Text

Units 1 & 2; Technical Specification Bases, Revisions 15. 16, 17, 18, 19, 20. 21, and 22
	ML043100130
Person / Time
Site:	Calvert Cliffs
Issue date:	11/03/2004
From:	Vanderheyden G; Constellation Energy Group
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	Download: ML043100130 (204)
	v • d • e

George Vanderheyden 1650 Calvert Cliffs Parkway Vice President Lusby, Maryland 20657 Calvert Cliffs Nuclear Power Plant 410.495.4455 Constellation Generation Group. LLC 410.495.3500 Fax I Constellation Energy November 3, 2004 U. S. Nuclear Regulatory Commission Washington, DC 20555 ATTENTION: Document Control Desk

SUBJECT:

Calvert Cliffs Nuclear Power Plant Unit Nos. I & 2; Docket Nos. 50-317 & 50-318 Technical Specification Bases. Revisions 15. 16, 17, 18, 19, 20. 21, and 22 Enclosed for your use is one copy of the Calvert Cliffs Technical Specifications Bases, Revisions 15, 16, 17, 18, 19, 20, 21, and 22. These revisions were performed under the Technical Specification Bases Control Program (Technical Specification 5.5.14). This program states, "Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71 (e)."

The Lists of Effective pages are included. Please replace the appropriate pages of your copies of the Technical Specification Bases with these enclosed pages.

Should you have questions regarding this matter, we will be pleased to discuss them with you.

Very trul GV/DLM/dlm

Enclosures:

As stated cc: Without Enclosures J. Petro, Esquire S. J. Collins, NRC J. E. Silberg, Esquire Resident Inspector, NRC R. V. Guzman, NRC R. 1. McLean, DNR ;A ~(D

PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 15 Remove and Discard Insert List of Revisions LOR-1 LOR-1 List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 Technical Specification Bases Pages B 3.4.1-1 through B 3.4.1-4 B 3.4.1-1 through B 3.4.1-5 B 3.5.2-1 through B 3.5.2-10 B 3.5.2-1 through B 3.5.2-9 B 3.6.6-3 and B 3.6.6-4 B 3.6.6-3 and B 3.6.6-4 B 3.7.11-1 through B 3.7.11-4 B 3.7.11-1 through B 3.7.11-4

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30,.1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 LOR-1 Rev. 15

January 9, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 15 B 3.1.2-1 Rev. 2 3.2.1-1 Rev. 2 LEP-2 Rev. 15 B 3.1.2-2 Rev. 2 3.2.1-2 Rev. 14 LEP-3 Rev. 15 B 3.1.2-3 Rev. 2 3.2.1-3 Rev. 14 LEP-4 Rev. 15 B 3.1.2-4' Rev. 2 3.2.1-4 Rev. 14 LEP-5 Rev. 15 B 3.1.2-5 Rev. 2 3.2.1-5 Rev. 14 i Rev. 2 B 3.1.2-6 Rev. 3. 3.2.1-6 Rev. 14 ii Rev. 2 B 3.1.3-l' Rev. 2 3.2.1-7 Rev. 14 iii Rev. 2 B 3.1.3-2 Rev. 2 3.2.2-1 Rev. 2 iv Rev. 2 8 3.1.3-3 Rev. 2 3.2.2-2 Rev. 8 B 2.1.1-1 Rev. 2 B 3.1.3-4 Rev. 2 3.2.2-3 Rev. 14 B 2.1.1-2 Rev. 2 B 3.1.3-5 Rev. 2 3.2.2-4 Rev. 12 B 2.1.1-3 Rev. 2 B 3.1.4-1 Rev. 2 3.2.2-5 Rev. 12 B 2.1.1-4 Rev. 2 B 3.1.4-2 Rev. 2 3.2.2-6 Rev. 12 B 2.1.2-1 Rev. 2 B 3.1.4-3 Revs. 2 3.2.3-1 Rev. 2 B 2.1.2-2 Rev. 2 B 3.1.4-4 Rev. 2 3.2.3-2 Rev. 8 B 2.1.2-3 Rev. 2 B 3.1.4-5 Rev. 2 3.2.3-3 Rev. 14 B 2.1.2-4 Rev. 2 B 3.1.4-6 Rev. 2 3.2.3-4 Rev. 12 B 3.0-1 Rev. 2 B 3.1.4-7 Rev. 2 3.2.3-5 Rev. 12 B 3.0-2 Rev. 2 B 3.1.4-8 Rev. 2 3.2.4-1 Rev. 2 B 3.0-3 Rev. 2 B 3.1.4-9 Rev. 2 3.2.4-2 Rev. 8 B 3.0-4 Rev. 2 B 3.1.4-10 Rev. 2 3.2.4-3 Rev. 14 B 3.0-5 Rev. 13 B 3.1.5-'1 Rev. 2 3.2.4-4 Rev. 8 B 3.0-6 Rev. 13 B 3.1.5-2 Rev. 2 3.2.4-5 Rev. 8 B 3.0-7 Rev. 13 B 3.1.5-3 Rev. 2 3.2.5-1 Rev. 2 B 3.0-8 Rev. 2 B 3.1.5-4" Rev. 2 3.2.5-2 Rev. 11 B 3.0-9 Rev. 2 B 3.1.5-5 Rev. 2 3.2.5-3 Rev. 14 B 3.0-10 Rev. 2 B 3.1.6-1 Rev. 2. 3.2.5-4 Rev. 11 B 3.0-11 Rev. 2 B 3.1.6-2 Rev. 2 3.2.5-5 Rev. 11 B 3.0-12 Rev. 2 B 3.1.6-3 Rev. 2 3.2.5-6 Rev. 11 B 3.0-13 Rev. 2 B 3.1.6-4 Rev. 2 3.3.1-1 Rev. 2 B 3.0-14 Rev. 2 B 3.1.6-5 Rev. 2 3.3.1-2 Rev. 2 B 3.0-15 Rev. 13 B 3.1.6-6 Rev. 2 3.3.1-3 Rev. 2 B 3.0-16 'Rev. 13 B 3.1.6-7. Rev. 2 3.3.1-4 Rev. 2 B 3.0-17 Rev. 13 B 3.1.7-1 Rev. 2 3.3.1-5 Rev. 2 B 3.0-18' Rev. 13 B 3.1.7-2 Rev. 2 3.3.1-6 Rev. 12 B 3.0-19 Rev. '13 B 3.1.7-3 Rev. 5 3.3.1-7 Rev. 12 B 3.1.1-1 Rev. 2 B 3.1.7-4 Rev. 2 3.3.1-8 Rev. 12 B 3.1.1-2 Rev. 2 B 3.1.7-5 Rev. 11 3.3.1-9 Rev. 12 B 3.1.1-3 Rev. 2 B 3.1.8-1 Rev. 2 3.3.1-10 Rev. 12 B 3.1.1-4 Rev. 2 B 3.1.8-2 Rev. 2 3.3.1-11 Rev. 5 B 3.1.1-5 Rev. 2 B 3.1.8-3 Rev. 2 3.3.1-12 Rev. 2 B 3.1.1-6 Rev. 2 B 3.1.8-4 Rev. -2 3.3.1-13 Rev. 12 B 3.1.1-7 Rev. 2 B 3.1.8-5 Rev. 2 3.3. 1-14 Rev. 11 LEP-1 Rev. 15

January 9, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.1-15 Rev. 11 B 3.3.4-1 Rev. 2 B 3.3.6-7 Rev. 12 B 3.3.1-16 Rev. 11 B 3.3.4-2 Rev. 2 B 3.3.6-8 Rev. 8 B 3.3.1-17 Rev. 11 B 3.3.4-3 Rev. 2 B 3.3.7-1 Rev. 14 B 3.3.1-18 Rev. 13 B 3.3.4-4 Rev. 2 B 3.3.7-2 Rev. 2 B 3.3.1-19 Rev. 11 B 3.3.4-5 Rev. 2 B 3.3.7-3 Rev. 2 B 3.3.1-20 Rev. 11 B 3.3.4-6 Rev. 2 B 3.3.7-4 Rev. 2 B 3.3.1-21 Rev. 11 B 3.3.4-7 Rev. 2 B 3.3.7-5 Rev. 2 B 3.3.1-22 Rev. 11 B 3.3.4-8 Rev. 2 B 3.3.7-6 Rev. 2 B 3.3.1-23 Rev. 11 B 3.3.4-9 Rev. 2 B 3.3.7-7 Rev. 2 B 3.3.1-24 Rev. 11 B 3.3.4-10 Rev. 2 B 3.3.8-1 Rev. 8 B 3.3.1-25 Rev. 11 B 3.3.4-11 Rev. 2 B 3.3.8-2 Rev. 2 B 3.3.1-26 Rev. 11 B 3.3.4-12 Rev. 2 B 3.3.8-3 Rev. 2 B 3.3.1-27 Rev. 11 B 3.3.4-13 Rev. 2 B 3.3.8-4 Rev. 2 B 3.3.1-28 Rev. 11 B 3.3.4-14 Rev. 2 B 3.3.9-1 Rev. 2 B 3.3.1-29 Rev. 11 B 3.3.4-15 Rev. 2 B 3.3.9-2 Rev. 2 B 3.3.1-30 Rev. 11 B 3.3.4-16 Rev. 2 B 3.3.9-3 Rev. 2 B 3.3.1-31 Rev. 11 B 3.3.4-17 Rev. 5 B 3.3.9-4 Rev. 2 B 3.3.1-32 Rev. 11 B 3.3.4-18 Rev. 2 B 3.3.9-5 Rev. 2 B 3.3.1-33 Rev. 12 B 3.3.4-19 Rev. 2 B 3.3.9-6 Rev. 2 B 3.3.1-34 Rev. 12 B 3.3.4-20 Rev. 2 B 3.3.9-7 Rev. 2 B 3.3.1-35 Rev. 2 B 3.3.4-21 Rev. 2 B 3.3.9-8 Rev. 3 B 3.3.2-1 Rev. 2 B 3.3.4-22 Rev. 12 B 3.3.10-1 Rev. 2 B 3.3.2-2 Rev. 2 B 3.3.4-23 Rev. 12 B 3.3.10-2 Rev. 2 B 3.3.2-3 Rev. 2 B 3.3.5-1 Rev. 2 B 3.3.10-3 Rev. 14 B 3.3.2-4 Rev. 2 B 3.3.5-2 Rev. 2 B 3.3.10-4 Rev. 14 B 3.3.2-5 Rev. 2 B 3.3.5-3 Rev. 2 B 3.3.10-5 Rev. 14 B 3.3.2-6 Rev. 2 B 3.3.5-4 Rev. 2 B 3.3.10-6 Rev. 14 B 3.3.2-7 Rev. 2 B 3.3.5-5 Rev. 2 B 3.3.10-7 Rev. 14 B 3.3.2-8 Rev. 2 B 3.3.5-6 Rev. 2 B 3.3.10-8 Rev. 14 B 3.3.2-9 Rev. 2 B 3.3.5-7 Rev. 2 B 3.3.10-9 Rev. 14 B 3.3.2-10 Rev. 2 B 3.3.5-8 Rev. 2 B 3.3.10-10 Rev. 14 B 3.3.3-1 Rev. 2 B 3.3.5-9 Rev. 2 B 3.3.10-11 Rev. 14 B 3.3.3-2 Rev. 2 B 3.3.5-10 Rev. 2 B 3.3.10-12 Rev. 14 B 3.3.3-3 Rev. 2 B 3.3.5-11 Rev. 2 B 3.3.10-13 Rev. 14 B 3.3.3-4 Rev. 2 B 3.3.5-12 Rev. 2 B 3.3.10-14 Rev. 14 B 3.3.3-5 Rev. 2 B 3.3.5-13 Rev. 2 B 3.3.10-15 Rev. 14 B 3.3.3-6 Rev. 2 B 3.3.5-14 Rev. 2 B 3.3.10-16 Rev. 14 B 3.3.3-7 Rev. 2 B 3.3.6-1 Rev. 2 B 3.3.10-17 Rev. 14 B 3.3.3-8 Rev. 2 B 3.3.6-2 Rev. 2 B 3.3.10-18 Rev. 14 B 3.3.3-9 Rev. 2 B 3.3.6-3 Rev. 2 B 3.3.11-1 Rev. 2 B 3.3.3-10 Rev. 2 B 3.3.6-4 Rev. 13 B 3.3.11-2 Rev. 2 B 3.3.3-11 Rev. 2 B 3.3.6-5 Rev. 2 B 3.3.11-3 Rev. 2 B 3.3.3-12 Rev. 2 B 3.3.6-6 Rev. 2 B 3.3.11-4 Rev. 2 LEP-2 Rev. 15

January 9, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.11-5 Rev. 2 B 3.4.9-3 Rev. 2 B 3.4.16-2 Rev. 2 B 3.3.12-1 Rev. 2 B 3.4.9-4 Rev. 2 B 3.4.16-3 Rev. 2 B 3.3.12-2 Rev. 2 B 3.4.9-5 Rev. 2 B 3.4.17-1 Rev. 2 B 3.3.12-3 Rev. 2 B 3.4.10-1 Rev. 2 B 3.4.17-2 Rev. 2 B 3.3.12-4 Rev. 2 B 3.4.10-2 Rev. 2 B 3.4.17-3 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4.1-2 Rev. 15 B 3.4.10-4 Rev. 2 B 3.5.1-2 Rev. 2 B 3.4.1-3 Rev. 15 B 3.4.11-1 Rev. 12 B 3.5.1-3 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-2 Rev. 12 B 3.5.1-4 Rev. 2 B 3.4.1-5 Rev. 15 B 3.4.11-3 Rev. 12 B 3.5.1-5 Rev. 2 B 3.4.2-1 Rev. 2 B 3.4.11-4 Rev. 12 B 3.5.1-6 Rev. 2 B 3.4.2-2 Rev. 2 B 3.4.11-5 Rev. 12 B .3.5.1-7 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B 3.4.3-2 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-3 Rev. 2 B 3.4.12-1 Rev. 2 B 3.5.2-1 Rev. 15 B 3.4.3-4 Rev. 2 B 3.4.12-2 Rev. 2 B 3.5.2-2 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-3 Rev. 2 B 3.5.2-3 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-4 Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-7 Rev. 2 B 3.4.12-5 Rev. 6 B 3.5.2-5 Rev. .15 B 3.4.3-8 Rev. 2 B 3.4.12-6 Rev. 2 B 3.5.2-6 Rev. 15 B 3.4.4-1 Rev. 2 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-2 Rev. 13 B 3.4.12-8 Rev. 2- B 3.5.2-8 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-9 Rev. 2 B 3.5.2-9 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.12-10 Rev. 2 B 3.5.3-1 Rev. 2 B 3.4.5-2 Rev. 8 B 3.4.12-11 Rev. 2 B 3.5.3-2 Rev. 2 B 3.4.5-3 Rev. 8 B 3.4.12-12 Rev. 2 B 3.5.3-3 Rev. 2 B 3.4.5-4 Rev. 8 B 3.4.12-13 Rev. 2 B 3.5.4-1 Rev. 2 B 3.4.6-1 Rev. 2 B 3.4.13-1 Rev. 2 B 3.5.4-2 Rev., 14 B 3.4.6-2 Rev. 8 B 3.4.13-2 Rev. 10 B 3.5.4-3 Rev. 2 B 3.4.6-3 Rev. 8 B 3.4.13-3 Rev. 2 B 3.5.4-4 Rev. 2 B 3.4.6-4 Rev. 8 B 3.4.13-4 Rev. 2 B 3.5.4-5 Rev. 2 B 3.4.6-5 Rev. 8 B 3.-4.13-5 Rev. 5 B 3.5.4-6 Rev. 2 B 3.4.7-1 Rev. 2 B 3.4.14-1 Rev. 2 B 3.5.5-1 Rev. 2 B 3.4.7-2 Rev. 2 B 3.4.14-2 Rev. 2 B 3.5.5-2 Rev. 2 B 3.4.7-3 Rev. 8 B 3.4.14-3 Rev. 2 B 3.5.5-3 Rev. 2 B 3.4.7-4 Rev. 8 B 3.4.14-4 Rev. 2 B 3.5.5-4 Rev. 2 B 3.4.7-5 Rev. 8 B 3.4.14-5 Rev. 2 B 3.5.5-5 Rev. 2 B 3.4.7-6 Rev. 8 B 3.4.15-1 Rev. 2 B 3.6.1-1 Rev. 2 B 3.4.8-1 Rev. 2 B 3.4.15-2 Rev. 2 B 3.6.1-2 Rev. 2 B 3.4.8-2 Rev. 2 B 3.4.15-3 Rev. 2 B 3.6.1-3 Rev. 2 B 3.4.8-3 Rev. 2 B 3.4.15-4 Rev. 3 B 3.6.1-4 Rev. 12 B 3.4.9-1 Rev. 2 B 3.4.15-5 Rev. 2 B 3.6.1-5 Rev. 2 B 3.4.9-2 Rev. 2 B 3.4.16-1 Rev. 2 B 3.6.2-1 Rev. 2 LEP-3 Rev. 15

U January 9, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.2-2 Rev. 2 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 B 3.6.2-3 Rev. 2 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.6.2-4 Rev. 2 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.6.2-5 Rev. 2 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.6.2-6 Rev. 2 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.6.2-7 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-8 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.3-1 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.3-2 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.3-3 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.3-4 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.3-5 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-6 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-7 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-8 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-9 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.4-1 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.4-2 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.4-3 Rev. 2 B 3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.5-1 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.5-2 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2 B 3.6.5-3 Rev. 3 B 3.7.4-4 Rev. 2 B 3.7.15-1 Rev. 2 B 3.6.6-1 Rev. 2 B 3.7.5-1 Rev. 2 B 3.7.15-2 Rev. 13 B 3.6.6-2 Rev. 2 B 3.7.5-2 Rev. 2 B 3.7.15-3 Rev. 14 B 3.6.6-3 Rev. 15 B 3.7.5-3 Rev. 2 B 3.7.15-4 Rev. 2 B 3.6.6-4 Rev. 15 B 3.7.5-4 Rev. 2 B 3.8.1-1 Rev. 5 B 3.6.6-5 Rev. 2 B 3.7.5-5 Rev. 2 B 3.8.1-2 Rev. 12 B 3.6.6-6 Rev. 2 B 3.7.6-1 Rev. 5 B 3.8.1-3 Rev. 2 B 3.6.6-7 Rev. 2 B 3.7.6-2 Rev. 2 B 3.8.1-4 Rev. 10 B 3.6.6-8 Rev. 2 B 3.7.6-3 Rev. 5 B 3.8.1-5 Rev. 7 B 3.6.6-9 Rev. 2 B 3.7.6-4 Rev. 5 B 3.8.1-6 Rev. 7 B 3.6.7-1 Rev. 2 B 3.7.6-5 Rev. 5 B 3.8.1-7 Rev. 3 B 3.6.7-2 Rev. 2 B 3.7.7-1 Rev. 5 B 3.8.1-8 Rev. 3 B 3.6.7-3 Rev. 2 B 3.7.7-2 Rev. 12 B 3.8.1-9 Rev. 3 B 3.6.7-4 Rev. 2 B 3.7.7-3 Rev. 2 B 3.8.1-10 Rev. 3 B 3.6.7-5 Rev. 2 B 3.7.7-4 Rev. 12 B 3.8.1-11 Rev. 3 B 3.6.7-6 Rev. 2 B 3.7.8-1 Rev. 8 B 3.8.1-12 Rev. 3 B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 B 3.8.1-13 Rev. 3 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 B 3.8.1-14 Rev. 3 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 B 3.8.1-15 Rev. 3 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 B 3.8.1-16 Rev. 3 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 B 3.8.1-17 Rev. 3 LEP-4 I4Rev. 15

January 9, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-18 Rev. 3 B 3.8.6-3 Rev. 2 B 3.9.4-3 Rev. 11 B 3.8.1-19 Rev. 3 B 3.8.6-4 Rev. 2 B 3.9.4-4 Rev. 13 B 3.8.1-20 Rev. 3 B 3.8.6-5 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-21 Rev. 3 B 3.8.6-6 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-22 Rev. 3 B 3.8.6-7 Rev. 2 B 3.9.5-3 Rev. 14 B 3.8.1-23 Rev. 3 B 3.8.7-1 Rev. 2 B 3.9.5-4 Rev. 14 B 3.8.1-24 Rev. 3 B 3.8.7-2 Rev. 2 B 3.9.5-5 Rev. 14 B 3.8.1-25 Rev. 3 B 3.8.7-3 Rev. 2 B 3.9.6-1 Rev. 2 B 3.8.1-26 Rev. 5 B 3.8.7-4 Rev. 2 B 3.9.6-2 Rev. 2 B 3.8.1-27 Rev. 5 B 3.8.8-1 Rev. 2 B 3.9.6-3 Rev. 2 B 3.8.1-28 Rev. 13 B 3.8.8-2 Rev. 2 B 3.8.1-29 Rev. 13 B 3.8.8-3 Rev. 2 B 3.8.1-30 Rev. 13 B 3.8.9-1 Rev. 5 B 3.8.2-1 Rev. 2 B 3.8.9-2 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-3 Rev. 2 B 3.8.2-3 Rev. 10 B 3.8.9-4 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-5 Rev. 2 B 3.8.2-5 Rev. 5 B 3.8.9-6 Rev. 2 B 3.8.2-6 Rev. 5 B 3.8.9-7 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-5 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-3 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-4 Rev. 5 B 3.8.3-8 Rev. 3 B 3.8.10-5 Rev. 5 B 3.8.3-9 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-1 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-2 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-3 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-4 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-5 Rev. 2 B 3.9.2-2 Rev. 2 B 3.8.4-6 Rev. 2 B 3.9.2-3 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.4-8 Rev. 2 B 3.9.3-2 Rev. 13 B 3.8.4-9 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.5-2 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.5-3 Rev. 2 B 3.9.3-6 Rev. 13 B.3.8.5-4 Rev. 2 _ . _

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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 BACKGROUND These Bases address requirements for maintaining RCS pressure, temperature, and flow rate within limits assumed in the safety-analyses. The safety analyses (Reference 1) of normal operating conditions and anticipated operational occurrences, assume initial conditions within the normal steady-state envelope. -The limits placed on departure from nucleate boiling (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.

The Limiting Condition for Operation (LCO) limit for minimum RCS pressure as measured at the pressurizer is consistent with operation within the nominal operating envelope and is bounded by the initial pressure in the analyses.

The LCO limit for maximum RCS cold leg temperature is consistent with operation at the indicated power level and is bounded by the initial temperature in the analyses.

Margin has been set aside in the DNB LCO to permit operation of the reactor based on the average Reactor Protective System (RPS) cold leg indications. Such operation is permissible provided no more-than one cold leg RPS resistance temperature detector (RTD) is out-of-service for any reason other than testing or planned maintenance.

Operation of the-reactor ..at power limited by the maximum RPS cold leg temperature is at all times acceptable and conservative. -

The LCO limit for minimum RCS flow rate is.bounded by the initial flow rate in the analyses. The RCS flow rate is not expected to vary during plant operation with all pumps running. -

Revision 15 UNITS 1 CALVERT CLIFFS - UNITS 1&&22 B 3.4.1-1 B 3.4.1-1 Revision 15

U-RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES APPLICABLE The requirements of LCO 3.4.1 represent the initial SAFETY ANALYSES conditions for DNB limited transients analyzed in the safety analyses (Reference 1). The safety analyses have shown that transients initiated from the limits of this LCO will meet the DNBR criterion. Changes to the facility that could impact these parameters must be assessed for their impact on the DNBR criterion. The transients analyzed include loss of coolant flow events and dropped or stuck control element assembly events. A key assumption for the analysis of these events is that the core power distribution is within the limits of LCO 3.1.6, LCO 3.2.4, and LCO 3.2.5. The safety analyses are performed over the following range of initial values: RCS pressure 2154-2300 psia, core inlet temperature

< 548 0F, and reactor vessel inlet coolant flow rate

> 370,000 gpm. I The RCS DNB limits satisfy 10 CFR 50.36(c)(2)(ii),

Criterion 2.

LCO This LCO specifies limits on the monitored process variables

- RCS pressurizer pressure, RCS cold leg temperature, and RCS total flow rate - to ensure that the core operates within the limits assumed for the plant safety analyses.

Operating within these limits will result in meeting the DNBR criterion in the event of a DNB limited transient.

The LCO numerical values for pressure and temperature (P/T) are given for the measurement location and have been adjusted for instrument error. Reactor Coolant System flow rate is given as an analytical value.

APPLICABILITY In MODE 1, the limits on RCS pressurizer pressure, RCS cold leg temperature, and RCS flow rate must be maintained during steady-state operation in order to ensure that DNBR criteria will be met in the event of an unplanned loss of forced coolant flow or other DNB limited transient. In all other MODEs, the power level is low enough so that DNBR is not a concern.

A Note has been added to indicate the limit on pressurizer

-press ure-may-be-exceeded- during-short-term-operati-ona-l- -

transients such as a THERMAL POWER ramp increase of

> 5% RATED THERMAL POWER (RTP) per minute or a THERMAL Revision 15 CALVERT CLIFFS -

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RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES POWER step increase of > 10% RTP. These conditions represent short-term perturbations where actions to control pressure variations might be counterproductive. Also, since they represent transients'initiated from power levels

< 100% RTP, an increased DNBR margin exists to offset the temporary pressure variations.

Another set of limits-on DNB related parameters is provided in Safety Limit (SL) 2.1.1. Those limits are less restrictive than the limits of this LCO, but violation of SLs merits a stricter, more severe Required Action. Should a violation of this LCO occur, the operator should check whether or not an SL may have been exceeded.

ACTIONS A.1 Pressurizer pressure and RCS cold leg temperature are controllable and measurable parameters. Reactor Coolant System flow rate is not a controllable parameter and is not expected to vary during steady-state operation. With any parameter not within its LCO limit, action must be taken to restore the parameter.

The two hour Completion Time for restoration of the parameters provides sufficient time to adjust plant parameters, to determine the cause of the off normal condition, and to restore the readings within limits. The Completion Time is based on plant operating experience that shows the parameter can be restored in this time period.

B.1 If Required Action A.1 is not met within the associated Completion Time, 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 at least MODE 2 within six hours.

In MODE 2, the reduced power condition eliminates the potential for violation of the accident analysis bounds.

Six hours is a reasonable time that permits the plant power to be reduced at an orderly rate in'conjunction with even control of steam generator (SG) heat removal.

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RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES SURVEILLANCE SR 3.4.1.1 REQUIREMENTS Since Required Action A.1 allows a Completion Time of two hours to restore parameters that are not within limits, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR Frequency for pressurizer pressure is sufficient to ensure that the pressure can be restored to a normal operation, steady-state condition following load changes, and other expected transient operations. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and verify operation is within safety analysis assumptions.

SR 3.4.1.2 Since Required Action A.1 allows a Completion Time of two hours to restore parameters that are not within limits, the 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR Frequency for cold leg temperature is sufficient to ensure that the RCS coolant temperature can be restored to a normal operation, steady-state condition following load changes, and other expected transient operations. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and to verify operation is within safety analysis assumptions.

SR 3.4.1.3 The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR Frequency for RCS total flow rate is performed using the installed flow instrumentation. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency has been shown by operating experience to be sufficient to assess for potential degradation and to verify operation is within safety analysis assumptions.

SR 3.4.1.4 Measurement of RCS total flow rate is performed once every 24 months. This verifies that the actual RCS flow rate is within the bounds of the analyses.

The Frequency of 24 months reflects the importance of verifying flow after a refueling outage where the core has been altered, which may have caused an alteration of flow resistance.

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RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES REFERENCES 1. Updated Final Safety Analysis Report (UFSAR),

Section 14.1.2, "rPlant Characteristics Considered in Safety Analysis" Revision 15 UNITS 1 CALVERT CLIFFS - UNITS

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ECCS - Operating B 3.5.2 B 3.5 EMERGENCY CORE COOLING SYSTEM (ECCS)

B 3.5.2 ECCS - Operating BASES BACKGROUND The function of the ECCS is to provide core cooling and negative reactivity,-to ensure that the reactor core is protected after any of the following accidents:

a. Loss of coolant accident;

b. Control element assembly ejection accident;

c. Secondary event, including uncontrolled steam release or excess feedwater heat removal event; and

d. Steam generator tube rupture.

The addition of negative reactivity by the ECCS during a secondary event where primary cooldown could add enough positive reactivity to achieve criticality and return to significant power was considered in design requirements for the ECCS.

There are two phases of ECCS operation: injection and recirculation. In the injection phase, all injection is initially added to the RCS via the cold legs. After the refueling water tank (RWT) has been depleted, the ECCS.

recirculation phase is entered as the ECCS suction is automatically transferred to the containment sump.

Two redundant, 100% capacity trains are provided. In MODEs 1 and 2, and MODE 3 with pressurizer pressure 2 1750 psia, each train consists of HPSI and LPSI charging subsystems. In MODEs 1land 2, and MODE 3-with pressurizer pressure 2 1750 psia, both trains must be OPERABLE. This ensures that 100% of the core cooling requirements can be provided in the event of a single active failure.

'Asuction header'supplies water'from the RWT or the containment sump'to the ECCS pumps. Separate piping supplies each train. The discharge headers from each HPSI pump divide into four supply lines. Both HPSI trains feed

-into each'of the four injection lines. The discharge header which is fed from both LPSI pumps divides into four supply lines, each feeding the injection line to each RCS cold leg.

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ECCS - Operating B 3.5.2 BASES For LOCAs that are too small to initially depressurize the RCS below the shutoff head of the HPSI pumps, the steam generators must provide the core cooling function.

During low temperature conditions in the RCS, limitations are placed on the maximum number of HPSI pumps that may be OPERABLE. Refer to LCO 3.4.12 Bases, for the basis of these requirements.

During a large break LOCA, RCS pressure will decrease to

< 200 psia in < 20 seconds. The safety injection systems are actuated upon receipt of a SIAS. If offsite power is available, the safeguard loads start immediately. If offsite power is not available, the engineered safety feature (ESF) buses shed normal operating loads and are connected to the diesel generators. Safeguard loads are then actuated in the programmed time sequence. The time delay associated with diesel starting, sequenced loading, and pump starting determines the time required before pumped flow is available to the core following a LOCA.

The active ECCS components, along with the passive SITs and RWT, covered in LCO 3.5.1 and LCO 3.5.4, provide the cooling water necessary to meet Reference 1, Appendix 1C, Criterion 44.

APPLICABLE The LCO helps to ensure that the following acceptance SAFETY ANALYSES criteria, established by Reference 2 for ECCSs, will be met following a LOCA:

a. Maximum fuel element cladding temperature is < 2200OF;

b. Maximum cladding oxidation is < 0.17 times the total cladding thickness before oxidation;

c. Maximum hydrogen generation from a zirconium water reaction is < 0.01 times the hypothetical amount generated if all of the metal in the cladding cylinders surrounding the fuel, excluding the cladding surrounding the plenum volume, were to react;

d. Core is maintained in a coolable geometry; and

e. Adequate long-term core cooling capability is maintained.

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ECCS - Operating B 3.5.2 BASES The LCO also limits the potential for a post-trip return to power, following a steam line break, and ensures that containment temperature limits are met.

Both HPSI and LPSI subsystems are assumed to be OPERABLE in the large break LOCA analysis at full power (Reference 1, Section 14.17). This analysis establishes a minimum required runout flow for the HPSI and LPSI pumps, as well as the maximum required response time for their actuation. The HPSI pumps are credited in the small break LOCA analysis.

This analysis establishes the flow and discharge head requirements at the design point for the HPSI pump. The steam generator tube rupture and steam line break analyses also credit the HPSI pumps, but are not limiting in their design.

The large break LOCA event with a loss of offsite power and a single failure (disabling one ECCS train) establishes the OPERABILITY requirements for the ECCS. During the blowdown stage of a LOCA,.the RCS depressurizes as primary coolant is ejected through-the break into Containment. The nuclear reaction is terminated either by moderator voiding during large breaks or control element assembly insertion during small breaks.. Following depressurization,.emergency cooling water is injected.into the cold legs, flows into the downcomer, fills the lower plenum, and refloods the core.

On.smaller breaks, RCS-pressure will stabilize at a value dependent upon break size, heat load, and injection flow.

The smaller the break, the higher this equilibrium pressure.

In all LOCA analyses, injection flow is not credited until RCS pressure drops below-the shutoff head of the HPSI pumps.

The LCO ensures that an ECCS train will deliver sufficient water to match decay heat boiloff rates soon enough to minimize core. uncovery for a large LOCA. It also ensures that-the accident assumptions are met for the small break LOCA and steam-line break. For.smaller LOCAs the steam generators serve as-the heat sink to provide core cooling.

Emergency Core Cooling System - Operating satisfies 10 CFR 50.36(c)(2)(ii), Criterion 3.

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ECCS - Operating B 3.5.2 BASES LCO In MODEs 1, 2, and 3, with pressurizer pressure

> 1750 psia, two independent (and redundant) ECCS trains are required to ensure that sufficient ECCS flow is available, assuming there is a single failure affecting either train. Additionally, individual components within the ECCS trains may be called upon to mitigate the consequences of other transients and accidents.

In MODEs 1 and 2, and in MODE 3 with pressurizer pressure

> 1750 psia, an ECCS train consists of a HPSI subsystem, and a LPSI subsystem.

Each HPSI and LPSI train includes the piping, instruments, and controls to ensure the availability of an OPERABLE flow path capable of taking suction from the RWT on a SIAS and automatically transferring suction to the containment sump upon a recirculation actuation signal.

During an event requiring ECCS actuation, a flow path is provided to ensure an abundant supply of water from the RWT to the RCS, via the HPSI and LPSI pumps and their respective supply headers, to each of the four cold leg injection nozzles. In the long-term, this flow path may be switched to take its supply from the containment sump and to supply part of its flow to the RCS hot legs via the pressurizer or the shutdown cooling (SDC) suction nozzles.

The flow path for each train must maintain its designed independence to ensure that no single failure can disable both ECCS trains.

In addition for the HPSI pump system to be considered OPERABLE, each HPSI pump system (consisting of a HPSI pump and one of two safety injection headers) must have balanced flows, such that the sum of the flow rates of the three lowest flow legs is > 470 gpm.

APPLICABILITY In MODEs 1 and 2, and in MODE 3 with RCS pressure

> 1750 psia, the ECCS OPERABILITY requirements for the limiting DBA large break LOCA are based on full power operation. Although reduced power would not require the same level of performance, the accident analysis does not provide for reduced cooling requirements in the lower MODEs.

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ECCS - Operating B 3.5.2 BASES The HPSI pump performance is based on the small break LOCA, which establishes the pump performance curve and has less dependence on power. The requirements of MODE 2, and MODE 3 with RCS pressure 2 1750 psia, are bounded by the MODE 1 analysis.

The ECCS functional requirements of MODE 3, with RCS pressure < 1750 psia, and MODE 4 are described in LCO 3.5.3.

In MODEs 5 and 6, unit conditions are such that the probability of an event requiring ECCS injection is extremely low. Core cooling requirements in MODE 5 are addressed by LCO 3.4.7 and LCO 3.4.8. MODE 6 core cooling requirements are addressed by LCO 3.9.4 and LCO 3.9.5.

ACTIONS A.1 If one or more trains are inoperable and at least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train is available, the inoperable components must be returned to OPERABLE status-within 72'hours. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time is based on'an'Nuclear Regulatory Commission study (Reference 3) using'a reliability evaluation and is a reasonable'amount-of time-to effect many repairs.

An ECCS train is inoperable if it is not capable of delivering the design flow to the RCS. The individual components are inoperable if they are not capable of -

performing their design function, or if supporting systems are not available.

The LCO requires the OPERABILITY of a number of independent subsystems. Due to-the redundancy of trains and the diversity of'subsystems, the inoperability of one component in a train does not render the ECCS incapable of performing

-its function. Neither'does the inoperability of two different components, each in'a different train, necessarily result-in a loss of function for the:ECCS. The intent of this Condition is to maintain a combination of OPERABLE equipment such-that 100% of the ECCS flow equivalent to 100%

of a single OPERABLE train remains available. This allows increased flexibility in plant operations when components in opposite trains are inoperable.

CALVERT CLIFFS - UNITS 1 & 2 B 3.5.2-5 Revision 15

-U ECCS - Operating B 3.5.2 BASES An event accompanied by a loss of offsite power and the failure of an emergency diesel generator can disable one ECCS train until power is restored. A reliability analysis (Reference 3) has shown that the impact with one full ECCS train inoperable is sufficiently small to justify continued operation for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

Reference 4 describes situations in which one component, such as a SDC total flow control valve, can disable both ECCS trains. With one or more components inoperable, such that 100% of the equivalent flow to a single OPERABLE ECCS train is not available, the facility is in a condition outside the accident analyses. Therefore, LCO 3.0.3 must be immediately entered.

B.1 and B.2 If the inoperable train cannot be restored to OPERABLE status within the associated Completion Time, 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 at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and pressurizer pressure reduced to

< 1750 psia within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power in an orderly manner and without challenging unit systems.

SURVEILLANCE SR 3.5.2.1 REQUIREMENTS Verification of proper valve position ensures that the flow path from the ECCS pumps to the RCS is maintained.

Misalignment of these valves could render both ECCS trains inoperable. Securing these valves in position by interrupting the control signal to the valve operator, ensures that the valves cannot be inadvertently misaligned.

These valves are of the type described in Reference 4, which can disable the function of both ECCS trains and invalidate the accident analysis. A 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is considered reasonable in view of other administrative controls ensuring that a mispositioned valve is an unlikely possibility.

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ECCS - Operating B 3.5.2 BASES SR 3.5.2.2 Verifying the correct'alignment for manual, power-operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing. A valve that receives an actuation signal is allowed to be in a non-accident position provided the valve automatically repositions within the proper stroke time. This SR does not require any testing or valve manipulation. Rather, it involves verification that those valves capable of being mispositioned are in the-correct position.

The 31 day Frequency is appropriate because the valves are operated under procedural control and an improper valve position would only affect a single train. This Frequency has been shown to be.acceptable through operating experience.

SR 3.5.2.3 Periodic surveillance testing of the HPSI and LPSI pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the American' Society of Mechanical Engineers Code,Section XI. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve. This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the;test flow is greater than or equal to the performance assumed in the unit'safety analysis.

Surveillance Requirements are specified in the Inservice Testing Program, which encompasses American Society of Mechanical Engineers Code,Section XI. American Society of Mechanical Engineers Code,Section XI provides the activities and Frequencies necessary to satisfy the requirements.

Revision 15 UNITS 1 CALVERT CLIFFS - UNITS 1&&22 B 3.5.2-7 B 3.5.2-7 Revision 15

ECCS - Operating B 3.5.2 BASES SR 3.5.2.4 The Surveillance Requirement was deleted in Amendment Nos. 260/237.

SR 3.5.2.5. SR 3.5.2.6. and SR 3.5.2.7 These SRs demonstrate that each automatic ECCS valve actuates to the required position on an actual, or simulated SIAS, and on a recirculation actuation signal; that each ECCS pump starts on receipt of an actual or simulated SIAS; and that the LPSI pumps stop on receipt of an actual or simulated recirculation actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. In order to assure the results of the low temperature overpressure protection analysis remain bounding, whenever flow testing into the RCS is required at RCS temperatures < 3650 F (Unit 1),

301OF (Unit 2), the HPSI pump shall recirculate RCS water (suction from the RWT isolated) or the requirements of LCO 3.4.12, shall be satisfied. The 24 month Frequency is based on the need to perform these surveillance tests under the conditions that apply during a plant outage and the potential for unplanned transients if the surveillance tests were performed with the reactor at power. The 24 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment. The actuation logic is tested as part of the Engineered Safety Feature Actuation System testing, and equipment performance is monitored as part of the Inservice Testing Program.

SR 3.5.2.8 Periodic inspection of the containment sump ensures that it is unrestricted and stays in proper operating condition.

The 24 month Frequency is based on the need to perform this surveillance test under the conditions that apply during an outage, on the need to have access to the location, and on the potential for unplanned transients if the surveillance test were performed with the reactor at power. This Frequency is sufficient to detect abnormal degradation and is confirmed by operating experience.

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ECCS - Operating B 3.5.2 BASES SR 3.5.2.9 Verifying that the SDC System open-permissive interlock is OPERABLE ensures that the SDC suction isolation valves are prevented from being remotely opened when RCS pressure, is at or above, the SDC System design suction pressure of 350 psia. The suction piping of the LPSI pumps, is the SDC component with the limiting design pressure rating. The interlock provides assurance that double isolation of the SDC System from the RCS is preserved whenever RCS pressure, is at or above, the design pressure. The 309 psia value specified in the Surveillance is the actual pressurizer pressure at the instrument tap elevation for PT-103 and PT-103-1 when the SDC System suction pressure is 350 psia.

The procedure for this surveillance test contains the required compensation to be applied to this value to account for instrument uncertainties. This surveillance test is normally performed using a simulated RCS pressure input signal. The 24 month Frequency is based on the need to perform this surveillance test under conditions that apply during an outage. The 24 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) for the equipment.

REFERENCES 1. UFSAR

2. 10 CFR 50.46, "Acceptance Criteria for Emergency Core Cooling Systems for Light Water Nuclear Power Plants"

3. Nuclear Regulatory Commission Memorandum to V. Stello, Jr., from R. L. Baer, "Recommended Interim Revisions to LCOs for ECCS Components," December 1, 1975

4. Inspection and Enforcement Information Notice No. 87-01, "RHR Valve Misalignment Causes Degradation of ECCS in PWRs," January 6, 1987 Revision 15 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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Containment Spray and Cooling Systems B 3.6.6 BASES APPLICABLE The Containment Spray and Cooling Systems limit the '

SAFETY ANALYSES temperature and'pressure that could be experienced following a DBA. The-limiting DBAs considered relative to containment temperature and pressure are LOCA and main SLB. The DBA, LOCA,-and main SLB'.are analyzed using.computer codes designed to predict the.resultant containment pressure and temperature transients. No DBAs are assumed to occur simultaneously or consecutively. The postulated DBAs are analyzed with regard to containment ESF systems, assuming the loss of one ESF bus, which is the worst case single active failure, resulting in one train of the Containment Spray System and one train of the-Containment Cooling System being rendered inoperable.

The analysis and evaluation show that under the worst case scenario, the highest peak containment pressure and temperature are within the design. (See the Bases for Specifications 3.6.4 and 3.6.5 for a.detailed discussion.)

The analyses and evaluations assume a power level of 102% RATED THERMAL POWER, one containment spray train and one containment cooling train operating, and initial (pre-accident) conditions of 1200 F and 16.5 psia. The analyses also assumes a response time delayed initiation, in order to provide a conservative calculation of peak containment pressure and temperature responses.

The modeled Containment Spray System actuation from the containment analysis is based upon a response time associated with exceeding the Containment High-High pressure setpoint coincidentwith an SIAS to achieve full flow through the containment spray nozzles.. The Containment Spray System total response time of 62.9 seconds for a main steam line break-and 70.9 seconds for a LOCA, includes diesel generator startup (for loss of offsite power),

sequencing equipment onto the emergency bus, containment spray pump startup, and spray line filling (Reference 1, Chapter 7).

The performance of~the containment cooling train for post-accident conditions -isgiven in Reference 1, Chapter 6. The results of the analysis, is that each train can provide approximately 67% of the required peak cooling capacity during the post-accident condition. The train post-accident Revision 15 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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Containment Spray and Cooling Systems B 3.6.6 BASES cooling capacity under varying containment ambient conditions, required to perform the accident analyses, is also shown in Reference 1, Chapter 6.

The modeled Containment Cooling System actuation from the containment analysis, is based upon the unit specific response time associated with exceeding the SIAS to achieve full Containment Cooling System air and safety grade cooling water flow.

The Containment Spray and Cooling Systems satisfy 10 CFR 50.36(c)(2)(ii), Criterion 3.

LCO During a DBA, a minimum of one containment cooling train and one containment spray train, is required to maintain the containment peak pressure and temperature, below the design limits (Reference 1, Chapter 6). Additionally, one containment spray train is also required to remove iodine from the containment atmosphere and maintain concentrations below those assumed in the safety analysis. To ensure that these requirements are met, two containment spray trains and two containment cooling trains (all four coolers) must be OPERABLE. Therefore, in the event of an accident, the minimum requirements are met, assuming that the worst case single active failure occurs.

Each Containment Spray System includes a spray pump, spray headers, nozzles, valves, piping, instruments, and controls to ensure an OPERABLE flow path capable of taking suction from the RWT upon an ESF actuation signal and automatically transferring suction to the containment sump. Each spray system flow path from the containment sump will be via an OPERABLE shutdown cooling heat exchanger.

Each Containment Cooling System includes cooling coils, dampers, fans, instruments, and controls to ensure an OPERABLE flow path.

APPLICABILITY In MODEs 1, 2, and 3, a DBA could cause a release of radioactive material to the Containment Structure and an increase in containment pressure and temperature, requiring the operation of the containment spray trains and containment cooling trains.

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SFPEVS B 3.7.11 B 3.7 PLANT SYSTEMS B 3.7.11 Spent Fuel Pool Exhaust Ventilation System (SFPEVS)

BASES BACKGROUND The SFPEVS filters airborne radioactive particulates and gases from the area of the fuel pool following a fuel handling accident involving recently irradiated fuel. I The SFPEVS consists of two independent, redundant exhaust fans, a HEPA filter, and an activated charcoal adsorber section consisting of two parallel charcoal adsorber banks for removal of gaseous activity (principally iodines).

Ductwork, valves or dampers, and instrumentation also form part of the system. The SFPEVS is supplied power by one non-safety-related power supply.

The SFPEVS is operated during normal unit operations.

During normal operation, the charcoal adsorbers are bypassed. When filtration of the air is required (i.e., during mo'vement'of recently irradiated fuel I assemblies in the Auxiliary Building), normal air discharges from the fuel handling area in the Auxiliary Building and through the system filter train. The prefilters remove any large particles in the'air to prevent excessive loading of the HEPA filters and charcoal adsorbers..

The SFPEVS is discussed in Reference 1, Sections 9.8.2.3 and 14.18, because it maybe used for normal, as well as post-accident, atmospheric cleanup functions.

APPLICABLE The SFPEVS'is designed to mitigate the consequences of a SAFETY ANALYSES fuel handling accident involving handling recently irradiated fuel (i.e., fuel that' has occupied part of a critical reactor core within the previous 32 days), in which all rods in the fuel assembly are assumed'to be damaged.

The analysis of the fuel handling accident is given in Reference 1, Section 14.18. The DBA analysis of the fuel handling accident assumes that the SFPEVS is functional.

The accident analysis accounts for the reduction in airborne radioactive-material provided by this filtration system.

The amount of fission products available for release from the Auxiliary Building is determined for a fuel handling accident. These assumptions and the analysis follow the guidance provided in Reference 2.

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U SFPEVS B 3.7.11 BASES The SFPEVS satisfies 10 CFR 50.36(c)(2)(ii), Criterion 3.

LCO The HEPA filter bank, two charcoal adsorber banks, two exhaust fans, and other equipment listed in the Background Section are required to be OPERABLE and in operation.

The SFPEVS is considered OPERABLE when the individual components necessary to control exposure in the Auxiliary Building are OPERABLE. The SFPEVS is considered OPERABLE when its associated:

a. Fans are OPERABLE;

b. HEPA filter and charcoal adsorber banks are not excessively restricting flow, and are capable of performing their filtration functions; and

c. Ductwork, valves, and dampers are OPERABLE, and air circulation can be maintained.

The SFPEVS is considered in operation when an OPERABLE exhaust fan is in operation, discharging through the OPERABLE HEPA Filter and one OPERABLE charcoal adsorber bank.

APPLICABILITY During movement of recently irradiated fuel assemblies in I the Auxiliary Building, the SFPEVS is required to be OPERABLE and in operation to mitigate the consequences of a fuel handling accident involving handling recently irradiated fuel. Due to radioactive decay, the SFPEVS is only required to mitigate fuel handling accidents involving handling recently irradiated fuel (i.e., fuel that has occupied part of a critical reactor core within the previous 32 days).

ACTIONS A.1 and A.2 When one SFPEVS charcoal adsorber bank or one SFPEVS exhaust fan, or both, are inoperable, action must be taken to verify an OPERABLE SFPEVS train is in operation, or movement of recently irradiated fuel assemblies in the Auxiliary I Building must be suspended. One OPERABLE SFPEVS train consists of one OPERABLE exhaust fan able to discharge through the OPERABLE HEPA filter and one OPERABLE charcoal CALVERT CLIFFS - UNITS 1 & 2 B 3.7.11-2 Revision 15

SFPEVS B 3.7.11 BASES adsorber bank. This ensures the proper equipment is operating for the Applicable Safety Analysis.

B.1 When there is no OPERABLE SFPEVS train or there is no OPERABLE SFPEVS train in operation during movement of recently irradiated fuel assemblies in the Auxiliary Building, action must be taken to place the unit in a condition in which the LCO does not apply. This Action involves immediately suspending movement of recently irradiated fuel assemblies in the Auxiliary Building. This does not preclude-the movement of fuel to a safe position.

SURVEILLANCE SR 3.7.11.1 REQUIREMENTS The SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that the SFPEVS is in operation. Verification includes verifying that one exhaust fan is operating and discharging through the HEPA filter bank and one charcoal adsorber bank. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient considering that the operators will be focused on-the movement of recently irradiated fuel assemblies within the Auxiliary Building. Thus, if anything were to occur to cause cessation of operation of the SFPEVS, it would be quickly identified.

SR 3.7.11.2 This SR verifies the performance of SFPEVS filter testing in accordance with the VFTP. The SFPEVS filter tests are in accordance with portions of Reference 3. The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). Specific test frequencies and additional information are discussed in detail in the VFTP.

SR 3.7.11.3 This SR verifies the integrity of the spent fuel storage pool area. The ability of the spent fuel storage pool area to maintain negative pressure with respect to potentially uncontaminated adjacent areas is periodically tested to verify proper function of the SFPEVS. During operation, the B 3.7.11-3 Revision 15 UNITS 11 &

CALVERT CLIFFS - UNITS

- &22 B 3.7.11-3 Revision 15

a SFPEVS B 3.7.11 BASES spent fuel storage pool area is designed to maintain a slight negative pressure in the spent fuel storage pool area, with respect to adjacent areas, to prevent unfiltered LEAKAGE.

This test is conducted on a 24 month Frequency. This Frequency is adequate to ensure the SFPEVS is capable of maintaining a negative pressure.

REFERENCES 1. UFSAR

2. Regulatory Guide 1.25, "Assumptions Used for Evaluating the Potential Radiological Consequences of a Fuel Handling Accident in the Fuel Handling and Storage Facility for Boiling and Pressurized Water Reactors (Safety Guide 25)," March 1972

3. Regulatory Guide 1.52, Revision 2, "Design, Testing, and Maintenance Criteria for Post Accident Engineered-Safety-Feature Atmosphere Cleanup System Air Filtration and Adsorption Units of Light-Water-Cooled Nuclear Power Plants," March 1978 CALVRT LIFS -UNIT 1 2 3..11- Reisin 1 CALVERT CLIFFS - UNITS I & 2 B 3.7. 11-4 Revision 15

PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 16 Remove and Discard Insert List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 List of Revisions LOR-1 LOR-1 Technical Specification Bases Pages iii and iv iii and iv B 3.3.10-7 through B 3.3.10-18 B 3.3.10-7 through B 3.3.10-17 B 3.6.7-1 through B 3.6.7-6

March 31, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 16 B 3.1.1-7 Rev. 2 B 3.1.8-5 Rev. 2 LEP-2 Rev. 16 B 3.1.2-1 Rev. 2 B 3.2.1-1 Rev. 2 LEP-3 Rev. 16 B 3.1.2-2 Rev. 2 B 3.2.1-2 Rev. 14 LEP-4 Rev. 16 B 3.1.2-3 Rev. 2 B 3.2.1-3 Rev. 14 LEP-5 Rev. 16 B 3.1.2-4 Rev. 2 B 3.2.1-4 Rev. 14 LOR-1 Rev. 16 B 3.1.2-5 Rev. 2 B 3.2.1-5 Rev. 14 Rev. 2 B 3.1.2-6 Rev. 3 B 3.2.1-6 Rev. 14 ii Rev. 2 B 3.1.3-1 Rev. 2 B 3.2.1-7 Rev. 14 iii Rev. 16 B 3.1.3-2 Rev. 2 B 3.2.2-1 Rev. 2 iv Rev. 2 B 3.1.3-3 Rev. 2 B 3.2.2-2 Rev. 8 B 2.1.1-1 Rev. 2 B 3.1.3-4 Rev. 2 B 3.2.2-3 Rev. 14 B 2.1.1-2 Rev. 2 B 3.1.3-5 Rev. 2 B 3.2.2-4 Rev. 12 B 2.1.1-3 Rev. 2 B 3.1.4-1 Rev. 2 B 3.2.2-5 Rev. 12 B 2.1.1-4 Rev. 2 B 3.1.4-2 Rev. 2 B 3.2.2-6 Rev. 12 B 2.1.2-1 Rev. 2 B 3.1.4-3 Rev. 2 B 3.2.3-1 Rev. 2 B 2.1.2-2 Rev. 2 B 3.1.4-4 Rev. 2 B 3.2.3-2 Rev. 8 B 2.1.2-3 Rev. 2 B 3.1.4-5 Rev. 2 B 3.2.3-3 Rev. 14 B 2.1.2-4 Rev. 2 B 3.1.4-6 Rev. 2 B 3.2.3-4 Rev. 12 B 3.0-1 Rev. 2 B 3.1.4-7 Rev. 2 B 3.2.3-5 Rev. 12 B 3.0-2 Rev. 2 B 3.1.4-8 Rev. 2 B 3.2.4-1 Rev. 2 B 3.0-3 Rev. 2 B 3.1.4-9 Rev. 2 B 3.2.4-2 Rev. 8 B 3.0-4 Rev. 2 B 3.1.4-10 Rev. 2 B 3.2.4-3 Rev. 14 B 3.0-5 Rev. 13 B 3.1.5-1 Rev. 2 B 3.2.4-4 Rev. 8 B 3.0-6 Rev. 13 B 3.1.5-2 Rev. 2 B 3.2.4-5 Rev. 8 B 3.0-7 Rev. 13 B 3.1.5-3 Rev. 2 B 3.2.5-1 Rev. 2 B 3.0-8 Rev. 2 B 3.1.5-4 Rev. 2 B 3.2.5-2 Rev. 11 B 3.0-9 Rev. 2 B 3.1.5-5 Rev. 2 B 3.2.5-3 Rev. 14 B 3.0-10 Rev. 2 B 3.1.6-1 Rev. 2 B 3.2.5-4 Rev. 11 B 3.0-11 Rev. 2 B 3.1.6-2 Rev. 2 B 3.2.5-5 Rev. 11 B 3.0-12 Rev. 2 B 3.1.6-3 Rev. 2 B 3.2.5-6 Rev. 11 B 3.0-13 Rev. 2 B 3.1.6-4 Rev. 2 B 3.3.1-1 Rev. 2 B 3.0-14 Rev. 2 B 3.1.6-5 Rev. 2 B 3.3.1-2 Rev. 2 B 3.0-15 Rev. 13 B 3.1.6-6 Rev. 2 B 3.3.1-3 Rev. 2 B 3.0-16 Rev. 13 B 3.1.6-7 Rev. 2 B 3.3.1-4 Rev. 2 B 3.0-17 Rev. 13 B 3.1.7-1 Rev. 2 B 3.3.1-5 Rev. 2 B 3.0-18 Rev. 13 B 3.1.7-2 Rev. 2 B 3.3.1-6 Rev. 12 B 3.0-19 Rev. 13 B 3.1.7-3 Rev. 5 B 3.3.1-7 Rev. 12 B 3.1.1-1 Rev. 2 B 3.1.7-4 Rev. 2 B 3.3.1-8 Rev. 12 B 3.1.1-2 Rev. 2 B 3.1.7-5 Rev. 11 B 3.3.1-9 Rev. 12 B 3.1.1-3 Rev. 2 B 3.1.8-1 Rev. 2 B 3.3.1-10 Rev. 12 B 3.1.1-4 Rev. 2 B 3.1.8-2 Rev. 2 B 3.3.1-11 Rev. 5 B 3.1.1-5 Rev. 2 B 3.1.8-3 Rev. 2 B 3.3.1-12 Rev. 2 B 3.1.1-6 Rev. 2 B 3.1.8-4 Rev. 2 B 3.3.1-13 Rev. 12 LEP-1 Rev. 16

-- a March 31, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.1-14 Rev. 11 B 3.3.3-12 Rev. 2 B 3.3.6-6 Rev. 2 B 3.3.1-15 Rev. 11 B 3.3.4-1 Rev. 2 B 3.3.6-7 Rev. 12 B 3.3.1-16 Rev. 11 B 3.3.4-2 Rev. 2 B 3.3.6-8 Rev. 8 B 3.3.1-17 Rev. 11 B 3.3.4-3 Rev. 2 B 3.3.7-1 Rev. 14 B 3.3.1-18 Rev. 13 B 3.3.4-4 Rev. 2 B 3.3.7-2 Rev. 2 B 3.3.1-19 Rev. 11 B 3.3.4-5 Rev. 2 B 3.3.7-3 Rev. 2 B 3.3.1-20 Rev. 11 B 3.3.4-6 Rev. 2 B 3.3.7-4 Rev. 2 B 3.3.1-21 Rev. 11 B 3.3.4-7 Rev. 2 B 3.3.7-5 Rev. 2 B 3.3.1-22 Rev. 11 B 3.3.4-8 Rev. 2 B 3.3.7-6 Rev. 2 B 3.3.1-23 Rev. 11 B 3.3.4-9 Rev. 2 B 3.3.7-7 Rev. 2 B 3.3.1-24 Rev. 11 B 3.3.4-10 Rev. 2 B 3.3.8-1 Rev. 8 B 3.3.1-25 Rev. 11 B 3.3.4-11 Rev. 2 B 3.3.8-2 Rev. 2 B 3.3.1-26 Rev. 11 B 3.3.4-12 Rev. 2 B 3.3.8-3 Rev. 2 B 3.3.1-27 Rev. 11 B 3.3.4-13 Rev. 2 B 3.3.8-4 Rev. 2 B 3.3.1-28 Rev. 11 B 3.3.4-14 Rev. 2 B 3.3.9-1 Rev. 2 B 3.3.1-29 Rev. 11 B 3.3.4-15 Rev. 2 B 3.3.9-2 Rev. 2 B 3.3.1-30 Rev. 11 B 3.3.4-16 Rev. 2 B 3.3.9-3 Rev. 2 B 3.3.1-31 Rev. 11 B 3.3.4-17 Rev. 5 B 3.3.9-4 Rev. 2 B 3.3.1-32 Rev. 11 B 3.3.4-18 Rev. 2 B 3.3.9-5 Rev. 2 B 3.3.1-33 Rev. 12 B 3.3.4-19 Rev. 2 B 3.3.9-6 Rev. 2 B 3.3.1-34 Rev. 12 B 3.3.4-20 Rev. 2 B 3.3.9-7 Rev. 2 B 3.3.1-35 Rev. 2 B 3.3.4-21 Rev. 2 B 3.3.9-8 Rev. 3 B 3.3.2-1 Rev. 2 B 3.3.4-22 Rev. 12 B 3.3.10-1 Rev. 2 B 3.3.2-2 Rev. 2 B 3.3.4-23 Rev. 12 B 3.3.10-2 Rev. 2 B 3.3.2-3 Rev. 2 B 3.3.5-1 Rev. 2 B 3.3.10-3 Rev. 14 B 3.3.2-4 Rev. 2 B 3.3.5-2 Rev. 2 B 3.3.10-4 Rev. 14 B 3.3.2-5 Rev. 2 B 3.3.5-3 Rev. 2 B 3.3.10-5 Rev. 14 B 3.3.2-6 Rev. 2 B 3.3.5-4 Rev. 2 B 3.3.10-6 Rev. 14 B 3.3.2-7 Rev. 2 B 3.3.5-5 Rev. 2 B 3.3.10-7 Rev. 16 B 3.3.2-8 Rev. 2 B 3.3.5-6 Rev. 2 B 3.3.10-8 Rev. 16 B 3.3.2-9 Rev. 2 B 3.3.5-7 Rev. 2 B 3.3.10-9 Rev. 16 B 3.3.2-10 Rev. 2 B 3.3.5-8 Rev. 2 B 3.3.10-10 Rev. 16 B 3.3.3-1 Rev. 2 B 3.3.5-9 Rev. 2 B 3.3.10-11 Rev. 16 B 3.3.3-2 Rev. 2 B 3.3.5-10 Rev. 2 B 3.3.10-12 Rev. 16 B 3.3.3-3 Rev. 2 B 3.3.5-11 Rev. 2 B 3.3.10-13 Rev. 16 B 3.3.3-4 Rev. 2 B 3.3.5-12 Rev. 2 B 3.3.10-14 Rev. 16 B 3.3.3-5 Rev. 2 B 3.3.5-13 Rev. 2 B 3.3.10-15 Rev. 16 B 3.3.3-6 Rev. 2 B 3.3.5-14 Rev. 2 B 3.3.10-16 Rev. 16 B 3.3.3-7 Rev. 2 B 3.3.6-1 Rev. 2 B 3.3.10-17 Rev. 16 B 3.3.3-8 Rev. 2 B 3.3.6-2 Rev. 2 B 3.3. 11-1 Rev. 2 B 3.3.3-9 Rev. 2 B 3.3.6-3 Rev. 2 B 3.3.11-2 Rev. 2 B 3.3.3-10 Rev. 2 B 3.3.6-4 Rev. 13 B 3.3.11-3 Rev. 2 B 3.3.3-11 Rev. 2 B 3.3.6-5 Rev. 2 B 3.3.11-4 Rev. 2 LEP-2 Rev. 16

March 31, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.11-5 Rev. 2 B 3.4.9-3 Rev. 2 B 3.4.16-;2 Rev. 2 B 3.3.12-1 Rev. 2 B 3.4.9-4 Rev. 2 B 3.4.16-:3 Rev. 2 B 3.3.12-2 Rev. 2 B 3.4.9-5 Rev. 2 B 3.4.17- 1 Rev. 2 B 3.3.12-3 Rev. 2 B 3.4.10-1 Rev. 2 B 3.4.17-:2 Rev. 2 B 3.3.12-4 Rev. 2 B 3.4.10-2 Rev. 2 B 3.4.17-:3 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4.1-2 Rev. 15 B 3.4.10-4 Rev. 2 B 3.5.1-2 Rev. 2 B 3.4.1-3 Rev. 15 B 3.4.11-1 Rev. 12 B 3.5.1-3 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-2 Rev. 12 B 3.5.1-4 Rev. 2 B 3.4.1-5 Rev. 15 B 3.4.11-3 Rev. 12 B 3.5.1-5 Rev. 2 B 3.4.2-1 Rev. 2 B 3.4.11-4 Rev. 12 B 3.5.1-6 Rev. 2 B 3.4.2-2 Rev. 2 B 3.4.11-5 Rev. 12 B 3.5.1-7 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B 3.4.3-2 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-3 Rev. 2 B 3.4.12-1 Rev. 2 B 3.5.2-1 Rev. 15 B 3.4.3-4 Rev. 2 B 3.4.12-2 Rev. 2 B 3.5.2-2 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-3 Rev. 2 B 3.5.2-3 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-4 Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-7 Rev. 2 B 3.4.12-5 Rev. 6 B 3.5.2-5 Rev. 15 B 3.4.3-8 Rev. 2 B 3.4.12-6 Rev. 2 B 3.5.2-6 Rev. 15 B 3.4.4-1 Rev. 2 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-2 Rev. 13 B 3.4.12-8 Rev. 2 B 3.5.2-8 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-9 Rev. 2 B 3.5.2-9 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.12-10 Rev. 2 B 3.5.3-1 Rev. 2 B 3.4.5-2 Rev. 8 B 3.4.12-11 Rev. 2 B 3.5.3-2 Rev. 2 B 3.4.5-3 Rev. 8 B 3.4.12-12 Rev. 2 B 3.5.3-3 Rev. 2 B 3.4.5-4 Rev. 8 B 3.4.12-13 Rev. 2 B 3.5.4-1 Rev. 2 B 3.4.6-1 Rev. 2 B 3.4.13-1 Rev. 2 B 3.5.4-2I Rev. 14 B 3.4.6-2 Rev. 8 B 3.4.13-2 Rev. 10 B 3.5.4-3 Rev. 2 B 3.4.6-3 Rev. 8 B 3.4.13-3 Rev. 2 B 3.5.4-4 Rev. 2 B 3.4.6-4 Rev. 8 B 3.4.13-4 Rev. 2 B 3.5.4-5 Rev. 2 B 3.4.6-5 Rev. 8 B 3.4.13-5 Rev. 5 B 3.5.4-6I Rev. 2 B 3.4.7-1 Rev. 2 B 3.4.14-1 Rev. 2 B 3.5.5-1 Rev. 2 B 3.4.7-2 Rev. 2 B 3.4.14-2 Rev. 2 B 3.5.5-20 Rev. 2 B 3.4.7-3 Rev. 8 B 3.4.14-3 Rev. 2 B 3.5.5-3I Rev. 2 B 3.4.7-4 Rev. 8 B 3.4.14-4 Rev. 2 B 3.5.5-4I Rev. 2 B 3.4.7-5 Rev. 8 B 3.4.14-5 Rev. 2 B 3.5.5-5i Rev. 2 B 3.4.7-6 Rev. 8 B 3.4.15-1 Rev. 2 B 3.6.1-1 Rev. 2 B 3.4.8-1 Rev. 2 B 3.4.15-2 Rev. 2 B 3.6.1-2 Rev. 2 B 3.4.8-2 Rev. 2 B 3.4.15-3 Rev. 2 B 3.6.1-3I Rev. 2 B 3.4.8-3 Rev. 2 B 3.4.15-4 Rev. 3 B 3.6.1-4I Rev. 12 B 3.4.9-1 Rev. 2 B 3.4.15-5 Rev. 2 B 3.6.1-5i Rev. 2 B 3.4.9-2 Rev. 2 B 3.4.16-1 Rev. 2 B 3.6.2-1I Rev. 2 LEP-3 Rev. 16

__ I March 31, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.2-2 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-3 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.2-4 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.2-6 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-2 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.3-6 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.3-9 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-4 Rev. 2 B 3.7.15-1 Rev. 2 B 3.6.4-2 Rev. 2 B 3.7.5-1 Rev. 2 B 3.7.15-2 Rev. 13 B 3.6.4-3 Rev. 2 B 3.7.5-2 Rev. 2 B 3.7.15-3 Rev. 14 B 3.6.5-1 Rev. 2 B 3.7.5-3 Rev. 2 B 3.7.15-4 Rev. 2 B 3.6.5-2 Rev. 2 B 3.7.5-4 Rev. 2 B 3.8.1-1 Rev. 5 B 3.6.5-3 Rev. 3 B 3.7.5-5 Rev. 2 B 3.8.1-2 Rev. 12 B 3.6.6-1 Rev. 2 B 3.7.6-1 Rev. 5 B 3.8.1-3 Rev. 2 B 3.6.6-2 Rev. 2 B 3.7.6-2 Rev. 2 B 3.8.1-4 Rev. 10 B 3.6.6-3 Rev. 15 B 3.7.6-3 Rev. 5 B 3.8.1-5 Rev. 7 B 3.6.6-4 Rev. 15 B 3.7.6-4 Rev. 5 B 3.8.1-6 Rev. 7 B 3.6.6-5 Rev. 2 B 3.7.6-5 Rev. 5 B 3.8.1-7 Rev. 3 B 3.6.6-6 Rev. 2 B 3.7.7-1 Rev. 5 B 3.8.1-8 Rev. 3 B 3.6.6-7 Rev. 2 B 3.7.7-2 Rev. 12 B 3.8.1-9 Rev. 3 B 3.6.6-8 Rev. 2 B 3.7.7-3 Rev. 2 B 3.8.1-10 Rev. 3 B 3.6.6-9 Rev. 2 B 3.7.7-4 Rev. 12 B 3.8.1-11 Rev. 3 B 3.6.7 Deleted B 3.7.8-1 Rev. 8 B 3.8.1-12 Rev. 3 B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 B 3.8.1-13 Rev. 3 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 B 3.8.1-14 Rev. 3 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 B 3.8.1-15 Rev. 3 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 B 3.8.1-16 Rev. 3 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 B 3.8.1-17 Rev. 3 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 B 3.8.1-18 Rev. 3 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.8.1-19 Rev. 3 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.8.1-20 Rev. 3 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.8.1-21 Rev. 3 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.8.1-22 Rev. 3 LEP-4 Rev. 16

March 31, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-23 Rev. 3 B 3.8.7-1 Rev. 2 B 3.9.5-4 Rev. 14 B 3.8.1-24 Rev. 3 B 3.8.7-2 Rev. 2 B 3.9.5-5 Rev. 14 B 3.8.1-25 Rev. 3 B 3.8.7-3 Rev. 2 B 3.9.6-1 Rev. 2 B 3.8.1-26 Rev. 5 B 3.8.7-4 Rev. 2 B 3.9.6-2 Rev. 2 B 3.8.1-27 Rev. 5 B 3.8.8-1 Rev. 2 B 3.9.6-3 Rev. 2 B 3.8.1-28 Rev. 13 B 3.8.8-2 Rev. 2 B 3.8.1-29 Rev. 13 B 3.8.8-3 Rev. 2 B 3.8.1-30 Rev. 13 B 3.8.9-1 Rev. 5 B 3.8.2-1 Rev. 2 B 3.8.9-2 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-3 Rev. 2 B 3.8.2-3 Rev. 10 B 3.8.9-4 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-5 Rev. 2 B 3.8.2-5 Rev. 5 B 3.8.9-6 Rev. 2 B 3.8.2-6 Rev. 5 B 3.8.9-7 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-5 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-3 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-4 Rev. 5 B 3.8.3-8 Rev. 3 B 3.8.10-5 Rev. 5 B 3.8.3-9 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-1 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-2 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-3 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-4 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-5 Rev. 2 B 3.9.2-2 Rev. 2 B 3.8.4-6 Rev. 2 B 3.9.2-3 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.4-8 Rev. 2 B 3.9.3-2 Rev. 13 B 3.8.4-9 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.5-2 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.5-3 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.5-4 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.6-1 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.6-2 Rev. 2 B 3.9.4-2 Rev. 2 B 3.8.6-3 Rev. 2 B 3.9.4-3 Rev. 11 B 3.8.6-4 Rev. 2 B 3.9.4-4 Rev. 13 B 3.8.6-5 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.6-6 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.6-7 Rev. 2 B 3.9.5-3 Rev. 14 LEP-5 Rev. 16

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 LOR-1 Rev. 16

TABLE OF CONTENTS B 3.6.5 Containment Air Temperature...................... B 3.6.5-1 B 3.6.6 Containment Spray and Cooling Systems............ B 3.6.6-1 B 3.6.7 Deleted I B 3.6.8 Iodine Removal System (IRS)...................... B 3.6.8-1 B 3.7 PLANT SYSTEMS........................................ B 3.7.1-1 B 3.7.1 Main Steam Safety Valves (MSSVs)................. B 3.7.1-1 B 3.7.2 Main Steam Isolation Valves (MSIVs).............. B 3.7.2-1 B 3.7.3 Auxiliary Feedwater (AFW) System................. B 3.7.3-1 B 3.7.4 Condensate Storage Tank (CST).................... B 3.7.4-1 B 3.7.5 Component Cooling (CC) System.................... B 3.7.5-1 B 3.7.6 Service Water (SRW) System....................... B 3.7.6-1 B 3.7.7 Saltwater (SW) System............................ B 3.7.7-1 B 3.7.8 Control Room Emergency Ventilation System (CREVS) ...................................... B 3.7.8-1 B 3.7.9 Control Room Emergency Temperature System (CRETS) ...................................... B 3.7.9-1 B 3.7.10 Emergency Core Cooling System (ECCS) Pump Room Exhaust Filtration System (PREFS) ............ B 3.7.10-1 B 3.7.11 Spent Fuel Pool Exhaust Ventilation System (SFPEVS) ..................................... B 3.7.11-1 B 3.7.12 Penetration Room Exhaust Ventilation System (PREVS) ...................................... B 3.7.12-1 B 3.7.13 Spent Fuel Pool (SFP) Water Level ................ B 3.7.13-1 B 3.7.14 Secondary Specific Activity...................... B 3.7.14-1 B 3.7.15 Main Feedwater Isolation Valves (MFIVs).......... B 3.7.15-1 B 3.8 ELECTRICAL POWER SYSTEMS............................. B 3.8.1-1 B 3.8.1 AC Sources-Operating ............................ B 3.8.1-1 B 3.8.2 AC Sources-Shutdown ............................. B 3.8.2-1 B 3.8.3 Diesel Fuel Oil.................................. B 3.8.3-1 B 3.8.4 DC Sources-Operating ............................ B 3.8.4-1 B 3.8.5 DC Sources-Shutdown ............................. B 3.8.5-1 B 3.8.6 Battery Cell Parameters.......................... B 3.8.6-1 B 3.8.7 Inverters-Operating ............................. B 3.8.7-1 B 3.8.8 Inverters-Shutdown .............................. B 3.8.8-1 B 3.8.9 Distribution Systems-Operating .................. B 3.8.9-1 B 3.8.10 Distribution Systems-Shutdown ................... B 3.8.10-1 B 3.9 REFUELING OPERATIONS................................. B 3.9.1-1 B 3.9.1 Boron Concentration............................. B 3.9.1-1 B 3.9.2 Nuclear Instrumentation.......................... B 3.9.2-1 CALVERT CLIFFS - UNITS 1 & 2 . .

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I TABLE OF CONTENTS B 3.9.3 Containment Penetrations ..................... B 3.9.3-1 B 3.9.4 Shutdown Cooling (SDC) and Coolant Circulation-High Water Level ...... B 3.9.4-1 B 3.9.5 Shutdown Cooling (SDC) and Coolant Circulation-Low Water Level ......... ............ B 3.9.5-1 B 3.9.6 Refueling Pool Water Level ..................... B 3.9.6-1 CALVERT CLIFFS - UNITS 1 & 2 iv Revision 2

PAM Instrumentation B 3.3.10 BASES a penetration flow path with two active valves. For containment penetrations with only one active CIV having control room indication, Note (b) requires a single channel of valve position indication to be OPERABLE. This is sufficient to redundantly verify the isolation status of each isolable penetration via indicated status of the active valve, as applicable, and prior knowledge of passive valve or system boundary status. If a penetration flow path is isolated, position indication for the CIV(s) in the associated penetration flow path is not needed to determine status. Therefore, the position indication for valves in an isolated penetration flow path is not required to be OPERABLE.

The CIV position PAM instrumentation consists of ZL-505, 506, 515, 516, 2080, 2180, 2181, 3832, 3833, 4260, 5291, 5292, 6900, and 6901 (Reference 5).

9. Containment Area Radiation (high range) Detector Containment area radiation detectors are provided to monitor for the potential of significant radiation releases and to provide release assessment for use by operations in determining the need to invoke site emergency plans.

Containment area radiation instrumentation consists of two radiation detectors with displays and alarm in the Control Room. The radiation detectors have a measurement range of 1 to 108 R/hr.

10. Pressurizer Pressure (wide range)

Pressurizer wide range pressure is a Category I variable provided for verification of core cooling and RCS integrity long-term surveillance.

Wide range pressurizer pressure is measured by two pressure transmitters with a span of 0 psia to 4000 psia. The pressure transmitters are located inside the Containment. Redundant monitoring CALVERT CLIFFS - UNITS 1 & 2 B 3.3.10-7 Revision 16

a PAM Instrumentation B 3.3.10 BASES capability is provided by two indication channels.

Control Room indications are provided.

Pressurizer pressure is a Type I variable because the operator uses this indication to monitor the cooldown of the RCS following a LOCA and other DBAs. Operator actions to maintain a controlled cooldown, such as adjusting steam generator pressure or level, would use this indication. Furthermore, pressurizer pressure is one factor that may be used in decisions to terminate RCP operation.

11. Steam Generator Pressure Transmitter Steam generator pressure transmitters are Category 1 instruments and are provided to monitor operation of decay heat removal via the steam generators.

There are four redundant pressure transmitters per steam generator, but only two per steam generator are required to satisfy the Technical Specification Requirements. The transmitter provides wide range indication over the range from 0 to 1200 psia. Each transmitter provides input to control room indication.

Since the primary indication used by the operator during an accident is the control room indicator, the PAM instrumentation Specification deals specifically with this portion of the instrument channel.

12. Pressurizer Level Transmitters Pressurizer level transmitters are used to determine whether to terminate safety injection, if still in progress, or to reinitiate safety injection if it has been stopped. Knowledge of pressurizer water' level is also used to verify the plant conditions necessary to establish natural circulation in the RCS and to verify that the plant is maintained in a safe shutdown condition.

Pressurizer Level instrumentation consists of two pressurizer level transmitters that provide input to control room indicators.

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PAM Instrumentation B 3.3.10 BASES

13. Steam Generator Water Level Transmitters Steam Generator Water Level transmitters are provided to monitor operation of decay heat removal via the steam generators. The Category I indication of steam generator level is the extended startup range level instrumentation. The extended startup range level covers a span of -40 inches to -63 inches (relative to normal operating level), above the lower tubesheet.

The measured differential pressure is displayed in inches of water at process conditions of the fluid.

Redundant monitoring capability is provided by four transmitters. The uncompensated level signal is input to the plant computer and a control room indicator.

Steam generator water level instrumentation consists of two level transmitters.

Operator action is based on the control room indication of steam generator water level. The RCS response during a design basis small break LOCA is dependent on the break size. For a certain range of break sizes, the boiler condenser mode of heat transfer is necessary to remove decay heat. Extended startup range level is a Type A variable because the operator must manually raise and control the steam generator level to establish boiler condenser heat transfer. Feedwater flow is increased until indication is in range.

14. Condensate Storage Tank Level Monitor Condensate storage tank (CST) level monitoring is provided to ensure water supply for AFW. Condensate Storage Tank 12 provides the ensured safety grade water supply for the AFW System. Inventory in CST 12 is monitored by level indication covering the full range of required usable water level. Condensate storage tank level is displayed on control room indicators and the plant computer. In addition, a control room annunciator alarms on low level.

Condensate storage tank level is considered a Type A variable because the control room meter and annunciator are considered the primary indication used by the Operator. The DBAs that require AFW are the steam line CALVERT CLIFFS - UNITS 1 & 2 B 3.3.10-9 Revision 16

PAM Instrumentation B 3.3.10 BASES break and loss of main feedwater. Condensate Storage Tank 12 is the initial source of water for the AFW System. However, as the CST is depleted, manual operator action is necessary to replenish the CST or align suction to the AFW pumps from an alternate source.

15, 16, 17, 18. Core Exit Temperature Core Exit Temperature indication is provided for verification and long-term surveillance of core cooling.

An evaluation was made of the minimum number of valid CETs necessary for inadequate core cooling detection.

The evaluation determined the reduced complement of CETs necessary to detect initial core uncovery and trend the ensuing core heatup. The evaluations account for core nonuniformities, including incore effects of the radial decay power distribution and excore effects of condensate runback in the hot legs and nonuniform inlet temperatures. Based on these evaluations, adequate or inadequate core cooling detection is ensured with two valid CETs per quadrant.

The design of the Incore Instrumentation System includes a Type K (chromel alumel) thermocouple within each of the 35 incore instrument detector assemblies.

The junction of each thermocouple is located more than a foot above the fuel assembly, inside a structure that supports and shields the incore instrument detector assembly string from flow forces in the outlet plenum region. These CETs monitor the temperature of the reactor coolant as it exits the fuel assemblies.

The CETs have a usable temperature range from 40'F to 2300'F, although accuracy is reduced at temperatures above 1800 0F.

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PAM Instrumentation B 3.3.10 BASES

19. Pressurizer Pressure (low range)

Pressurizer low range pressure is a Category I variable provided for verification of core cooling and RCS integrity long-term surveillance.

Low-range pressurizer pressure is measured by two pressure transmitters with a span of 0 psia to 1600 psia. The pressure transmitters are located inside the Containment. Redundant monitoring capability is provided by two indication channels.

Control Room indications are provided.

Pressurizer pressure is a Type I variable because the operator uses this indication to monitor the cooldown of the RCS following a LOCA and other DBAs. Operator actions to maintain a controlled cooldown, such as adjusting steam generator pressure or level, would use this indication. Furthermore, pressurizer pressure is one factor that may be used in decisions to terminate RCP operations.

Two indication channels are required to be OPERABLE for all but two Functions. Two OPERABLE channels ensure that no single failure, within either the PAM instrumentation or its auxiliary supporting features or power sources (concurrent with the failures that are a condition of or result from a specific accident), prevents the operators from being presented the information necessary for them to determine the safety status of the plant, and to bring the plant to and maintain it in a safe condition following that accident.

In Table 3.3.10-1 the exceptions to the two channel requirement are CIV position and the SMM.

Two OPERABLE CETs are required for each channel in each quadrant to provide indication of radial distribution of the coolant temperature rise across representative regions of the core. Power distribution symmetry was considered in determining the specific number and locations provided for diagnosis of local core problems. Therefore, two randomly selected thermocouples may not be sufficient to meet the two thermocouples per channel requirement in any quadrant. The two thermocouples in each channel must meet the additional Revision 16 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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PAM Instrumentation B 3.3.10 BASES requirement that one be located near the center of the core and the other near the core perimeter, such that the pair of CETs indicate the radial temperature gradient across their core quadrant. The two channels in each core quadrant must be electronically independent. A CETs operability is based on a comparison of the CET temperature indication with the hot leg resistance temperature detector temperature indication. Different criteria have been specified for interior CETs and peripheral CETs to account for the core radial power distribution. Plant specific evaluations in response to Item II.F.2 of NUREG-0737 should have identified the thermocouple pairings that satisfy these requirements.

Two sets of two thermocouples in each quadrant ensure a single failure will not disable the ability to determine the radial temperature gradient.

For loop- and steam generator-related variables, the required information is individual loop temperature and individual steam generator level. In these cases, two channels are required to be OPERABLE for each loop of steam generator to redundantly provide the necessary information.

In the case of CIV position, the important information is the status of the containment penetrations. The lCO requires one position indicator for each active CEV. This is sufficient to redundantly verify the isolation status of each isolable penetration either via indicated status of the active valve and prior knowledge of the passive valve or via system boundary status. If a normally active CIV 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.

The SMM, CETs, and the HJTC-based reactor vessel water level indication comprise the inadequate core cooling instrumentation. The function of the inadequate core cooling instrumentation is to enhance the ability of the plant operator to diagnose the approach to, and recovery from, inadequate core cooling.

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PAM Instrumentation B 3.3.10 BASES APPLICABILITY The PAM instrumentation LCO is applicable in MODEs 1, 2, and 3. These variables are related to the diagnosis and preplanned actions required to mitigate DBAs. The applicable DBAs are assumed to occur in MODEs 1, 2, and 3.

In MODEs 4, 5, and 6, plant conditions are such that the likelihood of an event occurring requiring PAM instrumentation is low; therefore, PAM instrumentation is not required to be OPERABLE in these MODEs.

ACTIONS Note 1 has been added in the ACTIONS to exclude the MODE change restriction of LCO 3.0.4. This exception allows entry into the applicable MODE while relying on the ACTIONS, even though the ACTIONS may eventually require plant shutdown. This exception is acceptable due to the passive function of the indication channels, the operator's ability to monitor an accident using alternate instruments and methods, and the low probability of an event requiring these indication channels.

Note 2 has been added in the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Specification may be entered independently for each Function listed in Table 3.3.10-1. The Completion Time(s) of the inoperable channel(s) of a Function will be tracked separately for each Function, starting from the time the Condition was entered for that Function.

A.1 When one or more Functions have one required indication channel that is inoperable, the required inoperable channel must be restored to OPERABLE status within 30 days. The 30-day Completion Time is based on operating experience and takes into account the remaining OPERABLE channel (or in the case of a Function that has only one required channel, other non-Reference 3 indication channels to monitor the Function), the passive nature of the instrument (no critical automatic action is assumed to occur from these instruments), and the low probability of an event requiring PAM instrumentation during this interval.

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PAM Instrumentation B 3.3.10 BASES B.1 This Required Action specifies initiation of actions in accordance with Specification 5.6.7, which requires a written report to be submitted to the NRC. This report discusses the results of the root cause evaluation of the inoperability and identifies proposed restorative Required Actions. This Required Action is appropriate in lieu of a shutdown requirement, given the likelihood of plant conditions that would require information provided by this instrumentation. Also, alternative Required Actions such as grab sampling or diverse indications are identified before a loss of functional capability condition occurs.

C.1 When one or more Functions have two required indication channels inoperable (i.e., two channels inoperable in the same Function), one channel in the Function should be restored to OPERABLE status within 7 days. The Completion Time of 7 days is based on the relatively low probability of an event requiring PAM instrumentation operation and the availability of alternate means to obtain the required information. Continuous operation with two required channels inoperable in a Function is not acceptable because the alternate indications may not fully meet all performance qualification requirements applied to the PAM instrumentation. Therefore, requiring restoration of one inoperable channel of the Function limits the risk that the PAM Function will be in a degraded condition should an accident occur.

D.1 This Required Action directs entry into the appropriate Condition referenced in Table 3.3.10-1. The applicable Condition referenced in the Table is Function-dependent.

Each time Required Action C.1 is not met and the associated Completion Time has expired, Condition D is entered for that channel and provides for transfer to the appropriate subsequent Condition.

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PAM Instrumentation B 3.3.10 BASES E.1 and E.2 If the Required Action and associated Completion Time of Condition C are not met, and Table 3.3.10-1 directs entry into Condition E, the plant must be brought to a MODE in which the requirements of this LCO do not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

F.1 Alternate means of monitoring containment area radiation have been developed and tested. These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. The HJTC-based reactor vessel water level instrumentation is one of three components of the inadequate core cooling instrumentation. The SMM instrumentation and CETs could be used to monitor inadequate core cooling. If these alternate means are used, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.7. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels.

SURVEILLANCE A Note at the beginning of the SRs specifies that the REQUIREMENTS following SRs apply to each PAM instrumentation Function in Table 3.3.10-1.

SR 3.3.10.1 Performance of the CHANNEL CHECK once every 31 days ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one indication channel to a similar parameter on other channels. It is based on the assumption that indication channels monitoring the same parameter should CALVERT CLIFFS - UNITS 1 & 2 B 3.3.10-15 Revision 16

a PAM Instrumentation B 3.3.10 BASES read approximately the same value. Significant deviations between the two indication channels could be an indication of excessive instrument drift in one of the channels or of something more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a qualitative assessment of the indication channel that considers indication channel uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.

If the channels are within the criteria, it is an indication that the channels are OPERABLE. If the channels are normally off-scale during times when surveillance testing is required, the CHANNEL CHECK will only verify that they are off-scale in the same direction. Off-scale low current loop channels are verified to be reading at the bottom of the range and not failed down-scale.

The Frequency of 31 days is based upon plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one indication channel of a given Function in any 31 day interval is a rare event. The CHANNEL CHECK supplements less formal, but more frequent, checks of channel during normal operational use of the displays associated with this LCO's required channels.

SR 3.3.10.2 Deleted.

SR 3.3.10.3 A CHANNEL CALIBRATION is performed every 24 months or approximately every refueling. CHANNEL CALIBRATION is a check of the indication channel including the sensor. The SR verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION of the CIV position indication channels will consist of verification that the position indication changes CALVERT CLIFFS - UNITS 1 & 2 B 3.3.10-16 Revision 16

PAM Instrumentation B 3.3.10 BASES from not-closed to closed when the valve is exercised to the isolation position as required by Technical Specification 5.5.8, Inservice Testing Program. The position switch is the sensor for the CIV position indication channels. A Note allows exclusion of neutron detectors, CETs, and reactor vessel level (HJTC) from the CHANNEL CALIBRATION.

The Frequency is based upon operating experience and consistency with the typical industry refueling cycle and is justified by an 24 month calibration interval for the determination of the magnitude of equipment drift.

REFERENCES 1. Letter from Mr. R. E. Denton (BGE) to NRC Document Control Desk, dated June 6, 1995, "License Amendment Request; Extension of Instrument Surveillance Intervals"

2. Letter from Mr. J. A. Tiernan (BGE) to NRC Document Control Desk, dated August 9, 1988, "Regulatory Guide 1.97 Review Update"

3. Regulatory Guide 1.97, "Instrumentation for Light-Water-Cooled Nuclear Power Plants To Assess Plant and Environs Conditions During and Following an Accident (Errata Published July 1981), December 1975

4. NUREG-0737, Supplement 1, Requirements for Emergency Response Capabilities (Generic Letter 82-33),

December 17, 1982

5. UFSAR, Chapter 7, "Instrumentation and Control" Revision 16 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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& 2 B 3.3.10-17 B 3.3.10-17 Revision 16

PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 17 Remove and Discard Insert List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 List of Revisions LOR-1 LOR-1 Technical Specification Bases Pages B 3.8.1-5 through B 3.8.1-30 B 3.8.1-5 through B 3.8.1-33

April 16, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 17 B 3.1.1-7 Rev. 2 B 3.1.8-5 Rev. 2 LEP-2 Rev. 17 B 3.1.2-1 Rev. 2 B 3.2.1-1 Rev. 2 LEP-3 Rev. 17 B 3.1.2-2 Rev. 2 B 3.2.1-2 Rev. 14 LEP-4 Rev. 17 B 3.1.2-3 Rev. 2 B 3.2.1-3 Rev. 14 LEP-5 Rev. 17 B 3.1.2-4 Rev. 2 B 3.2.1-4 Rev. 14 LOR-1 Rev. 17 B 3.1.2-5 Rev. 2 B 3.2.1-5 Rev. 14 i Rev. 2 B 3.1.2-6 Rev. 3 B 3.2.1-6 Rev. 14 ii Rev. 2 B 3.1.3-1 Rev. 2 B 3.2.1-7 Rev. 14 iii Rev. 16 B 3.1.3-2 Rev. 2 B 3.2.2-1 Rev. 2 iv Rev. 2 B 3.1.3-3 Rev. 2 B 3.2.2-2 Rev. 8 B 2.1.1-1 Rev. 2 B 3.1.3-4 Rev. 2 B 3.2.2-3 Rev. 14 B 2.1.1-2 Rev. 2 B 3.1.3-5 Rev. 2 B 3.2.2-4 Rev. 12 B 2.1.1-3 Rev. 2 B 3.1.4-1 Rev. 2 B 3.2.2-5 Rev. 12 B 2.1.1-4 Rev. 2 B 3.1.4-2 Rev. 2 B 3.2.2-6 Rev. 12 B 2.1.2-1 Rev. 2 B 3.1.4-3 Rev. 2 B 3.2.3-1 Rev. 2 B 2.1.2-2 Rev. 2 B 3.1.4-4 Rev. 2 B 3.2.3-2 Rev. 8 B 2.1.2-3 Rev. 2 B 3.1.4-5 Rev. 2 B 3.2.3-3 Rev. 14 B 2.1.2-4 Rev. 2 B 3.1.4-6 Rev. 2 B 3.2.3-4 Rev. 12 B 3.0-1 Rev. 2 B 3.1.4-7 Rev. 2 B 3.2.3-5 Rev. 12 B 3.0-2 Rev. 2 B 3.1.4-8 Rev. 2 B 3.2.4-1 Rev. 2 B 3.0-3 Rev. 2 B 3.1.4-9 Rev. 2 B 3.2.4-2 Rev. 8 B 3.0-4 Rev. 2 B 3.1.4-10 Rev. 2 B 3.2.4-3 Rev. 14 B 3.0-5 Rev. 13 B 3.1.5-1 Rev. 2 B 3.2.4-4 Rev. 8 B 3.0-6 Rev. 13 B 3.1.5-2 Rev. 2 B 3.2.4-5 Rev. 8 B 3.0-7 Rev. 13 B 3.1.5-3 Rev. 2 B 3.2.5-1 Rev. 2 B 3.0-8 Rev. 2 B 3.1.5-4 Rev. 2 B 3.2.5-2 Rev. 11 B 3.0-9 Rev. 2 B 3.1.5-5 Rev. 2 B 3.2.5-3 Rev. 14 B 3.0-10 Rev. 2 B 3.1.6-1 Rev. 2 B 3.2.5-4 Rev. 11 B 3.0-11 Rev. 2 B 3.1.6-2 Rev. 2 B 3.2.5-5 Rev. 11 B 3.0-12 Rev. 2 B 3.1.6-3 Rev. 2 B 3.2.5-6 Rev. 11 B 3.0-13 Rev. 2 B 3.1.6-4 Rev. 2 B 3.3.1-1 Rev. 2 B 3.0-14 Rev. 2 B 3.1.6-5 Rev. 2 B 3.3.1-2 Rev. 2 B 3.0-15 Rev. 13 B 3.1.6-6 Rev. 2 B 3.3.1-3 Rev. 2 B 3.0-16 Rev. 13 B 3.1.6-7 Rev. 2 B 3.3.1-4 Rev. 2 B 3.0-17 Rev. 13 B 3.1.7-1 Rev. 2 B 3.3.1-5 Rev. 2 B 3.0-18 Rev. 13 B 3.1.7-2 Rev. 2 B 3.3.1-6 Rev. 12 B 3.0-19 Rev. 13 B 3.1.7-3 Rev. 5 B 3.3.1-7 Rev. 12 B 3.1.1-1 Rev. 2 B 3.1.7-4 Rev. 2 B 3.3.1-8 Rev. 12 B 3.1.1-2 Rev. 2 B 3.1.7-5 Rev. 11 B 3.3.1-9 Rev. 12 B 3.1.1-3 Rev. 2 B 3.1.8-1 Rev. 2 B 3.3.1-10 Rev. 12 B 3.1.1-4 Rev. 2 B 3.1.8-2 Rev. 2 B 3.3.1-11 Rev. 5 B 3.1.1-5 Rev. 2 B 3.1.8-3 Rev. 2 B 3.3.1-12 Rev. 2 B 3.1.1-6 Rev. 2 B 3.1.8-4 Rev. 2 B 3.3.1-13 Rev. 12 LEM- Rev. 17

April 16, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.1-14 Rev. 11 B 3.3.3-12 Rev. 2 B 3.3.6-6 Rev. 2 B 3.3.1-15 Rev. 11 B 3.3.4-1 Rev. 2 B 3.3.6-7 Rev. 12 B 3.3.1-16 Rev. 11 B 3.3.4-2 Rev. 2 B 3.3.6-8 Rev. 8 B 3.3.1-17 Rev. 11 B 3.3.4-3 Rev. 2 B 3.3.7-1 Rev. 14 B 3.3.1-18 Rev. 13 B 3.3.4-4 Rev. 2 B 3.3.7-2 Rev. 2 B 3.3.1-19 Rev. 11 B 3.3.4-5 Rev. 2 B 3.3.7-3 Rev. 2 B 3.3.1-20 Rev. 11 B 3.3.4-6 Rev. 2 B 3.3.7-4 Rev. 2 B 3.3.1-21 Rev. 11 B 3.3.4-7 Rev. 2 B 3.3.7-5 Rev. 2 B 3.3.1-22 Rev. 11 B 3.3.4-8 Rev. 2 B 3.3.7-6 Rev. 2 B 3.3.1-23 Rev. 11 B 3.3.4-9 Rev. 2 B 3.3.7-7 Rev. 2 B 3.3.1-24 Rev. 11 B 3.3.4-10 Rev. 2 B 3.3.8-1 Rev. 8 B 3.3.1-25 Rev. 11 B 3.3.4-11 Rev. 2 B 3.3.8-2 Rev. 2 B 3.3.1-26 Rev. 11 B 3.3.4-12 Rev. 2 B 3.3.8-3 Rev. 2 B 3.3.1-27 Rev. 11 B 3.3.4-13 Rev. 2 B 3.3.8-4 Rev. 2 B 3.3.1-28 Rev. 11 B 3.3.4-14 Rev. 2 B 3.3.9-1 Rev. 2 B 3.3.1-29 Rev. 11 B 3.3.4-15 Rev. 2 B 3.3.9-2 Rev. 2 B 3.3.1-30 Rev. 11 B 3.3.4-16 Rev. 2 B 3.3.9-3 Rev. 2 B 3.3.1-31 Rev. 11 B 3.3.4-17 Rev. 5 B 3.3.9-4 Rev. 2 B 3.3.1-32 Rev. 11 B 3.3.4-18 Rev. 2 B 3.3.9-5 Rev. 2 B 3.3.1-33 Rev. 12 B 3.3.4-19 Rev. 2 B 3.3.9-6 Rev. 2 B 3.3.1-34 Rev. 12 B 3.3.4-20 Rev. 2 B 3.3.9-7 Rev. 2 B 3.3.1-35 Rev. 2 B 3.3.4-21 Rev. 2 B 3.3.9-8 Rev. 3 B 3.3.2-1 Rev. 2 B 3.3.4-22 Rev. 12 B 3.3.10-1 Rev. 2 B 3.3.2-2 Rev. 2 B 3.3.4-23 Rev. 12 B 3.3.10-2 Rev. 2 B 3.3.2-3 Rev. 2 B 3.3.5-1 Rev. 2 B 3.3.10-3 Rev. 14 B 3.3.2-4 Rev. 2 B 3.3.5-2 Rev. 2 B 3.3.10-4 Rev. 14 B 3.3.2-5 Rev. 2 B 3.3.5-3 Rev. 2 B 3.3.10-5 Rev. 14 B 3.3.2-6 Rev. 2 B 3.3.5-4 Rev. 2 B 3.3.10-6 Rev. 14 B 3.3.2-7 Rev. 2 B 3.3.5-5 Rev. 2 B 3.3.10-7 Rev. 16 B 3.3.2-8 Rev. 2 B 3.3.5-6 Rev. 2 B 3.3.10-8 Rev. 16 B 3.3.2-9 Rev. 2 B 3.3.5-7 Rev. 2 B 3.3.10-9 Rev. 16 B 3.3.2-10 Rev. 2 B 3.3.5-8 Rev. 2 B 3.3.10-10 Rev. 16 B 3.3.3-1 Rev. 2 B 3.3.5-9 Rev. 2 B 3.3.10-11 Rev. 16 B 3.3.3-2 Rev. 2 B 3.3.5-10 Rev. 2 B 3.3.10-12 Rev. 16 B 3.3.3-3 Rev. 2 B 3.3.5-11 Rev. 2 B 3.3.10-13 Rev. 16 B 3.3.3-4 Rev. 2 B 3.3.5-12 Rev. 2 B 3.3.10-14 Rev. 16 B 3.3.3-5 Rev. 2 B 3.3.5-13 Rev. 2 B 3.3.10-15 Rev. 16 B 3.3.3-6 Rev. 2 B 3.3.5-14 Rev. 2 B 3.3.10-16 Rev. 16 B 3.3.3-7 Rev. 2 B 3.3.6-1 Rev. 2 B 3.3.10-17 Rev. 16 B 3.3.3-8 Rev. 2 B 3.3.6-2 Rev. 2 B 3.3.11-1 Rev. 2 B 3.3.3-9 Rev. 2 B 3.3.6-3 Rev. 2 B 3.3.11-2 Rev. 2 B 3.3.3-10 Rev. 2 B 3.3.6-4 Rev. 13 B 3.3.11-3 Rev. 2 B 3.3.3-11 Rev. 2 B 3.3.6-5 Rev. 2 B 3.3.11-4 Rev. 2 LEP-2 Rev. 17

April 16, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.11-5 Rev. 2 B 3.4.9-3 Rev. 2 B 3.4.16-2 Rev. 2 B 3.3.12-1 Rev. 2 B 3.4.9-4 Rev. 2 B 3.4.16-3 Rev. 2 B 3.3.12-2 Rev. 2 B 3.4.9-5 Rev. 2 B 3.4.17-1 Rev. 2 B 3.3.12-3 Rev. 2 B 3.4.10-1 Rev. 2 B 3.4.17-2 Rev. 2 B 3.3.12-4 Rev. 2 B 3.4.10-2 Rev. 2 B 3.4.17-3 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4.1-2 Rev. 15 B 3.4.10-4 Rev. 2 B 3.5.1-2 Rev. 2 B 3.4.1-3 Rev. 15 B 3.4.11-1 Rev. 12 B 3.5.1-3 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-2 Rev. 12 B 3.5.1-4 Rev. 2 B 3.4.1-5 Rev. 15 B 3.4.11-3 Rev. 12 B 3.5.1-5 Rev. 2 B 3.4.2-1 Rev. 2 B 3.4.11-4 Rev. 12 B 3.5.1-6 Rev. 2 B 3.4.2-2 Rev. 2 B 3.4.11-5 Rev. 12 B 3.5.1-7 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B 3.4.3-2 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-3 Rev. 2 B 3.4.12-1 Rev. 2 B 3.5.2-1 Rev. 15 B 3.4.3-4 Rev. 2 B 3.4.12-2 Rev. 2 B 3.5.2-2 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-3 Rev. 2 B 3.5.2-3 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-4 Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-7 Rev. 2 B 3.4.12-5 Rev. 6 B 3.5.2-5 Rev. 15 B 3.4.3-8 Rev. 2 B 3.4.12-6 Rev. 2 B 3.5.2-6 Rev. 15 B 3.4.4-1 Rev. 2 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-2 Rev. 13 B 3.4.12-8 Rev. 2 B 3.5.2-8 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-9 Rev. 2 B 3.5.2-9 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.12-10 Rev. 2 B 3.5.3-1 Rev. 2 B 3.4.5-2 Rev. 8 B 3.4.12-11 Rev. 2 B 3.5.3-2 Rev. 2 B 3.4.5-3 Rev. 8 B 3.4.12-12 Rev. 2 B 3.5.3-3 Rev. 2 B 3.4.5-4 Rev. 8 B 3.4.12-13 Rev. 2 B 3.5.4-1 Rev. 2 B 3.4.6-1 Rev. 2 B 3.4.13-1 Rev. 2 B 3.5.4-2 Rev. 14 B 3.4.6-2 Rev. 8 B 3.4.13-2 Rev. 10 B 3.5.4-3 Rev. 2 B 3.4.6-3 Rev. 8 B 3.4.13-3 Rev. 2 B 3.5.4-4 Rev. 2 B 3.4.6-4 Rev. 8 B 3.4.13-4 Rev. 2 B 3.5.4-5 Rev. 2 B 3.4.6-5 Rev. 8 B 3.4.13-5 Rev. 5 B 3.5.4-6 Rev. 2 B 3.4.7-1 Rev. 2 B 3.4.14-1 Rev. 2 B 3.5.5-1 Rev. 2 B 3.4.7-2 Rev. 2 B 3.4.14-2 Rev. 2 B 3.5.5-2 Rev. 2 B 3.4.7-3 Rev. 8 B 3.4.14-3 Rev. 2 B 3.5.5-3 Rev. 2 B 3.4.7-4 Rev. 8 B 3.4.14-4 Rev. 2 B 3.5.5-4 Rev. 2 B 3.4.7-5 Rev. 8 B 3.4.14-5 Rev. 2 B 3.5.5-5 Rev. 2 B 3.4.7-6 Rev. 8 B 3.4.15-1 Rev. 2 B 3.6.1-1 Rev. 2 B 3.4.8-1 Rev. 2 B 3.4.15-2 Rev. 2 B 3.6.1-2 Rev. 2 B 3.4.8-2 Rev. 2 B 3.4.15-3 Rev. 2 B 3.6.1-3 Rev. 2 B 3.4.8-3 Rev. 2 B 3.4.15-4 Rev. 3 B 3.6.1-4 Rev. 12 B 3.4.9-1 Rev. 2 B 3.4.15-5 Rev. 2 B 3.6.1-5 Rev. 2 B 3.4.9-2 Rev. 2 B 3.4.16-1 Rev. 2 B 3.6.2-1 Rev. 2 LEP-3 Rev. 17

April 16, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.2-2 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-3 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.2-4 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.2-6 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-2 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.3-6 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.3-9 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-4 Rev. 2 B 3.7.15-1 Rev. 2 B 3.6.4-2 Rev. 2 B 3.7.5-1 Rev. 2 B 3.7.15-2 Rev. 13 B 3.6.4-3 Rev. 2 B 3.7.5-2 Rev. 2 B 3.7.15-3 Rev. 14 B 3.6.5-1 Rev. 2 B 3.7.5-3 Rev. 2 B 3.7.15-4 Rev. 2 B 3.6.5-2 Rev. 2 B 3.7.5-4 Rev. 2 B 3.8.1-1 Rev. 5 B 3.6.5-3 Rev. 3 B 3.7.5-5 Rev. 2 B 3.8.1-2 Rev. 12 B 3.6.6-1 Rev. 2 B 3.7.6-1 Rev. 5 B 3.8.1-3 Rev. 2 B 3.6.6-2 Rev. 2 B 3.7.6-2 Rev. 2 B 3.8.1-4 Rev. 10 B 3.6.6-3 Rev. 15 B 3.7.6-3 Rev. 5 B 3.8.1-5 Rev. 7 B 3.6.6-4 Rev. 15 B 3.7.6-4 Rev. 5 B 3.8.1-6 Rev. 17 B 3.6.6-5 Rev. 2 B 3.7.6-5 Rev. 5 B 3.8.1-7 Rev. 17 B 3.6.6-6 Rev. 2 B 3.7.7-1 Rev. 5 B 3.8.1-8 Rev. 17 B 3.6.6-7 Rev. 2 B 3.7.7-2 Rev. 12 B 3.8.1-9 Rev. 17 B 3.6.6-8 Rev. 2 B 3.7.7-3 Rev. 2 B 3.8.1-10 Rev. 17 B 3.6.6-9 Rev. 2 B 3.7.7-4 Rev. 12 B 3.8.1-11 Rev. 17 B 3.6.7 Deleted B 3.7.8-1 Rev. 8 B 3.8.1-12 Rev. 17 B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 B 3.8.1-13 Rev. 17 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 B 3.8.1-14 Rev. 17 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 B 3.8.1-15 Rev. 17 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 B 3.8.1-16 Rev. 17 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 B 3.8.1-17 Rev. 17 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 B 3.8.1-18 Rev. 17 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.8.1-19 Rev. 17 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.8.1-20 Rev. 17 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.8.1-21 Rev. 17 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.8.1-22 Rev. 17 LEP-4 Rev. 17

April 16, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-23 Rev. 17 B 3.8.6-5 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-24 Rev. 17 B 3.8.6-6 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-25 Rev. 17 B 3.8.6-7 Rev. 2 B 3.9.5-3 Rev. 14 B 3.8.1-26 Rev. 17 B 3.8.7-1 Rev. 2 B 3.9.5-4 Rev. 14 B 3.8.1-27 Rev. 17 B 3.8.7-2 Rev. 2 B 3.9.5-5 Rev. 14 B 3.8.1-28 Rev. 17 B 3.8.7-3 Rev. 2 B 3.9.6-1 Rev. 2 B 3.8.1-29 Rev. 17 B 3.8.7-4 Rev. 2 B 3.9.6-2 Rev. 2 B 3.8.1-30 Rev. 17 B 3.8.8-1 Rev. 2 B 3.9.6-3 Rev. 2 B 3.8.1-31 Rev. 17 B 3.8.8-2 Rev. 2 B 3.8.1-32 Rev. 17 B 3.8.8-3 Rev. 2 B 3.8.1-33 Rev. 17 B 3.8.9-1 Rev. 5 B 3.8.2-1 Rev. 2 B 3.8.9-2 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-3 Rev. 2 B 3.8.2-3 Rev. 10 B 3.8.9-4 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-5 Rev. 2 B 3.8.2-5 Rev. 5 B 3.8.9-6 Rev. 2 B 3.8.2-6 Rev. 5 B 3.8.9-7 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-5 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-3 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-4 Rev. 5 B 3.8.3-8 Rev. 3 B 3.8.10-5 Rev. 5 B 3.8.3-9 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-1 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-2 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-3 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-4 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-5 Rev. 2 B 3.9.2-2 Rev. 2 B 3.8.4-6 Rev. 2 B 3.9.2-3 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.4-8 Rev. 2 B 3.9.3-2 Rev. 13 B 3.8.4-9 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.5-2 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.5-3 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.5-4 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.6-1 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.6-2 Rev. 2 B 3.9.4-2 Rev. 2 B 3.8.6-3 Rev. 2 B 3.9.4-3 Rev. 11 B 3.8.6-4 Rev. 2 B 3.9.4-4 Rev. 13 LEP-5 Rev. 17

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 17 April 16, 2004 LOR-1 Rev. 17

AC Sources-Operating B 3.8.1 BASES required offsite circuits on a more frequent basis. Since the Required Action only specifies "perform," a failure of Surveillance Requirement (SR) 3.8.1.1 or SR 3.8.1.2 acceptance criteria does not result in a Required Action not met. However, if a second required circuit fails SR 3.8.1.1 or SR 3.8.1.2, the second offsite circuit is inoperable, and Condition D and/or G, as applicable, for the two offsite circuits inoperable, is entered.

A.2 Required Action A.2, which only applies if the train cannot be powered from an offsite source, is intended to provide assurance that an event coincident with a single failure of the associated DG will not result in a complete loss of safety function of critical redundant required features.

These features are powered from the redundant AC electrical power train(s). Single train systems may not be included.

The Completion Time for Required Action A.2 is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action, the Completion Time only begins on discovery that both:

a. The train has no offsite power supplying its loads; and

b. A required feature on another train is inoperable.

If at any time during the existence of Condition A (one required LCO 3.8.1.a offsite circuit inoperable) a redundant required feature subsequently becomes inoperable, this Completion Time begins to be tracked.

The Completion Time must be started if it is discovered that there is no offsite power to one train of the onsite Class 1E Electrical Power Distribution System coincident with one or more inoperable required support or supported features (or both) that are associated with the other train that has offsite power. Twenty-four hours is acceptable because it minimizes risk while allowing time for restoration before subjecting the unit to transients associated with shutdown.

Revision 17 CALVERT CLIFFS UNITS 1 CLIFFS - UNITS

& 2 I & 2 B 3.8.1-6 B 3.8.1-6 Revision 17

AC Sources-Operating B 3.8.1 BASES The remaining OPERABLE offsite circuits and DGs are adequate to supply electrical power to Train A and Train B of the onsite Class 1E Distribution System. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the component OPERABILITY of the redundant counterpart to the inoperable required feature.

Additionally, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

A.3 Consistent with Reference 6, operation may continue in Condition A for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

With one offsite circuit inoperable, the reliability of the offsite system is degraded, and the potential for a loss of offsite power is increased, with attendant potential for a challenge to the unit safety systems. In this Condition, however, the remaining OPERABLE offsite circuit and DGs are adequate to supply electrical power to the onsite Class 1E Distribution System.

The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

The second Completion Time for Required Action A.3 establishes a limit on the maximum time allowed for any combination of required AC power sources to be inoperable during any single contiguous occurrence of failing to meet LCO 3.8.1.a or LCO 3.8.1.b. If Condition A is entered while, for instance, an LCO 3.8.1.b DG is inoperable, and that DG is subsequently returned OPERABLE, the LCO may already have been not met for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This could lead to a total of 17 days, since initial failure to meet LCO 3.8.1.a or LCO 3.8.1.b, to restore the offsite circuit.

At this time, a LCO 3.8.1.b DG could again become inoperable, the circuit restored OPERABLE, and an additional 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (for a total of 20 days) allowed prior to complete restoration of LCOs 3.8.1.a and 3.8.1.b. The 17 day Completion Time provides a limit on the time allowed in a specified condition after discovery of failure to meet Revision 17 CLIFFS - UNITS CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES LCO 3.8.1.a or LCO 3.8.1.b. This limit is considered reasonable for situations in which Conditions A and B are entered concurrently. The "AND" connector between the 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and 17 day Completion Time means that both Completion Times apply simultaneously, and the more restrictive Completion Time must be met.

As in Required Action A.2, the Completion Time allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." This will result in establishing the "time zero" at the time that LCO 3.8.1.a or LCO 3.8.1.b was initially not met, instead of at the time Condition A was entered.

B.1 The 14 day Completion Time for Required Action B.5 is based on the OPERABILITY of both opposite-unit DGs and the availability of the OC DG. The OC DG is available to power the inoperable DG bus loads in the event of a station blackout or loss-of-offsite power. It is required to administratively verify both opposite-unit DGs OPERABLE and the OC DG available within one hour and to continue this action once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter until restoration of the required DG is accomplished. This verification provides assurance that both opposite-unit DGs and the OC DG are capable of supplying the onsite Class 1E AC Electrical Power Distribution System.

B.2 To ensure a highly reliable power source remains with an inoperable LCO 3.8.1.b DG, it is necessary to verify the availability of the offsite circuits on a more frequent basis. Since the Required Action only specifies "perform,"

a failure of SR 3.8.1.1 or SR 3.8.1.2 acceptance criteria does not result in a Required Action being not met.

However, if a circuit fails to pass SR 3.8.1.1 or SR 3.8.1.2, it is inoperable. Upon offsite circuit inoperability, additional Conditions and Required Actions must then be entered.

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AC Sources-Operating B 3.8.1 BASES B.3 Required Action B.3 is intended to provide assurance that a loss of offsite power, during the period that a LCO 3.8.1.b DG is inoperable, does not result in a complete loss of safety function of critical systems. These features are designed with redundant safety-related trains. Single train systems are not included. Redundant required feature failures consist of inoperable features with a train, redundant to the train that has an inoperable LCO 3.8.1.b DG.

The Completion Time for Required Action B.3 is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action, the Completion Time only begins on discovery that both:

a. An inoperable LCO 3.8.1.b DG exists; and

b. A required feature on another train is inoperable.

If at any time during the existence of this Condition (one LCO 3.8.1.b DG inoperable) a required feature subsequently becomes inoperable, this Completion Time begins to be tracked.

Discovering one required LCO 3.8.1.b DG inoperable coincident with one or more inoperable required support or supported features (or both) that are associated with the OPERABLE DGs, results in starting the Completion Time for the Required Action. Four hours from the discovery of these events existing concurrently, is acceptable because it minimizes risk while allowing time for restoration before subjecting the unit to transients associated with shutdown.

In this Condition, the remaining OPERABLE DGs and offsite circuits are adequate to supply electrical power to the onsite Class 1E Distribution System. Thus, on a component basis, single failure protection for the required feature's function may have been lost; however, function has not been lost. The four hour Completion Time takes into account the OPERABILITY of the redundant counterpart to the inoperable Revision 17 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES required feature. Additionally, the four hour Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

B.4.1 and B.4.2 Required Action B.4.1 provides an allowance to avoid unnecessary testing of OPERABLE DGs. If it can be determined that the cause of the inoperable DG does not exist on the OPERABLE DG(s), SR 3.8.1.3 does not have to be performed. If the cause of inoperability exists on other DG(s), the other DG(s) would be declared inoperable upon discovery and Condition E and/or I of LCO 3.8.1, as applicable, would be entered. Once the failure is repaired, the common cause failure no longer exists and Required Action B.4.1 is satisfied. If the cause of the initial inoperable DG cannot be confirmed not to exist on the remaining DG(s), performance of SR 3.8.1.3 suffices to provide assurance of continued OPERABILITY of the DG(s).

In the event the inoperable DG is restored to OPERABLE status prior to completing either B.4.1 or B.4.2, the corrective action program will continue to evaluate the common cause possibility. This continued evaluation, however, is no longer under the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months constraint imposed while in Condition B.

Consistent with Reference 7, 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is reasonable to confirm that the OPERABLE DG(s) is not affected by the same problem as the inoperable DG.

These Conditions (B.4.1 and B.4.2) do not address the availability of the OC DG.

B.5 Operation may continue in Condition B for a period that should not exceed 14 days.

Planned entry into this Required Action requires that a risk assessment be performed in accordance with a configuration risk management program (Reference 11). This ensures that a proceduralized probabilistic risk assessment-informed Revision 17 CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES process is in place that assesses the overall impact of plant maintenance on plant risk prior to entering this Required Action for planned activities.

In Condition B, the remaining OPERABLE DGs, available OC DG, and offsite circuits are adequate to supply electrical power to the onsite Class lE Distribution System. The 14 day Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

In addition to utilizing Calvert Cliffs Nuclear Power Plant's processes for evaluating risk, Reference 11, Calvert Cliffs will administratively limit DG OOS time to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for elective maintenance unless the following actions are completed:

a. Weather conditions will be evaluated prior to entering the extended DG Completion Time for elective maintenance. An extended DG Completion Time will not be entered for elective maintenance purposes if official weather forecasts are predicting severe conditions (tornado or thunderstorm warnings).

b. The condition of the offsite power supply will be evaluated prior to entering the extended DG Completion Time.

c. No elective maintenance will be performed in the switchyard, on the 4 kV Distribution System, or on the 13 kV Distribution System.

d. No maintenance or testing that affects the reliability of the train associated with the operable DG on the affected unit will be scheduled during the extended DG Completion Time. If any testing or maintenance activities, which affects the train reliability must be performed while the extended DG Completion Time is in effect, a 10 CFR 50.65(a)(4) evaluation will be performed.

e. Elective maintenance will not be performed on the alternate AC power source (OC DG). Personnel will be made aware of the dedication of the alternate AC source to the affected Unit.

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AC Sources-Operating B 3.8.1 BASES

f. Planned maintenance will not be performed on the Auxiliary Feedwater System.

g. The system dispatcher (System Operations and Maintenance Department) will be contacted prior to removing the DG from service and after it has been returned to service.

h. The operations crews will be briefed concerning the Unit activities, including compensatory measures established and the importance of promptly starting and aligning the alternate AC source (OC DG).

i. The on-shift operations crew will discuss and review the appropriate normal and emergency operating procedures prior to or shortly after assuming the watch for the first time after having scheduled days off while the extended DG Completion Time is in effect.

j. The condition of the grid will be evaluated prior to entering the extended DG 3.8.1 Condition B Completion Time for elective maintenance. An extended DG Completion Time will not be entered to perform elective maintenance when grid stress conditions are considered "High" per plant procedures. This will include conditions such as expected extreme summer temperatures and/or high demand.

The second Completion Time for Required Action B.5 establishes a limit on the maximum time allowed for any combination of required AC power sources to be inoperable during any single contiguous occurrence of failing to meet LCO 3.8.1.a or LCO 3.8.1.b. If Condition B is entered while, for instance, an LCO 3.8.1.a offsite circuit is inoperable and that circuit is subsequently returned OPERABLE, the LCO may already have not been met for up to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This could lead to a total of 17 days, since initial failure to meet LCO 3.8.1.a or LCO 3.8.1.b, to restore the DG. At this time, a LCO 3.8.1.a offsite circuit could again become inoperable, the DG restored OPERABLE, and an additional 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (for a total of 20 days) allowed prior to complete restoration of LCO 3.8.1.a and LCO 3.8.1.b. The 17 day Completion Time provides a limit on time allowed in a specified condition after discovery of failure to meet LCO 3.8.1.a or LCO 3.8.1.b. This limit is considered reasonable for situations in which Conditions A Revision 17 CALVERT CLIFFS CALVERT -

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AC Sources-Operating' B 3.8.1 BASES and B are entered concurrently. The "AND" connector between the 14 day and 17 day Completion Times means that both Completion Times apply simultaneously, and the more restrictive Completion Time must be met.

As in Required Action B.3, the Completion Time allows for an exception to the normal "time zero" for beginning the allowed time "clock." This will result in establishing the "time zero" at the time that LCO 3.8.1.a or LCO 3.8.1.b was initially not met, instead of at the time Condition B was entered.

C.1.1 and C.1.2 In Condition C with an opposite-unit DG inoperable and/or the OC DG unavailable, the remaining OPERABLE unit-specific DG and required qualified circuits are adequate to supply electrical power to the onsite Class lE Distribution System.

Consistent with Reference 6, operation may continue in Condition C for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

D.1 Pursuant to LCO 3.0.6, the Distribution System ACTIONS would not be entered even if all AC sources to it, were inoperable resulting in de-energization. Therefore, the Required Actions of Condition D are modified by a Note to indicate that when Condition D is entered with no AC source to any train, the Conditions and Required Actions for LCO 3.8.9, must be immediately entered. This allows Condition D to provide requirements for the loss of the LCO 3.8.1.c offsite circuit and DG without regard to whether a train is de-energized. Limiting Condition for Operation 3.8.9 provides the appropriate restrictions for a de-energized train.

To ensure a highly reliable power source remains with the one required LCO 3.8.1.c offsite circuit inoperable, it is necessary to verify the OPERABILITY of the remaining required offsite circuits on a more frequent basis. Since the Required Action only specifies "perform," a failure of B 3.8.1-13 Revision 17 CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES SR 3.8.1.1 or SR 3.8.1.2 acceptance criteria does not result in a Required Action not met. However, if a second required circuit fails SR 3.8.1.1 or SR 3.8.1.2, the second offsite circuit is inoperable, and Condition A and/or G, as applicable, for the two offsite circuits inoperable, is entered.

D.2 Required Action D.2, which only applies if the train cannot be powered from an offsite source, is intended to provide assurance that an event coincident with a single failure of the associated DG will not result in a complete loss of safety function for the CREVS, CRETS, or the H2 Analyzers.

The Completion Time for Required Action D.2 is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action, the Completion Time only begins on discovery that both:

a. The train has no offsite power supplying its loads; and

b. A train of CREVS, CRETS, or H2 Analyzer on the other train is inoperable.

If at any time during the existence of Condition D (one required LCO 3.8.1.c offsite circuit inoperable) a train of CREVS, CRETS, or H2 Analyzer becomes inoperable, this Completion Time begins to be tracked.

Discovering no offsite power to one train of the onsite Class 1E Electrical Power Distribution System coincident with one train of CREVS, CRETS or H, Analyzer that is associated with the other train that has offsite power, results in starting the Completion Times for the Required Action. Twenty-four hours is acceptable because it minimizes risk while allowing time for restoration before subjecting the unit to transients associated with shutdown.

The remaining OPERABLE offsite circuits and DGs are adequate to supply electrical power to Train A and Train B of the onsite Class lE Distribution System. The 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the component OPERABILITY of the Revision 17 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

& 2 1 & 2 B 3.8.1-14 B 3.8.1-14 Revision 17

AC Sources-Operating B 3.8.1 BASES redundant counterpart to the inoperable CREVS, CRETS, or H2 Analyzer. Additionally, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

D.3 Consistent with the time provided in ACTION A, operation may continue in Condition D for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . With one required LCO 3.8.1.c offsite circuit inoperable, the reliability of the offsite system is degraded, and the potential for a loss of offsite power is increased, with attendant potential for a challenge to the unit safety systems. In this Condition, however, the remaining OPERABLE offsite circuits and DGs are adequate to supply electrical power to the onsite Class 1E Distribution System.

If the LCO 3.8.1.c required offsite circuit cannot be restored to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the CREVS, CRETS, and H2 Analyzer associated with the offsite circuit must be declared inoperable. The ACTIONS associated with the CREVS, CRETS, and H2 Analyzer will ensure the appropriate actions are taken. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

E.1 The 14 day Completion Time for Required Action E.5 is based on the OPERABILITY of the other three safety-related DGs and the availability of the OC DG. The OC DG is available to power the inoperable DG bus loads in the event of a station blackout or loss-of-offsite power. It is required to administratively verify the three safety-related DGs OPERABLE and the OC DG available within one hour and to continue this action once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter until restoration of the required DG is accomplished. This verification provides assurance that the three safety-related DGs and the OC DG are capable of supplying the onsite Class lE AC Electrical Power Distribution System.

Revision 17 CALVERT CLIFFS UNITS 1 CLIFFS - UNITS I & 2

& 2 B 3.8.1-15 B 3.8.1-15 Revision 17

AC Sources-Operating B 3.8.1 BASES E.2 Pursuant to LCO 3.0.6, the Distribution System ACTIONS would not be entered even if all AC sources to it, were inoperable resulting in de-energization. Therefore, the Required Actions of Condition E are modified by a Note to indicate that when Condition E is entered with no AC source to any train, the Conditions and Required Actions for LCO 3.8.9 must be immediately entered. This allows Condition E to provide requirements for the loss of the LCO 3.8.1.c offsite circuit and DG without regard to whether a train is de-energized. Limiting Condition for Operation 3.8.9 provides the appropriate restrictions for a de-energized train.

To ensure a highly reliable power source remains with the one required LCO 3.8.1.c DG inoperable, it is necessary to verify the availability of the required offsite circuits on a more frequency basis. Since the Required Action only specifies "perform," a failure of SR 3.8.1.1 or SR 3.8.1.2 acceptance criteria does not result in a Required Action not met. However, if a circuit fails to pass SR 3.8.1.1 or SR 3.8.1.2, it is inoperable. Upon offsite circuit inoperability additional Conditions and Required Actions must then be entered.

E.3 Required Action E.3 is intended to provide assurance that a loss of offsite power, during the period the LCO 3.8.1.c DG is inoperable, does not result in a complete loss of safety function for the CREVS, CRETS, or the H2 Analyzers. The Completion Time is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock."

In this Required Action, the Completion Time only begins on discovery that both:

a. An inoperable LCO 3.8.1.c DG exists; and

b. A train of CREVS, CRETS, or H2 Analyzers on the other train is inoperable.

If at any time during the existence of this Condition (the LCO 3.8.1.c DG inoperable) a train of CREVS, CRETS, or H.

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AC Sources-Operating B 3.8.1 BASES Analyzer becomes inoperable, this Completion Time begins to be tracked.

Discovering the LCO 3.8.1.c DG inoperable coincident with one train of CREVS, CRETS, or H2 Analyzer that is associated with the one LCO 3.8.1.b DG results in starting the Completion Time for the Required Action. Four hours from the discovery of these events existing concurrently, is acceptable because it minimizes risk while allowing time for restoration before subjecting the unit to transients associated with shutdown.

In this Condition, the remaining OPERABLE DGs and offsite circuits are adequate to supply electrical power to the onsite Class 1E Distribution System. Thus, on a component basis, single failure protection for the CREVS, CRETS, or H2 Analyzer may have been lost; however, function has not been lost. The four hour Completion Time also takes into account the capacity and capability of the remaining CREVS, CRETS, and H2 Analyzer train, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

E.4.1 and E.4.2 Required Action E.4.1 provides an allowance to avoid unnecessary testing of OPERABLE DGs. If it can be determined that the cause of the inoperable DG does not exist on the OPERABLE DG(s), SR 3.8.1.3 does not have to be performed. If the cause of inoperability exists on other DG(s), the other DG(s) would be declared inoperable upon discovery and Condition B and/or I of LCO 3.8.1, as applicable, would be entered. Once the failure is repaired, the common cause failure no longer exists and Required Action E.4.1 is satisfied. If the cause of the initial inoperable DG cannot be confirmed not to exist on the remaining DG(s), performance of SR 3.8.1.3 suffices to provide assurance of continued OPERABILITY of the DG(s).

In the event the inoperable DG is restored to OPERABLE status prior to completing either E.4.1 or E.4.2, the corrective action program will continue to evaluate the common cause possibility. This continued evaluation, however, is no longer under the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months constraint imposed while in Condition E.

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AC Sources-Operating B 3.8.1 BASES Consistent with Reference 6, 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is reasonable to confirm that the OPERABLE DG(s) is not affected by the same problem as the inoperable DG.

These Conditions (E.4.1 and E.4.2) do not address the availability of the OC DG.

E.5 Consistent with the time provided in ACTION B, operation may continue in Condition E for a period that should not exceed 14 days. In Condition E, the remaining OPERABLE DGs, available OC DG, and offsite power circuits are adequate to supply electrical power to the Class lE Distribution System.

If the LCO 3.8.1.c DG cannot be restored to OPERABLE status within 14 days the CREVS, CRETS, and H2 Analyzer associated with this DG must be declared inoperable. The Actions associated with the CREVS, CRETS, and H2 Analyzer will ensure the appropriate Actions are taken.

The 14 day Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

F.1.1 and F.1.2 In Condition F, with an additional safety-related DG inoperable or the OC DG unavailable, the remaining OPERABLE DG and required qualified circuits are adequate to supply electrical power to the onsite Class 1E Distribution System.

Consistent with Reference 6, operation may continue in Condition F for a period that should not exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

F.1.3 If the LCO 3.8.1.c DG cannot be restored to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months the CREVS, CRETS, and H2 Analyzer associated with this DG must be declared inoperable. The Required CALVERT CLIFFS - UNITS 1 & 2 B 3.8.1-18 Revision 17

AC Sources-Operating B 3.8.1 BASES Actions associated with the CREVS and CRETS will ensure that the appropriate actions are taken.

The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

G.1 and G.2 Condition G is entered when both offsite circuits required by LCO 3.8.1.a are inoperable, or when the offsite circuit required by LCO 3.8.1.c and one offsite circuit required by LCO 3.8.1.a are concurrently inoperable, if the LCO 3.8.1.a offsite circuit is credited with providing power to the CREVS, CRETS, and H2 Analyzer.

Required Action G.1 is intended to provide assurance that an event with a coincident single failure will not result in a complete loss of redundant required safety functions. The Completion Time for this failure of redundant required features is reduced to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from that allowed for one train without offsite power (Required Action A.2). The rationale for the reduction to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is that Reference 6 allows a Completion Time of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for two required offsite circuits inoperable, based upon the assumption that two complete safety trains are OPERABLE. When a concurrent redundant required feature failure exists, this assumption is not the case, and a shorter Completion Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is appropriate. These features are powered from redundant AC safety trains. Single train features are not included in the list.

The Completion Time for Required Action G.1 is intended to allow the operator time to evaluate and repair any discovered inoperabilities. This Completion Time also allows for an exception to the normal "time zero" for beginning the allowed outage time "clock." In this Required Action, the Completion Time only begins on discovery that both:

a. Two required offsite circuits are inoperable; and

b. A required feature is inoperable.

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AC Sources-Operating B 3.8.1 BASES If at any time during the existence of Condition G (e.g., two required LCO 3.8.1.a offsite circuits inoperable) and a required feature becomes inoperable, this Completion Time begins to be tracked.

Consistent with Reference 6, operation may continue in Condition G for a period that should not exceed 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

This level of degradation means that the offsite electrical power system does not have the capability to effect a safe shutdown and to mitigate the effects of an accident; however, the onsite AC sources have not been degraded. This level of degradation could correspond to a total loss of the immediately accessible offsite power sources.

Because of the normally high availability of the offsite sources, this level of degradation may appear to be more severe than other combinations of two AC sources inoperable that involve one or more DGs inoperable. However, two factors tend to decrease the severity of this level of degradation:

a. The configuration of the redundant AC electrical power system that remains available is not susceptible to a single bus or switching failure; and

b. The time required to detect and restore an unavailable offsite power source is generally much less than that required to detect and restore an unavailable onsite AC source.

With two of the required offsite circuits inoperable, sufficient onsite AC sources are available to maintain the unit in a safe shutdown condition in the event of a DBA or transient. In fact, a simultaneous loss of offsite AC sources, a loss of coolant accident, and a worst case single failure were postulated as a part of the design basis in the safety analysis. Thus, the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Completion Time provides a period of time to effect restoration of one of the offsite circuits commensurate with the importance of maintaining an AC electrical power system capable of meeting its design criteria.

Consistent with Reference 6, with the available offsite AC sources two less than required by the LCO, operation may Revision 17 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES continue for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . If two offsite sources are restored within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , unrestricted operation may continue. If only one offsite source is restored within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , power operation continues in accordance with Condition A or D, as applicable.

H.1 and H.2 Pursuant to LCO 3.0.6, the Distribution System ACTIONS would not be entered even if all AC sources to it were inoperable resulting in de-energization. Therefore, the Required Actions of Condition H are modified by a Note to indicate that when Condition H is entered with no AC source to any train, the Conditions and Required Actions for LCO 3.8.9, must be immediately entered. This allows Condition H to provide requirements for the loss of one required LCO 3.8.1.a offsite circuit and one LCO 3.8.1.b DG without regard to whether a train is de-energized. Limiting Condition for Operation 3.8.9 provides the appropriate restrictions for a de-energized train.

Consistent with Reference 6, operation may continue in Condition H for a period that should not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

In Condition H, individual redundancy is lost in both the offsite electrical power system and the onsite AC electrical power system. Since power system redundancy is provided by two diverse sources of power, however, the reliability of the power systems in this Condition may appear higher than that in Condition G (loss of two required offsite circuits). l This difference in reliability is offset by the susceptibility of this power system configuration to a single bus or switching failure. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Completion Time takes into account the capacity and capability of the remaining AC sources, a reasonable time for repairs, and the low probability of a DBA occurring during this period.

I.1 With two LCO 3.8.1.b DGs inoperable, there are no remaining standby AC sources to provide power to most of the ESF systems. With one LCO 3.8.1.c DG inoperable and the LCO 3.8.1.b DG that provides power to the CREVS, CRETS, and H2 Analyzer inoperable, there are no remaining standby AC B 3.8.1-21 Revision 17 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS 1&& 2 2 B 3.8.1-21 Revision 17

AC Sources-Operating B 3.8.1 BASES sources to the CREVS, CRETS, and H2 Analyzers. Thus, with an assumed loss of offsite electrical power, insufficient standby AC sources are available to power the minimum required ESF functions. Since the offsite electrical power system is the only source of AC power for this level of degradation, the risk associated with continued operation for a short time could be less than that associated with an immediate controlled shutdown (the immediate shutdown could cause grid instability, which could result in a total loss of AC power). Since any inadvertent generator trip could also result in a total loss of offsite AC power, however, the time allowed for continued operation is severely restricted. The intent here is to avoid the risk associated with an immediate controlled shutdown and to minimize the risk associated with this level of degradation.

Consistent with Reference 6, with both LCO 3.8.1.b DGs inoperable, or with the LCO 3.8.1.b DG that provides power to the CREVS, CRETS, and H2 Analyzer and the LCO 3.8.1.c DG inoperable, operation may continue for a period that should not exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

J.1 and J.2 If any Required Action and associated Completion Time of Conditions A, B.2, B.3, B.4.1, B.4.2, .B.5, C, E.2, E.3, E.4.1, E.4.2, E.5, F, G, H, or I are not met, the unit must be brought to a MODE in which the LCO does not apply. To achieve this status, the unit must be brought to at least MODE 3 within six hours and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.

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AC Sources-Operating B 3.8.1 BASES K.1 Condition K corresponds to a level of degradation in which all redundancy in LCO 3.8.1.a and LCO 3.8.1.b AC electrical power supplies has been lost. At this severely degraded level, any further losses in the AC electrical power system will cause a loss of function. Therefore, no additional time is justified for continued operation. The unit is required by LCO 3.0.3 to commence a controlled shutdown.

SURVEILLANCE The AC sources are designed to permit inspection and REQUIREMENTS testing of all important areas and features, especially those that have a standby function, in accordance with Reference 1, GDC 18. Periodic component tests are supplemented by extensive functional tests during refueling outages (under simulated accident conditions). The SRs for demonstrating the OPERABILITY of the DGs are consistent with the recommendations of Reference 3, or Reference 4, and Reference 8.

When the SRs discussed herein specify voltage and frequency tolerances, the following is applicable. The minimum transient output voltage of 3740 V is 90% of the nominal 4160 V output voltage. This value allows for voltage drop to the terminals of 4000 V motors whose minimum operating voltage is specified as 90% or 3600 V. The specified maximum output voltage of 4400 V is equal to the maximum operating voltage specified for 4000 V motors. It ensures that for a lightly loaded distribution system, the voltage at the terminals of 4000 V is no more than the maximum rated operating voltages. The specified minimum and maximum frequencies of the DG are 58.8 Hz and 61.2 Hz, respectively.

These values are equal to +/- 2% of the 60 Hz nominal frequency and are the recommendations given in Reference 3.

The SRs are modified by a Note which states that SR 3.8.1.1 through SR 3.8.1.15 are applicable to LCO 3.8.1.a and LCO 3.8.1.b AC Sources. The Note also states that SR 3.8.1.16 is applicable to LCO 3.8.1.c AC sources. This Note clarifies that not all of the SRs are applicable to all the components described in the LCO.

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AC Sources-Operating B 3.8.1 BASES SR 3.8.1.1 and SR 3.8.1.2 These SRs assure proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power.

The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to their preferred power source, and that appropriate independence of offsite circuits is maintained.

The Frequency of once within one hour after substitution for a 500 kV circuit and every eight hours thereafter, for SR 3.8.1.1 was established to ensure that the breaker alignment for the SMECO circuit (which does not have Control Room indication) is in its correct position although breaker position is unlikely to change. The seven day Frequency for SR 3.8.1.2 is adequate since the 500 kV circuit breaker position is not likely to change without the operator being aware of it and because its status is displayed in the Control Room.

Surveillance Requirement 3.8.1.1 is modified by a Note which states that this SR is only required when SMECO is being credited for an offsite source. This SR will prevent unnecessary testing on an uncredited circuit.

SR 3.8.1.3 and SR 3.8.1.9 These SRs help to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and to maintain the unit in a safe shutdown condition.

To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs are modified by a Note (Note 2 for SR 3.8.1.3) to indicate that all DG starts for these surveillance tests may be preceded by an engine prelube period and followed by a warmup period prior to loading by an engine prelube period.

For the purposes of SR 3.8.1.9 testing, the DGs are required to start from standby conditions only for SR 3.8.1.9.

Standby conditions for a DG mean the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations.

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- AC Sources-Operating B 3.8.1 BASES In order to reduce stress and mechanical wear on diesel engines, the DG manufacturers recommend a modified start in which the starting speed of DGs is limited, warmup is limited to this lower speed, and the DGs are gradually accelerated to synchronous speed prior to loading. This is the intent of Note 3, which is only applicable when such modified start procedures are recommended by the manufacturer.

Surveillance Requirement 3.8.1.9 requires that, at a 184 day Frequency, the DG starts from standby conditions and achieves required voltage and frequency within 10 seconds.

The minimum voltage and frequency stated in the SR are those necessary to ensure the DG can accept DBA loading while maintaining acceptable voltage and frequency levels. The 10 second start requirement supports the assumptions of the design basis loss of coolant accident analysis in Reference 2, Chapter 14.

Since SR 3.8.1.9 requires a 10 second start, it is more restrictive than SR 3.8.1.3, and it may be performed in lieu of SR 3.8.1.3.

The 31 day Frequency for SR 3.8.1.3 is consistent with Reference 4 and Reference 3. The 184 day Frequency for SR 3.8.1.9 is a reduction in cold testing consistent with Reference 7. This Frequency provides adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.

SR 3.8.1.4 This SR verifies that the DGs are capable of synchronizing with the offsite electrical system and accepting loads greater than or equal to 4000 kW for No. 1A DG and greater than or equal to 90% of the continuous duty rating for the remaining DGs. The 90% minimum load limit is consistent with Reference 3 and is acceptable because testing of these DGs at post-accident load values is performed by SR 3.8.1.11. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.

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AC Sources-Operating B 3.8.1 BASES Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between 0.8 lagging and 1.0. The 0.8 value is the design rating of the machine, while 1.0 is an operational limitation. The 31-day Frequency for this SR is consistent with Reference 3.

This SR is modified by four Notes. Note 1 indicates that the diesel engine runs for this surveillance test may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized. Note 2 states that momentary transients because of changing bus loads do not invalidate this test. Note 3 indicates that this surveillance test shall be conducted on only one DG at a time in order to prevent routinely paralleling multiple DGs and to minimize the potential for effects from offsite circuit or grid perturbations. Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance.

SR 3.8.1.5 This SR provides verification that the level of fuel oil in the day tank is at or above the level at which fuel oil is automatically added. The level required by the SR is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of one hour of DG operation at full load plus 10%.

The 31-day Frequency is adequate to assure that a sufficient supply of fuel oil is available, since low level alarms are provided, and unit operators would be aware of any large uses of fuel oil during this period.

SR 3.8.1.6 Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Removal of water from the fuel oil day tanks once every 31 days eliminates the necessary environment for bacterial survival. This is the most effective means of controlling microbiological fouling.

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AC Sources-Operating B 3.8.1 BASES In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and from breakdown of the fuel oil by bacteria. Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight integrity of the fuel oil system. The SR Frequencies are consistent with Reference 8. This SR is for preventive maintenance. The presence of water does not necessarily represent failure of this SR provided the accumulated water is removed during the performance of this surveillance test.

SR 3.8.1.7 This SR demonstrates that one fuel oil transfer pump operates and transfers fuel oil from its associated storage tank to its associated day tank. This is required to support continuous operation of standby power sources. This SR provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERABLE.

The Frequency for this SR is 31 days. The 31-day Frequency corresponds to the design of the fuel transfer system. The design of fuel transfer systems is such that pumps will operate automatically or must be started manually in order to maintain an adequate volume of fuel oil in the day tanks during or following DG testing. In such a case, a 31-day Frequency is appropriate.

SR 3.8.1.8 Under accident and loss of offsite power conditions loads are sequentially connected to the bus by the automatic load sequencer (this SR verifies steps 1 through 5). The sequencing logic controls the permissive and closing signals to breakers to prevent overloading of the DGs due to high motor starting currents. The 10% load sequence time interval tolerance ensures that sufficient time exists for the DG to restore frequency and voltage prior to applying the next load, and that safety analysis assumptions 3.8.1-27 B 3.8.1-27 Revision 17 CLIFFS - UNITS CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES regarding ESF equipment time delays are not violated. The UFSAR provides a summary of the automatic loading of ESF buses.

The Frequency of 31 days is consistent with DG monthly testing and is sufficient to ensure the load sequencer operation as required.

SR 3.8.1.9 See SR 3.8.1.3.

SR 3.8.1.10 Transfer of each 4.16 kV ESF bus power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of the alternate circuit distribution network to power the shutdown loads. The 24 month Frequency of the Surveillance is based on engineering judgment, taking into consideration the unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.

Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency.

Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

SR 3.8.1.11 This SR provides verification that the DG can be operated at a load greater than predicted accident loads for at least 60 minutes once per 24 months. Operation at the greater than calculated accident loads will clearly demonstrate the ability of the DGs to perform their safety function. In order to ensure that the DG is tested under load conditions that are as close to design conditions as possible, testing must be performed using a DG load greater than or equal to calculated accident load and using a power factor < 0.85.

This power factor is chosen to be representative of the actual design basis inductive loading that the DG could experience. In addition, the post-accident load for No. 1A DG is significantly lower than the continuous rating of No. 1A DG. To ensure No. IA DG performance is not degraded, routine monitoring of engine parameters should be performed CALVERT CLIFFS - UNITS 1 & 2 B 3.8.1-28 Revision 17

AC Sources-Operating B 3.8.1 BASES during the performance of this SR for No. 1A DG (Reference 9).

This SR is modified by a Note which states that momentary transients due to changing bus loads do not invalidate this test. Similarly, momentary power factor transients above the limit will not invalidate the test. The 24 month Frequency is adequate to ensure DG OPERABILITY and it is consistent with the refueling interval.

SR 3.8.1.12 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 SR demonstrates the DG load response characteristics. This SR is accomplished by tripping the DG output breaker with the DG carrying greater than or equal to its associated single largest post-accident load while paralleled to offsite power.

Consistent with References 10, 3, and 4, 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.

The 24 month Frequency is consistent with the Reference 2, Chapter 8.

SR 3.8.1.13 This SR demonstrates that DG non-critical protective functions are bypassed on a required actuation signal. This SR is accomplished by verifying the bypass contact changes to the correct state which prevents actuation of the non-critical function. The non-critical protective functions are consistent with References 3 and 4, and Institute of Electrical and Electronic Engineers (IEEE)-387 and are listed in Reference 2, Chapter 8. Verifying the non-critical trips are bypassed will ensure DG operation during a required actuation. The non-critical trips are bypassed during DBAs and provide an alarm on an abnormal engine Revision 17 CALVERT CLIFFS -

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AC Sources-Operating B 3.8.1 BASES condition. A failure of the electronic governor results in the diesel generator operating in hydraulic mode. This alarm provides the operator with sufficient time to react appropriately. The DG availability to mitigate the DBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG.

The 24 month Frequency is based on engineering judgment, taking into consideration unit conditions required to perform the surveillance test, and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. This Frequency is consistent with Reference 2, Chapter 8.

SR 3.8.1.14 This SR ensures that the manual synchronization and load transfer from the DG to the offsite source can be made and that the DG can be returned to ready-to-load status when offsite power is restored. The DG is considered to be in ready-to-load status when the DG is at rated speed and voltage, the output breaker is open and can receive an auto-close signal on bus undervoltage, and the load sequence timers are reset.

The Frequency of 24 months takes into consideration unit conditions required to perform the surveillance test.

SR 3.8.1.15 In the event of a DBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to ESF systems so that the fuel, RCS, and containment design limits are not exceeded.

This SR demonstrates the DG operation during a loss of offsite power actuation test signal in conjunction with an ESF (i.e., safety injection) actuation signal. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG Revision 17 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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- AC Sources-Operating B 3.8.1 BASES system to perform these functions is acceptable. This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.

It is not necessary to energize loads which are dependent on temperature to load (i.e., heat tracing, switchgear HVAC compressor, computer room HVAC compressor). Also, it is acceptable to transfer the instrument AC bus to the non tested train to maintain safe operation of the plant during testing. Loads (both permanent and auto connect) < 15 kW do not require loading onto the diesel since these are insignificant loads for the DG.

Permanently- and auto-connected loads to the emergency diesel generators are defined as follows:

Permanently-Connected Load - Equipment that is not shed by an undervoltage or safety injection actuation signal and is normally operating, i.e., loads that are manually started, selected, or process signal controlled are not considered permanently-connected loads.

Auto-Connected Loads - Emergency equipment required for mitigating the events described in UFSAR Chapter 14 that are energized by loss-of-coolant incident sequencer actions after step zero and within the first minute of emergency diesel generator operation after the initiation of an undervoltage signal.

The Frequency of 24 months takes into consideration unit conditions required to perform the surveillance test and is intended to be consistent with an expected fuel cycle length of 24 months.

This SR is modified by a Note. The reason for the Note is to minimize mechanical wear and stress on the DGs during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations for DGs.

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AC Sources-Operating B 3.8.1 BASES SR 3.8.1.16 This SR lists the SRs that are applicable to the LCO 3.8.1.c (SRs 3.8.1.1, 3.8.1.2, 3.8.1.3, 3.8.1.5, 3.8.1.6, and 3.8.1.7). Performance of any SR for the LCO 3.8.1.c will satisfy both Unit 1 and Unit 2 requirements for those SRs.

Surveillance Requirements 3.8.1.4, 3.8.1.8, 3.8.1.9, 3.8.1.10, 3.8.1.11, 3.8.1.12, 3.8.1.13, 3.8.1.14, and 3.8.1.15, are not required to be performed for the LCO 3.8.1.c. Surveillance Requirement 3.8.1.10 is not required because this SR verifies manual transfer of AC power sources from the normal offsite circuit to the alternate offsite circuit, but only one qualified offsite circuit is necessary for the LCO 3.8.1.c. Surveillance Requirements 3.8.1.4, 3.8.1.11, and 3.1.8.12 are not required because they are tests that deal with loads.

Surveillance Requirement 3.8.1.8 verifies the interval between sequenced loads. Surveillance Requirement 3.8.1.14 verifies the proper sequencing with offsite power.

Surveillance Requirement 3.8.1.9 verifies that the DG starts within 10 seconds. These SRs are not required because they do not support the function of the LCO 3.8.1.c to provide power to the CREVS, CRETS, and H2 Analyzer. Surveillance Requirements 3.8.1.13 and 3.8.1.15 are not required to be performed because these SRs verify the emergency loads are actuated on an ESFAS signal for the Unit in which the test is being performed. The LCO 3.8.1.c DG will not start on an ESFAS signal for this Unit.

REFERENCES 1. 10 CFR Part 50, Appendix A, "General Design Criteria for Nuclear Power Plants"

2. UFSAR

3. Regulatory Guide 1.9, Revision 3, "Selection, Design, Qualification, and Testing of Emergency Diesel Generator Units Used as Class 1E Onsite Electric Power Systems at Nuclear Power Plants," July 1993

4. Safety Guide 9, Revision 0, March 1971

5. NRC Safety Evaluation for Amendment Nos. 19 and 5 for Calvert Cliffs Nuclear Power Plant Unit Nos. 1 and 2, dated January 14, 1977

6. Regulatory Guide 1.93, Revision 0, "Availability of Electric Power Sources," December 1974 CALVERT CLIFFS - UNITS 1 & 2 B 3.8.1-32 Revision 17

AC Sources-Operating B 3.8.1 BASES

7. Generic Letter 84-15, Proposed Staff Actions to Improve and Maintain Diesel Generator Reliability, July 2, 1984

8. Regulatory Guide 1.137, Revision 1, "Fuel-Oil Systems for Standby Diesel Generators," October 1979

9. Letter from Mr. D. G. McDonald, Jr. (NRC) to Mr. C. H. Cruse (BGE), dated April 2, 1996, Issuance of Amendments for Calvert Cliffs Nuclear Power Plant, Unit 1 (TAC No. M94030) and Unit 2 (TAC No. M94031)

10. IEEE Standard 308-1991, "IEEE Standard Criteria for Class 1E Power Systems for Nuclear Power Generating Stations"

11. NO-1-117, Integrated Risk Management Revision 17 CLIFFS - UNITS CALVERT CLIFFS -

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PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 18 Remove and Discard Insert List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 List of Revisions LOR-1 LOR-1 Technical Specification Bases Pages B 3.6.6-9 B 3.6.6-9 and B 3.6.6-10

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 17 April 16, 2004 18 May 5, 2004 LOR-1 Rev. 18

May 5, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 18 B 3.1.1-7 Rev. 2 B 3.1.8-5 Rev. 2 LEP-2 Rev. 18 B 3.1.2-1 Rev. 2 B 3.2.1-1 Rev. 2 LEP-3 Rev. 18 B 3.1.2-2 Rev. 2 B 3.2.1-2 Rev. 14 LEP-4 Rev. 18 B 3.1.2-3 Rev. 2 B 3.2.1-3 Rev. 14 LEP-S Rev. 18 B 3.1.2-4 Rev. 2 B 3.2.1-4 Rev. 14 LOR-1 Rev. 18 B 3.1.2-5 Rev. 2 B 3.2.1-5 Rev. 14 i Rev. 2 B 3.1.2-6 Rev. 3 B 3.2.1-6 Rev. 14 ii Rev. 2 B 3.1.3-1 Rev. 2 B 3.2.1-7 Rev. 14 iii Rev. 16 B 3.1.3-2 Rev. 2 B 3.2.2-1 Rev. 2 iv Rev. 2 B 3.1.3-3 Rev. 2 B 3.2.2-2 Rev. 8 B 2.1.1-1 Rev. 2 B 3.1.3-4 Rev. 2 B 3.2.2-3 Rev. 14 B 2.1.1-2 Rev. 2 B 3.1.3-5 Rev. 2 B 3.2.2-4 Rev. 12 B 2.1.1-3 Rev. 2 B 3.1.4-1 Rev. 2 B 3.2.2-5 Rev. 12 B 2.1.1-4 Rev. 2 B 3.1.4-2 Rev. 2 B 3.2.2-6 Rev. 12 B 2.1.2-1 Rev. 2 B 3.1.4-3 Rev. 2 B 3.2.3-1 Rev. 2 B 2.1.2-2 Rev. 2 B 3.1.4-4 Rev. 2 B 3.2.3-2 Rev. 8 B 2.1.2-3 Rev. 2 B 3.1.4-5 Rev. 2 B 3.2.3-3 Rev. 14 B 2.1.2-4 Rev. 2 B 3.1.4-6 Rev. 2 B 3.2.3-4 Rev. 12 B 3.0-1 Rev. 2 B 3.1.4-7 Rev. 2 B 3.2.3-5 Rev. 12 B 3.0-2 Rev. 2 B 3.1.4-8 Rev. 2 B 3.2.4-1 Rev. 2 B 3.0-3 Rev. 2 B 3.1.4-9 Rev. 2 B 3.2.4-2 Rev. 8 B 3.0-4 Rev. 2 B 3.1.4-10 Rev. 2 B 3.2.4-3 Rev. 14 B 3.0-5 Rev. 13 B 3.1.5-1 Rev. 2 B 3.2.4-4 Rev. 8 B 3.0-6 Rev. 13 B 3.1.5-2 Rev. 2 B 3.2.4-5 Rev. 8 B 3.0-7 Rev. 13 B 3.1.5-3 Rev. 2 B 3.2.5-1 Rev. 2 B 3.0-8 Rev. 2 B 3.1.5-4 Rev. 2 B 3.2.5-2 Rev. 11 B 3.0-9 Rev. 2 B 3.1.5-5 Rev. 2 B 3.2.5-3 Rev. 14 B 3.0-10 Rev. 2 B 3.1.6-1 Rev. 2 B 3.2.5-4 Rev. 11 B 3.0-11 Rev. 2 B 3.1.6-2 Rev. 2 B 3.2.5-5 Rev. 11 B 3.0-12 Rev. 2 B 3.1.6-3 Rev. 2 B 3.2.5-6 Rev. 11 B 3.0-13 Rev. 2 B 3.1.6-4 Rev. 2 B 3.3.1-1 Rev. 2 B 3.0-14 Rev. 2 B 3.1.6-5 Rev. 2 B 3.3.1-2 Rev. 2 B 3.0-15 Rev. 13 B 3.1.6-6 Rev. 2 B 3.3.1-3 Rev. 2 B 3.0-16 Rev. 13 B 3.1.6-7 Rev. 2 B 3.3.1-4 Rev. 2 B 3.0-17 Rev. 13 B 3.1.7-1 Rev. 2 B 3.3.1-5 Rev. 2 B 3.0-18 Rev. 13 B 3.1.7-2 Rev. 2 B 3.3.1-6 Rev. 12 B 3.0-19 Rev. 13 B 3.1.7-3 Rev. 5 B 3.3.1-7 Rev. 12 B 3.1.1-1 Rev. 2 B 3.1.7-4 Rev. 2 B 3.3.1-8 Rev. 12 B 3.1.1-2 Rev. 2 B 3.1.7-5 Rev. 11 B 3.3.1-9 Rev. 12 B 3.1.1-3 Rev. 2 B 3.1.8-1 Rev. 2 B 3.3.1-10 Rev. 12 B 3.1.1-4 Rev. 2 B 3.1.8-2 Rev. 2 B 3.3.1-11 Rev. 5 B 3.1.1-5 Rev. 2 B 3.1.8-3 Rev. 2 B 3.3.1-12 Rev. 2 B 3.1.1-6 Rev. 2 B 3.1.8-4 Rev. 2 B 3.3.1-13 Rev. 12 LEP-1 Rev. 18

May 5, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.1-14 Rev. 11 B 3.3.3-12 Rev. 2 B 3.3.6-6 Rev. 2 B 3.3.1-15 Rev. 11 B 3.3.4-1 Rev. 2 B 3.3.6-7 Rev. 12 B 3.3.1-16 Rev. 11 B 3.3.4-2 Rev. 2 B 3.3.6-8 Rev. 8 B 3.3.1-17 Rev. 11 B 3.3.4-3 Rev. 2 B 3.3.7-1 Rev. 14 B 3.3.1-18 Rev. 13 B 3.3.4-4 Rev. 2 B 3.3.7-2 Rev. 2 B 3.3.1-19 Rev. 11 B 3.3.4-5 Rev. 2 B 3.3.7-3 Rev. 2 B 3.3.1-20 Rev. 11 B 3.3.4-6 Rev. 2 B 3.3.7-4 Rev. 2 B 3.3.1-21 Rev. 11 B 3.3.4-7 Rev. 2 B 3.3.7-5 Rev. 2 B 3.3.1-22 Rev. 11 B 3.3.4-8 Rev. 2 B 3.3.7-6 Rev. 2 B 3.3.1-23 Rev. 11 B 3.3.4-9 Rev. 2 B 3.3.7-7 Rev. 2 B 3.3.1-24 Rev. 11 B 3.3.4-10 Rev. 2 B 3.3.8-1 Rev. 8 B 3.3.1-25 Rev. 11 B 3.3.4-11 Rev. 2 B 3.3.8-2 Rev. 2 B 3.3.1-26 Rev. 11 B 3.3.4-12 Rev. 2 B 3.3.8-3 Rev. 2 B 3.3.1-27 Rev. 11 B 3.3.4-13 Rev. 2 B 3.3.8-4 Rev. 2 B 3.3.1-28 Rev. 11 B 3.3.4-14 Rev. 2 B 3.3.9-1 Rev. 2 B 3.3.1-29 Rev. 11 B 3.3.4-15 Rev. 2 B 3.3.9-2 Rev. 2 B 3.3.1-30 Rev. 11 B 3.3.4-16 Rev. 2 B 3.3.9-3 Rev. 2 B 3.3.1-31 Rev. 11 B 3.3.4-17 Rev. 5 B 3.3.9-4 Rev. 2 B 3.3.1-32 Rev. 11 B 3.3.4-18 Rev. 2 B 3.3.9-5 Rev. 2 B 3.3.1-33 Rev. 12 B 3.3.4-19 Rev. 2 B 3.3.9-6 Rev. 2 B 3.3.1-34 Rev. 12 B 3.3.4-20 Rev. 2 B 3.3.9-7 Rev. 2 B 3.3.1-35 Rev. 2 B 3.3.4-21 Rev. 2 B 3.3.9-8 Rev. 3 B 3.3.2-1 Rev. 2 B 3.3.4-22 Rev. 12 B 3.3.10-1 Rev. 2 B 3.3.2-2 Rev. 2 B 3.3.4-23 Rev. 12 B 3.3.10-2 Rev. 2 B 3.3.2-3 Rev. 2 B 3.3.5-1 Rev. 2 B 3.3.10-3 Rev. 14 B 3.3.2-4 Rev. 2 B 3.3.5-2 Rev. 2 B 3.3.10-4 Rev. 14 B 3.3.2-5 Rev. 2 B 3.3.5-3 Rev. 2 B 3.3.10-5 Rev. 14 B 3.3.2-6 Rev. 2 B 3.3.5-4 Rev. 2 B 3.3.10-6 Rev. 14 B 3.3.2-7 Rev. 2 B 3.3.5-5 Rev. 2 B 3.3.10-7 Rev. 16 B 3.3.2-8 Rev. 2 B 3.3.5-6 Rev. 2 B 3.3.10-8 Rev. 16 B 3.3.2-9 Rev. 2 B 3.3.5-7 Rev. 2 B 3.3.10-9 Rev. 16 B 3.3.2-10 Rev. 2 B 3.3.5-8 Rev. 2 B 3.3.10-10 Rev. 16 B 3.3.3-1 Rev. 2 B 3.3.5-9 Rev. 2 B 3.3.10-11 Rev. 16 B 3.3.3-2 Rev. 2 B 3.3.5-10 Rev. 2 B 3.3.10-12 Rev. 16 B 3.3.3-3 Rev. 2 B 3.3.5-11 Rev. 2 B 3.3.10-13 Rev. 16 B 3.3.3-4 Rev. 2 B 3.3.5-12 Rev. 2 B 3.3.10-14 Rev. 16 B 3.3.3-5 Rev. 2 B 3.3.5-13 Rev. 2 B 3.3.10-15 Rev. 16 B 3.3.3-6 Rev. 2 B 3.3.5-14 Rev. 2 B 3.3.10-16 Rev. 16 B 3.3.3-7 Rev. 2 B 3.3.6-1 Rev. 2 B 3.3.10-17 Rev. 16 B 3.3.3-8 Rev. 2 B 3.3.6-2 Rev. 2 B 3.3.11-1 Rev. 2 B 3.3.3-9 Rev. 2 B 3.3.6-3 Rev. 2 B 3.3.11-2 Rev. 2 B 3.3.3-10 Rev. 2 B 3.3.6-4 Rev. 13 B 3.3.11-3 Rev. 2 B 3.3.3-11 Rev. 2 B 3.3.6-5 Rev. 2 B 3.3.11-4 Rev. 2 LEP-2 Rev. 18

May 5, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.11-5 Rev. 2 B 3.4.9-3 Rev. 2 B 3.4.16-2 Rev. 2 B 3.3.12-1 Rev. 2 B 3.4.9-4 Rev. 2 B 3.4.16-3 Rev. 2 B 3.3.12-2 Rev. 2 B 3.4.9-5 Rev. 2 B 3.4.17-1 Rev. 2 B 3.3.12-3 Rev. 2 B 3.4.10-1 Rev. 2 B 3.4.17-2 Rev. 2 B 3.3.12-4 Rev. 2 B 3.4.10-2 Rev. 2 B 3.4.17-3 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4.1-2 Rev. 15 B 3.4.10-4 Rev. 2 B 3.5.1-2 Rev. 2 B 3.4.1-3 Rev. 15 B 3.4.11-1 Rev. 12 B 3.5.1-3 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-2 Rev. 12 B 3.5.1-4 Rev. 2 B 3.4.1-5 Rev. 15 B 3.4.11-3 Rev. 12 B 3.5.1-5 Rev. 2 B 3.4.2-1 Rev. 2 B 3.4.11-4 Rev. 12 B 3.5.1-6 Rev. 2 B 3.4.2-2 Rev. 2 B 3.4.11-5 Rev. 12 B 3.5.1-7 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B 3.4.3-2 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-3 Rev. 2 B 3.4.12-1 Rev. 2 B 3.5.2-1 Rev. 15 B 3.4.3-4 Rev. 2 B 3.4.12-2 Rev. 2 B 3.5.2-2 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-3 Rev. 2 B 3.5.2-3 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-4 Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-7 Rev. 2 B 3.4.12-5 Rev. 6 B 3.5.2-5 Rev. 15 B 3.4.3-8 Rev. 2 B 3.4.12-6 Rev. 2 B 3.5.2-6 Rev. 15 B 3.4.4-1 Rev. 2 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-2 Rev. 13 B 3.4.12-8 Rev. 2 B 3.5.2-8 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-9 Rev. 2 B 3.5.2-9 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.12-10 Rev. 2 B 3.5.3-1 Rev. 2 B 3.4.5-2 Rev. 8 B 3.4.12-11 Rev. 2 B 3.5.3-2 Rev. 2 B 3.4.5-3 Rev. 8 B 3.4.12-12 Rev. 2 B 3.5.3-3 Rev. 2 B 3.4.5-4 Rev. 8 B 3.4.12-13 Rev. 2 B 3.5.4-1 Rev. 2 B 3.4.6-1 Rev. 2 B 3.4.13-1 Rev. 2 B 3.5.4-2 Rev. 14 B 3.4.6-2 Rev. 8 B 3.4.13-2 Rev. 10 B 3.5.4-3 Rev. 2 B 3.4.6-3 Rev. 8 B 3.4.13-3 Rev. 2 B 3.5.4-4 Rev. 2 B 3.4.6-4 Rev. 8 B 3.4.13-4 Rev. 2 B 3.5.4-5 Rev. 2 B 3.4.6-5 Rev. 8 B 3.4.13-5 Rev. 5 B 3.5.4-6 Rev. 2 B 3.4.7-1 Rev. 2 B 3.4.14-1 Rev. 2 B 3.5.5-1 Rev. 2 B 3.4.7-2 Rev. 2 B 3.4.14-2 Rev. 2 B 3.5.5-2 Rev. 2 B 3.4.7-3 Rev. 8 B 3.4.14-3 Rev. 2 B 3.5.5-3 Rev. 2 B 3.4.7-4 Rev. 8 B 3.4.14-4 Rev. 2 B 3.5.5-4 Rev. 2 B 3.4.7-5 Rev. 8 B 3.4.14-5 Rev. 2 B 3.5.5-5 Rev. 2 B 3.4.7-6 Rev. 8 B 3.4.15-1 Rev. 2 B 3.6.1-1 Rev. 2 B 3.4.8-1 Rev. 2 B 3.4.15-2 Rev. 2 B 3.6.1-2 Rev. 2 B 3.4.8-2 Rev. 2 B 3.4.15-3 Rev. 2 B 3.6.1-3 Rev. 2 B 3.4.8-3 Rev. 2 B 3.4.15-4 Rev. 3 B 3.6.1-4 Rev. 12 B 3.4.9-1 Rev. 2 B 3.4.15-5 Rev. 2 B 3.6.1-5 Rev. .2 B 3.4.9-2 Rev. 2 B 3.4.16-1 Rev. 2 B 3.6.2-1 Rev. 2 LEP-3 Rev. 18

May 5, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.2-2 Rev. 2 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.6.2-3 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-4 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.2-6 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-2 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-6 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.3-9 Rev. 2 B 3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2 B 3.6.4-2 Rev. 2 B 3.7.4-4 Rev. 2 B 3.7.15-1 Rev. 2 B 3.6.4-3 Rev. 2 B 3.7.5-1 Rev. 2 B 3.7.15-2 Rev. 13 B 3.6.5-1 Rev. 2 B 3.7.5-2 Rev. 2 B 3.7.15-3 Rev. 14 B 3.6.5-2 Rev. 2 B 3.7.5-3 Rev. 2 B 3.7.15-4 Rev. 2 B 3.6.5-3 Rev. 3 B 3.7.5-4 Rev. 2 B 3.8.1-1 Rev. 5 B 3.6.6-1 Rev. 2 B 3.7.5-5 Rev. 2 B 3.8.1-2 Rev. 12 B 3.6.6-2 Rev. 2 B 3.7.6-1 Rev. 5 B 3.8.1-3 Rev. 2 B 3.6.6-3 Rev. 15 B 3.7.6-2 Rev. 2 B 3.8.1-4 Rev. 10 B 3.6.6-4 Rev. 15 B 3.7.6-3 Rev. 5 B 3.8.1-5 Rev. 7 B 3.6.6-5 Rev. 2 B 3.7.6-4 Rev. 5 B 3.8.1-6 Rev. 17 B 3.6.6-6 Rev. 2 B 3.7.6-5 Rev. 5 B 3.8.1-7 Rev. 17 B 3.6.6-7 Rev. 2 B 3.7.7-1 Rev. 5 B 3.8.1-8 Rev. 17 B 3.6.6-8 Rev. 2 B 3.7.7-2 Rev. 12 B 3.8.1-9 Rev. 17 B 3.6.6-9 Rev. 18 B 3.7.7-3 Rev. 2 B 3.8.1-10 Rev. 17 B 3.6.6-10 Rev. 18 B 3.7.7-4 Rev. 12 B 3.8.1-11 Rev. 17 B 3.6.7 Del eted B 3.7.8-1 Rev. 8 B 3.8.1-12 Rev. 17 B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 B 3.8.1-13 Rev. 17 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 B 3.8.1-14 Rev. 17 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 B 3.8.1-15 Rev. 17 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 B 3.8.1-16 Rev. 17 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 B 3.8.1-17 Rev. 17 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 B 3.8.1-18 Rev. 17 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.8.1-19 Rev. 17 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.8.1-20 Rev. 17 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.8.1-21 Rev. 17 LEP-4 Rev. 18

May 5, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-22 Rev. 17 B 3.8.6-4 Rev. 2 B 3.9.4-4 Rev. 13 B 3.8.1-23 Rev. 17 B 3.8.6-5 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-24 Rev. 17 B 3.8.6-6 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-25 Rev. 17 B 3.8.6-7 Rev. 2 B 3.9.5-3 Rev. 14 B 3.8.1-26 Rev. 17 B 3.8.7-1 Rev. 2 B 3.9.5-4 Rev. 14 B 3.8.1-27 Rev. 17 B 3.8.7-2 Rev. 2 B 3.9.5-5 Rev. 14 B 3.8.1-28 Rev. 17 B 3.8.7-3 Rev. 2 B 3.9.6-1 Rev. 2 B 3.8.1-29 Rev. 17 B 3.8.7-4 Rev. 2 B 3.9.6-2 Rev. 2 B 3.8.1-30 Rev. 17 B 3.8.8-1 Rev. 2 B 3.9.6-3 Rev. 2 B 3.8.1-31 Rev. 17 B 3.8.8-2 Rev. 2 B 3.8.1-32 Rev. 17 B 3.8.8-3 Rev. 2 B 3.8.1-33 Rev. 17 B 3.8.9-1 Rev. 5 B 3.8.2-1 Rev. 2 B 3.8.9-2 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-3 Rev. 2 B 3.8.2-3 Rev. 10 B 3.8.9-4 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-5 Rev. 2 B 3.8.2-5 Rev. 5 B 3.8.9-6 Rev. 2 B 3.8.2-6 Rev. 5 B 3.8.9-7 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-5 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-3 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-4 Rev. 5 B 3.8.3-8 Rev. 3 B 3.8.10-5 Rev. 5 B 3.8.3-9 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-1 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-2 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-3 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-4 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-5 Rev. 2 B 3.9.2-2 Rev. 2 B 3.8.4-6 Rev. 2 B 3.9.2-3 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.4-8 Rev. 2 B 3.9.3-2 Rev. 13 B 3.8.4-9 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.5-2 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.5-3 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.5-4 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.6-1 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.6-2 Rev. 2 B 3.9.4-2 Rev. 2 B 3.8.6-3 Rev. 2 B 3.9.4-3 Rev. 11 LEP-5 Rev. 18

Containment Spray and Cooling Systems B 3.6.6 BASES 24 month Frequency is based on the need to perform these surveillance tests under the conditions that apply during a plant outage and the potential for an unplanned transient if the surveillance tests were performed with the reactor at power. Operating experience has shown that these components usually pass the surveillance tests when performed at the 24 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.

The surveillance test of containment sump isolation valves is also required by SR 3.5.2.5. A single surveillance test may be used to satisfy both requirements.

SR 3.6.6.7 This SR verifies that each containment cooling train actuates upon receipt of an actual or simulated actuation signal (i.e., the appropriate Engineered Safety Feature Actuation System signal). The 24 month Frequency is based on engineering judgment and has been shown to be acceptable through operating experience. See SR 3.6.6.5 and SR 3.6.6.6, above, for further discussion of the basis for the 24 month Frequency.

SR 3.6.6.8 With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through check valve bonnets. Performance of this SR demonstrates that each spray nozzle is unobstructed and provides assurance that spray coverage of the Containment Structure during an accident is not degraded.

Due to the passive design of the nozzle, a test after maintenance that could result in nozzle blockage is considered adequate. Maintenance that could result in nozzle blockage is generally loss of foreign material control or a flow of borated water through a nozzle. Should either of these events occur, a supervisory evaluation will be required to determine whether nozzle blockage is a possible result of the event.

Revision 18 CLIFFS - UNITS CALVERT CLIFFS -

& 2 1 &

UNITS 1 2 B 3.6.6-9 B 3.6.6-9 Revision 18

Containment Spray and Cooling Systems B 3.6.6 BASES REFERENCES 1. UFSAR

2. American Society of Mechanical Engineers, Boiler and Pressure Vessel Code,Section XI, "Rules for In-Service Inspection of Nuclear Power Plant Components" Revision 18 CLIFFS - UNITS CALVERT CLIFFS -

1&

UNITS 1 &22 B 3.6.6-10 B 3.6.6-10 Revision 18

PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 19 Remove and Discard Insert, List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 List of Revisions LOR-1 LOR-1 Technical Specification Bases Pages B 3.3.7-1 through B 3.3.7-7 B 3.3.7-1 through B 3.3.7-7 B 3.3.10-3 through B 3.3.10-17 B 3.3.10-3 through B 3.3.10-19 B 3.3.12-1 and B 3.3.12-2 B 3.3.12-1 and B 3.3.12-2 B 3.4.5-1 through B 3.4.5-4 B 3.4.5-1 through B 3.4.5-5 B 3.4.6-1 through B 3.4.6-5 B 3.4.6-1 through B 3.4.6-5 B 3.4.7-1 through B 3.4.7-6 B 3.4.7-1 through B 3.4.7-6 B 3.4.8-1 through B 3.4.8-3 B 3.4.8-1 through B 3.4.8-3 B 3.4.17-1 and B 3.4.17-2 B 3.4.17-1 and B 3.4.17-2 B 3.8.2-5 and B 3.8.2-6 B 3.8.2-5 through B 3.8.2-7 B 3.8.8-1 through B 3.8.8-3 B 3.8.8-1 through B 3.8.8-4 B 3.8.10-3 through B 3.8.10-5 B 3.8.10-3 through B 3.8.10-6 B 3.9.2-1 through B 3.9.2-3 B 3.9.2-1 through B 3.9.2-3 B 3.9.4-1 through B 3.9.4-4 B 3.9.4-1 through B 3.9.4-5 B 3.9.5-3 through B 3.9.5-5 B 3.9.5-3 through B 3.9.5-5

June 4, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 19 B 3.1.1-7 Rev. 2 B 3.1.8-5 Rev. 2 LEP-2 Rev. 19 B 3.1.2-1 Rev. 2 B 3.2.1-1 Rev. 2 LEP-3 Rev. 19 B 3.1.2-2 Rev. 2 B 3.2.1-2 Rev. 14 LEP-4 Rev. 19 B 3.1.2-3 Rev. 2 B 3.2.1-3 Rev. 14 LEP-5 Rev. 19 B 3.1.2-4 Rev. 2 B 3.2.1-4 Rev. 14 LOR-1 Rev. 19 B 3.1.2-5 Rev. 2 B 3.2.1-5 Rev. 14 i Rev. 2 B 3.1.2-6 Rev. 3 B 3.2.1-6 Rev. 14 ii Rev. 2 B 3.1.3-1 Rev. 2 B 3.2.1-7 Rev. 14 iii Rev. 16 B 3.1.3-2 Rev. 2 B 3.2.2-1 Rev. 2 iv Rev. 2 B 3.1.3-3 Rev. 2 B 3.2.2-2 Rev. 8 B 2.1.1-1 Rev. 2 B 3.1.3-4 Rev. 2 B 3.2.2-3 Rev. 14 B 2.1.1-2 Rev. 2 B 3.1.3-5 Rev. 2 B 3.2.2-4 Rev. 12 B Rev. Z B 3.1.4-i Kev. 2 b J.4.4- KeV.

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.B3.0-18 Rev. 13 B 3.1.7-2 Rev. 2 B 3.3.1-6 Rev. 12 B 3.0-19 Rev. 13 B 3.1.7-3 Rev. 5 B 3.3.1-7 Rev. 12 B 3.1.1-1 Rev. 2 B 3.1.7-4 Rev. 2 B 3.3.1-8 Rev. 12 B 3.1.1-2 Rev. 2 B 3.1.7-5 Rev. 11 B 3.3.1-9 Rev. 12 B 3.1.1-3 Rev. 2 B 3.1.8-1 Rev. 2 B.3.3.1-10 Rev. 12 B 3.1.1-4 Rev. 2 B 3.1.8-2 Rev. 2 B 3.3.1-11 Rev. 5 B 3.1.1-5 Rev. 2 B 3.1.8-3 Rev. 2 B 3.3.1-12 Rev. 2 B 3.1.1-6 Rev. 2 B 3.1.8-4 Rev. 2 B3.3.1-13 Rev. 12 LEP-1 Rev. 19

June 4, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.1-14 Rev. 11 B 3.3.3-12 Rev. 2 B 3.3.6-6 Rev. 2 B 3.3.1-15 Rev. 11 B 3.3.4-1 Rev. 2 B 3.3.6-7 Rev. 12 B 3.3.1-16 Rev. 11 B 3.3.4-2 Rev. 2 B 3.3.6-8 Rev. 8 B 3.3.1-17 Rev. 11 B 3.3.4-3 Rev. 2 B 3.3.7-1 Rev. 19 B 3.3.1-18 Rev. 13 B 3.3.4-4 Rev. 2 B 3.3.7-2 Rev. 19 B 3.3.1-19 Rev. 11 B 3.3.4-5 Rev. 2 B 3.3.7-3 Rev. 19 B 3.3.1-20 Rev. 11 B 3.3.4-6 Rev. 2 B 3.3.7-4 Rev. 19 B 3.3.1-21 Rev. 11 B 3.3.4-7 Rev. 2 B 3.3.7-5 Rev. 19 B 3.3.1-22 Rev. 11 B 3.3.4-8 Rev. 2 B 3.3.7-6 Rev. 19 B 3.3.1-23 Rev. 11 B 3.3.4-9 Rev. 2 B 3.3.7-7 Rev. 19 B 3.3.1-24 Rev. 11 B 3.3.4-10 Rev. 2 B 3.3.8-1 Rev. 8 B 3.3.1-25 Rev. 11 B 3.3.4-11 Rev. 2 B 3.3.8-2 Rev. 2 B 3.3.1-26 Rev. 11 B 3.3.4-12 Rev. 2 B 3.3.8-3 Rev. 2 B 3.3.1-27 Rev. 11 B 3.3.4-13 Rev. 2 B 3.3.8-4 Rev. 2 B 3.3.1-28 Rev. 11 B 3.3.4-14 Rev. 2 B 3.3.9-1 Rev. 2 B 3.3.1-29 Rev. 11 B 3.3.4-15 Rev. 2 B 3.3.9-2 Rev. 2 B 3.3.1-30 Rev. 11 B 3.3.4-16 Rev. 2 B 3.3.9-3 Rev. 2 B 3.3.1-31 Rev. 11 B 3.3.4-17 Rev. 5 B 3.3.9-4 Rev. 2 B 3.3.1-32 Rev. 11 B 3.3.4-18 Rev. 2 B 3.3.9-5 Rev. 2 B 3.3.1-33 Rev. 12 B 3.3.4-19 Rev. 2 B 3.3.9-6 Rev. 2 B 3.3.1-34 Rev. 12 B 3.3.4-20 Rev. 2 B 3.3.9-7 Rev. 2 B 3.3.1-35 Rev. 2 B 3.3.4-21 Rev. 2 B 3.3.9-8 Rev. 3 B 3.3.2-1 Rev. 2 B 3.3.4-22 Rev. 12 B 3.3.10-1 Rev. 2 B 3.3.2-2 Rev. 2 B 3.3.4-23 Rev. 12 B 3.3.10-2 Rev. 2 B 3.3.2-3 Rev. 2 B 3.3.5-1 Rev. 2 B 3.3.10-3 Rev. 14 B 3.3.2-4 Rev. 2 B 3.3.5-2 Rev. 2 B 3.3.10-4 Rev. 19 B 3.3.2-5 Rev. 2 B 3.3.5-3 Rev. 2 B 3.3.10-5 Rev. 19 B 3.3.2-6 Rev. 2 B 3.3.5-4 Rev. 2 B 3.3.10-6 Rev. 19 B 3.3.2-7 Rev. 2 B 3.3.5-5 Rev. 2 B 3.3.10-7 Rev. 19 B 3.3.2-8 Rev. 2 B 3.3.5-6 Rev. 2 B 3.3.10-8 Rev. 19 B 3.3.2-9 Rev. 2 B 3.3.5-7 Rev. 2 B 3.3.10-9 Rev. 19 B 3.3.2-10 Rev. 2 B 3.3.5-8 Rev. 2 B 3.3.10-10 Rev. 19 B 3.3.3-1 Rev. 2 B 3.3.5-9 Rev. 2 B 3.3.10-11 Rev. 19 B 3.3.3-2 Rev. 2 B 3.3.5-10 Rev. 2 B 3.3.10-12 Rev. 19 B 3.3.3-3 Rev. 2 B 3.3.5-11 Rev. 2 B 3.3.10-13 Rev. 19 B 3.3.3-4 Rev. 2 B 3.3.5-12 Rev. 2 B 3.3.10-14 Rev. 19 B 3.3.3-5 Rev. 2 B 3.3.5-13 Rev. 2 B 3.3.10-15 Rev. 19 B 3.3.3-6 Rev. 2 B 3.3.5-14 Rev. 2 B 3.3.10-16 Rev. 19 B 3.3.3-7 Rev. 2 B 3.3.6-1 Rev. 2 B 3.3.10-17 Rev. 19 B 3.3.3-8 Rev. 2 B 3.3.6-2 Rev. 2 B 3.3.10-18 Rev. 19 B 3.3.3-9 Rev. 2 B 3.3.6-3 Rev. 2 B 3.3.10-19 Rev. 19 B 3.3.3-10 Rev. 2 B 3.3.6-4 Rev. 13 B 3.3.11-1 Rev. 2 B 3.3.3-11 Rev. 2 B 3.3.6-5 Rev. 2 B 3.3.11-2 Rev. 2 LEP-2 Rev. 19

June 4, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.11-3 Rev. 2 B 3.4.8-3 Rev. 19 B 3.4.15-4 Rev. 3 B 3.3.11-4 Rev. 2 B 3.4.9-1 Rev. 2 B 3.4.15-5 Rev. 2 B 3.3.11-5 Rev. 2 B 3.4.9-2 Rev. 2 B 3.4.16-1 Rev. 2 B 3.3.12-1 Rev . 2 B 3.4.9-3 Rev. 2 B 3.4.16-2 Rev. 2 B 3.3.12-2 Rev. 19 B 3.4.9-4 Rev. 2 B 3.4.16-3 Rev. 2 B 3.3.12-3 Rev. 2 B 3.4.9-5 Rev. 2 B 3.4.17-1 Rev. 19 I1 B 3.3.12-4 Rev. 2 B 3.4.10-1 Rev. 2 B 3.4.17-2 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-2 Rev. 2 B 3.4.17-3 Rev. 2 B 3.4.1-2 Rev. 15 B 3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4.1-3 Rev. 15 B .3.4.10-4 Rev. 2 B 3.5.1-2 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-1 Rev. 12 B 3.5.1-3 Rev. 2 B 3.4.1-5 Rev. 15 B 3.4.11-2 Rev. 12 B 3.5.1-4 Rev. 2 B 3.4.2-1 Rev. 2 B 3.4.11-3 Rev. 12 B 3.5.1-5 Rev. 2 B 3.4.2-2 Rev. 2 B 3.4.11-4 Rev. 12 B 3.5.1-6 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-5 Rev. 12 B 3.5.1-7 Rev. 2 B 3.4.3-2 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B 3.4.3-3 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-4 Rev. 2 B 3.4.12-1 Rev. 2 B 3.5.2-1 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-2 Rev. 2 B 3.5.2-2 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-3 Rev. 2 B 3.5.2-3 Rev. 15 B 3.4.3-7 Rev. 2 B 3.4.12-4 Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-8 Rev. 2 B 3.4.12-5 Rev. 6 B 3.5.2-5 Rev. 15 B 3.4.4-1 Rev. 2 B 3.4.12-6 Rev. 2 B 3.5.2-6 Rev. 15 B 3.4.4-2 Rev. 13 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-8 Rev. 2 B 3.5.2-8 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.12-9 Rev. 2 B 3.5.2-9 Rev. 15 B 3.4.5-2 Rev. 19 B 3.4.12-10 Rev. 2 B 3.5.3-1 Rev. 2 B 3.4.5-3 Rev. 19 B 3.4.12-11 Rev. 2 B 3.5.3-2 Rev. 2 B 3.4.5-4 Rev. 19 B 3.4.12-12 Rev. 2 B 3.5.3-3 Rev. 2 B 3.4.5-5 Rev. 19 B 3.4.12-13 Rev. 2 B 3.5.4-1 Rev. 2 B 3.4.6-1 Rev. 19 B 3.4.13-1 Rev. .2 B 3.5.4-2 Rev. 14 B 3.4.6-2 Rev. 19 B 3.4.13-2 Rev. 10 B 3.5.4-3 Rev. 2 B 3.4.6-3 Rev. 8 B 3.4.13-3 Rev. 2 B 3.5.4-4 Rev. 2 B 3.4.6-4 Rev. 19 B 3.4.13-4 Rev. 2 B 3.5.4-5 Rev. 2 B 3.4.6-5 Rev. 19 B 3.4.13-5 Rev. 5 B 3.5.4-6 Rev. 2 B 3.4.7-1 Rev. 2 B 3.4.14-1 Rev. 2 B 3.5.5-1 Rev. 2 B 3.4.7-2 Rev. 19 B 3.4.14-2 Rev. 2 B 3.5.5-2 Rev. 2 B 3.4.7-3 Rev. 19 B 3.4.14-3 Rev. 2 B 3.5.5-3 Rev. 2 B 3.4.7-4 Rev. 19 B 3.4.14-4 Rev. 2 B 3.5.5-4 Rev. 2 B 3.4.7-5 Rev. 19 B 3.4.14-5 Rev. 2 B 3.5.5-5 Rev. 2 B 3.4.7-6 Rev. 19 B 3.4.15-1 Rev. 2 B 3.6.1-1 Rev. 2 B 3.4.8-1 Rev. 2 B 3.4.15-2 Rev. 2 B 3.6.1-2 Rev. 2 B 3.4.8-2 Rev. 19 B 3.4.15-3 Rev. 2 B 3.6.1-3 Rev. 2 LEP-3 Rev. 19

June 4, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.1-4 Rev. 12 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.6.1-5 Rev. 2 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.6.2-1 Rev. 2 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.6.2-2 Rev. 2 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.6.2-3 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-4 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.2-6 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-2 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-6 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.3-9 Rev. 2 B 3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2 B 3.6.4-2 Rev. 2 B 3.7.4-4 Rev. 2 B 3.7.15-1 Rev. 2 B 3.6.4-3 Rev. 2 B 3.7.5-1 Rev. 2 B 3.7.15-2 Rev. 13 B 3.6.5-1 Rev. 2 B 3.7.5-2 Rev. 2 B 3.7.15-3 Rev. 14 B 3.6.5-2 Rev. 2 B 3.7.5-3 Rev. 2 B 3.7.15-4 Rev. 2 B 3.6.5-3 Rev. 3 B 3.7.5-4 Rev. 2 B 3.8.1-1 Rev. 5 B 3.6.6-1 Rev. 2 B 3.7.5-5 Rev. 2 B 3.8.1-2 Rev. 12 B 3.6.6-2 Rev. 2 B 3.7.6-1 Rev. 5 B 3.8.1-3 Rev. 2 B 3.6.6-3 Rev. 15 B 3.7.6-2 Rev. 2 B 3.8.1-4 Rev. 10 B 3.6.6-4 Rev. 15 B 3.7.6-3 Rev. 5 B 3.8.1-5 Rev. 7 B 3.6.6-5 Rev. 2 B 3.7.6-4 Rev. 5 B 3.8.1-6 Rev. 17 B 3.6.6-6 Rev. 2 B 3.7.6-5 Rev. 5 B 3.8.1-7 Rev. 17 B 3.6.6-7 Rev. 2 B 3.7.7-1 Rev. 5 B 3.8.1-8 Rev. 17 B 3.6.6-8 Rev. 2 B 3.7.7-2 Rev. 12 B 3.8.1-9 Rev. 17 B 3.6.6-9 Rev. 18 B 3.7.7-3 Rev. 2 B 3.8.1-10 Rev. 17 B 3.6.6-10 Rev. 18 B 3.7.7-4 Rev. 12 B 3.8.1-11 Rev. 17 B 3.6.7 Deleted B 3.7.8-1 Rev. 8 B 3.8.1-12 Rev. 17 B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 B 3.8.1-13 Rev. 17 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 B 3.8.1-14 Rev. 17 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 B 3.8.1-15 Rev. 17 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 B 3.8.1-16 Rev. 17 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 B 3.8.1-17 Rev. 17 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 B 3.8.1-18 Rev. 17 LEP-4 Rev. 19

June 4, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-19 Rev. 17 B 3.8.5-4 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.1-20 Rev. 17 B 3.8.6-1 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.1-21 Rev. 17 B 3.8.6-2 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.1-22 Rev. 17 B 3.8.6-3 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.1-23 Rev. 17 B 3.8.6-4 Rev. 2 B 3.9.4-2 Rev. 19 B 3.8.1-24 Rev. 17 B 3.8.6-5 Rev. 2 B 3.9.4-3 Rev. 19 B 3.8.1-25 Rev. 17 B 3.8.6-6 Rev. 2 B 3.9.4-4 Rev. 19 B 3.8.1-26 Rev. 17 B 3.8.6-7 Rev. 2 B 3.9.4-5 Rev. 19 B 3.8.1-27 Rev. 17 B 3.8.7-1 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-28 Rev. 17 B 3.8.7-2 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-29 Rev. 17 B 3.8.7-3 Rev. 2 B 3.9.5-3 Rev. 19 B 3.8.1-30 Rev. 17 B 3.8.7-4 Rev. 2 B 3.9.5-4 Rev. 19 B 3.8.1-31 Rev. 17 B 3.8.8-1 Rev. 2 B 3.9.5-5 Rev. 19 B 3.8.1-32 Rev. 17 B 3.8.8-2 Rev. 19 B 3.9.6-1 Rev. 2 B 3.8.1-33 Rev. 17 B 3.8.8-3 Rev. 19 B 3.9.6-2 Rev. 2 B 3.8.2-1 Rev. 2 B 3.8.8-4 Rev. 19 B 3.9.6-3 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-1 Rev. 5 B 3.8.2-3 Rev. 10 B 3.8.9-2 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-3 Rev. 2 B 3.8.2-5 Rev. 19 B 3.8.9-4 Rev. 2 B 3.8.2-6 Rev. 19 B 3.8.9-5 Rev. 2 B 3.8.2-7 Rev. 19 B 3.8.9-6 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-7 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-5 Rev. 2 B 3.8.10-1 Rev. 5 B-3.8.3-6 Rev. 2 B 3.8.10-2 .Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-3 Rev. 19 B 3.8.3-8 Rev. 3 B 3.8.10-4 Rev. 19 B 3.8.3-9 Rev. 2 8 3.8.10-5 Rev. 19 B 3.8.4-1 Rev. 2 B 3.8.10-6 Rev. 19 B 3.8.4-2 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-3 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-4 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-5 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-6 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.2-2 Rev. 19 B 3.8.4-8 B 3.8.4-9 Rev.

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TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 17 April 16, 2004 18 May 5, 2004 19 June 4, 2004 LOR-1 Rev. 19

CRS B 3.3.7 B 3.3 INSTRUMENTATION B 3.3.7 Containment Radiation Signal (CRS)

BASES BACKGROUND This LCO encompasses CRS actuation, which is a plant-specific instrumentation system that performs an actuation Function required to mitigate offsite dose, but is not otherwise included in LCO 3.3.5 or LCO 3.3.6. This is a non-Nuclear Steam Supply System ESFAS Function that, because of differences in purpose, design, and operating requirements, is not included in LCOs 3.3.5 and 3.3.6.

The CRS provides protection from radioactive contamination in the Containment in the event an irradiated fuel assembly should be severely damaged during handling.

The CRS will detect abnormal amounts of radioactive material in the Containment.and will initiate purge valve closure to limit the release of radioactivity to the environment. The containment purge supply and exhaust valves are closed on a CRS when a high radiation level in Containment is detected.

The CRS includes two independent, redundant actuation logic channels. One actuation logic channel.("A" CRS Actuation Logic Channel) secures the containment purge exhaust fan and containment purge supply fan. This actuation logic channel also initiates isolation valve closure. A list of actuated valves and an additional description of the CRS are included in Reference 1, Section 7.3. Both trains of CRS are actuated on a two-out-of-four coincidence from the same four containment radiation sensor channels.

Trip Setpoints and Allowable Values Trip setpoints used in the sensor modules are based on the analytical limits stated in Reference 1, Chapter 14. The selectionof these trip setpoints is such that adequate protection is provided when all sensor and processing time delays are taken into account in the respective analytical limits. To allow for calibration tolerances, instrumentation uncertainties, and sensor channel drift, sensor module trip setpoints are conservatively adjusted with respect to the analytical limits. A detailed description of the methodology used to calculate the trip setpoints, including their explicit uncertainties, is CALVERT CLIFFS - UNITS 1 & 2 B 3.3.7-1 Revision 19

CRS B 3.3.7 BASES provided in Reference 2. The actual nominal trip setpoint entered into the sensor module is more conservative than that specified by the Allowable Value. One example of such a change in measurement error is drift during the SR interval. If the measured setpoint does not exceed the Allowable Value, the bistable is considered OPERABLE.

Sensor channels, measurement channels, sensor modules, and actuation logic are described in the Background for B 3.3.4.

Setpoints in accordance with the Allowable Value will help ensure that 10 CFR Part 100 exposure limits are not violated

-d--ririg-A-Ffe~l Ha-ndlingfAcci d-nt,-pov7idihg the plant is fis operated from within the LCOs at the onset of the Fuel Handling Accident and the equipment functions as designed.

APPLICABLE The CRS satisfies the requirements of 10 CFR SAFETY ANALYSES 50.36(c)(2)(ii), Criterion 3.

LCO Only the Allowable Values are specified in the LCO.

Operation with a trip setpoint less conservative than the nominal trip setpoint, but within its Allowable Value, is acceptable, provided that operation and testing are consistent with the assumptions of the plant-specific setpoint calculations.

Each nominal trip setpoint specified is more conservative than the analytical limit assumed in the Fuel Handling Accident analysis in order to account for instrument uncertainties appropriate to the actuation Function. These uncertainties are defined in Reference 2. A sensor channel is inoperable if its actual trip setpoint is not within its required Allowable Value.

The Bases for the LCO on the CRS are discussed below for each Function:

a. Manual Actuation The LCO on manual actuation backs up the automatic actuations and ensures operators have the capability to rapidly initiate the CRS Function if any parameter is trending toward its setpoint. At least one channel Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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CRS B 3.3.7 BASES must be OPERABLE to be consistent with the requirements of LCO 3.9.3.

b. Containment Radiation-High Trip The LCO on the radiation sensor channels requires that all four be OPERABLE. The radiation sensor channels have a measurement range of 10 104mr/hr.

The Containment Radiation-High trip setpoint is based on sensing radiation resulting from a fuel handling accident in order to prevent a release of radioactivity

_ _ through the containment.purge system. -

c. Actuation Logic One channel of actuation logic must be OPERABLE to be consistent with the requirements of LCO 3.9.3. If one fails, it must be restored to OPERABLE status.

APPLICABILITY In MODE 5 or 6, the CRS isolation of containment purge valves is not required to be OPERABLE. However, during CORE ALTERATIONS or during movement of irradiated fuel, there is the possibility of a Fuel Handling Accident requiring the CRS on high radiation in Containment. Accordingly, the CRS must be OPERABLE during CORE ALTERATIONS and when moving any irradiated fuel in Containment when the containment purge valves are open.

In MODEs 1, 2, 3, and 4, the containment purge valves are sealed closed.

ACTIONS A CRS sensor channel is inoperable when it does not satisfy the OPERABILITY criteria for the channel's Function. The most common cause of channel inoperability is outright failure or drift of the sensor module or measurement channel sufficient to exceed the tolerance allowed by Reference 2.

Typically, the drift is not large, which at worst would result in a delay of actuation rather than a total loss of Function. This determination is generally made during the performance of a CHANNEL CALIBRATION when the process instrument is set up for adjustment to bring it within specification. Sensor drift could also be identified during CHANNEL CHECKS. CHANNEL FUNCTIONAL TESTS identify sensor B 3.3.7-3 Revision 19 CALVERT -

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CRS B 3.3.7 BASES module drift. If the actual trip setpoint is not within the Allowable Value in SR 3.3.7.2, the channel is inoperable and the appropriate Conditions must be entered.

In the event that either a sensor channel's trip setpoint is found nonconservative with respect to the Allowable Value, or the sensor, instrument loop, signal processing electronics, or sensor module is found inoperable, that channel should be declared inoperable and the LCO Condition entered.

A.1. A.2.1, and A.2.2 Condition A applies to the failure of one Containment Radiation-High trip CRS channel. The Required Action is to place the affected channel in the trip condition within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , or suspend CORE ALTERATIONS and suspend movement of irradiated fuel assemblies within Containment immediately.

The Completion Time accounts for the fact that three redundant channels monitoring containment radiation are still available to provide a single trip input to the CRS logic to provide the automatic mitigation of a radiation.

release.

B.1 and B.2 Condition B applies to the failure of the required manual actuation or actuation logic, to the failure of more than one radiation sensor channel, or if the Required Action and associated Completion Time of Condition A are not met.

Required Action B.1 is to place the containment purge and exhaust isolation valves in the closed position. The Required Action immediately performs the isolation Function of the CRS. Required Action B.2 is to immediately enter the applicable Conditions and Required Actions for the affected isolation valves of LCO 3.9.3 that were made inoperable by the inoperable instrumentation of the CRS LCO. The Required Action directs the operator to take actions appropriate for the containment isolation Function of the CRS. The Completion Time accounts for the fact that the automatic capability to isolate Containment on valid containment high radiation signals is degraded during conditions in which a Fuel Handling Accident is possible and CRS provides the only automatic mitigation of radiation release.

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CRS B 3.3.7 BASES SURVEILLANCE SR 3.3.7.1 REQUIREMENTS Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one sensor channel to a similar parameter on other channels. It is based on the assumption that sensor channels monitoring the same parameter should read approximately the same value.

Significant deviations between the two sensor channels could

- -be'an indication-of excessive sensor channel -drift in one of the channels or of something more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a qualitative assessment of the sensor channel that considers sensor channel uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits.

The Frequency, about once every shift, is based on operating experience that demonstrates the rarity of sensor channel failure. Since the probability of two random failures in redundant channels in any 12-hour period is low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels. The CHANNEL CHECK supplements less formal, but more frequent, checks of the channel during normal operational use of the displays.

SR 3.3.7.2 Proper operation of the actuation relays is verified by verification of the relay driver output signal.

The Frequency of 92 days is based on plant operating experience with regard to actuation channel OPERABILITY, which demonstrates that failure of more than one channel of a given Function in any 92-day interval is a rare event.

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CRS B 3.3.7 BASES SR 3.3.7.3 A CHANNEL FUNCTIONAL TEST is performed on each containment radiation sensor channel to ensure the entire channel, except for sensor and initiating relays, will perform its intended function.

The Frequency of 92 days is based on plant operating experience with regard to sensor channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given Function in any 92-day interval is a rare event.

SR 3.3.7.4 CHANNEL CALIBRATION is a check of the sensor channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for sensor channel drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with Reference 2.

The Frequency is based upon the assumption of a 24-month calibration interval based on the refueling interval and the instruments not being inservice during power operations, but part of preparation for being placed in service is a CHANNEL CALIBRATION.

SR 3.3.7.5 Every 24 months, a CHANNEL FUNCTIONAL TEST is performed on the manual CRS actuation circuitry.

This surveillance test verifies that the actuation push buttons are capable of opening contacts in the actuation logic as designed, de-energizing the actuation relays and providing manual actuation of the Function. The 24-month Frequency is based on the need to perform this SR under the conditions that apply during a plant outage and the potential for an unplanned transient if the SR were performed with the reactor at power. Operating experience has shown these components usually pass the surveillance test when performed at a Frequency of once every 24 months.

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CRS B 3.3.7 BASES SR 3.3.7.6 This surveillance test ensures that the train actuation response times are less than or equal to the maximum times assumed in the analyses. Response times are defined in the same manner as ESF RESPONSE TIME. Response time testing acceptance criteria are included in Reference 1, Section 7.3. The 24-month Frequency is based upon plant operating experience, which shows random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences. Testing of the final actuating devices, which make up the bulk of the response time, is included. Testing of the final actuating device is one channel is included in the testing of-each actuation logic channel.

REFERENCES 1. UFSAR

2. CCNPP Setpoint File CAVR CLFS-UIS1&2 B ..- eiin1 CALVERT CLIFFS - UNITS 1 & 2 B 3.3.7-7 Revision 19

PAM Instrumentation B 3.3.10 BASES these Category I variables are important in reducing public risk.

LCO Limiting Condition for Operation 3.3.10 requires two OPERABLE indication channels for all but one Function to ensure no single failure prevents the operators from being presented with the information necessary to determine the status of the plant and to bring the plant to, and maintain it in, a safe condition following that accident.

Furthermore, provision of two indication channels allows a CHANNEL CHECK during the post-accident phase to confirm the validity of displayed information.

An indication channel consists of field transmitters or process sensors and associated instrumentation, providing a measurable electronic signal based upon the physical characteristics of the parameter being measured, plus a display of the measured parameter.

The exceptions to the two-channel requirement are CIV position and the subcooled margin monitoring (SMM) instrumentation. In the case of valve position, the important information is the status of the containment penetrations. The LCO requires one position indicator for each active CIV. This is sufficient to redundantly verify the isolation status of each isolable penetration, either via indicated status of the active valve and prior knowledge of the passive valve, or via system boundary status. If a normally active CIV 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. Alternate means are available for obtaining information provided by the SMM instrumentation.

Listed below are discussions of the specified instrument Functions listed in Table 3.3.10-1.

1. Wide Range Logarithmic Neutron Flux Monitors Wide range logarithmic neutron flux is a Category I variable indication is provided to verify reactor shutdown.

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PAM Instrumentation B 3.3.10 BASES The wide range logarithmic neutron flux PAM channels consist of two wide range neutron monitoring channels.

2, 3. RCS Outlet and Inlet Temperature Reactor Coolant System outlet and inlet temperatures are Category I variables provided for verification of core cooling and long-term surveillance.

Reactor outlet temperature inputs to the PAM are provided by four resistance elements and associated transmitters in each loop. The channels provide indication over a range of 501F to 7001F.

4. SMM The RCS SMM is part of the PAM System and is provided to monitor inadequate core cooling by calculating the margin to saturation based on the RCS pressure/

temperature relationships and displaying the calculated margin in degrees F on a control room display. Also, a control room low subcooled margin alarm is provided.

The RCS SMM portion of the PAM System is microprocessor-based and is provided with inputs from the RCS hot legs, cold legs, and wide range RCS pressure channels. The core exit thermocouple (CET)

SMM and upper head SMM functions are not required for channel operability.

The RCS SMM is one of three components of inadequate core cooling instrumentation. With the SMM portion of the PAM System inoperable, the CETs and the reactor vessel water level heated junction thermocouple (HJTC) sensors provide diverse indication of core cooling.

Alternate indications and methods for calculating subcooled margin exist in the event of a PAM System failure.

5. Reactor Vessel Water Level Reactor vessel water level indication is provided for verification and long-term surveillance testing of core cooling.

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PAM Instrumentation B 3.3.10 BASES This indication uses HJTC technology. This technology measures reactor coolant inventory with discrete heated junction thermocouple sensors located in different levels within a separator tube. The sensors enable a direct measurement of the collapsed liquid level above the fuel alignment plate. The collapsed level represents the amount of liquid mass that is in the reactor vessel above the core. Measurement of the collapsed water level is selected because it is a direct indication of the water inventory. The collapsed level. is obtained over the same temperature and pressure range as the saturation measurements, thereby encompassing all operating and accident conditions where it must function. Also, it functions during the recovery interval. Therefore, it is designed to survive the high steam temperature that may occur during the preceding core recovery interval.

The level range extends from the top of the vessel down to 10" above the top of the fuel alignment plate. The response time is short enough to track the level during small break LOCA events. The resolution is sufficient to show the initial level drop, the key locations near the hot leg elevation, and the lowest levels just above the alignment plate. This provides the operator with adequate indication to track the progression of the accident and to detect the consequences of its mitigating actions or the functionality of automatic equipment.

A channel has eight sensors in a probe. A channel is OPERABLE if four sensors, one in the upper three and three in the lower five, are OPERABLE.

6. Containment Sump Water Level (wide range) Monitor Containment sump water level monitors are provided for verification and long-term surveillance of RCS integrity.

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PAM Instrumentation B 3.3.10 BASES the containment flood level and utilize sealed reference legs to sense water level.

7. Containment Pressure (wide range) Monitor The containment pressure monitor is provided for verification of RCS and containment OPERABILITY.

Containment pressure instrumentation consists of three containment pressure transmitters with overlapping ranges that provide input to control room indicators.

The transmitters are located outside the Containment and are not subject to a harsh environment.

8. CIV Position Indicator Containment isolation valve position indicators are provided for verification of containment OPERABILITY and integrity.

In the case of CIV position, the important information is the isolation status of the containment penetration.

The LCO requires one channel of valve position indication in the Control Room to be OPERABLE for each active CIV in a containment penetration flow path, i.e., two total channels of CIV position indication for a penetration flow path with two active valves. For containment penetrations with only one active CIV having control room indication, Note (b) requires a single channel of valve position indication to be OPERABLE. This is sufficient to redundantly verify the isolation status of each isolable penetration via indicated status of the active valve, as applicable, and prior knowledge of passive valve or system boundary status. If a penetration flow path is isolated, position indication for the CIV(s) in the associated penetration flow path is not needed to determine status. Therefore, the position indication for valves in an isolated penetration flow path is not required to be OPERABLE.

The CIV position PAM instrumentation consists of ZL-505, 506, 515, 516, 2080, 2180, 2181, 3832, 3833, 4260, 5291, 5292, 6900, and 6901 (Reference 5).

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PAM Instrumentation B 3.3.10 BASES

9. Containment Area Radiation (high range) Detector Containment area radiation detectors are provided to monitor for the potential of significant radiation releases and to provide release assessment for use by operations in determining the need to invoke site emergency plans.

Containment area radiation instrumentation consists of two radiation detectors with displays and alarm in the Control Room. The radiation detectors have a measurement range of 1 to 106 R/hr.

10. Pressurizer Pressure (wide range)

Pressurizer wide range pressure is a Category I variable provided for verification of core cooling and RCS integrity long-term surveillance.

Wide range pressurizer pressure is measured by two pressure transmitters with a span of 0 psia to 4000 psia. The pressure transmitters are located inside the Containment. Redundant monitoring capability is provided by two indication channels.

Control Room indications are provided.

Pressurizer pressure is a Type I variable because the operator uses this indication to monitor the cooldown of the RCS following a LOCA and other DBAs. Operator actions to maintain a controlled cooldown, such as adjusting steam generator pressure or level, would use this indication. Furthermore, pressurizer pressure is one factor that may be used in decisions to terminate RCP operation.

11. Steam Generator Pressure Transmitter Steam generator pressure transmitters are Category 1 instruments and are provided to monitor operation of decay heat removal via the steam generators.

There are four redundant pressure transmitters per steam generator, but only two per steam generator are required to satisfy the Technical Specification Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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PAM Instrumentation B 3.3.10 BASES Requirements. The transmitter provides wide range indication over the range from 0 to 1200 psia. Each transmitter provides input to control room indication.

Since the primary indication used by the operator during an accident is the control room indicator, the PAM instrumentation Specification deals specifically with this portion of the instrument channel.

12. Pressurizer Level Transmitters Pressurizer level transmitters are used to determine whether to terminate safety injection, if still in progress, or to reinitiate safety injection if it has been stopped. Knowledge of pressurizer water level is also used to verify the plant conditions necessary to establish natural circulation in the RCS and to verify that the plant is maintained in a safe shutdown condition.

Pressurizer Level instrumentation consists of two pressurizer level transmitters that provide input to control room indicators.

13. Steam Generator Water Level Transmitters Steam Generator Water Level transmitters are provided to monitor operation of decay heat removal via the steam generators. The Category I indication of steam generator level is the extended startup range level instrumentation. The extended startup range level covers a span of -40 inches to -63 inches (relative to normal operating level), above the lower tubesheet.

The measured differential pressure is displayed in inches of water at process conditions of the fluid.

Redundant monitoring capability is provided by four transmitters. The uncompensated level signal is input to the plant computer and a control room indicator.

Steam generator water level instrumentation consists of two level transmitters.

Operator action is based on the control room indication of steam generator water level. The RCS response

. during a design basis small break LOCAlis dependent on the break.size. For a certain range of break sizes, CALVERT CLIFFS - UNITS 1 & 2 B 3.3.10-8 Revision 19

-PAM Instrumentation B 3.3.10 BASES the boiler condenser mode of heat transfer is necessary to remove decay heat.. Extended startup range.level is a Type A variable because the operator must manually raise and control the steam generator level to establish boiler condenser heat transfer. Feedwater flow is increased until indication is in range.

14. Condensate StoraQe Tank Level Monitor Condensate storage tank (CST) level monitoring is provided to ensure water supply for AFW. Condensate Storage Tank 12 provides the ensured safety grade water supply for the AFW System. Inventory in CST 12 is monitored by level indication covering the full range of required usable water level. Condensate storage tank level is displayed on control room indicators and the plant computer. In addition, a control room annunciator alarms on low level.

Condensate storage tank level is considered a Type A variable because the control room meter and annunciator are considered the primary indication used by the Operator. The DBAs that require AFW are the steam line break and loss of main feedwater. Condensate Storage Tank 12 is the initial source of water for the AFW System. However, as the CST is depleted, manual.

operator action is necessary to replenish the CST or align suction to the AFW pumps from an alternate source.

15, 16, 17, 18. Core Exit Temperature Core Exit Temperature indication is provided for verification and long-term surveillance of core cooling.

An evaluation was made of the minimum number of valid CETs necessary for inadequate core cooling detection.

The evaluation determined-the reduced complement of CETs necessary to detect initial core uncovery and trend the ensuing core heatup. The evaluations account

.for core nonuniformities, including incore effects of the radial decay power distribution and excore effects of condensate runback in the hot legs and nonuniform CALVERT CLIFFS - UNITS 1 & 2 B 3.3,.10-9 Revision 19

PAM Instrumentation B 3.3.10 BASES inlet temperatures. Based on these evaluations, adequate or inadequate core cooling detection is ensured with two valid CETs per quadrant.

The design of the Incore Instrumentation System includes a Type K (chromel alumel) thermocouple within each of the 35 incore instrument detector assemblies.

The junction of each thermocouple is located more than a foot above the fuel assembly, inside a structure that supports and shields the incore instrument detector assembly string from flow forces in the outlet plenum region. These CETs monitor the temperature of the reactor coolant as it exits the fuel assemblies.

The CETs have a usable temperature range from 400 F to 2300 0F, although accuracy is reduced at temperatures above 1800 0F.

19. Pressurizer Pressure (low range)

Pressurizer low range pressure is a Category I variable provided for verification of core cooling and RCS integrity long-term surveillance.

Low-range pressurizer pressure is measured by two pressure transmitters with a span of 0 psia to 1600 psia. The pressure transmitters are located inside the Containment. Redundant monitoring capability is provided by two indication channels.

Control Room indications are provided.

Pressurizer pressure is a Type I variable because the operator uses this indication to monitor the cooldown of the RCS following a LOCA and other DBAs. Operator actions to maintain a controlled cooldown, such as adjusting steam generator pressure or level, would use this indication. Furthermore, pressurizer pressure is one factor that may be used in decisions to terminate RCP operations.

Two indication channels are required to be OPERABLE for all but two Functions. Two OPERABLE channels ensure that no single failure, within either the PAM instrumentation or its Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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PAM Instrumentation B 3.3.10 BASES auxiliary supporting features or power sources (concurrent with the failures that are a condition of or result from a specific accident), prevents the operators from being presented the information necessary for them to determine the safety status of the plant, and to bring the plant to and maintain it in a safe condition following that accident.

In Table 3.3.10-1 the exceptions to the two channel requirement are CIV position and the SMM.

Two OPERABLE CETs are required for each channel in each quadrant to provide indication of radial distribution of the coolant temperature rise across representative regions of the core. Power distribution symmetry was considered in determining the specific number and locations provided for diagnosis of local core problems. Therefore, two randomly selected thermocouples may not be sufficient to meet the two thermocouples per channel requirement in any quadrant. The two thermocouples in each channel must meet the additional requirement that one be located near the center of the core and the other near the core perimeter, such that the pair of CETs indicate the radial temperature gradient across their core quadrant. The two channels in each core quadrant must be electronically independent. A CETs operability is based on a comparison of the CET temperature indication with the hot leg resistance temperature detector temperature indication. Different criteria have been specified for interior CETs and peripheral CETs to account for the core radial power distribution. Plant specific evaluations in response to Item II.F.2 of NUREG-0737 should have identified the thermocouple pairings that satisfy these requirements.

Two sets of two thermocouples in each quadrant ensure a single failure will not disable the ability to determine the radial temperature gradient.

For loop- and steam generator-related variables, the required information is individual loop temperature and individual steam generator level. In these cases, two channels are required to be OPERABLE for each loop of steam generator to redundantly provide the necessary information.

In the case of CIV position, the important information is the status of the containment penetrations. The LCO.

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PAM Instrumentation B 3.3.10 BASES requires one position indicator for each'active CIV. This is sufficient to redundantly verify the isolation status of each isolable penetration either via indicated status of the active valve and prior knowledge of the passive valve or via system boundary status. If a normally active CIV 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.

.The SMM, CETs, and the HJTC-based reactor. vessel water level indication comprise the inadequate core cooling instrumentation. The function of the inadequate core cooling instrumentation is to enhance the ability of the plant operator to diagnose the approach to, and recovery from, inadequate core cooling.

APPLICABILITY The PAM instrumentation LCO is applicable in MODEs 1, 2, and 3. These variables are related to the diagnosis and preplanned actions required to mitigate DBAs. The applicable DBAs are assumed to occur in MODEs 1, 2, and 3.

In MODEs 4, 5, and 6, plant conditions are such that the likelihood of an event occurring-requiring PAM instrumentation is low; therefore, PAM instrumentation is not required to be OPERABLE in these MODEs.

ACTIONS Note 1 has been added in the ACTIONS to exclude the MODE change restriction of LCO 3.0.4. This exception allows entry into the applicable MODE while relying on the ACTIONS, even though the ACTIONS may eventually require plant shutdown. This exception is acceptable due to the passive function of the indication channels, the operator's ability to monitor an accident using alternate instruments and methods, and the low probability of an event requiring these indication channels.

Note 2 has been added in the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Specification may be entered independently for each Function listed in Table 3.3.10-1. The Completion Time(s) of the inoperable channel(s) of a Function will be tracked separately for each Function, starting from the time the Condition was entered for that Function.

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~PAM Instrumentation B 3.3.10 BASES A.1 When one or more Functions have one required indication channel that is inoperable, the required inoperable channel must be restored to OPERABLE status within 30 days. The 30-day Completion Time is based on operating experience and takes into account the remaining OPERABLE channel (or in the case of a Function that has only one required channel, other non-Reference 3 indication channels to monitor the Function), the passive nature of the instrument (no critical automatic action is assumed to occur from these instrIfmentc). and the low prnhahility of an event requiming PAM instrumentation during this interval.

B.1 This Required Action specifies initiation of actions in accordance with Specification 5.6.7, which requires a

.written report to be submitted to the NRC. This report discusses the results of the root cause evaluation of the inoperability and identifies proposed restorative Required Actions. This Required Action is appropriate in lieu of a shutdown requirement, given the likelihood of plant conditions that would require information provided by this instrumentation. Also, alternative Required Actions such as grab sampling or diverse indications are identified before a loss of functional capability condition occurs.

C.1 When one or more Functions have two required indication channels inoperable (i.e., two channels inoperable in the same Function), one channel in the Function should be restored to OPERABLE status within 7 days. The Completion Time of 7 days is based on the relatively low probability of an event requiring PAM instrumentation operation and the availability of alternate means to obtain the required information. Continuous operation with two required

channels inoperable in a Function is not acceptable because the alternate indications may not fully meet all performance.

qualification requirements applied to the PAM instrumentation. Therefore, requiring restoration of one inoperable channel of the Function limits the risk that the

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PAM Instrumentation B 3.3.10 BASES PAM Function will be in a degraded condition should an accident occur.

D.1 This Required Action directs entry into the appropriate Condition referenced in Table 3.3.10-1. The applicable Condition referenced in the Table is Function-dependent.

Each time Required Action C.1 is not met and the associated Completion Time has expired, Condition D is entered for that channel and provides for transfer to the appropriate subsequent Condition.

Table 3.3.10-1, as printed on Technical Specification pages 3.3.10-4 and 3.3.10-5, references the wrong Conditions. When Technical Specification 3.3.10 was changed by License Amendments 262 and 239, the Conditions were resequenced but Table 3.3.10-1 was not changed to match.

This issue is addressed in IR4-023-627. A license amendment is being submitted to correct the table. Until the amendment is approved, the correct references are in Substitute Table 3.3.10-1 (at the end of this Section) and shall be used instead of Table 3.3.10-1.

E.1 and E.2 If the Required Action and associated Completion Time of Condition C are not met, and Table 3.3.10-1 (see basis for Required Action D.1) directs entry into Condition E, the plant must be brought to a MODE in which the requirements of this LCO do not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems..

F.1 Alternate means of monitoring containment area radiation have been developed and tested. These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. The Revision 19 CALVERT CLIFFS -

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PAM Instrumentation B 3.3.10 BASES HJTC-based reactor vessel water level instrumentation is one of three components of the inadequate core cooling instrumentation. The SMM instrumentation and CETs could be used to monitor inadequate core cooling. If these alternate means are used, the Required Action is not to shut down the plant, but rather to follow the directions of Specification 5.6.7. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels.

SURVEILLANCE A Note at the beginning of the SRs specifies that the REQUIREMENTS following SRs apply to each PAM instrumentation Function in Table 3.3.10-1.

SR 3.3.10.1 Performance of the CHANNEL CHECK once every 31 days ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one indication channel to a similar parameter on other channels. It is based on the assumption that indication channels monitoring the same parameter should read approximately the same value. Significant deviations between the two indication channels could be an indication of excessive instrument drift in one of the channels or of something more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a qualitative assessment of the indication channel that considers indication channel uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.

If the channels are within the criteria, it is an indication that the channels are OPERABLE. If the channels are normally off-scale during times when surveillance testing is required, the CHANNEL CHECK will only verify that they are off-scale in the same direction. Off-scale low current loop Revision 19 CALVERT CLIFFS - UNITS 1 CLIFFS - UNITS &2 I & 2 B 3.3.10-15 B 3.3.10-15 Revision '19

PAM Instrumentation B 3.3.10 BASES channels are verified to be reading at the bottom of the range and not failed down-scale.

The Frequency of 31 days is based upon plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one indication channel of a given Function in any 31 day interval is a rare event. The CHANNEL CHECK supplements less formal, but more frequent, checks of channel during normal operational use of the displays associated with this LCO's required channels.

SR 3.3.10.2 Deleted.

SR 3.3.10.3 A CHANNEL CALIBRATION .isperformed every 24 months or approximately every refueling. CHANNEL CALIBRATION is a check of the indication channel including the sensor. The SR verifies the channel responds to the measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION of the CIV position indication channels will consist of verification that the position indication changes from not-closed to closed when the valve is exercised to the isolation position as required by Technical Specification 5.5.8, Inservice Testing Program. The position switch is the sensor for the CIV position indication channels. A Note allows exclusion of neutron detectors, CETs, and reactor vessel level (HJTC) from the CHANNEL CALIBRATION.

The Frequency is based upon operating experience and consistency with the typical industry refueling cycle and is justified by an 24 month calibration interval for the determination of the magnitude of equipment drift.

REFERENCES 1. Letter from Mr. R. E. Denton (BGE) to NRC Document Control Desk, dated June 6, 1995, "License Amendment Request; Extension of Instrument Surveillance Intervals"

2. Letter from Mr. J. A. Tiernan (BGE) to NRC Document Control Desk, dated August 9, 1988, "Regulatory Guide 1.97 Review Update"

& 22 B 3.3.10-16 Revision 19 CALVERT CLIFFS -

UNITS 1 CLIFFS - UNITS 1& B 3.3.10-16 Revision 19

PAM Instrumentation B 3.3.10 BASES

3. Regulatory Guide 1.97, "Instrumentation for Light-Water-Cooled Nuclear Power Plants To Assess Plant and Environs Conditions During and Following an Accident (Errata Published July 1981), December 1975

4. NUREG-0737, Supplement 1, Requirements for Emergency Response Capabilities (Generic Letter 82-33),

December 17, 1982

5. UFSAR, Chapter 7, "Instrumentation and Control" 2 B 3.3.10-17 Revision 19

- UNITS 11 &

CALVERT CLIFFS - UNITS & 2 B 3.3.10-17 Revision 19

PAM Instrumentation B 3.3.10 BASES Substitute Table 3.3.10-1 (page 1 of 2)

Post-Accident Monitoring Instrumentation CONDITIONS REQUIRED REFERENCED INDICATION FROM REQUIRED FUNCTION CHANNELS ACTION D.1

1. Wide Range Logarithmic Neutron Flux 2 E A a-ult: A .s * *I C. nual-C0L %uuIloiL ululJb. Ju1Xiul L

3. Reactor Coolant Inlet Temperature 2 E

4. RCS Subcooled Margin Monitor 1 N/A

5. Reactor Vessel Water-Level 2 F

6. Containment Water Level (wide 2 E range)

7. Containment Pressure 2 E

8. Containment Isolation Valve 2 per penetration E Position flow path(a)(b)

9. Containment Area Radiation (high 2 F range)

10. Pressurizer Pressure (wide range) 2 E

11. Steam Generator Pressure 2 per steam E generator

12. Pressurizer Level 2 E

13. Steam Generator Water Level (wide 2 per steam E range) generator Revision 19 UNITS 1 CALVERT CLIFFS - UNITS I 8& 2 2 B 3.3.10-18 B 3.3.10-183 Revision 19

- PAM Instrumentation B 3.3.10 BASES Substitute Table 3.3.10-1 (page 2 of 2)

Post-Accident Monitoring Instrumentation

CONDITIONS REQUIRED REFERENCED INDICATION FROM REQUIRED FUNCTION CHANNELS ACTION D.1

14. Condensate Storage Tank Level 2 E

15. Core Exit Temperature-Quadrant 1 2(c) E

16. Core Exit Temperature-Quadrant 2 2( E

17. Core Exit Temperature-Quadrant 3 2(° E

18. Core Exit Temperature-Quadrant 4 2(W) E

19. Pressurizer Pressure (low range) 2 E (a) Not required for isolation valves whose associated penetration is isolated by at least one closed and de-activated automatic valve, closed manual valve, check valve with flow through the valve secured, blind flange, or equivalent.

(b) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

') A channel consists of two or more core exit thermocouples.

&2 B 3.3.10-19 Revision 19 UNITS 1 CALVERT CLIFFS - UNITS 1& 2 B 3.3.'10-19 Revision 19

Wide Range Logarithmic Neutron Flux Monitor Channels B 3.3.12 B 3.3 INSTRUMENTATION B 3.3.12 Wide Range Logarithmic Neutron Flux Monitor Channels BASES BACKGROUND The wide range logarithmic neutron flux monitor channels provide neutron flux power indication from < 1E-7% RATED THERMAL POWER to > 100% RATED THERMAL POWER. They also provide reactor protection when the RTCBs are shut, in the form of a Rate of Change of Power-High trip.

This LCO addresses MODEs 3, 4, and 5 with the RTCBs open. I When the RTCBs are shut, the wide range logarithmic neutron flux monitor channels are addressed by LCO 3.3.2. I When the RTCBs are open, two of the four wide range logarithmic neutron flux monitor channels must be available to monitor neutron flux power. In this application, the RPS channels need not be OPERABLE since the reactor trip Function is not required. By monitoring neutron flux power when the RTCBs are open, loss of SHUTDOWN MARGIN (SDM) I caused by boron dilution can be detected as an increase in flux. Alarms are also provided when power increases above the fixed bistable setpoints. Two channels must be OPERABLE to provide single failure protection and to facilitate detection of channel failure by providing CHANNEL CHECK capability.

APPLICABLE The wide range logarithmic neutron flux monitor channels SAFETY ANALYSES are necessary to monitor core reactivity changes. They are the primary means for detecting and triggering operator actions to respond to reactivity transients initiated from conditions in which the RPS is not required to be OPERABLE.

They also trigger operator actions to anticipate RPS actuation in the event of reactivity transients starting from shutdown or low power conditions.

The OPERABILITY of wide range logarithmic neutron flux monitor channels is not necessary to meet the assumptions of the safety analyses and provide for the mitigation of accident and transient conditions.

The wide range logarithmic neutron flux monitor channels satisfy 10 CFR 50.36(c)(2)(ii), Criterion 3.

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& 2 UNITS 11 & 2 B -3.3.12-1 Revision 2

Wide Range Logarithmic Neutron Flux Monitor Channels B 3.3.12 BASES LCO The LCO on the wide range logarithmic neutron flux monitor channels ensures that adequate information is available to verify-core reactivity conditions while shut down. A minimum of two wide range logarithmic neutron flux monitor channels are required to be OPERABLE.

APPLICABILITY In MODEs 3, 4, and 5, with RTCBs open or the CEDM System not capable of CEA withdrawal, wide range logarithmic neutron flux monitor channels must be OPERABLE to monitor core power for reactivity changes. In MODEs 1 and 2, and in MODEs 3, 4, and 5 with the RTCBs shut and the CEAs capable of withdrawal, the wide range logarithmic neutron flux monitor channels are addressed as part of the RPS in LCO 3.3.1.

The requirements for source range neutron flux monitoring in MODE 6 are addressed in LCO 3.9.2. The source range nuclear instrumentation channels provide neutron flux coverage the logarithmic channels use during refueling, when neutron flux may be extremely low. They are built into the wide range logarithmic neutron flux channels and PAM channels.

ACTIONS A.1 and A.2 With one required channel inoperable, it may not be possible to perform a CHANNEL CHECK to verify that the other required channel is OPERABLE. Therefore, with one or more required channels inoperable, the wide range logarithmic neutron flux monitoring Function cannot be reliably performed.

Consequently, the Required Actions are the same for one required channel inoperable or more than one required channel inoperable. The absence of reliable neutron flux indication makes it difficult to ensure SDM is maintained.

Required Action A.1 restricts the addition of positive reactivity (e.g., temperature or boron fluctuations associated with RCS inventory management or temperature control) to those that are accounted for in the calculated SDM.

SHUTDOWN MARGIN must be verified periodically to ensure that it is being maintained. Both required channels must be restored as soon as possible. The initial Completion-Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , and once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter, to perform SDM verification takes into consideration that Required-.

Action A.1 eliminates many of the means by which SDM can be CAVRTCIFS-UNT 1&2 .. 1- Rvsin1 CALVERT CLIFFS - UNITS 1 & 2 B 3.3.12-2 Revision 19

RCS Loops - MODE 3 B 3.4.5 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.5 RCS Loops - MODE 3 BASES BACKGROUND The primary function of the reactor coolant in MODE 3 is removal of decay heat and transfer of this heat, via the SGs, to the secondary plant fluid. The secondary function of the reactor coolant is to act as a carrier for soluble neutron poison, boric acid.

In MODE 3, RCPs are used to provide forced circulation heat I removal during heatup and cooldown. The MODE 3 decay heat removal requirements are low enough that a single RCS loop with one RCP is sufficient to remove core decay heat.

However, two RCS loops (i.e., RCS loop Nos. 11 and 12 for Unit 1 and RCS loop Nos. 21 and 22 for Unit 2) are required to be OPERABLE to provide redundant paths for decay heat removal. Only one RCP needs to be OPERABLE to declare the associated RCS loop OPERABLE.

Reactor coolant natural circulation is not normally used but is sufficient for core cooling. However, natural circulation does not provide turbulent flow conditions.

Therefore, boron reduction in natural circulation is prohibited because mixing to obtain a homogeneous concentration in all portions of the RCS cannot be ensured.

APPLICABLE Failure to provide heat removal may result in challenges to SAFETY ANALYSES a fission product barrier. The RCS loops are part of the primary success path, that functions or actuates to prevent or mitigate a DBA or transient that either assumes the failure of, or presents a challenge to, the integrity of a fission product barrier.

Reactor Coolant System Loops - MODE 3 satisfy I 10 CFR 50.36(c) (2)(ii), Criterion 3.

LCO The purpose of this LCO is to require two RCS loops to be available for heat removal, thus providing redundancy. The LCO requires the two loops to be OPERABLE with the intent of requiring both SGs to be capable (> -50 inches water level) of transferring heat from the reactor coolant at a controlled rate. Forced reactor coolant flow is the required way to transport heat, although natural circulation C

V AR L FS - NT 3. 4 - Re i io CALVERT CLIFFS -.-UNITS 1 & 2 B 3.4.5-1 Revision 2

RCS Loops - MODE 3 B 3.4.5 BASES flow provides adequate removal. A minimum of one running RCP meets the LCO requirement for one loop in operation.

Note 1 permits a limited period of operation without RCPs.

All RCPs may not be in operation for < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per eight hour period and < 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months per eight hour period for low flow testing. This means that natural circulation has been established. When in natural circulation, a reduction in boron concentration with water at a boron concentration less than required to assure that the SHUTDOWN MARGIN (SDM) of LCO 3.1.1 is maintained, is prohibited because an even concentration distribution throughout the RCS cannot be ensured. Core outlet temperature is to be maintained at least 10OF below the saturation temperature so that no vapor bubble may form and possibly cause a natural circulation flow obstruction.

In MODE 3, it is sometimes necessary to stop all RCPs (e.g., to perform surveillance or startup testing). The time period is acceptable because natural circulation is adequate for heat removal and the reactor coolant temperature can be maintained subcooled.

Note 2 requires that all of the following three conditions be satisfied before an RCP can be started when any RCS cold leg temperature is < 3650 F (Unit 1), < 3010 F (Unit 2):

a. the pressurizer water level is < 170 inches;

b. the pressurizer pressure is 5 300 psia (Unit 1),

< 320 psia (Unit 2); and

c. the secondary water temperature of each SG is < 300 F above the RCS temperature. The RCS temperature used for this AT evaluation is the average RCS temperature.

It may be conservatively measured using the cold leg, SDC return to the RCS, or, more accurately, the average RCS temperature depending on conditions. Where the measurement is taken is controlled by plant procedures.

Ensuring the above conditions are satisfied will preclude a power-operated relief valve (PORV) from opening as a result of the pressure surge in the RCS, when an RCP is started.

CALVERT CLIFFS - UNITS 1 & 2 -B 3.4.5-2 Revision 19

RCS Loops - MODE 3 B 3.4.5 BASES An OPERABLE loop consists of at least one OPERABLE RCP and an SG that is OPERABLE in accordance with the Steam Generator Tube Surveillance Program. An RCP is OPERABLE if it is capable of being powered and is able to provide forced flow, if required.

APPLICABILITY In MODE 3, the heat load is lower than at power; therefore, one RCS loop in operation is adequate for transport and heat removal. A second RCS loop is required to be OPERABLE but not in operation for redundant heat removal capability.

Operation in other MODEs is covered by: LCO 3.4.4, LCO 3.4.6, LCO 3.4.7, LCO 3.4.8, LCO 3.9.4, and LCO 3.9.5.

ACTIONS A.1 If one required RCS loop is inoperable, redundancy for forced flow heat removal is lost. The Required Action is restoration of the required RCS loop to OPERABLE status within a Completion Time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This time allowance is a justified period to be without the redundant, nonoperating loop, because a single loop in operation has a heat transfer capability greater than that needed to remove the decay heat produced in the reactor core.

B.1 If restoration is not possible within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the unit must be placed in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . In MODE 4, the plant may be placed on the Shutdown Cooling (SDC) System.

The Completion Time of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is compatible with required operation to achieve cooldown and depressurization from the existing plant conditions in an orderly manner and without challenging plant systems.

C.1 and C.2 If no RCS loop is in operation, except as provided in Note 1 in the LCO section, all operations involving introduction of water into the RCS with a boron concentration less than that required to meet the minimum SDM of LCO 3.1.1 must be immediately suspended. Action to restore one RCS loop to OPERABLE status and operation shall be initiated immediately and continued until one RCS loop is restored to OPERABLE Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

& 2 1 & 2 B 3.4.5-3 B 3.4.5-3 Revision 19

RCS Loops - MODE 3 B 3.4.5 BASES status and operation. Suspending the introduction of water into the RCS with a boron concentration less than that required to meet the minimum SDM of LCO 3.1.1 is required to assure continued safe operation. When water is added without forced circulation, unmixed coolant could be introduced to the core, however water added with a boron concentration meeting the minimum SDM maintains an acceptable margin to subcritical operations. The immediate Completion Times reflect the importance of maintaining operation for decay heat removal.

SURVEILLANCE SR 3.4.5.1 REQUIREMENTS This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that the required number of RCS loops are in operation. Verification includes flow rate, temperature, and pump status monitoring, which help ensure that forced flow is providing heat removal. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval has been shown by operating practice to be sufficient to regularly assess degradation and verify operation within safety analyses assumptions. In addition, Control Room indication and alarms will normally indicate loop status.

SR 3.4.5.2 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that the secondary side water level in each SG is > -50 inches. An adequate SG water level is required in order to have a heat sink for removal of the core decay heat from the reactor coolant. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval has been shown by operating practice to be sufficient to regularly assess degradation and verify operation within the safety analyses assumptions.

SR 3.4.5.3 Verification that the required number of RCPs are OPERABLE ensures that the single failure criterion is met and that an additional RCS loop can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power availability to the required RCPs. The Frequency of seven days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.

Revision 19 CALVERT CLIFFS CALVERT UNITS 1 CLIFFS - UNITS 1&& 2 2 B 3.4.5-4 B 3.4.5-4 .Revision 19

RCS Loops - MODE 3 B 3.4.5 BASES REFERENCES None

& 22 B 3.4.5-5 Revision 19

- UNITS 1 CALVERT CLIFFS - UNITS 1& B 3.4.5-5 Revision 19

RCS Loops - MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops - MODE 4 BASES r

DACK OUINDn in MODE 4, the primary function of the reaeter coolant 4s the removal of decay heat and transfer of this heat to the SGs or SDC.heat exchangers. The secondary function of the reactor coolant is to act as a carrier for soluble neutron poison, boric acid.

In MODE 4, either RCPs or SDC loops can be used for coolant circulation.. The intent of this LCO is to provide forced flow from at least one RCP or one SDC loop for decay heat removal and transport. The flow provided by one RCP or SDC loop is adequate' for heat removal. The other intent of this LCO is to require.that two paths be available to.provide redundancy for heat removal. For Unit 1, the two paths can be any combination of RCS loop No. 11, RCS loop No. 12, SDC loop No. 11, or SDC loop No. 12. For Unit 2, the two paths can be any combination of RCS loop No. 21, RCS loop No. 22, SDC loop No. 21, or SDC loop No. 22.

APPLICABLE In MODE 4, RCS circulation is considered in the SAFETY ANALYSES determination of the time available for mitigation of the accidental boron dilution event. The RCS and SDC loops provide this circulation.

Reactor Coolant System loops - MODE 4 have been identified

. in 10 CFR 50.36(c)(2)(ii) as important contributors to risk reduction.

LCO The purpose of this LCO is to require that at least two loops, RCS or SDC, be OPERABLE in MODE 4, and one of these loops be in.operation. The LCO allows the two loops that.

are required to be OPERABLE to consist of any combination of RCS and SDC System loops.. Any one loop in operation provides enough flow to remove the decay heat from the core with forced circulation. An additional loop is required to be OPERABLE to provide redundancy 'for heat removal.'

Note 1 permits all RCPs and SDC pumps to not be in operation

< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per eight hour period. The Note prohibits boron dilution with water at a boron concentration less than that required to assure the SDM of LCO 3.1.1 is maintained when CALVERT CLIFFS - UNITS 1 & 2 B 3.4.6-1 - Revision 19

RCS Loops - MODE 4 B 3.4.6 BASES forced flow is stopped because an even concentration distribution cannot be ensured. Core outlet temperature is to be maintained at least 10'F below saturation temperature so that no vapor bubble may form and possibly cause a natural circulation flow obstruction. The response of the RCS without the RCPs or SDC pumps depends on the core decay heat load and the length of time that the pumps are stopped.

As decay heat diminishes, the effects on RCS.temperature and pressure diminish. Without cooling by forced flow, higher heat loads will cause the reactor coolant temperature and pressure to increase at a rate proportional to the decay heat load. Because pressure can increase, the applicable system pressure limits [P/T limits or low temperature overpressure protection (LTOP) limits] must be observed and forced.SDC flow or heat removal via the SGs must be re-established prior to reaching the pressure limit. The circumstances for stopping both RCPs or SDC pumps are to be limited to situations where:

a. Pressure and temperature increases can be maintained well within the allowable pressure (P/T limits and LTOP) and 100 F subcooling limits; or

b. An alternate heat removal path through the SGs is in operation.

Note 2 requires that the following conditions be satisfied before an RCP may.be started with any RCS cold leg temperature.< 3650 F (Unit 1), < 301OF (Unit 2):

a. Pressurizer water level is < 170 inches;

b. Pressurizer pressure is < 300 psia (Unit 1), < 320 psia (Unit 2); and

c. Secondary side water temperature in each SG is < 300 F above the RCS.temperature. The RCS temperature used for this AT evaluation is the average RCS temperature.

It may be conservatively measured using the cold leg, SDC return to the'RCS, or, more accurately, the average RCS temperature depending on conditions. Where-the measurement is taken is controlled by plant procedures.

Satisfying the above conditions will preclude a PORV from opening due to a pressure surge in the RCS when the RCPis started.

Revision 19 CALVERT CLIFFS -

UNITS 1 CLIFFS - UNITS 1 &2

& 2. B 3.4.6-2

'B 3.4.6-2 Revision 19

RCS Loops - MODE 4 B 3.4.6 BASES An OPERABLE RCS loop consists of at least one OPERABLE RCP and an SG that is OPERABLE in accordance with the Steam Generator Tube Surveillance Program, and has the minimum water level specified in SR 3.4.6.2.

Similarly, for the SDC System, an OPERABLE SDC loop is composed of the OPERABLE SDC pump(s) capable of providing forced flow to the SDC heat exchanger(s). Reactor coolant pumps and SDC pumps are OPERABLE if they are capable of being powered and are able to provide flow if required.

APPLICABILITY In MODE 4, this.LCO applies because it is possible to remove core decay heat and to provide proper boron mixing with either the RCS loops and SGs, or the SDC System.

Operation in other MODEsjis covered by: LCO 3.4.4, LCO 3.4.5, LCO 3.4.7, LCO 3.4.8, LCO 3.9.4, and LCO 3.9.5.

ACTIONS A.1 If only one required RCS loop is OPERABLE and in operation, and no SDC loops are OPERABLE, redundancy for heat removal is lost. Action must be initiated immediately to restore a second loop to OPERABLE status. The immediate Completion Time reflects the importance of maintaining the availability of two paths for decay heat removal.

B.1 If one required SDC loop is OPERABLE and in operation and no RCS loops are OPERABLE, redundancy for heat removal is lost.

The plant must be-placed in MODE 5 within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Placing the plant in MODE 5 is a conservative action with regard to decay heat removal. With only one SDC loop OPERABLE, redundancy for decay heat removal is lost and, in the event of a loss of the remaining SDC loop, it would be safer to initiate that loss from MODE 5 (< 2000F) rather-than MODE 4 (> 2001F to < 300F). The Completion Time of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is reasonable, based on operating experience, to reach MODE 5 from MODE 4, with only one SDC loop operating, in an orderly manner and without challenging plant systems.

Revision 8 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS CALVERT -

&.2.2 .

1 & B 3.4.6-3 B 3.4.6-3 -Revision 8

RCS Loops - MODE 4 B 3.4.6 BASES C.1 and C.2 If no RCS or SDC loops are OPERABLE or in operation, except during conditions permitted by Note 1 in the LCO section, all operations involving introduction of water into the RCS with a boron concentration less than that-required to meet the minimum SDM of LCO 3.1.1, must be suspended and action to restore one RCS or SDC loop to OPERABLE status and operation must be initiated. The required margin to criticality must not be reduced in this type of operation.

Suspending the introduction of water into the RCS with a boron concentration less than that required to meet the minimum SDM of LCO 3.1.1 is required to assure continued safe operation. When water is added without forced circulation, unmixed coolant could be introduced to the core, however water added with a boron concentration meeting the minimum SDM maintains an acceptable margin to subcritical operations. The immediate Completion Times reflect the importance of decay heat removal. The action to restore must continue until one loop is restored to operation.

SURVEILLANCE SR 3.4.6.1 REQUIREMENTS This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one required loop is in operation. This ensures forced flow is providing heat removal. Verification includes flow rate, temperature, or pump status monitoring. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency has been shown by operating practice to be sufficient to regularly assess RCS loop status. In addition, Control Room indication and alarms will normally indicate loop status.

SR 3.4.6.2 This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of secondary side water level in the required SG(s) > -50 inches. An adequate SG water level is required in order to have a heat sink for removal of the-core decay heat from the reactor coolant. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval has been shown by operating practice to be sufficient to regularly assess degradation and verify operation within safety analyses assumptions.

CALVERT CLIFFS - UNITS 1 & 2 B 3.4.6-4 Revision 19

RCS Loops - MODE 4 B 3.4.6 BASES SR 3.4.6.3 Verification that the required pump is OPERABLE ensures that an additional RCS or SDC loop can be placed in operation, if needed to maintain decay heat removal and reactor coolant circulation.. Verification is performed by verifying proper breaker alignment and power available to the required loop components that are not in operation. For an RCS loop, the required component is a pump. For an SDC loop, the required components are the pump and valves. The Frequency of seven days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.

REFERENCES None CALVERT CLIFFS - UNITS 1 & 2 3 B 3.4.6-5 Revision 19

RCS Loops - MODE 5, Loops Filled B 3.4.7 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.7 RCS Loops - MODE 5, Loops Filled -

BASES BACKGROUND In MODE 5 with the RCS loops filled, the primary function of the reactor coolant is the removal of decay heat, and the transfer of this heat either to the SG secondary side coolant, or the component cooling water via the SDC heat exchangers. While the principal means for decay heat removal is via the SDC System, the SGs are specified as a backup means for redundancy. Even though the SGs cannot produce steam in this MODE, they are capable of being a heat sink due to their large contained volume of secondary side water. As long as the SG secondary side water is at a lower temperature than the reactor coolant, heat transfer will occur. The rate of heat transfer is directly proportional to the temperature difference. Due to the non-condensable I gasses that come out of solution and restrict flow through the SG tubes, the SGs can only be credited when the RCS is capable of being pressurized. The secondary function of the reactor coolant is to act as a carrier for soluble neutron poison, boric acid.

In MODE 5 with RCS loops filled, the SDC loops are the principal means for decay heat removal. The number of loops in operation can vary to suit the operational needs. The intent of this LCO is to provide forced flow from at least one SDC loop for decay heat removal and transport. The flow provided by one SDC loop is adequate for decay heat removal.

The other intent of this LCO is to require that a second path be available to provide redundancy for decay heat removal.

The LCO provides for redundant paths of decay heat removal capability. The first path can be an SDC loop (i.e., SDC loop No. 11 or No. 12 for Unit 1, and SDC loop No. 21 or No. 22 for Unit 2) that must be OPERABLE and in operation.

The second path can be another OPERABLE SDC loop (i.e., SDC loop No. 11 or No. 12 for Unit 1, and SDC loop No. 21 or No. 22 for Unit 2), or through the SGs, each having an adequate water level.

Revision 2 CALVERT CALVERT CLIFFS - UNITS 1 CLIFFS - UNITS & 2 1 & 2 B 3.4.7-1 B 3.4-.7-1 Revision 2

RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES APPLICABLE In MODE 5, RCS circulation is considered in the SAFETY ANALYSES determination of the time available for-mitigation of the accidental boron dilution event. The SDC loops provide this circulation.

Reactor Coolant System loops - MODE 5 (Loops Filled) have been identified in 10 CFR 50.36(c)(2)(ii) as important contributors to risk reduction.

LCO The purpose of this LCO is to require at least one of the SDC loops be OPERABLE and in operation with an additional SDC loop OPERABLE, or secondary side water level of each SG shall be 2 -50 inches. One SDC loop provides sufficient forced circulation to perform the safety functions of the reactor coolant under these conditions. The second SOC loop is normally maintained OPERABLE as a backup to the operating SDC loop, to provide redundant paths for decay heat removal.

However, if the standby SDC loop is not OPERABLE, a sufficient alternate method to provide redundant paths for decay heat removal is two SGs with their secondary side water levels 2 -50 inches. Should the operating SDC loop fail, the SGs could be used to remove the decay heat.

Note 1 permits all.SDC pumps to not be in operation

< 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per eight hour period. The circumstances for stopping both SDC loops are to be limited to situations where P/T increases can be maintained well within the allowable pressure (P/T and LTOP) and 100F subcooling limits, or an alternate heat removal path through the SG(s) is in operation.

This LCO is modified by a Note that prohibits boron dilution with water at a boron concentration less than that required to assure the SDM of LCO 3.1.1 is maintained when SDC forced flow is stopped because an even concentration distribution cannot be ensured. Core outlet-temperature is to be maintained at least 10OF below saturation temperature, so that no vapor bubble would form and possibly cause a natural circulation flow obstruction.. In this MODE, the SG(s) can be used as the backup for SDC heat removal. To ensure their availability, the RCS loop flow path is to be maintained with subcooled liquid.

CALVERT CLIFFS - UNITS 1 & 2 B,3.4.7-2 Revision 19

RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES In MODE 5, it is sometimes necessary to stop all RCP or SDC forced circulation. This is permitted to change operation from one SDC loop to the other, perform surveillance or startup testing, perform the transition to and from the SDC, or to avoid operation below the RCP minimum net positive suction head limit. The time period is acceptable because natural circulation is acceptable for decay heat removal, the reactor coolant temperature can be maintained subcooled, and boron stratification affecting reactivity control is not expected.

Note 2 allows one SDC loop to be inoperable for a period of up to two hours, provided that the other SDC loop is OPERABLE and in operation. This permits periodic surveillance tests to be performed on the inoperable loop during the only time when such testing is safe and possible.

Note 3 requires that the following conditions be satisfied before an RCP may be started with any RCS cold leg temperature < 3650F (Unit 1), < 3010F (Unit 2):

a. Pressurizer water level must be < 170 inches;

b. Pressurizer pressure < 300 psia (Unit 1), < 320 psia (Unit 2); and

c. Secondary side water temperature in each SG must be

< 300F above the RCS temperature. The RCS temperature used for this AT evaluation is the average RCS temperature. It may be conservatively measured using the cold leg, SDC return to the RCS, or, more accurately, the average RCS temperature depending on conditions. Where the measurement is taken is controlled by plant procedures.

Satisfying the-above conditions will preclude opening a PORV during a pressure transient when the RCP is started.

Note 4 provides for an orderly transition from MODE 5 to MODE 4 during a planned heatup by permitting SDC loops to not be in operation when at least one RCP is in operation.

This Note provides for the transition to MODE 4 where an RCP is permitted to be in operation and replaces the RCS circulation function provided by the SDC loops.

Revision 19 CALVERT CLIFFS CALVERT -

UNITS 1 CLIFFS - UNITS & 22 I & B 3.4.7-3 B 3.4.7-3 Revision 19

. RCS Loops - MODE 5, Loops-Filled B 3.4.7 BASES An OPERABLE SDC loop is composed of an OPERABLE SDC pump and an OPERABLE SDC heat exchanger.

__ ___ - _-_ _ _SDC-pumps- are -OPERABLE- 4f-t-hey-are-c-apabl-e*-of-bei ng -powered-and are able to provide flow if required. An OPERABLE SG can perform as a heat sink when it has an adequate water level and is OPERABLE in accordance with the Steam Generator Tube Surveillance Program.

APPLICABILITY In MODE 5 with RCS loops filled, this LCO requires forced circulation to remove decay heat from the core and to provide proper boron mixing. One SDC loop provides sufficient circulation for these purposes.

Operation in other MODEs is covered by: LCO 3.4.4, LCO 3.4.5, LCO 3.4.6, LCO 3.4.8, LCO 3.9.4, and LCO 3.9.5.

ACTIONS A.1 and A.2 If the required SDC loop is inoperable and any SGs have secondary side water levels < -50 inches, redundancy for heat removal is lost. Action must be initiated immediately to restore a second SDC loop to OPERABLE status or.to restore the water level in the required SGs. Either Required Action A.1 or Required Action A.2 will restore redundant decay heat removal paths. The immediate Completion Times reflect the importance of maintaining the availability of two paths for decay heat removal.

B.1 and B.2 If no SDC loop is in operation, except as permitted in Note 1, all operations involving introduction of water into the RCS with a boron concentration less than that required, to meet the minimum SDM of LCO 3.1.1 must be suspended.

Action to restore one SDC loop to OPERABLE status and place it in operation must be initiated. The required margin to criticality must not be reduced in this type of operation.

Suspending the introduction of water into the RCS with a boron concentration less than that required to meet the minimum SDM of LCO 3.1.1 is required to assure.continued safe operation. When water is added without forced circulation, unmixed coolant could be introduced to the core, however water added with a boron concentration meeting

,A, lrnTPI TrrC _ ITIreC 1 0 2, M A '7A - On

-; DAd LMLVrtK1 %,LlrrD - l viii 1 at L D J.+/-t nteVl S on IV

.RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES the minimum'SDM maintains an acceptable margin to subcritical operations. The immediate Completion Times reflect the importance of maintaining operation for decay

-heat-removal-SURVEILLANCE SR 3.4.7.1 REQUIREMENTS This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one SDC loop is in operation. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing decay heat removal. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency has been shown by operating practice to be sufficient to regularly assess degradation and verify operation is within safety analyses assumptions. In addition, Control Room indication and alarms will normally indicate loop status.

The SDC flow is established to ensure that core outlet temperature is maintained sufficiently below saturation to allow time for swapover to the standby SDC loop should the operating loop be lost.

SR 3.4.7.2 Verifying the SGs are OPERABLE by ensuring their secondary side water levels are 2 -50 inches ensures that redundant heat removal paths are available if the second SDC loop is inoperable. This surveillance test is required to be performed when the LCO requirement is being met by use of the SGs. If both SDC loops are OPERABLE, this SR is not needed. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency has been shown by operating practice to be sufficient to regularly assess degradation and verify operation within safety analyses assumptions.

SR 3.4.7.3 Verification that the second SDC loop is OPERABLE ensures that redundant paths for decay-heat removal are available.

The requirement also ensures that the additional loop can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the required pumps and valves that are not in operation. This surveillance test is required to be CALVERT CLIFFS - UNITS 1 & 2 B 3.4.7-~5 Revision 19

RCS Loops MODE 5, Loops Filled B 3.4.7 BASES performed when the'LCO requirement is being met by one of two SDC loops, e.g., both SGs have < -50 inches water level. The Frequency of seven days is considered reasonable

in-v-iew-of- other--administ-rat-ive cont-rol-s-ava-i-lable-and -has----- - -

been shown to be acceptable by operating experience.

REFERENCES None Revision 19 CALVERT CLIFFS - UNITS UNITS 1 &2 1 & 2 B 3.4.7-6 B 3.4.7-6 Revision'19

RCS Loops - MODE 5,. Loops Not Filled B 3.4.8 B 3.4 REACTOR COOLANT SYSTEM (RCS)

B 3.4.8 RCS Loops - MODE 5, Loops Not Filled BASES

- BACKGROUND_ _- - iIs- 0 5ib .ODE .itbheRCS loops- not fi U edl, theprimary _- - - - - -

function of the reactor coolant is the removal of decay heat and transfer of this heat to the SDC heat exchangers. The SGs are not available as a heat sink when the loops are not I filled. The secondary function of the reactor coolant is to act as a carrier for the soluble neutron poison, boric acid.

In MODE 5 with loops not filled, only the SDC System can be used for coolant circulation. The number of loops in operation can vary to suit the operational needs. The intent of this LCO is to provide forced flow from at least one SDC loop for decay heat removal and transport and to require that two paths (i.e., SDC loop No. 11 or No. 12 for Unit 1, and SDC loop No. 21 or No. 22 for Unit 2) be l1 available to provide redundancy for heat removal.

APPLICABLE In MODE 5, RCS circulation is considered in determining SAFETY ANALYSES the time available for mitigation of the accidental boron dilution event. The SDC loops provide this circulation.

The flow provided by one SDC loop is adequate for decay heat removal and for boron mixing.

Reactor Coolant System loops - MODE 5 (loops not filled) satisfy 10 CFR 50.36(c)(2)(ii), Criterion 4.

LCO The purpose of this LCO is to require a minimum of two SDC loops be OPERABLE and one of these loops be in operation.

An OPERABLE loop is one that is capable of transferring heat from the reactor coolant at a controlled rate. Heat cannot be removed via the SDC System unless forced flow is used. A minimum of one running SDC pump meets the LCO requirement for one loop in operation. An additional SDC loop is required to be OPERABLE to meet the single failure criterion.

Note 1 permits the SOC pumps to not be in operation for

< 15 minutes when switching from one loop to another. The circumstances for stopping both SDC pumps are to be limited to situations when theoutage time is short and the core outlet temperature is maintained at least 101F below .

CALVERT CLIFFS - UNITS 1 & 2 B 3.4.8-1 Revision 2

RCS Loops - MODE 5, Loops Not Filled B 3.4.8 BASES saturation temperature. The Note prohibits boron dilution with water at a boron concentration less than that required to assure the SDM of LCO 3.1.1 is maintained or draining operations when SDC forced -flow is *stopped.

I' Note 2 allows one SDC loop to be inoperable for a period of two hours provided that the other loop is OPERABLE and in operation. This permits periodic surveillance tests to be performed on the inoperable loop during the only time when these tests are safe and possible.

An OPERABLE SDC loop is composed of an OPERABLE SDC pump capable of providing forced flow to an OPERABLE SDC heat exchanger, along with the appropriate flow and temperature instrumentation for control, protection, and indication.

Shutdown cooling pumps are OPERABLE if they are capable of being powered and are able to provide flow if required.

APPLICABILITY In MODE 5 with loops not filled, this LCO requires core heat removal and coolant circulation by the SDC System.

Operation in other MODEs is covered by: LCO 3.4.4, LCO 3.4.5, LCO 3.4.6, LCO 3.4.7, LCO 3.9.4, and LCO 3.9.5.

ACTIONS A.1 If the required SDC loop is inoperable, redundancy for heat removal is lost. Action must be initiated immediately to restore a second loop to OPERABLE status. The Completion Time reflects the importance of maintaining the availability of two paths for heat removal.

B.1 and B.2 If no SDC loop is OPERABLE or in operation, except as provided in Note 1, all operations involving introduction of water into the RCS with a boron concentration less than that required to meet the minimum SDM of LCO 3.1.1 must be suspended. Action to restore one SDC loop to OPERABLE status and place it in operation must be initiated immediately. The required margin to criticality must not be reduced in this type of operation. Suspending the introduction of water into the RCS with a boron concentration less than that required to meet the minimum PAIt xfrT rI TtCC IIMTTC I P 9 2 i3 A 0 - Dl....;^n tn WiLvV l ARILI V VJ - U1~1 I I a LtC D JOt.0-C McV] bl un AD

RCS Loops. - MODE 5, Loops Not Filled.

B 3.4.8 BASES SDM of LCO 3.1.1 is required to assure continued safe operation. When water is added without forced circulation, unmixed coolant could be introduced to the core, however

...water added with a boron concentration-meeting the minimum SDM maintains an acceptable margin to subcritical.

operations. The immediate Completion Time reflects the importance of maintaining operation for decay heat removal.

SURVEILLANCE SR 3.4.8.1 REQUIREMENTS This SR requires verification every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that one SDC loop is in operation.. Verification includes flow rate, temperature, or.pump status monitoring, which help ensure that forced flow is providing decay heat removal. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency has been shown by operating practice to be sufficient to regularly assess degradation and verify operation is within safety analyses assumptions.

SR 3.4.8.2 Verification that the required number of loops are OPERABLE ensures that redundant paths for heat removal are available and that additional loops can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment.and indicated power available to the required pumps and valves that are not in operation. The Frequency.of seven days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.

REFERENCES None CALVERT CLIFFS - UNITS 1 & 2 B 3.4.8-3 Revision 19

STE RCS Loops - MODES'4 and 5 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Special Test Exception (STE) RCS Loops - MODES 4 and 5 BASES

-.BACKGROUND- ----

This-STE-to LCO-3;-4-.6, LCO-3.4.7, and-LCO 3.4.8, allows no RCS or SDC loops to be in operation during the time intervals required: 1) for local leak rate testing of Containment Penetration Number 41 (SDC); and 2) for maintenance on the common SDC suction line or on the SDC flow control valve (CV-306).

APPLICABLE As described in LCO 3.0.7, compliance with Special Test SAFETY ANALYSIS Exception LCOs is optional, and therefore no criteria of 10 CFR 50.36(c)(2)(ii) applies. Special Test Exception LCOs provide flexibility to perform certain operations by appropriately modifying requirements of other LCOs. A discussion of the criterion satisfied for the other LCOs is provided in their respective Bases.

LCO This LCO is provided to allow for the performance of testing and maintenance in MODEs 4 and 5 (normally after a refueling), where the core cooling requirements are significantly different than after the core has been operating. Without this LCO, plant operations would be held bound to the normal .operation LCOs for reactor coolant loops and circulation (MODEs 4 and 5), and the appropriate tests or maintenance could not be performed in these MODEs.

In MODEs 4 and 5, operation is allowed under no flow conditions provided: the xenon reactivity is < 0.1% Ak/k and approaching stability, no operations are permitted which could cause introduction of water into the RCS with a boron concentration less than that required by LCO 3.9.1, the charging pumps are de-energized, the charging flow paths are isolated, and the SHUTDOWN MARGIN requirement of LCO 3.1.1 is verified at least once per eight hours. These limits along with the SRs ensure no SLs or fuel design limits will be violated.

The exception is allowed even though there are no bounding safety analyses. These tests or maintenance are allowed since they are performed under close supervision during the test program and must stay within the requirements. of.the LCO.

.CALVERT CLIFFS - UNITS 1 & 2 B 3.4.17-1 , Revision 19.

STE RCS Loops - MODES 4 and 5 3.4.17 '

BASES APPLICABILITY The LCO ensures that while within this LCO the plant will not be operated in any other MODE besides MODEs 4 and 5 without forced circulation. This is because the MODEs of Applicability-for-this-Specification -are-MODEs-4-and-5; ---

This Specification allows testing and maintenance to be performed on the SDC System while SDC is required to be I OPERABLE.

ACTIONS A.1 If one or more requirements of the LCO are not met, all activities being performed under this STE must be immediately suspended. These activities are local leak rate testing of the SDC penetration and maintenance on valves in the SDC System. The Completion Time to suspend these activities immediately ensures the plant is not placed in an unanalyzed condition and prevents exceeding the specified acceptable fuel design limits.

SURVEILLANCE SR 3.4.17.1 REQUIREMENTS Xenon reactivity must be verified to be within limits once within one hour prior to suspending the reactor coolant circulation requirements of LCO'3.4.6, LCO 3.4.7, and LCO 3.4.8. The frequency of once within one hour prior to suspending the applicable RCS Loops LCO will ensure that the xenon reactivity is within limits and trending toward stability prior to suspending forced flow cooling. This will ensure no SLs or fuel design limits will be violated while testing or maintenance are being conducted.

SR 3.4.17.2 and SR 3.4.17.3 I

Verifying the charging pumps are de-energized and the charging flow paths are isolated, ensures that the major source of a boron reduction is not available. These two SRs support the requirement that no source be available that could cause an RCS boron concentration reduction. These SRs are required to be verified at a frequency of one hour. The one hour frequency is sufficient to ensure that these sources will niot be available to cause a reduction of the RCS boron concentration.

CALVERT~~~~~

~ ~ ~ ~ B .. 72RvsoCLFS.UIS1&2 CALVERT CLIFFS - UNITS I & 2 B 3.4.17-2 Revision 2

AC Sources-Shutdown B 3.8.2 BASES offsite power available may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIONS and fuel movement. By the allowance of the option-to--declare-required-features--inoperable,-with no offsite power available, appropriate restrictions will be implemented in accordance with the affected required features LCO's ACTIONS.

A.2.1, A.2.2, A.2.3. A.2.4. B.1. B.2. B.3. and B.4 With the offsite circuit not available to all required trains, the option would still exist to declare all required features inoperable. Since this option may involve undesired administrative efforts, the allowance for sufficiently conservative actions is made. With the required DG inoperable, the minimum required diversity of AC power sources is not available. It is, therefore, required to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of the required SHUTDOWN MARGIN (SDM) (MODE 5) or boron concentration (MODE 6).

Suspending positive reactivity additions that could result in failure to meet the minimum SOM or boron concentration limit is required to assure continued safe operation.

Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for the minimum SDM or refueling boron concentration.

This may result in an overall reduction in RCS boron concentration, but provides an acceptable margin to maintaining subcritical operation. Introduction of temperature changes including temperature increases when operating with a positive moderator temperature coefficient (MTC) must also be evaluated to ensure they do not result in a loss of the required SDM.

Suspension of these activities does not preclude completion of actions to establish a safe conservative condition.

These actions minimize the probability or the occurrence of postulated events. It is further required, to immediately initiate action to restore the required AC sources and to continue this action until restoration is accomplished in order to provide the necessary AC power to the unit safety systems.

Revision 19 CALVERT CLIFFS - UNITS I1&& 2 CLIFFS - UNITS 2 B 3.8.2-5 B 3.8.2-5 Revision 19

AC Sources-Shutdown B 3.8.2 BASES The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required AC electrical power sources should be completed. as quickly as possible in order to minimize the time during which the unit safety systems may be without sufficient power.

Pursuant to LCO 3.0.6, the Electrical Distribution System's ACTIONS are not entered even if all AC sources to it are inoperable, resulting in de-energization. Therefore, the Required Actions of Condition A are modified by a Note to indicate that when Condition A is entered with no AC power to any required ESF bus, the ACTIONS for LCO 3.8.10 must be immediately entered. This Note allows Condition A to provide requirements for the loss of the offsite circuit, whether or not a train is de-energized. Limiting Condition for Operation 3.8.10 provides the appropriate restrictions for the situation involving a de-energized train.

SURVEILLANCE SR 3.8.2.1 and SR 3.8.2.2 REQUIREMENTS Surveillance Requirements 3.8.2.1 and 3.8.2.2 require the performance of SRs from LCO 3.8.1 that are necessary for ensuring the OPERABILITY of the AC sources in other than MODEs 1, 2, 3, and 4. Surveillance Requirement 3.8.1.10 is not required to be met, since only one offsite circuit is required to be OPERABLE. Surveillance Requirements 3.8.1.4, 3.8.1.8, 3.8.1.13, and 3.8.1.15 are related to automatic starting of the DGs for an operating unit, which is not applicable for a shutdown unit. Surveillance Requirement 3.8.1.16 is related to LCO 3.8.2.c and 3.8.2.d AC sources, and is addressed by SR 3.8.2.2.

Surveillance Requirement 3.8.2.1 is modified by a Note. The Note lists SRs not required to be performed in order to preclude de-energizing a required 4.16 kV ESF bus or disconnecting a required offsite circuit during performance of SRs. With limited AC Sources available, a single event could compromise both the required circuit and the DG. It is the intent that these SRs must still be capable of being met, but actual performance is not required during periods when the DG and offsite circuit are required to be OPERABLE.

CALVERT CLIFFS - UNITS 1 & 2 B 3.8.2-6 Revision 19

AC Sources-Shutdown B 3.8.2 BASES Refer to the corresponding Bases for LCO 3.8.1 for a discussion of each SR.

REFERENCES None Revision 19 CLIFFS - UNITS CALVERT CLIFFS -

& 2 I &

UNITS 1 2 8 3.8.2-7 B 3.8.2-7 Revision 19

Inverters-Shutdown

B 3.8.8 B 3.8 ELECTRICAL POWER SYSTEMS B 3.8.8 Inverters-Shutdown BASES BACKGROUND A description of the inverters is provided in the Bases for LCO 3.8.7. I APPLICABLE The initial conditions of DBA and transient analyses in SAFETY ANALYSES Reference 1, Chapters 6 and 14, assume ESF systems are OPERABLE. The DC to AC inverters are designed to provide the required capacity, capability, redundancy, and reliability to ensure the availability of necessary power to the RPS and ESFAS instrumentation and controls so that the fuel, RCS, and containment design limits are not exceeded.

The OPERABILITY of the inverters is consistent with the initial assumptions of the accident analyses and the requirements for the supported systems' OPERABILITY.

The OPERABILITY of the minimum inverters to each AC vital bus during MODEs 5 and 6 ensures that:

I

a. The unit can be maintained in the shutdown or refueling condition for extended periods;

b. Sufficient instrumentation and control capability is available for monitoring and maintaining the unit status; and

c. Adequate power is available to mitigate events postulated during shutdown, such as a fuel handling accident.

The inverters were previously identified as part of the distribution system and, as such, satisfy 10 CFR 50.36(c)(2)(ii), Criterion 3.

LCO The inverters ensure the availability of electrical power for the instrumentation for systems required to shut down the reactor and maintain it in a safe condition after an AOO I or a postulated DBA. The battery powered inverters provide uninterruptible supply of AC electrical power to the AC vital buses even if the 4.16 kV safety buses are de-energized. OPERABILITY of the inverters requires that the vital bus be powered by the inverter. This ensures the CALVERT CLIFFS - UNITS 1 & 2 B 3.8.8-1. Revision 2

Inverters-Shutdown B 3.8.8 BASES availability of sufficient inverter power sources to operate the unit in a safe manner and .to mitigate the consequences of postulated events during shutdown (e.g., fuel'handling accidents).

APPLICABILITY The inverters required to be OPERABLE in MODEs 5 and 6 and during movement of irradiated fuel assemblies provide assurance that:

a. Systems to provide adequate coolant inventory makeup are available for the irradiated fuel in the core;

b. Systems needed to mitigate a fuel handling accident are available;

c. Systems necessary to mitigate the effects of events that can lead to core damage during shutdown are available; and

d. Instrumentation and control capability is available for monitoring and maintaining the unit in a cold shutdown condition or refueling condition.

Inverter requirements for MODEs 1, 2, 3, and 4 are covered in LCO 3.8.7.

ACTIONS Limiting Condition for Operation 3.0.3 is not applicable while in MODEs 5 or 6. However, since irradiated fuel assembly movement can occur in MODEs 1, 2, 3, or 4, the ACTIONS have been modified by a Note stating that LCO 3.0.3 is not applicable. If moving irradiated fuel assemblies while in MODEs 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODEs 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Therefore, in either case, inability to suspend movement of irradiated fuel assemblies would not be sufficient reason to require a reactor shutdown.

A.1. A.2.1. A.2.2. A.2.3. and A.2.4 If two trains are required by LCO 3.8.10, the remaining OPERABLE inverters may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIONS, fuel movement, operations with a potential for draining the reactor vessel, and operations with a potential for positive reactivity additions. By the allowance of the option to CALVERT CLIFFS - UNITS 1 & 2 B 3.8.8-2 Revision 19

Inverters-Shutdown B 3.8.8 BASES.

declare required features inoperable with the associated inverter(s) inoperable, appropriate restrictions will be implemented in accordance with the affected required features LCOs'.Required Actions. In many instances, this option may involve undesired administrative efforts. It is therefore required to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of the required SDM (MODE 5) or boron concentration (MODE 6).

Suspending positive reactivity additions that could result in failure to-meet the minimum SDM or boron concentration limit is required to assure continued safe operation.

Introduction of coolant.inventory must be from sources that have a boron concentration greater'than that required in the RCS for the minimum SDM or refueling boron concentration.

This may result in an overall reduction in RCS boron concentration, but provides an-acceptable margin to maintaining subcritical operation. Introduction of temperature changes including temperature increase's when operating with a positive MTC must also be evaluated to ensure they do not result in a loss of the required SDM.

Suspension of these activities shall not preclude.completion of actions to establish a safe conservative condition.

These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required inverters and to continue this action until restoration 'isaccomplished in order to provide the necessary inverter power to the unit safety systems.

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required inverters should be completed as quickly as possible in order.to minimize the time the unit safety systems may be without power or powered from a constant voltage source transformer.

SURVEILLANCE SR 3.8.8.1 REQUIREMENTS This SR verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter. The verification of proper CALVERT CLIFFS - UNITS 1 & 2 B 3.8.8-3 Revision 19

Inverters-Shutdown B 3.8.8 BASES voltage output ensures that the required power is readily available for the instrumentation connected to the AC vital buses. The seven day Frequency takes into account the redundant capability of the inverters and other indications available in the Control Room that alert the operator to inverter malfunctions.

REFERENCES .1. UFSAR Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

1&

& 22 B 3.8.8-4 B 3.8.8-4 Revision 19

Distribution Systems-Shutdown B 3.8.10 BASES action. If moving irradiated fuel assemblies while in MODEs 1, 2, 3, or 4, the fuel movement is independent of reactor operations. Therefore, in either case, inability to suspend movement of irradiated fuel assemblies would not be sufficient reason to require a reactor shutdown.

The ACTIONS have been modified by a second Note stating that performance of Required Actions shall not preclude completion of actions to establish a safe conservative position. This clarification is provided to avoid stopping movement of irradiated fuel assemblies while in a non-conservative position based on compliance with the Required Actions.

A.1. A.2.1, A.2.2. A.2.3. A.2.4. and A.2.5 Although redundant required features may require redundant trains of electrical power distribution subsystems to be OPERABLE, one OPERABLE distribution subsystem train may be capable of supporting sufficient required features to allow continuation of CORE ALTERATIONS and fuel movement. By allowing the option to declare required features associated with an inoperable distribution subsystem inoperable,.

appropriate restrictions are implemented in accordance with the affected distribution subsystems LCO's Required Actions.

In many instances, this option may involve undesired administrative efforts. Therefore, the allowance for sufficiently conservative actions is made [i.e., to suspend CORE ALTERATIONS, movement of irradiated fuel assemblies, and operations involving positive reactivity additions that could result in loss of the required SDM (MODE 5) or boron concentration (MODE 6)]. Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for the minimum SDM or refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides an acceptable margin to maintaining subcritical operation.

Introduction of temperature changes including temperature increases when operating with a positive MTC must also be evaluated to ensure they do not result is a loss of the required SDM.

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Distribution Systems-Shutdown B 3.8.10 BASES Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition.

These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required AC and DC electrical power distribution subsystems and to continue this action until restoration is accomplished in order to provide the necessary power to the unit safety systems.

Notwithstanding performance of the above conservative

_ _ -- Re.quiredActions, ayrequiyiedshutdowncoolingl(SDC)__

subsystem may be inoperable. In this case, Required Actions A.2.1 through A.2.4 do not adequately address the concerns relating to coolant circulation and heat removal.

Pursuant to LCO 3.0.6, the SDC ACTIONS would not be entered.

Therefore, Required Action A.2.5 is provided to direct declaring SDC inoperable, which results in taking the appropriate SDC actions. The SDC subsystem(s) declared inoperable and not in operation as a result of not meeting this LCO, may be used if needed. However, the appropriate actions are still required to be taken.

The Completion Time of immediately is consistent with the required times for actions requiring prompt attention. The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power.

SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This SR verifies that the AC, DC, and AC vital bus Electrical Power Distribution System is functioning properly, with all the buses energized. The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses. The seven day Frequency takes into account the redundant capability of the electrical power distribution subsystems, and other-indications available in the Control Room that alert the operator to subsystem malfunctions.

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Distribution Systems-Shutdown B 3.8.10 BASES REFERENCES 1. UFSAR.

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Distribution Systems-Shutdown B 3.8.10 BASES Table B 3.8.10-1 .(page 1 of 1)

AC and DC Electrical Power Distribution Systems 1 4160 Volt Emergency Bus 1 480 Volt Emergency Bus 2 120 Volt AC Vital Busses 2 125 Volt DC Busses - 125--Volt-Battery-Banks-(one-of-which-may-be the-reserve-battery)--(one- --- --

associated battery charger per battery bank supplying the required DC busses)

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Nuclear Instrumentation B 3.9.2 B 3.9 REFUELING OPERATIONS B 3.9.2 Nuclear Instrumentation BASES -

BACKGROUND The source range monitors (SRMs) are used during refueling operations to monitor the core reactivity condition. The installed SRMs are part of the wide range nuclear instrumentation which are part of the Nuclear Instrumentation System. These detectors are located external to the reactor vessel and detect neutrons leaking from the core. The use of portable detectors is permitted, provided the LCO requirements are met.

The installed SRMs are fission chambers operating in the proportional region of the gas filled detector characteristic curve. The detectors monitor the neutron flux in counts per second. The instrument range (shutdown monitors) covers five decades of neutron flux (1E+5 cps).

with at least a +/- 5% instrument accuracy. The detectors also provide continuous visual indication in the Control Room and an audible indication in the Control Room and I Containment to alert operators to a possible dilution accident. The Nuclear Instrumentation System is designed in accordance with the criteria presented in Reference 1, Appendix 1C.

If used, portable detectors should be functionally equivalent to the Nuclear Instrumentation System SRMs. I APPLICABLE Two OPERABLE SRMs are required to provide a signal to alert SAFETY ANALYSES .the operator to unexpected changes in core reactivity such as by a boron dilution accident or an improperly loaded fuel assembly. The safety analysis of the uncontrolled boron dilution accident is described in Reference 1, Chapter 14. I The analysis of the uncontrolled boron dilution accident shows that normally available SHUTDOWN MARGIN would be I reduced, but there is sufficient time for the operator to take corrective actions.

The SRMs satisfy 10 CFR 50.36(c)(2)(ii), Criterion 3.

LCO This LCO requires two SRMs OPERABLE to ensure that redundant monitoring capability is available to detect changes in core reactivity.

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Nuclear Instrumentation B 3.9.2 BASES APPLICABILITY In MODE 6, the SRMs must be OPERABLE to determine changes in core reactivity. There is no other direct means available to check core reactivity levels.

In MODEs 2, 3, 4, and 5, the installed source range detectors and circuitry are required to be OPERABLE by LCO 3.3.2.

ACTIONS A.1 and A.2 With only one SRM OPERABLE, redundancy has been lost. Since

- ~thes~e-instruments-r-he~-l diec-enhof-monito-ing- -~ -

core reactivity conditions, CORE ALTERATIONS and introduction of water into the RCS with a boron concentration less than that required to meet the minimum boron concentration of LCO 3.9.1 must be suspended immediately. Suspending positive reactivity additions that could result in failure to meet the minimum boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for the minimum refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides acceptable margin to maintaining subcritical operation. Performance of Required Action A.1 shall not preclude completion of movement of a component to a safe position.

B.1 With no SRM OPERABLE, action to restore a monitor to OPERABLE status shall be initiated immediately. Once initiated, action shall be continued until an SRM is restored to OPERABLE status.

B.2 With no SRM OPERABLE, there is no direct means of detecting changes in core reactivity. However, since CORE ALTERATIONS and positive reactivity additions *are not to be made, the core reactivity condition is stabilized until the SRMs are OPERABLE. This stabilized condition is determined by performing SR 3.9.1.1 to verify that the required boron concentration exists.

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Nuclear Instrumentation B 3.9.2 BASES The Completion Time of once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient to obtain and analyze a reactor coolant sample for boron concentration and ensures that unplanned changes in boron concentration would be identified. The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Frequency is reasonable, considering the low probability of a change in core reactivity during this period.

SURVEILLANCE SR 3.9.2.1 REQUIREMENTS Surveillance Requirement 3.9.2.1 is the performance of a CHANNEL CHECK, which is a comparison of the parameter indicated on one channel to a similar parameter on other _ _

channels. It is based on the assumption that the two indication channels should be consistent with core conditions. Changes in fuel loading and core geometry can result in significant differences between source range channels, but each channel should be consistent with its local conditions.

The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is consistent with the CHANNEL CHECK Frequency specified similarly for the same instruments in LCO 3.3.1.

SR 3.9.2.2 Surveillance Requirement 3.9.2.2 is the performance of a CHANNEL CALIBRATION every 24 months. This SR is modified by a Note stating that neutron detectors are excluded from the CHANNEL CALIBRATION. This is because generating a meaningful test signal is difficult; the detectors are of simple construction, and any failures in the detectors will be apparent as a change in channel output. This Frequency is the same as that employed for the same channels in-the other applicable MODEs.

REFERENCES 1. UFSAR Revision 19 CALVERT CLIFFS CALVERT -

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SDC and Coolant Circulation-High Water Level B 3.9.4 B 3.9 REFUELING OPERATIONS B 3.9.4 Shutdown Cooling (SDC) and Coolant Circulation-High Water Level BASES BACKGROUND The purposes of the SDC System in MODE 6 are to remove decay heat and other residual heat from the RCS, to provide mixing of borated coolant, to provide sufficient coolant circulation to minimize the effects of a boron dilution accident, and to prevent boron stratification (Reference 1).

Heat is removed from the RCS by circulating reactor coolant through the SDC heat exchanger(s), where the heat is transferred to the Component Cooling Water System via the SDC heat exchanger(s). The coolant is then returned to the RCS via the RCS cold leg(s). Operation of the SDC System for normal cooldown or decay heat removal is manually accomplished from the Control Room. The heat removal rate is adjusted by controlling the flow of reactor coolant through the SDC heat exchanger(s) and bypassing the heat exchanger(s). Mixing of the reactor coolant is maintained by this continuous circulation of reactor coolant through the SDC System.

APPLICABLE If the reactor coolant temperature is not maintained below SAFETY ANALYSES 200'F, boiling of the reactor coolant could result. This could lead to inadequate cooling of the reactor fuel due to a resulting loss of coolant in the reactor vessel.

Additionally, boiling of the reactor coolant could lead to a reduction in boron concentration in the coolant, due to the I boron plating out on components near the areas of the boiling activity, and due to the possible addition of water I to the reactor vessel with a lower boron concentration than is required to keep the reactor subcritical. The loss of reactor coolant and the reduction of boron concentration in the reactor coolant would eventually challenge the integrity of the fuel cladding, which is a fission product barrier.

One loop of the SDC System is required to be operational in MODE 6, with the water level 2 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, to prevent this challenge. -The LCO does permit de-energizing of the SDC pump for short durations under the condition that the boron concentration is not diluted. This conditional de-energizing of the SDC pump does not result in a challenge to the fission product barrier.

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SDC and Coolant Circulation-High Water Level B 3.9.4 BASES Shutdown cooling and Coolant Circulation-High Water Level satisfies 10 CFR 50.36(c)(2)(ii), Criterion 2.

LCO Only one SDC loop is required for decay heat removal in MODE 6, with water level 2 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel.

Only one SDC loop is required because the volume of water above the irradiated fuel assemblies seated in the reactor vessel provides backup decay heat removal capability. At least one SDC loop must be OPERABLE and in operation to provide:

- a.

- emoval-f-decay~heat,

b. Mixing of borated coolant to minimize the possibility of a criticality; and

c. Indication of reactor coolant temperature.

An OPERABLE SDC loop.includes an SDC pump, a heat exchanger, valves, piping, instruments, and controls to ensure an OPERABLE flow path, and to determine the low end temperature. The flow path starts in one of the RCS hot legs and is returned to.the RCS cold legs.

The LCO is modified by a Note that allows the required operating SDC loop not to be in operation for up to one hour

in each eight hour period, provided no operations are permitted that would cause the introduction of water into the RCS with a boron concentration less than that required to meet the minimum boron concentration of LCO 3.9.1. Boron concentration reduction with water at boron concentrations less than that required to meet the minimum boron concentration of LCO 3.'9.1 is prohibited because uniform concentration distribution cannot be ensured without forced circulation. This permits operations such as core mapping or alterations in the vicinity of the reactor vessel hot leg nozzles, and RCS to SDC isolation valve testing. During this one hour period, decay heat is removed by natural convection to the large mass of water in the refueling pool.

A second Note also allows both SDC loops not to be in operation during the time required for local leak rate testing of Containment Penetration Number 41 pursuant to the requirements of SR 3.6.1.1 or to permit maintenance on Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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SDC.and Coolant Circulation-High Water Level B 3.9.4 BASES valves located in the common SDC suction line. In addition to the requirement in Note 1 regarding control of boron concentration, CORE ALTERATIONS are suspended and all containment penetrations must be in the status described in LCO 3.9.3. This allowance is necessary to perform required maintenance and testing.

APPLICABILITY One SDC loop must be in operation in MODE 6, with the water level 2 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, to provide decay heat removal. The 23 ft level was selected because it corresponds to the 23 ft requirement established for fuel movement in LCO 3.9.6.

Requirements for the SDC System in other MODEs are covered by LCOs in Section 3.4 and Section 3.5. Shutdown cooling loop requirements in MODE 6, with the water level < 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, are located in LCO 3.9.5.

ACTIONS Shutdown cooling loop requirements are met by having one SDC loop OPERABLE and in operation, except as permitted in the Note to the LCO.

A.1 If one required SDC loop is inoperable or not in operation, action shall be immediately initiated and continued until the SDC loop is restored to OPERABLE status and to operation. An immediate Completion Time is necessary for an operator to initiate corrective actions.

A.2 If SDC loop requirements are not met, there will be no forced circulation to provide mixing to establish uniform boron concentrations. Suspending positive reactivity additions that could result in failure to meet the minimum boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for the minimum refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides an acceptable margin Revision 19 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

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SDC and Coolant Circulation-High Water Level B 3.9.4 BASES to maintaining subcritical operation. In addition, to ensure compliance with the action is maintained, the charging pumps shall be de-energized and charging flow paths closed as part of Required Action A.2.

A.3 If SDC loop requirements are not met, actions shall be taken immediately to suspend loading irradiated fuel assemblies in the core. With no forced circulation cooling, decay heat removal from the core occurs by natural convection to the heat sink provided by the water above the core. A minimum refueling water level of 23 ft above the irradiated fuel assemblies seated in the reactor vessel provides an adequate available heat sink. Suspending any operation that would increase the decay heat load, such as loading a fuel assembly, is a prudent action under this condition.

A.4 If SDC loop requirements are not met, all containment penetrations providing direct access from containment atmosphere to the outside atmosphere through a filtered or unfiltered pathway-must be closed-to prevent fission products, if released by a loss of decay heat event, from escaping the Containment Structure. The four hour Completion Time allows fixing most SDC problems without incurring the additional action of violating the containment atmosphere. The emergency air lock temporary closure device cannot be credited for containment closure for a loss of shutdown cooling event. At least one door in the emergency air lock must be closed to satisfy this action statement.

SURVEILLANCE SR 3.9.4.1 REQUIREMENTS This SR demonstrates that the SDC loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability, and to prevent thermal and boron stratification in the core. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator in the Control Room for monitoring the SDC System.

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SDC and Coolant Circulation-High Water Level B 3.9.4 BASES REFERENCES 1. UFSAR, Section 9.2, "Shutdown Cooling System" Revision 19 UNITS 1 CALVERT CLIFFS - UNITS 1&& 2 2 B 3.9.4-5 B 3.9.4-5 Revision 19

SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES

> 10OF below saturation temperature. The Note prohibits introduction of water with a boron concentration less than that required by LCO.3.9.1 or draining operations when SDC forced flow is stopped.

APPLICABILITY Two SDC loops are required to be OPERABLE, and one.SDC loop must be in operation in MODE 6, with the water level < 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, to provide decay heat removal.

Requirements for the SDC System in other MODEs are covered by LCOs in Section 3.4. MODE 6 requirements, with a water level > 23 ft above the irradiated fuel assemblies seated in the reactor vessel, are covered in LCO 3.9.4.

ACTIONS A.1 and A.2 If one SDC loop is inoperable, action shall be immediately initiated and continued until the SDC loop is restored to OPERABLE status and is in operation, or until the water level is 2 23 ft above the irradiated fuel assemblies seated in the reactor vessel. When the water level is established at 2 23 ft above the irradiated fuel assemblies seated in the reactor vessel, the Applicability will change to that of LCO 3.9.4, and only one SDC loop is required to be OPERABLE and in operation. An immediate Completion Time is necessary for an operator to initiate corrective actions.

B.1 If no SDC loop is in operation or.no SDC loops are OPERABLE, there will be no forced circulation to provide mixing to .

establish uniform boron concentrations. Suspending positive reactivity additions that could result in failure to meet the minimum boron concentration limit is *required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than-that required in the RCS for the minimum refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides an acceptable margin to maintaining subcritical operation. In addition, to ensure compliance with the action is maintained, the charging pumps shall be de-energized and charging flow paths closed as part of Required Action B.1.

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SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES B.2 If no SDC loop is in operation or no SDC loops are OPERABLE, action shall be initiated immediately and continued without interruption to restore one SDC loop to OPERABLE status and operation. Since the unit is in Conditions A and B concurrently, the restoration of two OPERABLE SDC loops and one operating SDC loop should be accomplished expeditiously.

B.3 If no SDC loop is in operation, all. containment penetrations providing direct access from the containment atmosphere to the outside atmosphere through a filtered or unfiltered pathway must be closed within four hours. With the SDC loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere. Closing containment penetrations that are open to the outside atmosphere through a filtered or unfiltered pathway ensures that dose limits are not exceeded. The emergency air lock temporary closure device cannot be credited for containment closure for a loss of shutdown cooling event. At least one door in the emergency air lock must e closed to satisfy this action statement.

The Completion Time of four hours is reasonable, based on the low probability of the coolant boiling in that time.

SURVEILLANCE SR 3.9.5.1 REQUIREMENTS This SR demonstrates that one SDC loop is operating and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. This SR also demonstrates that the other SDC loop is OPERABLE.

In addition, during operation of the SDC loop with the water level in the vicinity of the reactor vessel nozzles, the SDC loop flow rate determination must also consider the SDC pump suction requirements. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator to monitor the SDC System in the Control Room.

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SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES Verification that the required loops are OPERABLE and in operation ensures that loops can be placed in operation as needed, to maintain decay heat and retain forced circulation. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is considered reasonable, since other administrative controls are available and have proven to be acceptable by operating experience.

SR 3.9.5.2 This SR demonstrates that the SDC loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available for the operator in the Control Room for monitoring the SDC System.

SR 3.9.5.3 Verification that the required pump and valves are OPERABLE ensures that an additional SDC loop can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the required pump and valves. The Frequency of seven days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.

REFERENCES 1. UFSAR, Section 9.2, "Shutdown Cooling System" CALVERT~~~~~

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July 1, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.1-4 Rev. 12 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.6.1-5 Rev. 2 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.6.2-1 Rev. 2 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.6.2-2 Rev. 2 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.6.2-3 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-4 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.2-6 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-2 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-6 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.3-9 Rev. 2 B.3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2.

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July 1, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-17 Rev. 17 B 3.8.5-2 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.1-18 Rev. 17 B 3.8.5-3 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.1-19 Rev. 17 B 3.8.5-4 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.1-20 Rev. 17 B 3.8.6-1 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.1-21 Rev. 17 B 3.8.6-2 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.1-22 Rev. 17 B 3.8.6-3 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.1-23 Rev. 17 B 3.8.6-4 Rev. 2 B 3.9.4-2 Rev. 19 B 3.8.1-24 Rev. 17 B 3.8.6-5 Rev. 2 B 3.9.4-3 Rev. 19 B 3.8.1-25 Rev. 17 B 3.8.6-6 Rev. 2 B 3.9.4-4 Rev. 19 B 3.8.1-26 Rev. 17 B 3.8.6-7 Rev. 2 B 3.9.4-5 Rev. 19 B 3.8.1-27 Rev. 17 B 3.8.7-1 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-28 Rev. 17 B 3.8.7-2 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-29 Rev. 17 B 3.8.7-3 Rev. 2 B 3.9.5-3 Rev. 19 B 3.8.1-30 Rev. 17 B 3.8.7-4 Rev. 2 B 3.9.5-4 Rev. 19 B 3.8.1-31 Rev. 17 B 3.8.8-1 Rev. 2 B 3.9.5-5 Rev. 19 B 3.8.1-32 Rev. 17 B 3.8.8-2 Rev. 19 B 3.9.6-1 Rev. 2 B 3.8.1-33 Rev. 17 B 3.8.8-3 Rev. 19 B 3.9.6-2 Rev. 2 B 3.8.2-1 Rev. 2 B 3.8.8-4 Rev. 19 B 3.9.6-3 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-1 Rev. 5 B 3.8.2-3 Rev. 10 B 3.8.9-2 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-3 Rev. 2 B 3.8.2-5 Rev. 19 B 3.8.9-4 Rev. 2 B 3.8.2-6 Rev. 19 B 3.8.9-5 Rev. 2 B 3.8.2-7 Rev. 19 B 3.8.9-6 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-7 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-5 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-3 Rev. 19 B 3.8.3-8 Rev. 3 B 3.8.10-4 Rev. 19 B 3.8.3-9 Rev. 2 B 3.8.10-5 Rev. 19 B 3.8.4-1 Rev. 2 B 3.8.10-6 Rev. 19 B 3.8.4-2 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-3 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-4 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-5 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-6 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.2-2 Rev. 19 B 3.8.4-8 Rev. 2 B 3.9.2-3 Rev. 19 B 3.8.4-9 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-2 Rev. 13 LEP-5 Rev. 20

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 17 April 16, 2004 18 May 5, 2004 19 June 4, 2004 20 July 1, 2004 LOR- I Rev. 20

TABLE OF CONTENTS B 3.6.5 Containment Air Temperature...................... B 3.6.5-1 B 3.6.6 Containment Spray and Cooling Systems........... B 3.6.6-1 B 3.6.7 Deleted -

B 3.6.8 Iodine Removal System (IRS) ...................... '.' B 3.6.8-1 B 3.7 PLANT SYSTEMS. . .. ' ...... B 3.7.1-1 B 3.7.1 Main Steam Safety Valves (MSSVs) .... ;............ B 3.7.1-1 B 3.7.2 Main Steam Isolation Valves (MSIVs).............. B 3.7.2-1 B 3.7.3 Auxiliary Feedwater (AFW) System................. B 3.7.3-1 B 3.7.4 Condensate Storage Tank (CST) .................... B 3.7.4-1 B 3.7.5 Component Cooling (CC) System.................... B 3.7.5-1 B 3.7.6 Service Water (SRW) System...................... B 3.7.6-1 B 3.7.7 Saltwater (SW) System ............................ B 3.7.7-1 B 3.7.8 Control Room Emergency Ventilation System (CREVS) ...................................... B 3.7.8-1 B 3.7.9 Control Room Emergency Temperature System (CRETS) ...................................... B 3.7.9-1 B 3.7.10 Emergency Core Cooling System (ECCS) Pump Room Exhaust Filtration System (PREFS) ............ B 3.7.10-1 B 3.7.11 Spent Fuel Pool Exhaust Ventilation System (SFPEVS) ..................................... B 3.7.11-1 B 3.7.12 Penetration Room Exhaust Ventilation System (PREVS) ..................................... B 3.7.12-1 B 3.7.13 Spent Fuel Pool (SFP) Water Level................ B 3.7.13-1 B 3.7.14 Secondary Specific Activity...................... B 3.7.14-1 B 3.7.15 Main Feedwater Isolation Valves (MFIVs).......... B 3.7.15-1 B 3.7.16 Spent Fuel Pool (SFP) Boron Concentration........ B 3.7.16-1 I B 3.8 ELECTRICAL POWER SYSTEMS............................. B 3.8.1-1 B 3.8.1 AC Sources-Operating ............................ B 3.8.1-1 B 3.8.2 AC Sources-Shutdown ............................. B 3.8.2-1 B 3.8.3 Diesel Fuel Oil .................................. B 3.8.3-1 B 3.8.4 DC Sources-Operating ............................ B 3.8.4-1 B 3.8.5 DC Sources-Shutdown ............................. B 3.8.5-1 B 3.8.6 Battery Cell Parameters.. ........... B 3.8.6-1 B 3.8.7 Inverters-Operating ............................. B 3.8.7-1 B 3.8.8 Inverters-Shutdown .............................. B 3.8.8-1 B 3.8.9 Distribution Systems-Operating .................. B 3.8.9-1 B 3.8.10 Distribution Systems-Shutdown ................... B 3.8.10-1 B 3.9 REFUELING OPERATIONS................................ B 3.9.1-1 B 3.9.1 Boron Concentration .............................. B 3.9.1-1 CALVERT CLIFFS - UNITS 1 & 2 iii Revision 20

TABLE OF CONTENTS B.3.9.2 Nuclear Instrumentation........................ B 3.9.2-1 B 3.9.3 Containment Penetrations......................... B 3.9.3-1 B 3.9.4 Shutdown Cooling (SDC) and Coolant Circulation-High Water Level ............................. B 3.9.4-1 B 3.9.5 Shutdown Cooling (SDC) and Coolant Circulation-Low Water Level .............................. B 3.9.5-1 B 3.9.6 Refueling Pool Water Level ....................... B 3.9.6-1.

CALVERT CLIFFS - UNITS 1 & 2 iv Revision 20

SFP Boron Concentration B 3.7.16 B 3.7 PLANT SYSTEMS B 3.7.16 Spent Fuel Pool (SFP) Boron Concentration BASES BACKGROUND Fuel assemblies are stored in the spent fuel racks in accordance with criteria based on 10.CFR 50.68. If credit is taken for soluble boron, the k-effective of the spent fuel storage racks loaded with fue16of.the maximum fuel assembly reactivity must not exceed 0.95, at a 95%

probability, 95% confidence level, if flooded with borated water, and the k-effective must remain below 1.0 (subcritical) at-.a 95% probability, .95% confidence level, if flooded-with unborated-water. In addition, the maximum nominal U-235 enrichment of the fresh fuel assemblies is limited to 5.0 weight percent.

APPLICABLE

The criticality analysis was done-such that the criteria of SAFETY ANALYSES 10 CFR 50.68 are met. Boron dilution events are credible, postulated accidents, when credit for soluble boron *is taken.. :The minimum SFP boron concentration in this Technical Specification supports the normal and accident boron assumption in the required calculations (References 1 and 2).

For other accident scenarios,.the double contingency principle of ANSI, N 16.1-1975 requires two unlikely, independent concurrent events to produce a criticality accident and thus allows.credit for the nominal soluble boron concentration.

.The concentration of dissolvedtboron in the SFP satisfies Criterion 2 of 10 CFR 50.36(c) (2) (ii).

LCO The specified concentration of dissolved-boron in the SFP preserves the assumptions used in the analyses of the potential accident scenarios described above. This concentration of dissolved boron is the minimum required concentration for fuel assembly storage and movement within the SFP.

APPLICABILITY This LCO applies whenever fuel assemblies are stored in the SFP.

Revision 20 UNITS 1 CLIFFS - UNITS CALVERT CLIFFS -

& 2 1 & 2 B 3.7.16-1 B 3.7.16-1 Revision 20

SFP Boron Concentration B 3.7.16 BASES ACTIONS A.1 and A.2 The Required Actions are modified by a Note indicating that LCO 3.0.3 does not apply.

When the concentration of'boron in the SFP is less than required, immediate action must be taken to preclude an accident from happening or to mitigate'the consequences of an accident in progress.' This is most efficiently achieved by immediately suspending the movement of fuel assemblies.

This does-not preclude the movement of fuel assemblies to a safe position. In addition, action must be immediately initiated to restore boron concentration'to within limits.

If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4,'the fuel movement is independent of reactor operation.

Therefore, inability to suspend movement of fuel assemblies is not'a sufficient reason to require a reactor shutdown.

SURVEILLANCE SR 3.7.16.1 REQUIREMENTS This SR verifies that the concentration of boron in the SFP is within the required limit. As long as this SR is met, the analyzed incidents are fully addressed. The 7 day Frequency is appropriate because no major replenishment of pool water is expected to take place'over a short period of time.

REFERENCES 1. CA06016: Units 1 and 2 SFP Dilution Analysis

2. CA06011: Unit 1 SFP Enrichment Limit with Soluble Boron Credit Revision 29 CALVERT CLIFFS -

UNITS-1 &

CLIFFS - UNITS1 &22 B 3.7.16-2 B 3.7.16-2 Revision 20

PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 21 Remove and Discard Insert List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 List of Revisions LOR-1 LOR-1 Technical Specification Bases Pages B 3.7.16-1 and B 3.7.16-2 B 3.7.16-1 and B 3.7.16-2

August 11, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 21 B 3.1.1-7 Rev. 2 B 3;1.-8-5 'Rev. 2 LEP-2 Rev'. 21 B 3.1.2-1 Rev. 2 B-43.2.1-1 Rev. 2 LEP-3 Rev. 21 B 3.1;2-2 Rev. 2 Br3.2'1-2 -Rev; 14 LEP-4 ' Rev. 21 B 3.1.2-3 " Rev. 2 B '3.2.1-3 Rev. 14 LEP-5 'Rev. 21 B 3.1.2-4 Rev. 2 B 3.2.1-4 "Rev. 14 LOR-1 <'Rev. 21' B 3.1'.2-5 Rev. 2 .

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August 11, 2004 TECHNICAL'SPECIFICATIONS'BASES LIST OF EFFECTIVE PAGES B 3.3.11-3 Rev. 2 B 3.4.8-3 Rev. 19 .B3.4.15-4 Rev. 3 B 3.3.11-4 Rev. 2 B 3.4.9-1 Rev. 2 B 3.4.15-5 *Rev. 2 B 3.3.11-5 Rev. 2 B 3.4.9-2 Rev.: 2 B 3.4.16-1 Rev. 2 B: 3.3.12-1 Rev. 2 B 3.4.9-3 Rev.-2 B 3.4'.16-2 Rev. 2 B 3.3.12-2 Rev.'19 B'3.4.9-4 Rev. 2 B 3.4.16-3 Rev. 2 B 3.3.12-3 :Rev. 2 B 3.4.9-5 Rev. 2 B;3.'4.17-1 Rev. 19 B 3.3.12-4 Rev. 2 B 3.4.10-1 Rev. 2 B 3.'4.17-2 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-2 Rev. 2 B-3'.4.17-3 Rev. 2 B 3.4.1-2 Rev. 15 B'3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4. 1-3 Rev. 15 B 3.4.10-4 Rev.'2 B 3.5.1-2 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-1 Rev.' 12 B 3;5.1-3 Rev., 2 B 3.4.1-5 Rev. -15 B 3.4.11-2 -Rev. 12 B 3.5.1-4 'Re6.' 2 B 3.4.2-1 Rev. -2 B 3.4.11-3 Rev. '12 B 3.5.1-5 Rev. 2 B 3.4.2-2 Rev. '2 B 3.4.11-4 Rev.-12 B 3.5.1-6 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-5 Rev. '12 B 3.5.1-7 Rev. 2 B 3.4.3-2 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B'3.4.3-3 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-4 Rev. 2 B 3.4.12-1 Rev. 2 B-3.5.2-1 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-2 Rev. 2' B 3.5.2-2 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-3 Rev. '2 B'3.5.2-3 Rev. 15 B'3.4.3-7 Rev. 2 B 3.4.12-4 '-Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-8 Rev. 2 B 3.4.12-5 Rev. 6' B 3.5.2-5 Rev. 15 B 3.4.4-1 Rev. 2' B 3.4.12-6 Rev. 2 B 3.5.2-6 Rev.' 15 B 3.4.4-2 Rev. 13 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-8 Rev.' '2 B 3.5.2-8 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.'12-9 Rev.'2 B '3.'5.2-9 Rev. 15 B 3.4.5-2 Rev. 19 B 3.4.12-10 Rev.

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August 11, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.1-4 Rev. 12 B 3.7.1-3 Rev. 13 3.7.9-1 Rev. 2 B 3.6.1-5 Rev. 2 B 3.7.1-4 Rev. 13 3.7.9-2 Rev. 13 B 3.6.2-1 Rev. 2 B 3.7.1-5 Rev. 13 3.7.9-3 Rev. 11 B 3.6.2-2 Rev.. 2 B 3.7.2-1 Rev. 14 3.7.9-4 Rev. 11 B 3.6.2-3 Rev. 2 B 3.7.2-2 Rev. 14 3.7.10-1 Rev. 9 B 3.6.2-4 Rev. 2 B 3.7.2-3 Rev. 14 3.7.10-2 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-4 Rev. 14 3.7.10-3 Rev. 2 B 3.6.2-6 Rev. 2 B 3.7.2-5 Rev. 14 3.7.11-1 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-1 Rev. 2' 3.7.11-2 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-2 Rev. 2 3.7.11-3 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-3 Rev. 12 3.7.11-4 Rev. 15 B 3.6.3-2 Rev. 2 B 3.7.3-4 Rev. 12 3.7.12-1 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-5 Rev. 12 3.7.12-2 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-6 Rev. 12 3.7.12-3 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-7 Rev. 12 3.7.12-4 Rev. 2 B 3.6.3-6 Rev. 2 B 3.7.3-8 Rev. 13 3.7.13-1 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-9 Rev. 13 3.7.13-2 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.3-10 Rev. 12 3.7.13-3 Rev. 8 B 3.6.3-9 Rev. 2 B 3.7.4-1 Rev. 2 3.7.14-1 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-2 Rev. 8 3.7.14-2 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-3 Rev. 2 3.7.14-3 Rev. 2 B 3.6.4-2 Rev. 2 B 3.7.4-4 Rev. 2 3.7.15-1 Rev. 2 B 3.6.4-3 Rev. 2 B 3.7.5-1 Rev. 2 3.7.15-2 Rev. 13 B 3.6.5-1 Rev. 2 B 3.7.5-2 Rev. 2 3.7.15-3 Rev. 14 B 3.6.5-2 Rev. 2 B 3.7.5-3 Rev. 2 3.7.15-4 Rev. 2 B 3.6.5-3 Rev. 3 B 3.7.5-4 Rev. 2 3.7.16-1 Rev. 21 B 3.6.6-1 Rev. 2 B 3.7.5-5 Rev. 2 3.7.16-2 Rev. 21 B 3.6.6-2 Rev. 2 B 3.7.6-1 Rev. 5 3.8.1-1 Rev. 5 B 3.6.6-3 Rev. 15 B 3.7.6-2 Rev. 2 3.8.1-2 Rev. 12 B 3.6.6-4 Rev. 15 B 3.7.6-3 Rev. 5 3.8.1-3 Rev. 2 B 3.6.6-5 Rev. 2 B 3.7.6-4 Rev. 5 3.8.1-4 Rev. 10 B 3.6.6-6 Rev. 2 B 3.7.6-5 Rev. 5 3.8.1-5 Rev. 7 B 3.6.6-7 Rev. 2 B 3.7.7-1 Rev. 5 3.8.1-6 Rev. 17, B 3.6.6-8 Rev. 2 B 3.7.7-2 Rev. 12 3.8.1-7 Rev. 17 B 3.6.6-9 Rev. 18 B 3.7.7-3 Rev. 2 3.8.1-8 Rev. 17 B 3.6.6-10 Rev. 18 B 3.7.7-4 Rev. 12 3.8.1-9 Rev. 17 B 3.6.7 Del eted B 3.7.8-1 Rev. 8 3.8.1-10 Rev. 17' B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 3.8.1-11 Rev. 17 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 3.8.1-12 Rev. 17 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 3.8.1-13 Rev. 17 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 3.8.1-14 Rev. 17 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 3.8.1-15 Rev. 17 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 3.8.1-16 Rev. 17 LEP-4 Rev. 21

August 11, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-17 Rev. 17 B 3.8.5-2 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.1-18 Rev. 17 B 3.8.5-3 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.1-19 Rev. 17 B 3.8.5-4 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.1-20 Rev. 17 B 3.8.6-1 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.1-21 Rev. 17 B 3.8.6-2 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.1-22 Rev. 17 B 3.8.6-3 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.1-23 Rev. 17 B 3.8.6-4 Rev. 2 B 3.9.4-2 Rev. 19 B 3.8.1-24 Rev. 17 B 3.8.6-5 Rev. 2 B 3.9.4-3 Rev. 19 B 3.8.1-25 Rev. 17 B 3.8.6-6 Rev. 2 B 3.9.4-4 Rev. 19 B 3.8.1-26 Rev. 17 B 3.8.6-7 Rev. 2 B 3.9.4-5 Rev. 19 B 3.8.1-27 Rev. 17 B 3.8.7-1 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-28 Rev. 17 B 3.8.7-2 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-29 Rev. 17 B 3.8.7-3 Rev. 2 B 3.9.5-3 Rev. 19 B 3.8.1-30 Rev. 17 B 3.8.7-4 Rev. 2 B 3.9.5-4 Rev. 19 B 3.8.1-31 Rev. 17 B 3.8.8-1 Rev. 2 B 3.9.5-5 Rev. 19 B 3.8.1-32 Rev. 17 B 3.8.8-2 Rev. 19 B 3.9.6-1 Rev. 2 B 3.8.1-33 Rev. 17 B 3.8.8-3 Rev. 19 B 3.9.6-2 Rev. 2 B 3.8.2-1 Rev. 2 B 3.8.8-4 Rev. 19 B 3.9.6-3 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-1 Rev. 5 B 3.8.2-3 Rev. 10 B 3.8.9-2 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-3 Rev. 2 B 3.8.2-5 Rev. 19 B 3.8.9-4 Rev. 2 B 3.8.2-6 Rev. 19 B 3.8.9-5 Rev. 2 B 3.8.2-7 Rev. 19 B 3.8.9-6 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-7 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-5 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-3 Rev. 19 B 3.8.3-8 Rev. 3 B 3.8.10-4 Rev. 19 B 3.8.3-9 Rev. 2 B 3.8.10-5 Rev. 19 B 3.8.4-1 Rev. 2 B 3.8.10-6 Rev. 19 B 3.8.4-2 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-3 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-4 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-5 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-6 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.2-2 Rev. 19 B 3.8.4-8 Rev. 2 B 3.9.2-3 Rev. 19 B 3.8.4-9 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-2 Rev. 13 LEP-5 Rev. 21

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 17 April 16, 2004 18 May 5, 2004 19 June 4, 2004 20 July 1, 2004 21 August 11, 2004 LOR-1 Rev. 21

SFP Boron Concentration B 3.7.16 B 3.7 PLANT SYSTEMS -

B 3.7.16 Spent Fuel Pool (SFP) Boron Concentration BASES BACKGROUND Unit 1 SFP only I Fuel assemblies are stored in the spent fuel racks in accordance with criteria based'on'10 CFR 50.68. If credit is taken for soluble.boron,'the k-effective of the spent

-fuel storage racks loaded with fuel of the maximum fuel assembly reactivity must not exceed '0.95, at a 95%

probability, 95% confidence-level, if flooded with borated water, and the k-effective must remain below 1.0

'(subcritical) at' a 95% probability, 95% confidence level, if flooded with'unborated water. In addition, the maximum nominal U-235 enrichment of the fresh fuel assemblies is limited 'to 5.0 weight percent.

APPLICABLE ' ' The'criticality analysis was done such that the criteria of SAFETY ANALYSES 10 CFR'50.68 are met. Boron dilution events are credible, postulated accidents', when credit for soluble boron is taken. The minim'umn SFP boron-concentration in this Technical Specification supports the normal and accident boron assumption in the required calculations (References 1 and 2).

For other accident scenarios, the double contingency principle of ANSI N'16.1-1975'requires two unlikely, independent concurrent events .to produce a criticality accident and-thus allows ,credit'for the nominal soluble boron concentration.

The concentration of dissolved boron in the SFP satisfies Criterion 2 of;10 CFR 50.36(c)(2)(ii).

LCO The specified concentration of dissolved boron in the SFP preserves the assumptions used in the analyses of the potential accident scenarios described above. This concentration of dissolved boron is the minimum required concentration for fuel assembly storage and movement within the Unit 1 SFP.

APPLICABILITY This LCO applies whenever fuel assemblies are stored in the Unit 1 SFP.

Revision 21 CALVERT CLIFFS -.

UNIT 1 CLIFFS - UNIT 1 B 3.7.16-1 B 3.7.16-1. .Revision 21

SFP Boron Concentration B 3.7.16 BASES ACTIONS A.1 and A.2 The Required Actions are modified by a Note indicating that LCO 3.0.3 does not apply.

When the concentration of boron in the Unit 1 SFP is less than required, immediate action must be taken to preclude an accident from happening or to mitigate the consequences of an accident in progress. This is most efficiently achieved by immediately suspending the movement of fuel assemblies.

This does not preclude the movement of fuel assemblies to a safe position. In addition, action must be immediately initiated to restore boron concentration to within limits.

If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation.

Therefore, inability to suspend movement of fuel assemblies is not a sufficient reason to require a reactor shutdown.

SURVEILLANCE SR 3.7.16.1 REQUIREMENTS This SR verifies that the concentration of boron in the Unit 1 SFP is within the requiredlimit. As long as this SR I is met, the analyzed incidents are fully addressed. The 7 day Frequency is appropriate because no major replenishment of pool water is expected to take place over a short period of time.

REFERENCES 1. CA06016: Units 1 and 2 SFP Dilution Analysis

2. CA06011: Unit 1 SFP Enrichment Limit with Soluble Boron Credit B 3.7.16-2 Revision 21 CALVERT CLIFFS -

UNIT 1 CLIFFS - UNIT 1 B 3.7.16-2 Revision 21

PAGE REPLACEMENT INSTRUCTIONS Calvert Cliffs Nuclear Power Plant Technical Specification Bases - Revision 22 Remove and Discard Insert List of Effective Pages LEP-1 through LEP-5 LEP-1 through LEP-5 List of Revisions LOR-1 LOR-1 Technical Specification Bases Panes B 3.4.12-5 and B 3.4.12-6 B 3.4.12-5 and B 3.4.12-6 B 3.9.4-3 through B 3.9.4-5 B 3.9.4-3 through B 3.9.4-5 B 3.9.5-3 through B 3.9.5-5 B 3.9.5-3 through B 3.9.5-6

October 13, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES LEP-1 Rev. 22 B 3.1.1-7 Rev. 2 B 3.1.8-5 Rev. 2 LEP-2 Rev. 22 B 3.1.2-1 Rev. 2 B 3.2.1-1 Rev. 2 LEP-3 Rev. 22 B 3.1.2-2 Rev. 2 B 3.2.1-2 Rev. 14 LEP-4 Rev. 22 B 3.1.2-3 Rev. 2 B 3.2.1-3 Rev. 14 LEP-5 Rev. 22 B 3.1.2-4 Rev. 2 B 3.2.1-4 Rev. 14 LOR-1 Rev. 22 B 3.1.2-5 Rev. 2 B 3.2.1-5 Rev. 14 i Rev. 2 B 3.1.2-6 Rev. 3 B 3.2.1-6 Rev. 14 ii Rev. 2 B 3.1.3-1 Rev. 2 B 3.2.1-7 Rev. 14

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October 13, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.1-14 Rev. 11 B 3.3.3-12 Rev. 2 B 3.3.6-6 Rev. 2 B 3.3.1-15 Rev. 11 B 3.3.4-1 Rev. 2 B 3.3.6-7 Rev. 12 B 3.3.1-16 Rev. 11 B 3.3.4-2 Rev. 2 B 3.3.6-8 Rev. 8 B 3.3.1-17 Rev. 11 B 3.3.4-3 Rev. 2 B 3.3.7-1 Rev. 19 B 3.3.1-18 Rev. 13 B 3.3.4-4 Rev. 2 B 3.3.7-2 Rev. 19 B 3.3.1-19 Rev. 11 B 3.3.4-5 Rev. 2 B 3.3.7-3 Rev. 19 B 3.3.1-20 Rev. 11 B 3.3.4-6 Rev. 2 B 3.3.7-4 Rev. 19 B 3.3.1-21 Rev. 11 B 3.3.4-7 Rev. 2 B 3.3.7-5 Rev. 19 B 3.3.1-22 Rev. 11 B 3.3.4-8 Rev. 2 B 3.3.7-6 Rev. 19 B 3.3.1-23 Rev. 11 B 3.3.4-9 Rev. 2 B 3.3.7-7 Rev. 19 B 3.3.1-24 Rev. 11 B 3.3.4-10 Rev. 2 B 3.3.8-1 Rev. 8 B 3.3.1-25 Rev. 11 B 3.3.4-11 Rev. 2 B 3.3.8-2 Rev. 2 B 3.3.1-26 Rev. 11 B 3.3.4-12 Rev. 2 B 3.3.8-3 Rev. 2 B 3.3.1-27 Rev. 11 B 3.3.4-13 Rev. 2 B 3.3.8-4 Rev. 2 B 3.3.1-28 Rev. 11 B 3.3.4-14 Rev. 2 B 3.3.9-1 Rev. 2 B 3.3.1-29 Rev. 11 B 3.3.4-15 Rev. 2 B 3.3.9-2 Rev. 2 B 3.3.1-30 Rev. 11 B 3.3.4-16 Rev. 2 B 3.3.9-3 Rev. 2 B 3.3.1-31 Rev. 11 B 3.3.4-17 Rev. 5 B 3.3.9-4 Rev. 2 B 3.3.1-32 Rev. 11 B 3.3.4-18 Rev. 2 B 3.3.9-5 Rev. 2 B 3.3.1-33 Rev. 12 B 3.3.4-19 Rev. 2 B 3.3.9-6 Rev. 2 B 3.3.1-34 Rev. 12 B 3.3.4-20 Rev. 2 B 3.3.9-7 Rev. 2 B 3.3.1-35 Rev. 2 B 3.3.4-21 Rev. 2 B 3.3.9-8 Rev. 3 B 3.3.2-1 Rev. 2 B 3.3.4-22 Rev. 12 B 3.3.10-1 Rev. 2 B 3.3.2-2 Rev. 2 B 3.3.4-23 Rev. 12 B 3.3.10-2 Rev. 2 B 3.3.2-3 Rev. 2 B 3.3.5-1 Rev. 2 B 3.3.10-3 Rev. 14 B 3.3.2-4 Rev. 2 B 3.3.5-2 Rev. 2 B 3.3.10-4 Rev. 19 B 3.3.2-5 Rev. 2 B 3.3.5-3 Rev. 2 B 3.3.10-5 Rev. 19 B 3.3.2-6 Rev. 2 B 3.3.5-4 Rev. 2 B 3.3.10-6 Rev. 19 B 3.3.2-7 Rev. 2 B 3.3.5-5 Rev. 2 B 3.3.10-7 Rev. 19 B 3.3.2-8 Rev. 2 B 3.3.5-6 Rev. 2 B 3.3.10-8 Rev. 19 B 3.3.2-9 Rev. 2 B 3.3.5-7 Rev. 2 B 3.3.10-9 Rev. 19 B 3.3.2-10 Rev. 2 B 3.3.5-8 Rev. 2 B 3.3.10-10 Rev. 19 B 3.3.3-1 Rev. 2 B 3.3.5-9 Rev. 2 B 3.3.10-11 Rev. 19 B 3.3.3-2 Rev. 2 B 3.3.5-10 Rev. 2 B 3.3.10-12 Rev. 19 B 3.3.3-3 Rev. 2 B 3.3.5-11 Rev. 2 B 3.3.10-13 Rev. 19 B 3.3.3-4 Rev. 2 B 3.3.5-12 Rev. 2 B 3.3.10-14 Rev. 19 B 3.3.3-5 Rev. 2 B 3.3.5-13 Rev. 2 B 3.3.10-15 Rev. 19 B 3.3.3-6 Rev. 2 B 3.3.5-14 Rev. 2 B 3.3.10-16 Rev. 19 B 3.3.3-7 Rev. 2 B 3.3.6-1 Rev. 2 B 3.3.10-17 Rev. 19 B 3.3.3-8 Rev. 2 B 3.3.6-2 Rev. 2 B 3.3.10-18 Rev. 19 B 3.3.3-9 Rev. 2 B 3.3.6-3 Rev. 2 B 3.3.10-19 Rev. 19 B 3.3.3-10 Rev. 2 B 3.3.6-4 Rev. 13 B 3.3.11-1 Rev. 2 B 3.3.3-11 Rev. 2 B 3.3.6-5 Rev. 2 B 3.3.11-2 Rev. 2 LEP-2 Rev. 22

October 13, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.3.11-3 Rev. 2 B 3.4.8-3 Rev. 19 B 3.4.15-4 Rev. 3 B 3.3.11-4 Rev. 2 B 3.4.9-1 Rev. 2 B 3.4.15-5 Rev. 2 B 3.3.11-5 Rev. 2 B 3.4.9-2 Rev. 2 B 3.4.16-1 Rev. 2 B 3.3.12-1 Rev. 2 B 3.4.9-3 Rev. 2 B 3.4.16-2 Rev. 2 B 3.3.12-2 Rev. 19 B 3.4.9-4 Rev. 2 B 3.4.16-3 Rev. 2 B 3.3.12-3 Rev. 2 B 3.4.9-5 Rev. 2 B 3.4.17-1 Rev. 19 B 3.3.12-4 Rev. 2 B 3.4.10-1 Rev. 2 B 3.4.17-2 Rev. 2 B 3.4.1-1 Rev. 15 B 3.4.10-2 Rev. 2 B 3.4.17-3 Rev. 2 B 3.4.1-2 Rev. 15 B 3.4.10-3 Rev. 2 B 3.5.1-1 Rev. 2 B 3.4.1-3 Rev. 15 B 3.4.10-4 Rev. 2 B 3.5.1-2 Rev. 2 B 3.4.1-4 Rev. 15 B 3.4.11-1 Rev. 12 B 3.5.1-3 Rev. 2 B 3.4.1-5 Rev. 15 B 3.4.11-2 Rev. 12 B 3.5.1-4 Rev. 2 B 3.4.2-1 Rev. 2 B 3.4.11-3 Rev. 12 B 3.5.1-5 Rev. 2 B 3.4.2-2 Rev. 2 B 3.4.11-4 Rev. 12 B 3.5.1-6 Rev. 2 B 3.4.3-1 Rev. 2 B 3.4.11-5 Rev. 12 B 3.5.1-7 Rev. 2 B 3.4.3-2 Rev. 2 B 3.4.11-6 Rev. 12 B 3.5.1-8 Rev. 14 B 3.4.3-3 Rev. 2 B 3.4.11-7 Rev. 12 B 3.5.1-9 Rev. 14 B 3.4.3-4 Rev. 2 B 3.4.12-1 Rev. 2 B 3.5.2-1 Rev. 15 B 3.4.3-5 Rev. 2 B 3.4.12-2 Rev. 2 B 3.5.2-2 Rev. 15 B 3.4.3-6 Rev. 2 B 3.4.12-3 Rev. 2 B 3.5.2-3 Rev. 15 B 3.4.3-7 Rev. 2 B 3.4.12-4 Rev. 2 B 3.5.2-4 Rev. 15 B 3.4.3-8 Rev. 2 B 3.4.12-5 Rev. 6 B 3.5.2-5 Rev. 15 B 3.4.4-1 Rev. 2 B 3.4.12-6 Rev. 22 B 3.5.2-6 Rev. 15 B 3.4.4-2 Rev. 13 B 3.4.12-7 Rev. 2 B 3.5.2-7 Rev. 15 B 3.4.4-3 Rev. 13 B 3.4.12-8 Rev. 2 B 3.5.2-8 Rev. 15 B 3.4.5-1 Rev. 2 B 3.4.12-9 Rev. 2 B 3.5.2-9 Rev. 15 B 3.4.5-2 Rev. 19 B 3.4.12-10 Rev. 2 B 3.5.3-1 Rev. 2 B 3.4.5-3 Rev. 19 B 3.4.12-11 Rev. 2 B 3.5.3-2 Rev. 2 B 3.4.5-4 Rev. 19 B 3.4.12-12 Rev. 2 B 3.5.3-3 Rev. 2 B 3.4.5-5 Rev. 19 B 3.4.12-13 Rev. 2 B 3.5.4-1 Rev. 2 B 3.4.6-1 Rev. 19 B 3.4.13-1 Rev. 2 B 3.5.4-2 Rev. 14 B 3.4.6-2 Rev. 19 B 3.4.13-2 Rev. 10 B 3.5.4-3 Rev. 2 B 3.4.6-3 Rev. 8 B 3.4.13-3 Rev. 2 B 3.5.4-4 Rev. 2 B 3.4.6-4 Rev. 19 B 3.4.13-4 Rev. 2 B 3.5.4-5 Rev. 2 B 3.4.6-5 Rev. 19 B 3.4.13-5 Rev. 5 B 3.5.4-6 Rev. 2 B 3.4.7-1 Rev. 2 B 3.4.14-1 Rev. 2 B 3.5.5-1 Rev. 2 B 3.4.7-2 Rev. 19 B 3.4.14-2 Rev. 2 B 3.5.5-2 Rev. 2 B 3.4.7-3 Rev. 19 B 3.4.14-3 Rev. 2 B 3.5.5-3 Rev. 2 B 3.4.7-4 Rev. 19 B 3.4.14-4 Rev. 2 B 3.5.5-4 Rev. 2 B 3.4.7-5 Rev. 19 B 3.4.14-5 Rev. 2 B 3.5.5-5 Rev. 2 B 3.4.7-6 Rev. 19 B 3.4.15-1 Rev. 2 B 3.6.1-1 Rev. 2 B 3.4.8-1 Rev. 2 B 3.4.15-2 Rev. 2 B 3.6.1-2 Rev. 2 B 3.4.8-2 Rev. 19 B 3.4.15-3 Rev. 2 B 3.6.1-3 Rev. 2 LEP-3 Rev. 22

October 13, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.6.1-4 Rev. 12 B 3.7.1-3 Rev. 13 B 3.7.9-1 Rev. 2 B 3.6.1-5 Rev. 2 B 3.7.1-4 Rev. 13 B 3.7.9-2 Rev. 13 B 3.6.2-1 Rev. 2 B 3.7.1-5 Rev. 13 B 3.7.9-3 Rev. 11 B 3.6.2-2 Rev. 2 B 3.7.2-1 Rev. 14 B 3.7.9-4 Rev. 11 B 3.6.2-3 Rev. 2 B 3.7.2-2 Rev. 14 B 3.7.10-1 Rev. 9 B 3.6.2-4 Rev. 2 B 3.7.2-3 Rev. 14 B 3.7.10-2 Rev. 2 B 3.6.2-5 Rev. 2 B 3.7.2-4 Rev. 14 B 3.7.10-3 Rev. 2 B 3.6.2-6 Rev. 2 B 3.7.2-5 Rev. 14 B 3.7.11-1 Rev. 15 B 3.6.2-7 Rev. 2 B 3.7.3-1 Rev. 2 B 3.7.11-2 Rev. 15 B 3.6.2-8 Rev. 2 B 3.7.3-2 Rev. 2 B 3.7.11-3 Rev. 15 B 3.6.3-1 Rev. 2 B 3.7.3-3 Rev. 12 B 3.7.11-4 Rev. 15 B 3.6.3-2 Rev. 2 B 3.7.3-4 Rev. 12 B 3.7.12-1 Rev. 2 B 3.6.3-3 Rev. 2 B 3.7.3-5 Rev. 12 B 3.7.12-2 Rev. 2 B 3.6.3-4 Rev. 2 B 3.7.3-6 Rev. 12 B 3.7.12-3 Rev. 2 B 3.6.3-5 Rev. 2 B 3.7.3-7 Rev. 12 B 3.7.12-4 Rev. 2 B 3.6.3-6 Rev. 2 B 3.7.3-8 Rev. 13 B 3.7.13-1 Rev. 8 B 3.6.3-7 Rev. 2 B 3.7.3-9 Rev. 13 B 3.7.13-2 Rev. 8 B 3.6.3-8 Rev. 2 B 3.7.3-10 Rev. 12 B 3.7.13-3 Rev. 8 B 3.6.3-9 Rev. 2 B 3.7.4-1 Rev. 2 B 3.7.14-1 Rev. 2 B 3.6.3-10 Rev. 2 B 3.7.4-2 Rev. 8 B 3.7.14-2 Rev. 2 B 3.6.4-1 Rev. 2 B 3.7.4-3 Rev. 2 B 3.7.14-3 Rev. 2 B 3.6.4-2 Rev. 2 B 3.7.4-4 Rev. 2 B 3.7.15-1 Rev. 2 B 3.6.4-3 Rev. 2 B 3.7.5-1 Rev. 2 B 3.7.15-2 Rev. 13 B 3.6.5-1 Rev. 2 B 3.7.5-2 Rev. 2 B 3.7.15-3 Rev. 14 B 3.6.5-2 Rev. 2 B 3.7.5-3 Rev. 2 B 3.7.15-4 Rev. 2 B 3.6.5-3 Rev. 3 B 3.7.5-4 Rev. 2 B 3.7.16-1 Rev. 21 B 3.6.6-1 Rev. 2 B 3.7.5-5 Rev. 2 B 3.7.16-2 Rev. 21 B 3.6.6-2 Rev. 2 B 3.7.6-1 Rev. 5 B 3.8.1-1 Rev. 5 B 3.6.6-3 Rev. 15 B 3.7.6-2 Rev. 2 B 3.8.1-2 Rev. 12 B 3.6.6-4 Rev. 15 B 3.7.6-3 Rev. 5 B 3.8.1-3 Rev. 2 B 3.6.6-5 Rev. 2 B 3.7.6-4 Rev. 5 B 3.8.1-4 Rev. 10 B 3.6.6-6 Rev. 2 B 3.7.6-5 Rev. 5 B 3.8.1-5 Rev. 7 B 3.6.6-7 Rev. 2 B 3.7.7-1 Rev. 5 B 3.8.1-6 Rev. 17 B 3.6.6-8 Rev. 2 B 3.7.7-2 Rev. 12 B 3.8.1-7 Rev. 17 B 3.6.6-9 Rev. 18 B 3.7.7-3 Rev. 2 B 3.8.1-8 Rev. 17 B 3.6.6-10 Rev. 18 B 3.7.7-4 Rev. 12 B 3.8.1-9 Rev. 17 B 3.6.7 Deleted B 3.7.8-1 Rev. 8 B 3.8.1-10 Rev. 17 B 3.6.8-1 Rev. 2 B 3.7.8-2 Rev. 11 B 3.8.1-11 Rev. 17 B 3.6.8-2 Rev. 2 B 3.7.8-3 Rev. 11 B 3.8.1-12 Rev. 17 B 3.6.8-3 Rev. 2 B 3.7.8-4 Rev. 11 B 3.8.1-13 Rev. 17 B 3.6.8-4 Rev. 2 B 3.7.8-5 Rev. 11 B 3.8.1-14 Rev. 17 B 3.7.1-1 Rev. 2 B 3.7.8-6 Rev. 11 B 3.8.1-15 Rev. 17 B 3.7.1-2 Rev. 9 B 3.7.8-7 Rev. 11 B 3.8.1-16 Rev. 17 LEP-4 Rev. 22

October 13, 2004 TECHNICAL SPECIFICATIONS BASES LIST OF EFFECTIVE PAGES B 3.8.1-17 Rev. 17 B 3.8.5-2 Rev. 2 B 3.9.3-3 Rev. 13 B 3.8.1-18 Rev. 17 B 3.8.5-3 Rev. 2 B 3.9.3-4 Rev. 13 B 3.8.1-19 Rev. 17 B 3.8.5-4 Rev. 2 B 3.9.3-5 Rev. 13 B 3.8.1-20 Rev. 17 B 3.8.6-1 Rev. 2 B 3.9.3-6 Rev. 13 B 3.8.1-21 Rev. 17 B 3.8.6-2 Rev. 2 B 3.9.3-7 Rev. 13 B 3.8.1-22 Rev. 17 B 3.8.6-3 Rev. 2 B 3.9.4-1 Rev. 2 B 3.8.1-23 Rev. 17 B 3.8.6-4 Rev. 2 B 3.9.4-2 Rev. 19 B 3.8.1-24 Rev. 17 B 3.8.6-5 Rev. 2 B 3.9.4-3 Rev. 19 B 3.8.1-25 Rev. 17 B 3.8.6-6 Rev. 2 B 3.9.4-4 Rev. 22 B 3.8.1-26 Rev. 17 B 3.8.6-7 Rev. 2 B 3.9.4-5 Rev. 22 B 3.8.1-27 Rev. 17 B 3.8.7-1 Rev. 2 B 3.9.5-1 Rev. 2 B 3.8.1-28 Rev. 17 B 3.8.7-2 Rev. 2 B 3.9.5-2 Rev. 14 B 3.8.1-29 Rev. 17 B 3.8.7-3 Rev. 2 B 3.9.5-3 Rev. 19 B 3.8.1-30 Rev. 17 B 3.8.7-4 Rev. 2 B 3.9.5-4 Rev. 22 B 3.8.1-31 Rev. 17 B 3.8.8-1 Rev. 2 B 3.9.5-5 Rev. 22 B 3.8.1-32 Rev. 17 B 3.8.8-2 Rev. 19 B 3.9.5-6 Rev. 22 B 3.8.1-33 Rev. 17 B 3.8.8-3 Rev. 19 B 3.9.6-1 Rev. 2 B 3.8.2-1 Rev. 2 B 3.8.8-4 Rev. 19 B 3.9.6-2 Rev. 2 B 3.8.2-2 Rev. 2 B 3.8.9-1 Rev. 5 B 3.9.6-3 Rev. 2 B 3.8.2-3 Rev. 10 B 3.8.9-2 Rev. 2 B 3.8.2-4 Rev. 5 B 3.8.9-3 Rev. 2 B 3.8.2-5 Rev. 19 B 3.8.9-4 Rev. 2 B 3.8.2-6 Rev. 19 B 3.8.9-5 Rev. 2 B 3.8.2-7 Rev. 19 B 3.8.9-6 Rev. 2 B 3.8.3-1 Rev. 2 B 3.8.9-7 Rev. 2 B 3.8.3-2 Rev. 2 B 3.8.9-8 Rev. 2 B 3.8.3-3 Rev. 2 B 3.8.9-9 Rev. 2 B 3.8.3-4 Rev. 2 B 3.8.9-10 Rev. 2 B 3.8.3-5 Rev. 2 B 3.8.10-1 Rev. 5 B 3.8.3-6 Rev. 2 B 3.8.10-2 Rev. 5 B 3.8.3-7 Rev. 2 B 3.8.10-3 Rev. 19 B 3.8.3-8 Rev. 3 B 3.8.10-4 Rev. 19 B 3.8.3-9 Rev. 2 B 3.8.10-5 Rev. 19 B 3.8.4-1 Rev. 2 B 3.8.10-6 Rev. 19 B 3.8.4-2 Rev. 2 B 3.9.1-1 Rev. 11 B 3.8.4-3 Rev. 2 B 3.9.1-2 Rev. 13 B 3.8.4-4 Rev. 2 B 3.9.1-3 Rev. 10 B 3.8.4-5 Rev. 2 B 3.9.1-4 Rev. 10 B 3.8.4-6 Rev. 2 B 3.9.2-1 Rev. 2 B 3.8.4-7 Rev. 2 B 3.9.2-2 Rev. 19 B 3.8.4-8 Rev. 2 B 3.9.2-3 Rev. 19 B 3.8.4-9 Rev. 2 B 3.9.3-1 Rev. 13 B 3.8.5-1 Rev. 2 B 3.9.3-2 Rev. 13 LEP-5 Rev. 22

TECHNICAL SPECIFICATION BASES LIST OF REVISIONS AND ISSUE DATES Rev. Date Issued Date to NRC 0 May 4, 1998 1 August 28, 1998 October 30, 1998 2 August 28, 1998 October 30, 1998 3 October 28, 1998 October 30, 1998 4 March 16, 1999 October 18, 1999 5 October 18, 1999 October 18, 1999 6 April 14, 2000 October 24, 2000 7 May 18, 2000 October 24, 2000 8 June 29, 2000 October 24, 2000 9 October 24, 2000 October 24, 2000 10 February 1, 2001 November 13, 2001 11 March 22, 2001 November 13, 2001 12 November 13, 2001 November 13, 2001 13 September 5, 2002 December 19, 2002 14 May 14, 2003 October 21, 2003 15 January 9, 2004 16 March 31, 2004 17 April 16, 2004 18 May 5, 2004 19 June 4, 2004 20 July 1, 2004 21 August 11, 2004 22 October 13, 2004 LOR-1 Rev. 22

LTOP System B 3.4.12 BASES HPSI loop MOV, then two PORVs or an RCS vent 2 2.6 square inches are capable of maintaining RCS pressure below limits.

Thus, the LCO allows only one HPSI pump OPERABLE with flow throttled, or with an RCS vent 2 2.6 square inches during the LTOP MODEs.

Also to limit pressure overshoot over the PORV setpoint, the remaining HPSI and two charging pumps are rendered incapable of injection, and the RCPs are disabled during water solid operation.

Heatup and cooldown analyses established the temperature of LTOP Applicability at 3650 F (Unit 1), and 301OF (Unit 2) and below, based on Standard Review Plan criteria. Above this temperature, the RCPB is sufficiently above the nil-ductility temperature and the pressurizer safety valves provide the reactor vessel pressure protection against brittle fracture. The vessel materials were assumed to have a fluence level equal to 4.49 x 1019 n/cm2 (Unit 1),

4.0 x 1019 n/cm2 (Unit 2).

The consequences of a LOCA in LTOP conform to Reference 1, Appendix K and 10 CFR 50.46, requirements, by having SITs operable in MODE 3 and one HPSI pump available for manual actuation.

PORV Performance The fracture mechanics analyses show that the vessel is protected when the PORVs are set to open at or below the curves in Figure 3.4.12-1 and are applicable when the SDC System is not in operation. The setpoint is derived by modeling the performance of the LTOP System, assuming the limiting case of loss of SDC and one charging pump injecting into the RCS during water solid operation. These analyses consider pressure overshoot beyond the PORV opening setpoints, resulting from signal processing and valve stroke times. The PORV setpoints below the derived limit ensure the Reference 1, Appendix G limits will be met. When the SDC System is in operation, the PORV lift setting must be <

429 psia (Unit 1), < 443 psia (Unit 2). This ensures that the PORV lift setting is low enough to mitigate overpressure Revision 6 UNITS 1 CALVERT CLIFFS - UNITS

- 1&& 2 2 B 3.4.12-5 B 3.4.12-5 Revision 6

LTOP System B 3.4.12 BASES transients when SDC is in operation, since RCS temperature measurement is not accurate in this condition.

The PORV setpoints will be re-evaluated for compliance when the revised P/T limits conflict with the LTOP analysis limits. The P/T limits are periodically modified as the reactor vessel material toughness decreases due to embrittlement caused by neutron irradiation. Revised P/T limits are determined using neutron fluence projections and the results of examinations of the reactor vessel material irradiation surveillance specimens. The Bases for LCO 3.4.3 l discuss these examinations.

The PORVs are considered active components. Thus, the failure of one PORV represents the worst case, single active failure.

RCS Vent Performance With the RCS depressurized, analyses shows a vent size of 1.3 square inches is capable of mitigating the limiting allowed LTOP overpressure transient provided a pressurizer steam volume exists, two of the three HPSI pumps are disabled and the remaining HPSI pump's flow is throttled.

In that event, this size vent maintains RCS pressure less than the maximum RCS pressure on the P/T limit curve. A 2.6 square inch vent is required to allow for single failures of other equipment, such as HPSI throttle valves.

An 8 square inch vent is sufficient to preclude RCS overpressure events. Therefore, when an 8 square inch vent is established, LTOP System requirements are not necessary to maintain RCS pressure within limits.

The RCS vent size will also be re-evaluated for compliance each time the P/T limit curves are revised based on the results of the vessel material surveillance.

The RCS vent is passive and is not subject to active failure.

LTOP System satisfies 10 CFR 50.36(c)(2)(ii), Criterion 2.

Revision 22 CALVERT CLIFFS - UNITS 1 CLIFFS - UNITS 1&& 22 B 3.4.12-6 B 3.4.12-6 Revision 22

SDC and Coolant Circulation-High Water Level B 3.9.4 BASES valves located in the common SDC suction line. In addition to the requirement in Note 1 regarding control of boron concentration, CORE ALTERATIONS are suspended and all containment penetrations must be in the status described in LCO 3.9.3. This allowance is necessary to perform required maintenance and testing.

APPLICABILITY One SDC loop must be in operation in MODE 6, with the water level 2 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, to provide decay heat removal. The 23 ft level was selected because it corresponds to the 23 ft requirement established for fuel movement in LCO 3.9.6.

Requirements for the SDC System in other MODEs are covered by LCOs in Section 3.4 and Section 3.5. Shutdown cooling loop requirements in MODE 6, with the water level < 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, are located in LCO 3.9.5.

ACTIONS Shutdown cooling loop requirements are met by having one SDC loop OPERABLE and in operation, except as permitted in the Note to the LCO.

A.1 If one required SDC loop is inoperable or not in operation, action shall be immediately initiated and continued until the SDC loop is restored to OPERABLE status and to operation. An immediate Completion Time is necessary for an operator to initiate corrective actions.

A.2 If SDC loop requirements are not met, there will be no forced circulation to provide mixing to establish uniform boron concentrations. Suspending positive reactivity additions that could result in failure to meet the minimum boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for the minimum refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides an acceptable margin 1&&2 B 3.9.4-3 Revision 19

- UNITS 1 CALVERT CLIFFS - UNITS 2 B 3.9.4-3 Revision 19

SDC and Coolant Circulation-High Water Level B 3.9.4 BASES to maintaining subcritical operation. In addition, to ensure compliance with the action is maintained, the charging pumps shall be de-energized and charging flow paths closed as part of Required Action A.2.

A.3 If SDC loop requirements-are not met, actions shall be taken immediately to suspend loading irradiated fuel assemblies in the core. With no forced circulation cooling, decay heat removal from the core occurs by natural convection to the heat sink provided by the water above the core. A minimum refueling water level of 23 ft above the irradiated fuel assemblies seated in the reactor vessel provides an adequate available heat sink. Suspending any operation that would increase the decay heat load, such as loading a fuel assembly, is a prudent action under this condition.

A.4.1. A.4.2, A.5. A.6.1. and A.6.2 If no SDC is in operation, the following actions must be taken:

a. the equipment hatch must be closed and secured with a minimum of four bolts or the containment outage door must be closed;

b. one door in each air lock must be closed; and

c. each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being closed by an OPERABLE containment purge valve isolation system. This requirement is to be applied to each penetration separately. The decision to apply A.6.1 or A.6.2 is made for each penetration, depending on whether or not that penetration has an OPERABLE containment purge valve isolation system.

With SDC loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere. Performing the actions described above ensure that all containment penetrations are either CALVERT CLIFFS - UNITS 1 & 2 B 3.9.4-4 Revision 22

SDC and Coolant Circulation-High Water Level B 3.9.4 BASES closed or can be closed so that the does limits are not exceeded.

The Completion Time of four hours allows fixing of most SDC problems and is reasonable, based on the low probability of the coolant boiling in that time.

The emergency air lock temporary closure device cannot be credited for containment closure for a loss of shutdown cooling event. At least one door in the emergency air lock must be closed to satisfy this action statement.

SURVEILLANCE SR 3.9.4.1 REQUIREMENTS This SR demonstrates that the SDC loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability, and to prevent thermal and boron stratification in the core. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator in the Control Room for monitoring the SDC System.

REFERENCES 1. UFSAR, Section 9.2, "Shutdown Cooling System" Revision 22 CLIFFS - UNITS CALVERT CLIFFS -

UNITS 11&& 2 2 B 3.9.4-5 B 3.9.4-5 Revision 22

SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES

> 10OF below saturation temperature. The Note prohibits introduction of water with a boron concentration less than that required by LCO 3.9.1 or draining operations when SDC forced flow is stopped.

APPLICABILITY Two SDC loops are required to be OPERABLE, and one SDC loop must be in operation in MODE 6, with the water level < 23 ft above the top of the irradiated fuel assemblies seated in the reactor vessel, to provide decay heat removal.

Requirements for the SDC System in other MODEs are covered by LCOs in Section 3.4. MODE 6 requirements, with a water level 2 23 ft above the irradiated fuel assemblies seated in the reactor vessel, are covered in LCO 3.9.4.

ACTIONS A.1 and A.2 If one SDC loop is inoperable, action shall be immediately initiated and continued until the SDC loop is restored to OPERABLE status and is in operation, or until the water level is 2 23 ft above the irradiated fuel assemblies seated in the reactor vessel. When the water level is established at 2 23 ft above the irradiated fuel assemblies seated in the reactor vessel, the Applicability will change to that of LCO 3.9.4, and only one SDC loop is required to be OPERABLE and in operation. An immediate Completion Time is necessary for an operator to initiate corrective actions.

B.1 If no SDC loop is in operation or no SDC loops are OPERABLE, there will be no forced circulation to provide mixing to establish uniform boron concentrations. Suspending positive reactivity additions that could result in failure to meet the minimum boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that required in the RCS for the minimum refueling boron concentration. This may result in an overall reduction in RCS boron concentration, but provides an acceptable margin to maintaining subcritical operation. In addition, to ensure compliance with the action is maintained, the charging pumps shall be de-energized and charging flow paths closed as part of Required Action B.1.

CALVERT CLIFFS - UNITS 1 & 2 B 3.9.5-3 Revision 19

SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES B.2 If no SDC loop is in operation or no SDC loops are OPERABLE, action shall be initiated immediately and continued without interruption to restore one SDC loop to OPERABLE status and operation. Since the unit is in Conditions A and B concurrently, the restoration of two OPERABLE SDC loops and one operating SDC loop should be accomplished expeditiously.

B.3.1. B.3.2, B.4. B.5.1. and B.5.2 If no SDC is in operation, the following actions must be taken:

a. the equipment hatch must be closed and secured with a minimum of four bolts or the containment outage door must be closed;

b. one door in each air lock must be closed; and

c. each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being closed by an OPERABLE containment purge valve isolation system. This requirement is to be applied to each penetration separately. The decision to apply B.5.1 or B.5.2 is made for each penetration, depending on whether or not that penetration has an OPERABLE containment purge valve isolation system.

With SDC loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere. Performing the actions described above ensure that all containment penetrations are either closed or can be closed so that the does limits are not exceeded.

The Completion Time of four hours allows fixing of most SDC problems and is reasonable, based on the low probability of the coolant boiling in that time.

The emergency air lock temporary closure device cannot be credited for containment closure for a loss of shutdown B 3.9.5-4 Revision 22

- UNITS 1 CALVERT CLIFFS - UNITS 1&& 2 2 B 3.9.5-4 Revision 22

SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES cooling event. At least one door in the emergency air lock must be closed to satisfy this action statement.

SURVEILLANCE SR 3.9.5.1 REQUIREMENTS This SR demonstrates that one SDC loop is operating and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. This SR also demonstrates that the other SDC loop is OPERABLE.

In addition, during operation of the SDC loop with the water level in the vicinity of the reactor vessel nozzles, the SDC loop flow rate determination must also consider the SDC pump suction requirements. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator to monitor the SDC System in the Control Room.

Verification that the required loops are OPERABLE and in operation ensures that loops can be placed in operation as needed, to maintain decay heat and retain forced circulation. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is considered reasonable, since other administrative controls are available and have proven to be acceptable by operating experience.

SR 3.9.5.2 This SR demonstrates that the SDC loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core. The Frequency of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is sufficient, considering the flow, temperature, pump control, and alarm indications available for the operator in the Control Room for monitoring the SDC System.

SR 3.9.5.3 Verification that the required pump and valves are OPERABLE ensures that an additional SDC loop can be placed in operation, if needed, to maintain decay heat removal and 2 B 3.9.5-5 Revision 22 UNITS 1 CALVERT CLIFFS - UNITS 1&& 2 B 3.9.5-5 Revision 22

SDC and Coolant Circulation-Low Water Level B 3.9.5 BASES reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to the required pump and valves. The Frequency of seven days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.

REFERENCES 1. UFSAR, Section 9.2, "Shutdown Cooling System" CALVERT CLIFFS - UNITS 1 & 2 B 3.9.5-6 Revision 22

ML043100130

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