 53 TR 3.7-22 (15xv) 58 TR 3.9-12 (13x) 32 TR 5-19 53 TR 3.7-23 (lSxvi) 5 TR 3.11-1 83 TR 5-20 53 TR 3.7-24 (lsxvii) 5 TR 3.11-2 5

TR 5-21 94 TR 3.7-25 (15xviii) 58 TR 3.11-3 5

TR 5-22 8

TR 3.7-26 (lSxix) 5 TR 3.11-4 5

TR 3.7-27 (15xx) 5 TR 3.11-5 5

RIVER BEND TR-b Revision 100

TECHNICAL REQUIREMENTS MANUAL TABLE OF CONTENTS TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.3.7.1 3.3.7.2 3.3.7.3 3.3.7.4 3.3.7.5 3.3.7.6 3.3.7.7 3.3.7.8.1 3.3.7.8.2 3.3.7. 8. 3 3.3.8.1 3.3.8.2 3.3.9 3.3. 10 3.3.11.2 3.3.11.3 3.3.12

3. 3.13

3. 3.14 Control Room Fresh Air (CRFA) System Turbine Overspeed Protection

( Deleted Feedwater/Main Turbine Level 8 Trip Instrumentation Fire Detection Instrumentation Seismic Monitoring Instrumentation Loose-Part Detection System (Deleted)

Traversing In-core Probe System (Not Used)

Offgas System Radiation Monitoring Instrumentation Offgas System Hydrogen Monitoring Instrumentation Loss of Power (LOP) Instrumentation RPS Electric Power Monitoring (Not Used)

(Not Used)

Radioactive Liquid Effluent Monitoring Radioactive Gaseous Effluent Monitoring Meteorological Monitoring Instrumentation Ultrasonic Feedwater Flow Meters Primary Containment and Drywell Hydrogen Analyzers TR 3.3-48 TR 3.3-51 TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.3-53 3.3-55 3.3-62 3.3-65 3.3-66 3.3-69 3.3-72 3.3-74 3.3-75 3.3-76 3.3-81 3.3-86 3.3-88 3.3-90 I TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.4 3.4.1 3.4.1.1 3.4.2 3.4.3 3.4.4 3.4.5 3.4.6 3.4. 6.1 3.4.7 3.4.8 3.4.9 3.4.10 3.4.11 3.4.11.1 3.4.11.2 3.4. 12 3.4.13 3.4. 14 REACTOR COOLANT SYSTEM (RCS)

Recirculation Loops Operating Recirculation Loop Operating (Single Loop)

(Not Used)

Stuck Open Safety/Relief Valves (S/RVs)

RCS Operational LEAKAGE Reactor Coolant System Pressure Isolation Valves Reactor Coolant System Pressure Isolation Valve Pressure Monitors RCS Leakage Detection Instrumentation (Not Used)

(Not Used)

RCS Pressure and Temperature (P/T) Limits Pressure/Temperature Limits (Vessel Hdyro)

Second Recirculation Loop Startup (Not Used)

Chemistry Structural Integrity TR 3.4-1 TR 3.4-2 TR TR TR 3.4-4 3.4-5 3.4-6 TR 3.4-7 TR 3.4-9 TR TR TR 3.4-10 3.4-11 3.4-12 TR 3.4-13 TR 3.4-17 TR 3.5 TR 3.5.1 TR 3.5.1.1 TR 3.5.2 TR 3.5.3 TR 3.5.4 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM ECCS -

Operating ECCS-Operating (keep fill)

(Not Used)

Suppression Pool Pumpback System (SPPS)

TR 3.5-1 TR 3.5-2 TR 3.5-3 RIVER BEND TR-ii Revision 100

TECHNICAL REQUIREMENTS MANUAL TABLE OF CONTENTS TR 3.6 TR TR TR 3.6.1.1 3.6.1.2 3.6.1.2.1 TR 3.6.1.3 TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.6.1.4 3.6.1.5 3.6.1.6 3.6.1.7 3.6.1.8 3.6.1.9 3.6.1.10 3.6.2.1 3.6.2.2 3.6.2.3 3.6.3.1 3.6.3.2 3.6.3.3 3.6.4.1 3.6.4.2 3.6.4.3 3.6.4.4 3.6.4.5 3.6.4.6 3.6.4.7 3.6.5.1 3.6.5.2 3.6.5.3 3.6.5.4 3.6.5.5 CONTAINMENT SYSTEMS Primary Containment -

Operating Primary Containment Air Locks 1

Primary Containment Air Lock Seal Air Flask Pressure instrumentation Primary Containment Isolation Valves (PCIVs)

(Not Used)

Primary Containment Air Temperature (Not Used)

(Not Used)

Penetration Valve Leakage Control System (PVLCS)

Main Steam -

Positive Leakage Control System (MS-PLCS)

(Not Used)

Suppression Pool Average Temperature (Deleted)

Suppression Pool Water Level (Deleted)

(Not Used)

Primary Containment Hydrogen Recombiners (Not Used)

(Not Used)

Secondary Containment Isolation Dampers (SCIDs) and Fuel Building Isolation Dampers (FBIDs)

Standby Gas Treatment (SGT) System DELETED (Not Used)

(Not Used)

Fuel Building Ventilation System -

Fuel Handling Drywell (Not Used)

Drywell Isolation Valves (Not Used)

Drywell Air Temperature TR TR TR 3.6-1 TR 3.6-3 TR 3.6-4 3.6-5 3.6-12 TR 3.6-13 TR 3.6-15 TR 3.6-16 TR 3.6-17 TR 3.6-18 TR 3.6-19 TR 3.6-20 TR 3.6-21 TR 3.6-23 TR 3.6-24 TR 3.6-25 TR 3.6-27 TR 3.7 TR 3.7.1 TR TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.7.2 3.7.3 3.7.4 3.7.5 3.7.6 3.7.7 3.7.8 3.7.9.1 3.7.9.2 3.7.9.3 3.7.9.4 3.7.9.5 3.7.9.6 3.7.10 3.7.11 PLANT SYSTEMS Standby Service Water (SSW) System and Ultimate Heat Sink (UHS)

Control Room Fresh Air (CRFA) System Control Room Air Conditioning (AC) System (Not Used)

Main Turbine Bypass System (Not Used)

Snubbers Sealed Source Contamination Fire Suppression Systems Spray and/or Sprinkler Systems Halon Systems Fire Hose Stations Yard Fire Hydrants and Hydrant Hose Houses Fire-Rated Assemblies Area Temperature Monitoring Structural Settlement TR TR TR TR TR TR TR TR TR TR TR TR TR TR 3.7-1 3.7-5 3.7-6 3.7-7 3.7-8 3.7-9 3.7-11 3.7-15 3.7-18 3.7-20 3.7-24 3.7-27 3.7-29 3.7-32 RIVER BEND TR-iii Revision 98

Applicability TR 3.0 3.0 SURVEILLANCE REQUIREMENT (TSR) APPLICABILITY TSR 3.0.1 TSRs shall be met during the MODES or other specified conditions in the Applicability for individual TLCOs unless otherwise stated in the TSR.

Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the TLCO.

Failure to perform a Surveillance within the specified Frequency shall be failure to meet the TLCO except as provided in TSR 3.0.3.

Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

The requirements for compliance with TSRs noted as applicable to Technical Specification LCOs shall be the Technical Specification surveillance requirement applicability, SR 3.0.1 through SR 3.0.4.

TSR 3.0.2 The specified Frequency for each TSR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per.

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

TSR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the TLCO not met may be delayed, from the time of discovery, 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.

This delay period is permitted to allow performance of the Surveillance.

A risk evaluation shall be performed for any surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the TLCO must immediately be declared not met, and the applicable Condition(s) must be entered.

When the Surveillance is performed within the delay period and the Surveillance is not met, the TLCO must immediately be declared not met, and the applicable Condition(s) must be entered.

(continued)

RIVER BEND TR 3.0-3 Revision 92

Primary Containment and Drywell Isolation Instrumentation TR 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5)

Primary Containment and Drywell Isolation Instrumentation FUNCTION APPLICABLE REQUIRED CONDITIONS SURVEILLANCE NOMINAL MODES OR CHANNELS REFERENCED REQUIREMENTS SETPOINT OTHER PER TRIP FROM SPECIFIED SYSTEM REQUIRED CONDITIONS ACTION C.1

1. Main Steam Line Isolation (continued)

h.

Deleted

i.

Deleted

j.

Manual Initiation 1,

2, 3

2 G

SR 3.3.6.1.6 NA

k.

DELETED

1.

Main Steam Line 1,

2. 3 1

)

TLCO L TSR 3.3.6.1.1 15.0 x full Radiation - High-Nigh 1

TSR 3.3.6.1.2 power TSR 3.3.6.1.5 background TSR 3.3.6.1.6 (Allowable Value S 18.0 x full power background)

2. Primary Containment and Drywell Isolation

a.

Reactor Vessel Water 1, 2, 3 2 (b)

H SR 3.3.6.1.1

-43 inches Level -Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

b.

Drywell Pressure-High 1, 2, 3 2 (b)

H SR 3.3.6.1.1 1.68 paid SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

c.

Containment Purge

1. 2, 3 1

K SR 3.3.6.1.1 1.17 R/hr Isolation Radiation -

SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6

d.

Manual Initiation

1. 2, 3 2(b)

C SR 3.3.6.1.6 NA (continued)

I (b)

Also required to initiate the associated drywell isolation function.

(f) Only trips and isolates mechanical vacuum pumps, reactor sample valves, (h)

Setpoints based on norn.l water chemistry (new hydrogen injection).

RIVER BEND TR 3.3-33 (57ii) and provides monitoring/alarm.

Revision 97

Secondary Containment and Fuel Building Isolation Instrumentation TR 3.3.6.2 TABLE 3.3.6.2-2 Secondary Containment and Fuel Building Isolation Instrumentation TRIP FUNMtION

1.

Reactor Vessel Water Level Low Low Level 2

2.

Drywell Pressure - High

3.

Fuel Building Ventilation Exhaust Radiation -

High

4.

Fuel Building Ventilation Exhaust Radiation -

High

5.

Manual Initiation VALVE GROUP OPERATED BY SIGNAL

11, 12, 1 3 (.Cb) C.)

13""

13 '"'

11, 12, 1.3("'b) t)

The valve groups listed are designated in Table 3.6.4.2-1.

(a)

Also actuates ventilation isolation dampers.

(b)

Also starts Standby Gas Treatment.

(c)

Also starts Fuel Building Exhaust Filter Trains A and B RIVER BEND TR 3.3-43 (61ii) l Revision 98

CRFA System Instrumentation TR 3.3.7.1 TLCO 3.3.7.1 APPLICABILITY:

One channel of Control room ventilation remote intake radiation monitor alarm function shall be OPERABLE with its alarm setpoint < 0.97 x 10-5 PCi/cc.

MODES 1, 2, 3, and during movement of recently irradiated fuel assemblies in the primary containment or fuel building I

I I

ACTIONS I

CONDITION REQUIRED ACTION COMPLETION TIME A. Required channel A.1 Restore to operable.

7 days inoperable.

I RIVER BEND (71ii)

Revision 91

Traversing In-core Probe System TR 3.3.7.7 TR 3.3.7.7 Traversing In-core Probe System TLCO 3.3.7.7 The traversing in-core probe (TIP) system shall be OPERABLE I

with:

a.

TIP detector information for TIP channels that correspond with operable LPRMs.

OR

b.

at least 20 channels with TIP detector information and

c.

data collected to support use of SUBTIP methodology for inoperable TIP channels.

APPLICABILITY:

When the traversing in-core probe is used for recalibration of the LPRM detectors.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. The traversing in-core A.1 Do not use the system for Immediately probe system the above applicable inoperable.

monitoring or calibration.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.7.7.1

NOTE--------------------

Only required to be met during use for LPRM calibration.

Normalizing each of the above required Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months detector outputs.

prior to use for LPRM calibration.

RIVER BEND TR 3.3-66 (71xix)

Revision 96

LOP Instrumentation TR 3.3.8.1 TR 3.3.8.1 Loss of Power (LOP) Instrumentation Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation FUNCTION REQUIRED SURVEILLANCE CHANNELS REQUIREMENTS PER DIVISION TRIP SETPOINT

1. Divisions 1 and 2 - 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage* 4.16 kV basis

b. Loss of Voltage -Time Delay

c. Degraded Voltage* 4.16 kV basis

d. Degraded Voltage

Time Delay, No LOCA

e. Degraded Voltage-Time Delay, LOCA

2. Division 3 - 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage *4.16 kV basis

b. Loss of Voltage

Time Delay

c. Degraded Voltage* 4.16 kV basis

d. Degraded Voltage

Time Delay, No LOCA

e. Degraded Voltage *Time Delay, LOCA 3

SR SR SR SR 3

SR SR SR 3

SR SR SR SR 3

SR SR SR 3

SR SR SR 2

SR SR 2

SR SR SR SR 2

SR SR SR 2

SR SR SR 3.3.8.1.1 3.3. 8. 1.2 3.3. 8. 1.3 3.3.8.1.4 3.3. 8. 1.2 3.3. 8. 1.3 3.3.8.1.4 3.3. 8.1.1 3.3. 8.1.2 3.3. 8.1.3 3.3. 8.1.4 3.3. 8.1.2 3.3. 8.1.3 3.3. 8.1.4 3.3. 8.1. 2 3.3. 8.1. 3 3.3. 8.1. 4 3.3. 8. 1. 1 3.3. 8. 1.3 3.3. 8.1.4 3.3. 8.1.3 3.3. 8. 1.4 3.3. 8.1. 1 3.3. 8 1. 2 3.3. 8.1.3 3.3. 8.1.4 3.3. 8. 1.2 3.3. 8.1. 3 3.3. 8. 1. 4 3.3. 8. 1.2 3.3. 8. 1. 3 3.3. 8.1.4 2 2910 V and S 3030 V 2 2.7 seconds and S 3.3 seconds 2 3692 V and S 3733 V 2 54 seconds and S 66 seconds 2 4.56 seconds and s 5.54 seconds 2 2892 V and 5 3198 V 2 2.7 seconds and S 3.3 seconds

? 3675 V and S 3720 V 2 54 seconds and S 66 seconds a 4.63 seconds and S S.57 seconds I

I I

RIVER BEND TR 3.3-74 (74 i)

Revision 91

Primary Containment and Drywell Hydrogen Analyzers I TR 3.3.14 1 TR 3.3.14 Primary Containment and Drywell Hydrogen Analyzers TLCO 3.3.14.1 Primary containment and drywell hydrogen analyzers shall be operable.

APPLICABILITY:

MODES 1 and 2

NOTE---------------------------------------

TLCO 3.0.4 is not applicable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One analyzer A.1 Restore to OPERABLE 30 days inoperable.

B.

Required Action and B.1 Initiate action to prepare Immediately associated Completion and submit a Special Time of Condition A Report not met C.

Two hydrogen C.1 Restore one analyzer to 7 days analyzers inoperable OPERABLE status D.

Required Action and D.1 Be in MODE 3 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition C not met SURVEILLANCE REOUIREMENTS SURVEILLANCE FREQUENCY TSR 3.3.14.1 Perform CHANNEL CHECK.

31 days TSR 3.3.14.2 Perform CHANNEL CALIBRATION.

92 days RIVER BEND TR 3.3-90 (40i)

Revision 100 I

PCIVS TR 3.6.1.3 TABLE 3.6.1.3-1 (page 5 of 6)

PRIMARY CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION SECONDARY PENETRATION VALVE TIME CONTAINMENT SYSTEM VALVE NUMBER(a)

NUMBER GROUPW)

(Seconds)

BYPASS PATH (Yes/No)

c.

Other Isolation Valves Feedwater Line lB21-AOVF032AIC) 1KJB*Z3A Yes Feedwater Line lB21*VFOlOA(b) 1KJB*Z3A Yes Feedwater Line lB21*AOVF032B(c) 1KJB*Z3B Yes Feedwater Line lB21-VFO1OB~b) 1KJB*Z3B Yes RWCU Disch. to Condenser 1WCS-RV144 1KJB-Z4 Yes RWCU Backwash Disch.

lWCS*RV54 lKJB*ZS Yes HPCS to Reactor 2E22A0VF005lb) IC)

lKJBZ9, No lDRB-Z10 Supp. Pool Pump-Back Return lDFR-V18 11J) lKJB-Zll No Line Supp. Pool Pump-Back Return lDFRVl82 1) lKJB-Zll No Line HPCS Th. Relief to Supp. Pool lE22-RVF014(l) lKJB-Zll No HPCS Th. Relief to Supp. Pool lE22*RVF0351 )

lKJB-Zll No HPCS Th. Relief to Supp. Pool lE22-RVF039(l) 1KJB-Zll No LPCS to Reactor lE21-AOVF006 (b) (C) lKJB*Z13.

No IDRB*Z14 RHR Shutdown Cooling Sup.

1RHS*V240 1KJB*Z20 No LPCI C to Reactor 1E12-AOVF041C(b) (C) 1KJB-Z21C, No lDRB-Z22C RCIC/RHR Isolation 1E12-VF102(q) lKJB-Z18C No RHR A Thermal Relief to Supp RH.S-RV67A(](q) lKJB-Z23A No Pool RHR A Hx V&R to Supp. Pool lEl2*RVF025A(')(q) 1KJB*Z23A No RHR A Hx V&R to Supp. Pool 1E12*RVF017A(J)(q) 1KJB-Z23A No RHR A Hx V&R to Supp. Pool lEl2*RVF005U)

(q) 1KJB*Z23A No LPCS Th. Relief to Supp. Pool lE21*RVF018(ID(q) 1KJB*Z23A No LPCS Th. Relief to Supp. Pool lE21-RVF031(J)(q)

IKJB*Z23A No RHR Stm Condensing Th. Relief lE12.RVF036(J)(q) 1KJB*Z23A No to Supp. Pool RHR B Thermal Relief to Supp RHS -V6 7B(I(q) lKJB*Z23B No Pool RHR B Hx V&R to Supp. Pool lEl2BRVF025C(')(q) 1KJB*Z23B No RHR B Hx V&R to Supp.

Pool lEl2*RVF025B0I (q) 1KJB*Z23B No RHR B Hx V&R to Supp. Pool lEl2*RVF030(J)(q) 1KJB*Z23B No RHR B Hx V&R to Supp. Pool lEl2*RVF101I()(ql 1KJB*Z23B No RHR B Hx V&R to Supp. Pool lEl2*RVF017B(T)hq) 1KJB*Z23B No SPC Disch. to RHR Th. Relief RHS-RV66( 1) 1KJB*Z24C No SPC Suction from RHR Th. Relief RHS-RV65(')

lKJB-Z25C No Fuel Pool C&C Disch.

lSFC-V101 1KJB-Z26 No Fuel Pool C&C Suction lSFC-V350 1KJB-Z27 No Fuel Pool Purif. Suction lSFC-V351 1KJB-Z28 No CRD Hyd. Sys. Sup.

lC11VF122 1KJB-Z29 No continued I

RIVER BEND TR 3.6-10 (2 ovi)

Revision 93

Primary Containment Hydrogen Recombiners TR 3.6.3.1 TR 3.6.3.1 Primary Containment Hydrogen Recombiners TLCO 3.6.3.1 APPLICABILITY:

One primary containment hydrogen reconbiner shall be operable.

When both divisions of hydrogen igniters are inoperable, requiring entry to TS 3.6.3.2 Condition B

NOTE----------------------------------

Refer to Technical Specification Bases B.3.6.3.2 Action B.1 regarding recombiner function.

ACTIONS CONDITION REQUIRED ACTION COTIME A. With no hydrogen A.1 Enter TS 3.6.3.2 Immediately recombiner operable Condition C SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.6.3.1.1 Perform a functional test for the 18 months hydrogen recombiner TSR 3.6.3.1.2 Visually examine the primary 18 months containment hydrogen recombiner enclosure and verify there is no evidence of abnormal conditions TSR 3.6.3.1.3 Perform a resistance to ground test 18 months for each heater phase TSR 3.6.3.1.4 Perform a CHANNEL CALIBRATION on 18 months control room recombiner indication instrumentation and control circuits.

I I

I RIVER BEND (40i)

Revision 100

TR 3.6.4.4 Deleted I

RIVER BEND TR 3.6-21 (54i)

Revision 98

Drywell Isolation Valves TR 3.6.5.3 TR 3.6.5.3 Drywell Isolation Valves TABLE 3.6.5.3-1 (page 1 of 2)

DRYWELL ISOLATION VALVES SYSTEM VALVE PENETRATION VALVE MAXIMUM NUMBER BGU ISOLATION TIME (seconds)

a.

Automatic Isolation Valves(d)

I RPCCW Supply RPCCW Return RPCCW Return Service Water Supply Service Water Supply Service Water Return Service Water Return Cont./Drywell Purge Sup.

Cont./Drywell Purge Rtn.

Cont./Drywell Purge Sup.

Cont./Drywell Purge Rtn.

Hydrogen Mixing Line Inlet Hydrogen Mixing Line Inlet Hydrogen Mixing Line Inlet Hydrogen Mixing Line Inlet Hydrogen Mixing Line Exhaust Hydrogen Mixing Line Exhaust Hydrogen Mixing Line Exhaust Hydrogen Mixing Line Exhaust Reactor Plant Sampling Reactor Plant Sampling

b.

Manual Isolation Valves Service Air Supply Instrument Air Supply Service Water Supply Service Water Supply Service Water Return Service Water Return Air Sup. for Main Steam SRV Air Sup. for Main Steam SRV Cont Atmos. Monitor Probe Cont Atmos. Monitor Probe Cont Atmos. Monitor Probe Cont Atmos. Monitor Probe Cont Atmos. Monitor Probe Cont Atmos. Monitor Probe lCCP*MOV142 lCCP-MOV144 1CCP-MOV143 ISWP*MOV4A ISWP*MOV4B lSWP^MOVSA 1SWP-MOVSB 1HVR-AOV125 lHVR-AOV126 IHVR*AOV147 1HVR*AOV14 a 1CPM*MOV2A 1CPM*MOV4A 1CPM'MOV2B 1CPM*MOV4B 1CPM1MOV3A lCPM'MOV1A 1CPM*MOV3B lCPM*MOV1B 1B331AOVF019 lB33-AOVF020 1DRBIZ50 1DRB-Z51 1DRB-Z51 lDRB-Z54 1DRBIZ54 1DRB*Z55 1DRB'Z55 lDRB-Z32 1DRB-Z34 1DRB-Z32 1DRB-Z34 lDRB-Z57A lDRB-Z57A lDRB-Z57B 1DRB-Z57B lDRB-Z58A 1DRB-Z58A lDRB-Z58B 1DRB-Z58B lDRB-Z449 1DRB*Z449 1

1 1

10 10 10 10 10 10 10 10 9

9 30 30 30

52. 8

51. 7

50. 6

53. 9 3

3 3

3 33 33 33 33 33 33 33 33 5

5 I

1SAS-V489 1IAS-V79 1HVN-V542 lSWP-V205 1HVN*VS43 1SWP*V206 1SVVIV50 ISVV*V53 1CMS*SOV34A(b) 1CMS0SOV34B (b) 1CMSOSOV34C(b)

ICMS-SOV34D(b) 1CMS'SOV32A(b)

ICMS-SOV32G(b) lDRB-Z45 lDRB-Z47 lDRB-ZS4 lDRB-Z54 2DRB*Z55 IDRB-ZS5 lDRB-Z107 2DRBIZ112 lDRB-Z500 lDRB-Z430 IDRB-Z499 IDRBIZ428 IDRB*Z333 1DRB*Z335

c.

Other Isolation Valves Main Main Main Main Main Steam SRV Steam SRV Steam SRV Steam SRV Steam SRV Disch.

Disch.

1B21-RVF047A 1B21-RVF041A 1B21-RVF051G lB21*RVF041L 1B211RVF047C 1DRB-Z136 1DRB-Z137 1DRB*Z138 1DRB-Z139 1DRB*Z140 (continued)

RIVER BEND TR 3.6-25 (70i)

Revision 96

Drywell Isolation Valves TR 3.6.5.3 TABLE 3.6.5.3-1 (page 2 of 2)

DRYWELL ISOLATION VALVES (continued)

SYSTEM VALVE PENETRATION NUMBER NUMBER

c.

other Isolation Valves (continued)

Main Steam SRV Disch.

LPCI A to Reactor LPCI B to Reactor Reactor Bldg. Floor Drain I Reactor Bldg. Floor Drain I Reactor Bldg. Floor Drain I Reactor Bldg. Floor Drain I Reactor Bldg. Equip. Drain Reactor Bldg. Equip. Drain Reactor Bldg. Equip. Drain Reactor Bldg. Equip. Drain Service Air supply Instr. Air Supply RPCCW Supply Service Water Supply Service Water Return SLCS Injection SLCS Injection SLCS Injection SLCS Injection RPCCW Return Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air.Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SW Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SRI Air Sup. for Main Steam SRW Air Sup. for Main Steam SRI Air Sup. for Main Steam SW Air Sup. for Main Steam SRW Recirc. Pump Seal Water Sul Recirc.

Pump Seal Water Sul Recirc.

Pump Seal Water Sul Recirc. Pump Seal Water Sul Hdr.

Hdr.

lB21*RVF041G lB21'RVFOSlC lB21*RVF041C lB21'RVF047B lB21-RVF041B lB21'RVF051B lB21*RVF041F lB21^RVF047F iB21^RVF041D lB21'RVF047D lB21'RVF051D lE12*AOVF04IA(a) lEl2*AOVF04IB(a) lDFR^V4 IDFR^V3 lDFR'Vl lDFR-V2 lDER-V14 lDER-V15 lDER-Vl6 lDER-Vl7 lSAS-V487 lIAS-V78 ICCP-Vil9 iSWP-RVll9 ISWP-RV140 lC41-VEXF004A lC41-VEXF004B lC41-VF006 lC41*VF007 lCCP*Vl33 lB21*VF036A IB21^VF036F IB21^VF036G lB21^VF036P lB21*VF039C lB21^VF039H lB21^VF039K lB21^VF0395 lB21^VF036J lB21^VF036L lB21^VF036M lB21^VF036N lB21^VF036R 1B21^VF039B 1B21^VF039D lB21^VF039E 1B33-VF013A lB33-VF017A lB33-VF013B lB33'VF017B lDRB-Zl4l lDRB-Z142 lDRB-Z143 IDRB-Z144 IDRB-Z145 IDRB-Z146 lDRB*Z147 lDRB*Zl4a lDRB-Z149 lDRB-Z150 lDRB-Z151 lDRB-Z22A 1DRB-Z22B 1DRBIZ37A lDRB-Z37A lDRB-Z37B 1DRB-Z37B 1DRB-Z40A 1DRB-Z40A 1DRB-Z40B lDRB-Z4OB lDRB*Z45 1DRB*Z47 1DRBIZ50 1DRB*Z54 1DRB*Z55 1DRBIZS6 1DRB*Z56 1DRB-Z56 1DRB*Z56 lDRB-Z51 lDRB-Z107 lDRB-Z107 lDRB-ZlO7 lDRB-Z107 lDRB*ZlO7 lDRB-Z107 1DRB-Z107 lDRB-Z107 IDRB-Z112 IDRB-Z1i2 IDRB*Z112 lDRB'Z112 IDRB*Z1i2 IDRB*Zll2 IDRBZI12 1DRBZ112 2DRB*Zl33 2DRBZ133 lDRB*Z135 IDRBIZ135 tV p.

Jp.

(a) Testable check valve.

(b) Receives a remote manual isolation signal.

(c) Valve groups are designated in Table 3.3.6.1-2 (d) Due to Generic Letter 96-06 concerns, drywell integrity is no longer assumed for penetrations lDRB*Z152 through lDRB*Z159 and associated valves lRCS*MOV59A/B through lRCS*MOV61A/B (Ref. ER-99-0741).

RIVER BEND TR 3.6-26 (70ii)

Revision 96

Snubbers TR 3.7.7 TR 3.7.7 Snubbers TLCO 3.7.7 All required snubbers shall be OPERABLE.

The only snubbers excluded from this requirement are those installed on nonsafety-related systems and then only if their failure or failure of the system on which they are installed would have no adverse effect on any safety-related system.

APPLICABILITY:

MODE 1, 2 and 3, MODES 4 and 5 for snubbers located on systems required OPERABLE in MODES 4 or 5.

ACTIONS

NOTE------------------------------------

Separate Condition entry is allowed for each required snubber.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more A.1 Declare the supported Immediately required system inoperable, snubbers inoperable on AND a system A.2 Replace or restore the Prior to inoperable snubber(s) to returning OPERABLE status, supported system to OPERABLE AND status A.3 Perform engineering Prior to evaluations per the returning applicable section of supported system the approved ISI to OPERABLE Program.

status SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.7.7.1

NOTE-----------------

The Snubber Inspection program shall be submitted to the NRC in accordance with the requirements of 10 CFR 50.55a(g).

Each required snubber shall be As specified demonstrated to be OPERABLE by in the implementing the examination and test approved requirements of the approved ISI Snubber Program.

Inspection program I

I RIVER BEND (15i)

Revision 94

Fire Suppression Systems TR 3.7.9.1 3.7.9.1 Fire Suppression Systems

NOTE--------------------------------------

The Operating License, NPF-47, may require prior NRC approval for changes to this Technical Requirement.

TLCO 3.7.9.1 The fire suppression water system shall be OPERABLE with:

a.

Three fire suppression pumps, each with a capacity of 1500 gpm, with their discharges aligned to the fire suppression header, and for the diesel pumps,

1.

300 gallons of fuel in the fuel day tank, and

2.

Two starting 24 Volt battery banks and two chargers OPERABLE for each diesel engine, I

b.

Two separate fire water tanks, each with a minimum contained volume of 253,000 gallons, and

c.

An OPERABLE flow path capable of taking suction from both water storage tanks and transferring the water through distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valves, the last valve ahead of the water flow alarm device on each sprinkler or hose standpipe, and the last valve ahead of the deluge valve on each deluge or spray system, required to be OPERABLE per Requirements 3.7.9.5, 3.7.9.4, and 3.7.9.2.

APPLICABILITY:

At all times.

ACTIONS

NOTE----------------------------------

The provisions of TLCO 3.0.4 are not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One pump inoperable A.1 Restore the inoperable 7 days pump to OPERABLE status OR A.2 Provide an alternate 7 days backup pump B.

One water supply B.1 Restore the inoperable 7 days inoperable water supply to OPERABLE status OR B.2 Provide an alternate 7 days backup supply (continued)

RIVER BEND (lsiv)

Revision 93

Area Temperature Monitoring TR 3.7.10 TR 3.7.10 Area Temperature Monitoring TLCO 3.7.10 The temperature of each area shown in Table 3.7.10-1 shall be maintained within the limits indicated in Table 3.7.10-1.

APPLICABILITY: Whenever the equipment in an affected area is required to be OPERABLE.

ACTIONS

NOTE----------------------------------

Separate Condition entry is allowed for each area.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more areas A.1 Restore the area to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months exceeding the within its temperature temperature limit(s) limit.

shown in Table 3.7.10-1 B.

One or more areas B.1 Enter Condition C Immediately exceeding the temperature limit(s)

AND shown in Table 3.7.10-1 by >

B.2.1 Restore the area to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 30OF within its temperature limit OR B.2.2 Declare the equipment in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the affected area inoperable.

C.

Condition B entered C.1 Initiate action to Immediately document the condition OR in the Corrective Action program, specifically Required Action and providing a record of associated the amount by which and Completion Time for the cumulative time the Condition A not met temperature in the affected area exceeded its limit and an analysis to demonstrate the continued OPERABILITY of the affected equipment.

RIVER BEND (l5xxii)

Revision 95

Electrical Equipment Protective Devices TR 3.8.11 TABLE 3.8.11-1 (page 2 of 7)

PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTION DEVICES

1.

Type Square D (continued)

PRIMARY PROTECTION Location SECONDARY PROTECTION Location 1LAR-BKR1B 1LAR-BKR2B 1LAR-BKR3B 1LAR-BKR4B 1LAR-BKR5B 1LAR-BKR6B 1LAR-BKR7B 1LAR-BKR8B lLAR-BKR9B lLAR-BKR10B ILAR-BKR11B lLAR-BKR12 B lLAR-BKR13B lLAR-BKR14B lLAR-BKR16B ILAR-BKR17B lLAR-BKR18B lLAR-BKR19B lSCA-BKR2A12 lSCA-BKR2D12 lSCA-BKR2F12 1SCA-BKR2D14 lSCA-BKR8A22 1SCA-BKR8B22 lHTS*BKR2M-1 1HTS*BKR2M-2 1HTS*BKR2M-3 lHTS*BKR2M-4 1HTS*BKR2N-1 1HTS*BKR2N-2 lHTS-BKRlN-15 SCV-PNL2B1-5(Branch) lLAR-BKR1A ILAR-BKR2A ILAR-BKR3A 1LAR-BKR4A ILAR-BKR5A ILAR-BKR6A ILAR-BKR7A 1LAR-BKRBA 1LAR-BKR9A lLAR-BKR1OA lLAR-BKR1lA 1LAR-BKR12A ILAR-BKR13A ILAR-BKR14A lLAR-BKR16A 1LAR-BKR17A lLAR-BKR18A lLAR-BKR19A lSCA-BKR2A11 lSCA-BKR2Dll 1SCA-BKR2Fll 1SCA-BKR2D13 lSCA-BKR8A21 1SCA-BKR8B21 SCV-PNL2B1-M(Main) 1LAR-PNL1R1 lLAR-PNL1R2 1LAR-PNL1R3 1LAR-PNL1R4 1LAR-PNL1R5 lLAR-PNL1R6 lLAR-PNL1R7 lLAR-PNL1R8 lLAR-PNL1R9 1LAR-PNLlR10 1LAR-PNLlRll 1LAR-PNLlR12 lLAR-PNLlR13 lLAR-PNLlR14 lLAR-PNL1R16 lLAR-PNLlR17 lLAR-PNLlR18 lLAR-PNL1R19 1SCA-PNL2A1 1SCA-PNL2D1 1SCA-PNL2F2 1SCA-PNL2D3 1SCA-PNL8A2 1SCA-PNL8B2 1HTS*PNL2M 1HTS*PNL2M 1HTS*PNL2M lHTS*PNL2M 1HTS*PNL2N 1HTS*PNL2N lHTS-PNLlN SCV*PNL2B1 I

(continued)

RIVER BEND TR 3.8-13 (42vi)

Revision 95

Electrical Equipment Protective Devices TR 3.8.11 TABLE 3.8.11-1 (page 3 of 7)

PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTION DEVICES C.

480 VAC Molded Case Circuit Breakers 1.Gould Circu~it Type FVNR Location lEHS*MCC2A lEHS*MCC2B lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A 1NHS-MCC2A lNHS-MCC2B lNHS-MCC2B 1NHS-MCC2B lNHS-MCC2B lNHS-MCC2C 1NHS-MCC2D 1NHS-MCC2E 1NHS-MCC2E lNHS-MCC2E lNHS-MCC2E lNHS-MCC2E lNHS-MCC2E lNHS-MCC2F lNHS-MCC2F lNHS-MCC2F lNHS-MCC2F 1NHS-MCC2F lNHS-MCC2F lNHS-MCC2F lNHS-MCC8A lNHS-MCC8A NHS-MCC8B lNHS-MCC8B lNHS-MCC102B Breaker Tvye A821 with Gould Starter/Controller I

Cubicle 2B 2B 2A 3C 3D 4D 4E 6E 4C 5C 6B 6C 1E 3B 2C 3B 4D 4E 6C 1C 3B 3C 4A 5A 5C 6B 6C 2E 3E 1D 3C 3A EauiD. No.

iCPM*FNlA lCPM*FNlB lC41-DO02 IDER-PlA IDER-P2A 1DFR-P2A lDFR-PlA lHVR-FNlA IDER-PIB 1DER-P2B 1DFR-P2B lHVR-FNlD lB33-COOlAH lB33-COO1BH lHVR-FNlC lG36-COOlA lWCS-PSA 1B33-D003A2 1B33-D003A5 lG36-AOO1AG lG36-COOlB lHVR-FNlB lDFR-PlB lWCS-P5B 1B33-D003B5 1B33-D003B2 1G36-A002AG 1F42-D002 1DFR-P6A F42-EOO1 1DFR-P6B lCPP-FNl I

(continued)

RIVER BEND TR 3.8-14 (42vii)

Revision 95

Electrical Equipment Protective Devices TR 3.8.11 TABLE 3.8.11-1 (page 4 of 7)

PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTION DEVICES C.

480 VAC Molded Case Circuit Breakers (continued)

2.

Gould Circuit Type FVR Breaker Tvne A822 with Gould Starter/Controller

_

I Location 1EHS*MCC2A 1EHS*MCC2A 1EHS*MCC2A lEHS*MCC2A 1EHS*MCC2A 1EHS*MCC2A 1EHS*MCC2A lEHS*MCC2B 1EHS*MCC2B 1EHS*MCC2B lEHS*MCC2B lEHS*MCC2B lEHS*MCC2B lEHS*MCC2B 1EHS*MCC2B lEHS*MCC2B lEHS*MCC2C 1EHS*MCC2C lEHS*MCC2C 1EHS*MCC2C lEHS*MCC2C 1EHS*MCC2C lEHS*MCC2C lEHS*MCC2C 1EHS*MCC2C lEHS*MCC2C 1EHS*MCC2C 1EHS*MCC2D lEHS*MCC2D 1EHS*MCC2D lEHS*MCC2D lEHS*MCC2D lEHS*MCC2D lEHS*MCC2D 1EHS*MCC2D lEHS*MCC2D lEHS*MCC2D lEHS*MCC2D lEHS*MCC2K Cubicle 2A 5A 5B 5C 6A 6B 6C lB 1D 2A 5A 5B 5C 6A 6B 6C 1D 2C 2D 3A 3B 3C 4A 4B 4C 5B 5C 1C 1D 2C 2D 3A 3B 3C 4A 4B 4C 5A 1D EauiD. No.

lC41*MOVFOOlA 1SWP*MOV4A 1SWP*MOV5B lSWP*MOV502A 1RCS*MOV58A lRCS*MOV59A lSWP*MOV503A lSFC*MOV120 lSFC*MOV139 1C41*MOVFOOlB 1SWP*MOV4B 1SWP*MOV5A 1SWP*MOV502B 1RCS*MOV58B 1RCS*MOV59B 1SWP*MOV503B lCCP*MOV142 lCCP*MOV143 lCPM*MOV1A lCPM*MOV2A 1CPM*MOV3A 1E12*MOVF037A 1E12*MOVF042A lHVN*MOV22A 1RCS*MOV6OA 1RCS*MOV61A lCPM*MOV4A lB21*MOVFO16 1CPM*MOVlB lCPM*MOV2B lCPM*MOV3B lCPM*MOV4B lCPP*MOV104 lE51*MOVF063 lE51*MOVF076 1G33*MOVF001 1G33*MOVF028 1WCS*MOV178 lCCP*MOV144 (continued)

RIVER BEND TR 3.8-15 (42viii)

Revision 95

Electrical Equipment Protective Devices TR 3.8.11 TABLE 3.8.11-1 (page 5 of 7)

PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTION DEVICES C.

480 VAC Molded Case Circuit Breakers (continued)

2.

Gould Circuit Breaker Tvoe A822 with Tvye FVR (continued)

Gould Starter/Controller I

Location lEHS*MCC2K lEHS*MCC2K lEHS*MCC2K 1EHS*MCC2K EHS-MCC2K lEHS*MCC2K 1EHS*MCC2K lEHS*MCC2K lEHS*MCC2K 1EHS*MCC2K lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2B lNHS-MCC2B lNHS-MCC2B lNHS-MCC2B lNHS-MCC2B lNHS-MCC2D lNHS-MCC2D lNHS-MCC2D 1NHS-MCC2E lNHS-MCC2E lNHS-MCC2F lNHS-MCC8A Cubicle 2A 2B 2C 3D 4A 4D SA 6C 6D 7D 1C 1D SC 5D 7D 3B 3C 4D 5D 6D 2E 3D 4D 3A 5E 2D 4E Equip. No.

1RCS*MOV6OB lRCS*MOV61B 1HVN*MOV22B 1E12*MOVF042B E12-MOVF009 1G33*MOVF053 1G33*MOVF040 lHVN*MOV102 lE12*MOVF037B lCCP*MOV158 lB21-MOVFOO0 lB33-MOVF023A lG33-MOVF102 lB33-MOVF067A lG33-MOVF106 lG33-MOVF042 lB21-MOVF002 lG33-MOVF044 lG33-MOVF100 lG33-MOVF101 lB21-MOVFOO5 lB33-MOVF067B 1B33-MOVF023B lG33-MOVF031 lG33-MOVF107 lG33-MOVF104 lCll-MOVF003 I

3.

Gould Circuit Breaker Type HE43 lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2A lNHS-MCC2C lNHS-MCC2D lNHS-MCC2D lNHS-MCC8A lNHS-MCC8A 2B 2C 2D 3B 1CT SC 5D 1E 2D lPOP-WR2GO1 lPOP-WR2AO1 lPOP-WR2AO2 lPOP-WR2GO2 1H22-PNLP008 lPOP-WR2D01 lPOP-WR2DO2 lF15-EO06 1F15-E005 (continued)

RIVER BEND TR 3.8-16 (42ix)

Revision 95

Electrical Equipment Protective Devices TR 3.8.11 TABLE 3.8.11-1 (page 6 of 7)

PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTION DEVICES C.

480 VAC Molded Case Circuit Breakers (continued)

3.

Gould Circuit Breaker Type HE43 (continued)

Location 1NHS-MCC8A lNHS-MCC8A lNHS-MCC8A lNHS-MCCSB lNHS-MCC2F 1NHS-MCC2F 1NHS-MCC2E lNHS-MCC2A 1NHS-MCC2A lNHS-MCC2B lNHS-MCC8A

4.

Gould Circuit Type FVNR lEHS*MCC2A lEHS*MCC2B 1NHS-MCC2B lNHS-MCC2E 1NHS-MCC2E 1NHS-MCC2F 1NHS-MCC2F lNHS-MCC2D

5.

Gould Circuit Type 2SP1W INHS-MCC102A lNHS-MCC102A 1NHS-MCC102A lNHS-MCC102B 1NHS-MCC102B 1NHS-MCC102B Cubicle Equip. No.

4C 6B 6C 2A 2A 2B 3C 3A 4A iC 3D JRB-RCPT1 1FNR-P06 1FNR-PO8 lFNR-P07 lPOP-WR2F01 lJRB-ELlA POP-WR2EO1 lFNR-PO9 lFNR-P10 lFNR-Pl1 POP-WR8AO1 Breaker Type A80 with Gould Starter/Controller 2C 2C 2D ID 6D 4D 6D 1E 1C41*COOlA lC41*COOlB lC41*D003 lB33-DO03Al 1B33-D003A4 1B33-D003Bl lB33-D003B4 1G36-C002 Breaker Type A80 with Gould Starter/Controller I

iC 2C 3B IC 2C 3B lDRS-UClA lDRS-UCIC lDRS-UClE lDRS-UCIB lDRS-UCID lDRS-UClF I

(continued)

RIVER BEND TR 3.8-17 (42x)

Revision 95

Inclined Fuel Transfer System TR 3.9.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.9.15.1 Verify that no personnel are in areas Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months immediately adjacent to the IFTS tube and prior to the that the floor plugs are installed and startup of the access doors, to rooms through which the IFTS IFTS tube penetrates, are closed and locked.

TSR 3.9.15.2 Verify that at least one IFTS carriage 7 days position indicator at each carriage position is OPERABLE and at least one level sensor is OPERABLE or the level can be confirmed visually.

TSR 3.9.15.3 Verify that the warning lights outside of 7 days each access door are OPERABLE or the floor plug is installed for the applicable access doors.

TSR 3.9.15.4 Verify that the access interlock and palm 7 days switch are OPERABLE for the containment isolation valve room.

TSR 3.9.15.5 Verify that the blocking valve in the 7 days Fuel Building IFTS hydraulic power unit is OPERABLE.

Continued RIVER BEND TR 3.9-11 (13ix)

Revision 99

ADMINISTRATION TR 5.0 TR 5.4 Procedures TR 5.4.1 Written procedures shall be established, implemented, and maintained covering the activities referenced below:

a.

The applicable procedures recommended in Appendix A of Regulatory Guide 1.33, Revision 2, February 1978.

b.

The emergency operating procedures required to implement the requirements of NUREG-0737 and supplements thereto.

c.

Refueling operations.

d.

Surveillance and test activities of safety-related equipment.

e.

Security Plan implementation.

f.

Emergency Plan implementation.

g.

Fire Protection Program implementation.

h.

Process Control Program implementation.

i.

Offsite Dose Calculation Manual implementation.

j.

Quality Assurance Program for effluent and environmental monitoring.

k.

Technical Requirements Manual implementation.

1.

Technical Specifications Bases Control Program implementation.

TR 5.4.2 Each procedure of Requirement 5.4.1, and changes thereto, shall be reviewed and approved in accordance with Requirement 5.8.2.1.

TR 5.4.3 Temporary changes to procedures of Requirement 5.4.1 may be made provided:

a.

The intent of the original procedure is not altered;

b.

The change is approved by two members of the plant management staff, at least one of whom holds a Senior Operator license on the unit affected; and

c.

The change is documented, reviewed by the OSRC as required by USAR Section 13.4.1, and approved in accordance with Requirement 5.8.2.1 within 14 days of implementation.

TR 5.4.4 Procedures may use either the plant specific title listed in Technical Requirement 5.2.1 or the generic Technical Specification title when identifying a person fulfilling the responsibilities of a position delineated in Technical Specifications.

RIVER BEND TR 5-6 Revision 94

ADMINISTRATION TR 5.0 TR 5.6.3 Annual Effluent Release Report (continued)

The Annual Radioactive Effluent Release Report shall include any changes made during the reporting period to the PROCESS CONTROL PROGRAM (PCP) and to the ODCM, as well as a listing of new locations for dose calculations and environmental monitoring identified by the land use census pursuant to Requirement 3.12.2.

TR 5.6.4 and TR 5.6.5 (Not Used)

TR 5.6.6 (Deleted)

TR 5.6.7 (not used)

TR 5.6.8 Startup Report I

TR 5.6.8.1 A summary report of plant startup and power escalation testing shall be submitted following (1) receipt of an Operating License, (2) amendment to the license involving a planned increase in power level, (3) installation of fuel that has a different design or has been manufactured by a different fuel supplier, and (4) modifications that may have significantly altered the nuclear, thermal, or hydraulic performance of the unit.

RIVER BEND TR 5-13 Revision 94

ADMINISTRATION TR 5.0 TR 5.9.2 The following records shall be retained for the duration of the unit Operating License:

a.

Records and drawing changes reflecting unit design modifications made to systems and equipment described in the Final Safety Analysis Report.

b.

Records of new and irradiated fuel inventory, fuel transfers, and assembly burnup histories.

c.

Records of radiation exposure for all individuals entering radiation control areas.

d.

Records of gaseous and liquid radioactive material released to the environs.

e.

Records of transient or operational cycles for those unit components identified by the Technical Specification 5.5.5 program.

f.

Records of reactor tests and experiments.

g.

Records of training and qualification for current members of the unit staff.

h.

Records of inservice inspections performed pursuant to Technical Specifications and Technical Requirements.

i.

Not Used.

j.

Records of reviews performed for changes made to procedures or equipment or reviews of tests and experiments pursuant to 10 CFR 50.59.

k.

Records of meetings of the OSRC and the SRC.

1.

Records of the service lives of all snubbers, including the date at which the service life commences, and associated installation and maintenance records.

m.

Records of analysis required by the Radiological Environmental Monitoring Program that would permit evaluation of the accuracy of the analysis at a later date.

This should include procedures effective at the specified times and QA records showing that these procedures were followed.

TR 5.9.3 Records of quality assurance activities required by the Quality Assurance Program Manual not listed in requirements 5.9.1 and 5.9.2 are retained in accordance with Regulatory Guide 1.88, Revision 2.

RIVER BEND TR 5-21 Revision 94 River Bend Station RBG-46419 Technical Specifications Bases Change Package

TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES PAGER REV NUMBER I

PACE I

NUMBER I

REV PAGE lREV NUMBER I

PAGE NUMBER I

REV 2.0-1 2.0-2 2.0-3 2.0-4 2.0-5 2.0-6 2.0-7 2.0-8 2.0-9 3.0-1 3.0-2 3.0-3 3.0-4 3.0-5 3.0-6 3.0-7 3.0-8 3.0-9 3.0-10 3.0-11 3.0-12 3.0-13 3.0-13a 3.0-14 3.0-15 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 3.1-22 3.1-23 0

6-15 6-15 6-15 115 115 0

115 115 0

0 0

108 108 108 0

0 0

0 3-10 3-10 3-10 3-10 3-10 0

0 0

6-13 0

1 0

0 5-2 0

3.1-24 3.1-25 3.1-26 3.1-27 3.1-28 3.1-29 3.1-30 3.1-31 3.1-32 3.1-33

3. 1-34 3.1-35 3.1-36

3. 1-37 3.1-38 3.1-39 3.1-40 3.1-41 3.1-42 3.1-43 3.1-44 3.1-45 3.1-46 3.1-47 3.1-48 3.1-49 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 3.2-14 3.2-15 3.2-16 3.2-17 3.2-18 107 107 0

0 0

6-14 6-14 6-14 0

6-13 6-13 6-13 0

0 0

5-6 1

6-14 1

115 118 118 0

115 0

6-4 6-4 3-7 0

6-15 6-4 6-15 0

6-4 6-4 4-8 4-8 4-8 4-8 4-8 4-8 4-8 3.3-1 3.3-2 3.3-3 3.3-4 3.3-5 3.3-6 3.3-7 3.3-8 3.3-8a 3.3-8b 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 3.3-25a 3.3-26 3.3-27 3.3-28 3.3-29 3.3-30 3.3-31 3.3-31a 3.3-32 3.3-33 3.3-34 3.3-35 3.3-36 3.3-37 3.3-38 3.3-39 3.3-39a 3.3-39b 3.3-39c 3.3-39d 0

6-7 0

0 0

0 6 -4 4 -8 4 -8 4 -8 4 -8 4 -8 1

0 6 -4 0

0 0

2 -7 1

1 1

6 -4 6-15 1

5-1 4 -8 0

0 0

0 4 -8 4 -8 4 -8 4 -8

3. 3-39e

3. 3-39f

3. 3-39g

3. 3-39h 3.3-40 3.3-41 3.3-42 3.3-43 3.3-44 3.3-45 3.3-46 3.3-47 3.3-48 3.3-49 3.3-50 3.3-51 3.3-52 3.3-53 3.3-54 3.3-55 3.3-56 3.3-57 3.3-58 3.3-59 3.3-60 3.3-61 3.3-62 3.3-63 3.3-64 3.3-65 3.3-66 3.3-67 3.3-68 3.3-69 3.3-70 3.3-71

3. 3-72 3.3-73

3. 3-74 3.3-75 3.3-76 3.3-77 3.3-78 3.3-79 101 4-8 4-8 4-8 0

6-13 6-6 6-13 0

0 0

0 6 -13 1

0 1

116 6-2 122 1

0 0

0 1

0 0

0 1

1 1

0 0

1 1

2-1 2-1 0

106 0

0 I

RIVER BEND TSB-a Revision No. 122

TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES PAGE I REV NUMBERl PAGE I REV NUMBER I

PAGE I REV NUMBER l

PAGE I REV NUMBER 3.3-80 3.3-81 3.3-82 3.3-83 3.3-84 3.3-85 3.3-86 3.3-87 3.3-88 3.3-89 3.3-90 3.3-91 3.3-92 3.3-93 3.3-94 3.3-95 3.3-96 3.3-97 3.3-98 3.3-99 3.3-100 3.3-101 3.3-102 3.3-103 3.3-104 3.3-105 3.3-106 3.3-107 3.3-108 3.3-109 3.3-110 3.3-111 3.3-112 3.3-113 3.3-114 3.3-115 3.3-116 3.3-117 3.3-118 0

0 0

0 6-12 0

0 0

0 103 0

0 3.3-120 3.3-121 3.3-122 3.3-123 3.3-124 3.3-125 3.3-126 3.3-127 3.3-128 3.3-129 3.3-130 3.3-131 3.3-132 3.3-133 3.3-134 3.3-135 3.3-136 3.3-137 3.3-138 3.3-139 3.3-140 3.3-141 3.3-142 3.3-143 3.3-144 3.3-145 3.3-146 3.3-147 3.3-148 3.3-149 3.3-150 3.3-151 3.3-152 3.3-153 3.3-154 3.3-155 3.3-156 3.3-157 3.3-158 113 0

0 4-1 0

2-6 0

0 0

115 115 0

104 110 115 2-6 0

0 109 0

109 0

0 116 0

0 0

115 115 0

3.3-160 3.3-161 3.3-162 3.3-163 3.3-164 3.3-165 3.3-166 3.3-167 3.3-168 3.3-169 3.3-170 3.3-171 3.3-172 3.3-173 3.3-174 3.3-175 3.3-176 3.3-177 3.3-178 3.3-179 3.3-180 3.3-181 3.3-182 3.3-183 3.3-184 3.3-185 3.3-186 3.3-187 3.3-188 3.3-189 3.3-190 3.3-191 3.3-192 3.3-193 3.3-194 3.3-195 3.3-196 3.3-197 3.3-198 104 0

0 0

110 6-5 6-5 6-5 6-5 6-5 6-5 6-5 6-5 6-5 6-5 0

0 1

0 0

3-4 0

3.3-200 3.3-201 3.3-202 3.3-203 3.3-204 3.3-205

3. 3-206 3.3-207 3.3-208

3. 3-209 3.3-210 3.3-211 3.3-212 3.3-213 3.3-214 3.3-215 3.3-216 3.3-217 3.3-218 3.3-219 3.3-220 3.3-221 3.3-222 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 0

115 0

0 3-4 0

0 0

1 1

1 107 0

3-3 3-3 0

0 0

1 0

4-8 4 -8 114 4-8 112 4-8 4 -8 0

0 0

6-7 1

I B 3.3-119 B 3.3-159 B 3.3-199 B 3.4-17 RIVER BEND TSB-b Revision No. 116

TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES PAGE R REV NUMB3ERl PAGE I REV NUMBER I

PAGE NUMBER I

REV PAGE I REV NUMBER l

3.4-18 3.4-19 3.4-20 3.4-21 3.4-21a 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 3.4-34 3.4-35 3.4-36 3.4-37 3.4-38 3.4-39 3.4-40 3.4-41 3.4-42 3.4-43 3.4-44 3.4-45 3.4-46 3.4-47 3.4-48 3.4-49 3.4-50 3.4-51 3.4-52 3.4-53 3.4-54 3.4-55 3.4-56 3.4-57 0

109 109 109 109 0

0 0

3-4 0

0 0

110 110 110 110 0

0 0

0 6-4 6-13 6-4 0

0 3.4-58 3.4-59 3.4-60 3.4-61 3.4-62 3.4-63 3.5-1 3.5-2 3.5-3 3.5-4 3.5-5 3.5-6 3.5-7 3.5-8 3.5-9 3.5-10 3.5-11 3.5-12 3.5-13

3. 5-13a 3.5-14 3.5-15 3.5-16 3.5-17 3.5-18 3.5-19 3.5-20 3.5-21 3.5-22 3.5-23 3.5-24 3.5-25 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 0

0 0

6-13 6-14 6-14 0

0 6-14 3-7 0

0 0

0 113 109 109 109 109 0

0 0

6-14 6-9 0

0 0

2-1 2-1 2-1 0

110 110 2-3 2-3 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 3.6-22 3.6-23 3.6-24 3.6-24a 3.6-25 3.6-26 3.6-27 3.6-28 3.6-29 3.6-30 3.6-31 3.6-32 3.6-33 3.6-34 3.6-35 3.6-36 3.6-37 3.6-38 3.6-39 3.6-40 3.6-41 3.6-42 3.6-43 3.6-44 3.6-45 3.6-46 3.6-47 3.6-48 3.6-49 2-3 2-3 101 6-10 110 3-4 0

0 3-4 3-4 3-4 0

110 0

6-11 6-11 110 3-9 121 110 2-1 0

0 0

109 0

109 109 0

0 0

0 3-9 3-9 3-9 3-9 1

0 0

3.6-50 3.6-51 3.6-52 3.6-53 3.6-54 3.6-55 3.6-56 3.6-57 3.6-58 3.6-59 3.6-60 3.6-61 3.6-62 3.6-63 3.6-64 3.6-65 3.6-66 3.6-67 3.6-68 3.6-69 3.6-70 3.6-71 3.6-72 3.6-73 3.6-74 3.6-75 3.6-76 3.6-77 3.6-78 3.6-79 3.6-80 3.6-81 3.6-82 3.6-83 3.6-84 3.6-85 3.6-86 3.6-87 3.6-88 3.6-89 6-13 110 110 0

0 0

0 3-4 0

0 0

0 122 122 122 122 122 122 0

0 0

0 6-12 3-3 122 0

0 2-8 2-8 121 6-5 115 6-5 110 6-5 6-5 I

RIVER BEND TSB-c Revision No. 122

TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES PAGE I REV NUMBER PAGE I

NUMBER REV PAGE NUMBER REV PAGE REV NUMBER I

_~~~~~

_4 3.6-90 3.6-91 3.6-92 3.6-93 3.6-94 3.6-95 3.6-96 3.6-97 3.6-98 3.6-99 3.6-100 3.6-101 3.6-102 3.6-103 3.6-104 3.6-105 3.6-106 3.6-107 3.6-108 3.6-109 3.6-110 3.6-111 3.6-112 3.6-113 3.6-114 3.6-115 3.6-116 3.6-117 3.6-118 3.6-119 3.6-120 3.6-121 3.6-122 3.6-123 3.6-124 3.6-125 3.6-126 3.6-127 3.6-128 6-5 115 6-5 115 6-5 6-5 0

1 0

0 0

121 121 121 6-5 110 0

6-5 6-5 6-5 6-5 6-5 0

6-5 6-5 0

0 0

0 110 121 119 2-4 2-4 2-4 2-4 2-4 2-4 110 3.6-129 3.6-130 3.6-131 3.6-132 3.6-133 3.6-134 3.6-135 3.6-136 3.6-137 3.6-138 3.6-139 3.6-140 3.6-141 3.6-142 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 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 3-4 2-4 2-4 3-4 3-4 2-8 2-8 6-2 2-8 2-8 2-8 2-8 2-8 2-8 110 110 110 1

1 0

3-1 1

0 110 110 110 115 115 0

110 4-4 110 6-13 115 6-13 0

0 1

6-14 3.7-26 3.7-27 3.7-28 3.7-29 3.7-30 3.7-31 3.8-1 3.8-2 3.8-3 3.8-4 3.8-5 3.8-6 3.8-7 3.8-8 3.8-8a 3.8-9 3.8-10 3.8-11 3.8-12 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 6-7 0

0 115 0

115 0

5-3 0

0 105 0

0 105 105 105 0

0 0

0 102 102 102 102 102 117 117 102 113 113 113 102 102 113 113 113 113 102 3.8-32 3.8-33 3.8-34 3.8-35 3.8-36 3.8-37 3.8-38 3.8-39 3.8-40 3.8-41 3.8-42 3.8-43 3.8-44 3.8-45 3.8-46 3.8-47 3.8-48 3.8-49 3.8-50 3.8-51 3.8-52 3.8-53 3.8-54 3.8-55 3.8-56 3.8-57 3.8-58 3.8-59 3.8-60 3.8-61 3.8-62 3.8-63 3.8-64 3.8-65 3.8-66 3.8-67 3.8-68 3.8-69 3-1 3-1 110 0

0 115 110 102 102 3-2 0

0 0

0 3-2 3-2 0

5-5 0

0 1

0 120 120 120 110 110 115 0

0 0

0 1

4-5 4-5 1

I RIVER BEND TSB-d Revision No. 121

TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES PAGE NUMBER REV PAGE I

NUMBER PAGE lREV NUMBER I

PAGE I REV NUMBER I

-XI 3.8-70 3.8-71 3.8-72 3.8-73 3.8-74 3.8-75 3.8-76 3.8-77 3.8-78 3.8-79 3.8-80 3.8-81 3.8-82 3.8-83 3.8-84 3.8-85 3.8-86 3.8-87 3.8-88 3.8-89 3.8-90 3.8-91 3.8-92 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 3.9-13 3.9-14 3.9-15 3.9-16 3.9-17 111 111 111 0

110 115 110 0

0 1

0 0

0 103 0

0 1

110 115 115 0

0 0

4-5 119 0

0 0

103 0

0 0

0 6-14 3.9-18 3.9-19 3.9-20 3.9-21 3.9-22 3.9-23 3.9-24 3.9-25 3.9-26

3. 9-27 3.9-28

3. 9-28a 3.9-29 3.9-30 3.9-31 3.9-32

3. 9-32a 3.10-1 3.10-2 3.10-3 3.10-4 3.10-5 3.10-6 3.10-7 3.210-8 3.10-9 3.10-10 3.10-11 3.10-12 3.10-13 3.10-14 3.10-15 3.10-16 3.10-17 3.10-18 3.10-19 3.10-20 3.10-21 3.10-22 0

115 119 115 115 119 115 0

0 4-2 4-2 4-2 0

0 0

0 B

B B

B 3.10-23 3.10-24 3.10-25 3.10-26 3.10-27 3.10-28 3.10-29 3.10-30 3.10-31 3.10-32 3.10-33 3.10-34 3.10-35 3.10-36 3.10-37 3.10-38 0

0 0

6-14 RIVER BEND TSB-e Revision No. 119

SDV Vent and Drain Valves B 3.1.8 BASES APPLICABLE allow continuous drainage of the SDV during normal plant operation to SAFETY ANALYSES ensure the SDV has sufficient capacity to contain the reactor coolant (continued) discharge during a full core scram. To automatically ensure this capacity, a reactor scram (LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation") is initiated if the SDV water level exceeds a specified setpoint. The setpoint is chosen such that all control rods are inserted before the SDV has insufficient volume to accept a full scram.

SDV vent and drain valves satisfy Criterion 3 of the NRC Policy Statement.

LCO The OPERABILITY of all SDV vent and drain valves ensures that, during a scram, the SDV vent and drain valves will close to contain reactor water discharged to the SDV piping. Since the vent and drain lines are provided with two valves in series, the single failure of one valve in the open position will not impair the isolation function of the system.

Additionally, the valves are required to be open to ensure that a path is available for the SDV piping to drain freely at other times.

APPLICABILITY In MODES 1 and 2, scram may be required, and therefore, the SDV vent and drain valves must be OPERABLE. In MODES 3 and 4, control rods are not able to be withdrawn since the reactor mode switch is in Shutdown and a control rod block is applied. This provides adequate controls to ensure that only a single control rod can be withdrawn. Also, during MODE 5, only a single control rod can be withdrawn from a core cell containing fuel assemblies. Therefore, the SDV vent and drain valves are not required to be OPERABLE in these MODES since the reactor is subcritical and only one rod may be withdrawn and subject to scram.

ACTIONS The ACTIONS table is modified by Note 1 indicating that a separate Condition entry is allowed for each SDV vent and drain line. This is acceptable, since the Required Actions for each Condition provide appropriate compensatory actions for each inoperable SDV line.

Complying with the Required Actions may allow for continued operation, and subsequent inoperable SDV lines are governed by subsequent Condition entry and application of associated Required Actions.

The ACTIONS table is modified by a second Note stating that an isolated line may be unisolated under administrative control to allow draining and venting of the SDV. When a line is isolated, the potential for an inadvertent scram due to high SDV level is increased. During these periods, the line may be unisolated under administrative control. This allows any accumulated water in the line to be drained, to preclude a reactor scram on SDV high level. This is acceptable, since the administrative controls ensure the valve can be closed quickly, by a dedicated operator, if a scram occurs with the valve open.

(continued)

I RIVER BEND B 3.1-46 Revision No. 118

SDV Vent and Drain Valves B 3.1.8 BASES ACTIONS A. 1 (continued)

When one SDV vent or drain valve is inoperable in one or more lines, the associated line must be isolated to contain the reactor coolant during a scram. The 7 day Completion Time is reasonable, given the level of redundancy in the lines and the low probability of a scram occurring during the time the valve(s) are inoperable and the line is not isolated.

The SDV is still isolable since the redundant valve in the affected line is OPERABLE. Since the SDV is still isolable, the affected SDV line may be opened. This allows accumulated water in the line to be drained to preclude a reactor scram on SDV high level. During these periods, the single failure criterion may not be preserved, and a higher risk exists to allow reactor water out of the primary system during a scram.

B.1 If both valves in a line are inoperable, the line must be isolated to contain the reactor coolant during a scram.

The 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Completion Time to isolate the line is based on the low probability of a scram occurring while the line is not isolated and unlikelihood of significant CRD seal leakage.

C.1 If any Required Action and associated Completion Time is not met, the plant must be brought to a MODE in which the LCO does not apply. To achieve this status, the plant must be brought to MODE 3 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The allowed Completion (continued)

RIVER BEND B 3.1-47 Revision No. 118

PAM Instrumentation B 3.3.3.1 BASES LCO

9. Primary Containment Area Radiation (High Range)

(continued)

Primary containment area radiation (high range) is a Category I variable provided to monitor for the potential of significant radiation releases and to provide release assessment for use by operators in determining the need to invoke site emergency plans.

Primary containment area radiation (high range) PAM instrumentation consists of two high range containment area radiation signals transmitted from separate radiation elements and continuously displayed on two control room LED digital displays. The RM-23 control and display modules are the primary indication used by the operator during an accident. Therefore, the PAM Specification deals specifically with this portion of the instrument channel.

10. 11. Drywell and Containment Hydrogen Analyzer DELETED

12. Penetration Flow Path, Automatic Primary Containment Isolation Valve (PCIV) Position PCIV position is provided for verification of containment integrity. In the case of PCIV position, the important information is the status of the containment penetration flow path. The LCO requires one channel of valve position indication in the control room to be OPERABLE for each automatic PCIV in a containment penetration flow path, i.e.,

(continued)

RIVER BEND B 3.3-54 Revision No. 122

PCIVs B 3.6.1.3 BASES SURVEILLANCE SR 3.6.1.3.9 (continued)

REQUIREMENTS evaluations of Reference 4 are met. The leakage rate of each bypass leakage path is assumed to be the maximum pathway leakage (leakage through the worse of the two isolation valves) unless the penetration is isolated by use of one closed and de-activated power operated or automatic valve, closed manual valve, or blind flange. In this case, the leakage rate of the isolated bypass leakage path is assumed to be the actual pathway leakage through the isolation device. If both isolation valves in the penetration are closed, the actual leakage rate is the lesser leakage rate of the two valves. This method of quantifying maximum pathway leakage is only to be used for this SR (i.e., Appendix J, Option B maximum pathway leakage limits are to be quantified in accordance with Appendix J, Option B). The Frequency is required by the Primary Containment Leakage Rate Testing Program (Ref. 5).

A note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2 and 3. In the other conditions the Reactor Coolant System is not pressurized and primary containment leakage limits are not required.

SR 3.6.1.3.10 The analyses in References 2 and 3 are based on leakage out of the primary containment that is less than the specified leakage rate. The leakage rate of 150 scfh when pressurized to Ž Pa, 7.6 psig, per main steam line provides assurance that the assumptions in the radiological evaluations of Reference 4 are met. Leakage through the valves sealed in each division of MS-PLCS must be < 150 scfh per division when tested at 2 Pa' 7.6 psig. The leakage rate must be verified to be in accordance with the leakage test requirements of Reference 4, as modified by approved exemptions.

A note is added to this SR which states that these valves are only required to meet this leakage limit in MODES 1, 2 and 3. In the other conditions, the Reactor Coolant System is not pressurized and specific primary containment leakage limits are not required. The Frequency is required by the Primary Containment Leakage Rate Testing Program (Ref. 5).

___(continued)

RIVER BEND B 3.6-27 Revision No. 121

Primary Containment Hydrogen Recombiners B 3.6.3.1 B 3.6 CONTAINMENT SYSTEMS B 3.6.3.1 Primary Containment Hydrogen Recombiners DELETED I

RIVER BEND B 3.6-66 Revision No. 122

Primary Containment Hydrogen Recombiners B 3.6.3.1 DELETED I

RIVER BEND B 3.6-67 Revision No. 122

Primary Containment Hydrogen Recombiners B 3.6.3.1 DELETED RIVER BEND B 3.6-68 Revision No. 122

Primary Containment Hydrogen Recombiners B 3.6.3.1 DELETED RIVER BEND B 3.6-69 Revision No. 122

Primary Containment Hydrogen Recombiners B 3.6.3.1 DELETED I

RIVER BEND B 3.6-70 Revision No. 122

Primary Containment Hydrogen Recombiners B 3.6.3.1 DELETED I

RIVER BEND B 3.6-71 Revision No. 122

Primary ContainmentlDrywell Hydrogen Mixing System B 3.6.3.3 B 3.6 CONTAINMENT SYSTEMS B 3.6.3.3 Primary Containment/Drywell Hydrogen Mixing System BASES BACKGROUND The Primary Containment/Drywell Hydrogen Mixing System ensures a uniformly mixed post accident containment atmosphere, thereby minimizing the potential for local hydrogen burns due to a pocket of hydrogen above the flammable concentration.

The Primary Containment/Drywell Hydrogen Mixing System is an Engineered Safety Feature and is designed to operate following a loss of coolant accident (LOCA) in post accident environments without loss of function. The system has two independent subsystems, each consisting of a hydrogen mixing fan and associated valves, controls, and piping.

Each subsystem is sized to pump 513 scfm. Each subsystem is powered from a separate emergency power supply. Since each subsystem can provide 100% of the mixing requirements, the system will provide its design function with a worst case single active failure.

Following a LOCA, the drywell is immediately pressurized due to the release of steam into the drywell environment. This pressure is relieved by the lowering of the water level within the weir wall, clearing the drywell vents and allowing the mixture of steam and noncondensibles to flow into the primary containment through the suppression pool, removing much of the heat from the steam. The remaining steam in the drywell begins to condense as steam flow from the reactor pressure vessel ceases, the drywell pressure falls rapidly. The Emergency Operating Procedures (EOPs) and the Severe Accident Procedures (SAPs) require actuation of the hydrogen mixing system when the drywell hydrogen concentration reaches the minimum detectable level, and the Reactor Pressure Vessel (RPV), pressure drops below 30 psig.

When the hydrogen mixing system is actuated, the air from the primary containment enters the drywell through two openings. These openings are located diametrically opposite each other on the circumference of the drywell, just above the suppression pool. The drywell atmosphere is exhausted into the larger primary containment volume through two penetrations located at the top of the drywell by means of two recirculation fans. Thus, the air from the primary (continued)

RIVER BEND B 3.6-78 Revision No. 122

Secondary Containment-Operating B 3.6.4.1 B 3.6 CONTAINMENT SYSTEMS B 3.6.4.1 Secondary Containment-Operating BASES BACKGROUND The function of the secondary containment is to contain, dilute, and hold up fission products that may leak from primary containment following a Design Basis Accident (DBA). In conjunction with operation of the Standby Gas Treatment (SGT) System and closure of certain valves whose lines penetrate the secondary containment, the secondary containment is designed to reduce the activity level of the fission products prior to release to the environment and to isolate and contain fission products that are released during certain operations that take place inside primary containment, when primary containment is not required to be OPERABLE, or that take place outside primary containment.

The secondary containment consists of the shield building and auxiliary building, and completely encloses the primary containment and those components that may be postulated to contain primary system fluid. This structure forms a control volume that serves to hold up and dilute the fission products. It is possible for the pressure in the control volume to rise relative to the environmental pressure (e.g., due to pump/motor heat load additions). To prevent ground level exfiltration while allowing the secondary containment to be designed as a conventional structure, the secondary containment requires support systems to maintain the control volume pressure at less than the external pressure. Requirements for these systems are specified separately in LCO 3.6.4.2, "Secondary Containment Isolation Dampers (SCIDs) and Fuel Building Isolation Dampers (FBIDs)," and LCO 3.6.4.3, "Standby Gas Treatment (SGT)

System."

The isolation devices for the penetrations in the secondary containment boundary are a part of the secondary containment barrier. To maintain this barrier:

a.

All Auxiliary Building penetrations and Shield Building annulus penetrations required to be closed during accident conditions are either:

(continued)

I RIVER BEND B 3.6-83 Revision No. 121

B 3.6 CONTAINMENT SYSTEMS B 3.6.4.4 Deleted RIVER BEND B 3.6-1 01 Revision No. 121

THIS PAGE INTENTIONALLY LEFT BLANK I

RIVER BEND B 3.6-102 Revision No. 121

THIS PAGE INTENTIONALLY LEFT BLANK I

RIVER BEND B 3.6-103 Revision No. 121

Drywell B 3.6.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.5.1.3 The analyses in Reference I are based on a maximum drywell bypass leakage. This Surveillance ensures that the actual drywell bypass leakage is less than or equal to the acceptable AI/k design value of 1.0 ft. As left drywell bypass leakage, prior to the first startup after performing a required drywell bypass leakage test, is required to be

< 10% of the drywell bypass leakage limit. At all other times between required drywell leakage rate tests, the acceptance criteria is based on design ANk. At the design A/{k the containment temperature and pressurization response are bounded by the assumptions of the safety analysis. Due to NRC Generic Letter 96-06 concerns, integrity of the reactor recirculation flow control valve hydraulic power unit (2HPU) penetrations cannot be assumed. For this reason, 0.0164 ft is added to the drywell bypass leakage surveillance result (Ref. 3). This surveillance is performed at least once every 10 years on a performance based frequency. This frequency is modified on a one time basis until June 23, 2009. The frequency is consistent with the difficulty of performing the test, risk of high radiation exposure, and the remote possibility that sufficient component failures will occur such that the drywell bypass leakage limit will be exceeded. If during the performance of this required Surveillance the drywell bypass leakage rate is greater than the drywell bypass leakage limit, the Surveillance Frequency is increased to every 48 months. If during the performance of the subsequent consecutive Surveillance the drywell bypass leakage rate is less than or equal to the drywell bypass leakage limit, the 10 year Frequency may be resumed. If during the performance of two consecutive Surveillances the drywell bypass leakage is greater than the drywell bypass leakage limit, the Surveillance Frequency is increased to at least once every 24 months.

The 24 month Frequency is maintained until during the performance of two consecutive Surveillances the drywell bypass leakage rate is less than or equal to the drywell bypass leakage limit, at which time the 10 year Frequency may be resumed. For two Surveillances to be considered consecutive, the Surveillances must be performed at least 12 months apart. Since the frequency is performance based, the Frequency was concluded to be acceptable from a reliability standpoint.

I SR 3.6.5.1.4 The exposed accessible drywell interior and exterior surfaces are inspected to ensure there are no apparent physical defects that would prevent the drywell from (continued)

RIVER BEND B 3.6-120 Revision No. 121

Drywell B 3.6.5.1 BASES SURVEILLANCE SR 3.6.5.1.4 (continued)

REQUIREMENTS performing its intended function. This SR ensures that drywell structural integrity is maintained. The Frequency was chosen so that the interior and exterior surfaces of the drywell can be inspected in conjunction with the inspections of the primary containment required by 10 CFR 50, Appendix J (Ref. 2). Due to the passive nature of the drywell structure, the specified Frequency is sufficient to identify component degradation that may affect drywell structural integrity.

SR 3.6.5.1.5 This SR requires a test be performed to verify seal leakage of the drywell air lock doors at 3.0 psid. An administrative seal leakage rate limit has been established in plant procedures to ensure the integrity of the seals.

The Surveillance is only required to be performed once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each closing. The Frequency of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is based on operating experience.

SR 3.6.5.1.6 This SR requires a test to be performed to verify air lock leakage of the drywell air lock at pressures 2 3 psid. Prior to the performance of this test, the air lock is pressurized to 2 19.2 psid. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for violating the drywell boundary. Operating experience has shown these components usually pass the Surveillance and requires the SR to be performed once each refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

REFERENCES

1.

USAR, Chapter 6 and Chapter 15.

2.

10 CFR 50, Appendix J

3.

Engineering Request (ER)-RB-99-0741 RIVER BEND B 3.6-121 Revision No. 119

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.9 REQUIREMENTS Each DG is provided with an engine overspeed trip to prevent damage to the engine. Recovery from the transient caused by the loss of a large load could cause diesel engine overspeed, which, if excessive, might result in a trip of the engine. This Surveillance demonstrates the DG load response characteristics and capability to reject the largest single load while maintaining a specified margin to the overspeed trip. The referenced load for DG 1A is the 917.5 kW low pressure core spray pump; for DG 1 B, the 462.2 kW residual heat removal (RHR) pump; and for DG 1 C the 1995 kW HPCS pump. The Standby Service Water (SS")

pump values are not used as the largest load since the SSW supplies cooling to the associated DG. If this load were to trip, it would result in the loss of the DG. As required by IEEE-308 (Ref. 13), the load rejection test is acceptable if the increase in diesel speed does not exceed 75% of the difference between synchronous speed and the overspeed trip setpoint, or 15% above synchronous speed, whichever is lower. For the River Bend Station the lower value results from the first criteria. The 18 month frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref. 9).

This SR has been modified by two Notes. The reason for Note 1 is that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

1)

Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2)

Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.

In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as possible, Note 2 requires that, if synchronized to offsite power, testing be performed using a power factor

< 0.9. This power factor is chosen to be representative of the actual design basis inductive loading that the DG could experience.

(continued)

RIVER BEND B 3.8-1 9 Revision No. 117

AC Sources - Operating B 3.8.1 BASES SURVEILLANCE SR 3.8.1.10 REQUIREMENTS This Surveillance demonstrates the DG capability to reject a full load, i.e.,

maximum expected accident load, without overspeed tripping or exceeding the predetermined voltage limits. The DG full load rejection may occur because of a system fault or inadvertent breaker tripping. This Surveillance ensures proper engine generator load response under the simulated test conditions. This test simulates the loss of the total connected load that the DG experiences following a full load rejection and verifies that the DG does not trip upon loss of the load. These acceptance criteria provide DG damage protection. While the DG is not expected to experience this transient during an event and continue to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.

In order to ensure that the DG is tested under load conditions that are as close to design basis conditions as possible, testing must be performed using a power factor < 0.9. This power factor is chosen to be representative of the actual design basis inductive loading that the DG would experience.

The 18 month Frequency is consistent with the recommendation of Regulatory Guide 1.108 (Ref. 9) and is intended to be consistent with expected fuel cycle lengths.

This SR has been modified by a Note. The reason for the Note is that credit may be taken for unplanned events that satisfy this SR. Examples of unplanned events may include:

1)

Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2)

Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.

(continued)

RIVER BEND B 3.8-20 Revision No. 117

DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.6 (continued)

REQUIREMENTS the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensure that these requirements can be satisfied. Momentary transients that are not attributable to charger performance do not invalidate this test.

The Surveillance Frequency is acceptable, given the unit conditions required to perform the test and the other administrative controls existing to ensure adequate charger performance during these 18 month intervals.

In addition, this Frequency is intended to be consistent with expected fuel cycle lengths.

SR 3.8.4.7 A battery service test is a special test of the battery's capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length correspond to the design duty cycle requirements as specified in Reference 4.

The Surveillance Frequency of 18 months is consistent with the recommendations of Regulatory Guide 1.32 (Ref. 9) and Regulatory Guide 1.129 (Ref. 10), which state that the battery service test should be performed during refueling operations or at some other outage, with intervals between tests not to exceed 18 months.

This SR is modified by two Notes. Note 1 allows the once per 60 months performance of SR 3.8.4.8 in lieu of SR 3.8.4.7. This substitution is acceptable because the battery performance test (SR 3.8.4.8) represents a more severe test of battery capacity than the battery service test (SR 3.8.4.7). Because both the battery service test and the battery performance test involve battery capacity determination, complete battery replacement invalidates the previous performance of these surveillance requirements. In addition to requiring the re-performance of both of these surveillance tests prior to declaring the battery OPERABLE, complete battery replacement also resets the 60 month time period used for substitution of the service test by the performance test. For this reason, substitution is acceptable for performance testing conducted within the first two years of service of a new battery as required by Reference 8.

The reason for Note 2 is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. The Division IlIl test may be performed in Mode 1, 2, or 3 in conjunction with HPCS system outages. Credit may be taken for unplanned events that satisfy the Surveillance. Examples of unplanned events may include:

1)

Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and (continued)

RIVER BEND B 3.8-56 Revision No. 120

DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.7 (continued)

REQUIREMENTS

2)

Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.

SR 3.8.4.8 A battery performance test is a test of constant current capacity of a battery, normally done in the as found condition, after having been in service, to detect any change In the capacity determined by the acceptance test. The test is intended to determine overall battery degradation due to age and usage.

The acceptance criteria for this Surveillance is consistent with IEEE-450 (Ref. 8) and IEEE-485 (Ref. 11). These references recommend that the battery be replaced if its capacity is below 80% of the manufacturers rating. A capacity of 80% shows that the battery rate of deterioration is increasing, even if there is ample capacity to meet the load requirements.

The Surveillance Frequency for this test is normally 60 months. If the battery shows degradation, or if the battery has reached 85% of its expected life the Surveillance Frequency is reduced to 18 months.

Degradation is indicated, according to IEEE-450 (Ref. 8), when the battery capacity drops by more than 10% of rated capacity relative to its capacity on the previous performance test, or when it is 2 10% below the manufacturers rating. These Frequencies are based on the recommendations in IEEE-450 (Ref. 8).

This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DC electrical power subsystem from service, perturb the electrical distribution system, and challenge safety systems. The Division IlIl test may be performed in Mode 1. 2, or 3 in conjunction with HPCS system outages. Credit may be taken for unplanned events that satisfy the Surveillance. Examples of unplanned events may include:

(continued)

RIVER BEND B 3.8-57 Revision No. 120

DC Sources - Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS SR 3.8.4.8 (continued)

1)

Unexpected operational events which cause the equipment to perform the function specified by this Surveillance, for which adequate documentation of the required performance is available; and

2)

Post corrective maintenance testing that requires performance of this Surveillance in order to restore the component to OPERABLE, provided the maintenance was required, or performed in conjunction with maintenance required to maintain OPERABILITY or reliability.

REFERENCES 1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

10 CFR 50, Appendix A, GDC 17.

Regulatory Guide 1.6, March 10, 1971.

IEEE Standard 308, 1978.

USAR, Section 8.3.2.

USAR, Chapter 6.

USAR, Chapter 15.

Regulatory Guide 1.93, December 1974.

IEEE Standard 450,1995.

Regulatory Guide 1.32, February 1977.

Regulatory Guide 1.129, December 1974.

IEEE Standard 485.

I RIVER BEND B 3.8-58 Revision No. 120

Refueling Equipment Interlocks B 3.9.1 BASES ACTIONS to allow control rods to be withdrawn in accordance with LCO 3.10.6 while (continued) complying with these actions. This verification that all required control rods are fully Inserted is in addition to the periodic verifications required by SR 3.9.3.1 and SR 3.10.6.2. Like Required Action A.1, Required Actions A.2.1 and A.2.2 ensure that unacceptable operations are blocked (e.g., loading fuel into a cell with the control rod withdrawn.)

The alternative option (Required Actions A.2.1 and A.2.2) also allows fuel movement to continue rather than halting refueling activities to perform SR 3.9.1.1 should it become due before completion of fuel movement actives. This option should not be used to eliminate the first performance of the SR before starting in-vessel fuel movements. The objective of the option is to provide flexibility under limited circumstances, not to disable the refueling interlocks indefinitely and is only allowed for a period not to exceed 31 days, after which time the performance of the SR 3.9.1.1 would be required.

SURVEILLANCE SR 3.9.1.1 REQUIREMENTS Performance of a CHANNEL FUNCTIONAL TEST demonstrates each required refueling equipment interlock will function properly when a simulated or actual signal indicative of a required condition is injected into the logic. The CHANNEL FUNCTIONAL TEST may be performed by any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

The 7 day Frequency is based on engineering judgment and is considered adequate in view of other indications of refueling interlocks and their associated input status that are available to unit operations personnel.

Should this SR become due before completion of fuel movement activities, fuel movement may continue rather than halting refueling activities to perform the SR provided that required Actions A.2.1 and A.2.2 are met. As discussed above, this option should not be used to eliminate the first performance of the SR before starting in-vessel fuel movements and Is only allowed for a period not to exceed 31 days, after which time the performance of the SR 3.9.1.1 would be required.

REFERENCES

1.

10 CFR 50, Appendix A, GDC 26.

2.

USAR, Section 7.7.1.5.

3.

USAR, Section 15.4.1.1.

RIVER BEND B 3.9-4 Revision No. 119

RPV Water Level-Irradiated Fuel B 3.9.6 BASES APPLICABLE RPV water level satisfies Criterion 2 of the NRC Policy Statement.

SAFETY ANALYSES (continued)

LCO A minimum water level of 23 ft above the top of the RPV flange is required to ensure that the radiological consequences of a postulated fuel handling accident are within acceptable limits, as provided by the guidance of Reference 3.

APPLICABILITY LCO 3.9.6 is applicable when moving irradiated fuel assemblies within the RPV. The LCO minimizes the possibility of a fuel handling accident in containment that is beyond the assumptions of the safety analysis.

Requirements for handling of new fuel assemblies or control rods (where water depth to the RPV flange is not of concern) are covered by LCO 3.9.7, "RPV Water Level-New Fuel or Control Rods." Requirements for fuel handling accidents in the spent fuel storage pool are covered by LCO 3.7.6, "Fuel Pool Water Level."

ACTIONS A.1 If the water level is < 23 ft above the top of the RPV flange, all operations Involving movement of Irradiated fuel assemblies within the RPV shall be suspended immediately to ensure that a fuel handling accident cannot occur. The suspension of irradiated fuel movement shall not preclude completion of movement of a component to a safe position.

SURVEILLANCE SR 3.9.6.1 REQUIREMENTS Verification of a minimum water level of 23 ft above the top of the RPV flange ensures that the design basis for the postulated fuel handling accident analysis during refueling operations is met. Water at the required level limits the consequences of damaged fuel rods, which are postulated to result from a fuel handling accident in containment (Ref. 2).

(continued)

I RIVER BEND B 3.9-20 Revision No. 119

RPV Water Level-New Fuel or Control Rods B 3.9.7 BASES APPLICABLE RPV water level satisfies Criterion 2 of the NRC Policy Statement.

SAFETY ANALYSES (continued)

LCO A minimum water level of 23 ft above the top of irradiated fuel assemblies seated within the RPV is required to ensure that the radiological consequences of a postulated fuel handling accident are within acceptable limits, as provided by the guidance of Reference 3.

APPLICABILITY LCO 3.9.7 is applicable when moving new fuel assemblies or handling control rods (i.e., movement with other than the normal control rod drive) over irradiated fuel assemblies seated within the RPV. The LCO minimizes the possibility of a fuel handling accident in containment that is beyond the assumptions of the safety analysis. If irradiated fuel is not present within the RPV, there can be no significant radioactivity release as a result of a postulated fuel handling accident. Requirements for fuel handling accidents in the spent fuel storage pool are covered by LCO 3.7.6, "Fuel Pool Water Level." Requirements for handling irradiated fuel over the RPV are covered by LCO 3.9.6, "Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel."

ACTIONS A.1 If the water level is < 23 ft above the top of irradiated fuel assemblies seated within the RPV, all operations involving movement of new fuel assemblies and handling of control rods within the RPV shall be suspended immediately to ensure that a fuel handling accident cannot occur. The suspension of fuel movement and control rod handling shall not preclude completion of movement of a component to a safe position.

SURVEILLANCE SR 3.9.7.1 REQUIREMENTS Verification of a minimum water level of 23 ft above the top of the irradiated fuel assemblies seated within the RPV ensures that the design basis for the postulated fuel handling accident analysis during refueling (continued)

RIVER BEND B 3.9-23 Revision No. 119

RBG-46419, Revisions to the Technical Requirements Manual and the Technical Specifications Bases

Text

Subject:

Enclosures:

Navigation menu

RBG-46419, Revisions to the Technical Requirements Manual and the Technical Specifications Bases

Text

Subject:

Enclosures:

Navigation menu

Search