Text

Amends 94 & 75 to Licenses DPR-53 & DPR-69,respectively, Changing Tech Specs to Revise Limiting Conditions for Operation & Surveillance Requirements Re Range & Location of wide-range Flux Monitor for Remote Shutdown
	ML20092C375
Person / Time
Site:	Calvert Cliffs
Issue date:	06/06/1984
From:	John Miller; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20092C377	List: ML20092C375; ML20092C379;
References
	NUDOCS 8406210151
	Download: ML20092C375 (34)
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m3RtCp ig UNITED STATES y '

(

g NUCLEAR REGULATORY COMMISSION E

WASHINGTON. D. C. 20555

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BALTIMORE GAS AND ELECTRIC COMPANY DOCKET N0. 50-317 CALVERT CLIFFS NUCLEAR POWER PLANT UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 94 License No. DPR-53 1.

The Nuclear Regulatory Comission (the Comission) has found that:

A.

The application for amendment by Baltimore Gas & Electric Company

)

(the licensee) dated January 27, 1984, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Comission's rules and regulations set forth in 10 CFR Chapter I; ti.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Comission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations; D.

The issuance of this amendment will not be inimical to the comon defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Ccmission's regulations and all applicable requirements have been satisfied.

1 8406210151 840606 PDR ADOCK 05000317 P

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Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. OPR-53 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 94, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifica-tions.

3.

This license amendment is effective as of the date of its issuance.

FOR THE NUCLE,AR REGULATORY COMMISSION nes R. Miller, Chief Operating Reactors Branch #3 Division of Licensing

Attachment:

Changes to the Technical Specifications Date of Issuance: June 6,1984 e

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ATTACHMENT TO LICENSE AMENDMENT NO. 94 FACILTIY OPERATING LICENSE N0.'DPR-53 DOCKET NO. 50-317 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain vertical lines indicating the areas of change. The corresponding overleaf pages are provided to maintain document completeness.

Pages I

XVI 1-2 3/4 3-43 3/4 3/44 3/4 4-10 3/4 4-12 3/4 4-19 3/4 6-9 3/4 7-66 3/4 7-69 3/4 7-72 3/4 7-73 3/4 7-75 3/4 7-77 6-7 6-10 6-12 6-14 6-16 6-17 6-18 6-19 e

INDEX l

DEFINITIONS SECTION PAGE 1.C DEFINITIONS D e f i ne d T e rms..............................................

1 -1 Thermal Power..............................................

1 -1 Ra te d Th e rm al Powe r........................................

1 -1 Operational Mode...........................................

1 -1 Action.....................................................

1 -1 O p e r a b l e - O p e ra b i l i ty.....................................

1 -1 Reportable Event.......

1 -2 l

C o n t ai nme n t I n te g r i ty......................................

1 -2 C h ann e l C a l i b ra t i on........................................

1 -2 C h a n n el C h e c k..............................................

1 -3 Channel Functional Test....................................

1 -3 C o r e A l te r a ti on............................................

1 -3 Shutdown Margin............................................

1-3 Identified Leakage.........................................

1 -4 Un i d ent i fi ed L ea k ag e.......................................

1 -4 Pressure Boundary Leakage..................................

1 -4 Controlled Leakage.........................................

1 -4 A z imu tha l Po we r T i l t.......................................

1-4 Do s e Equ i val en t I -131......................................

1 -4 E-Average Di si ntegrati on Energy............................

1-5 S tag ge red Te s t Ba s i s.......................................

1-5 Frequency Notation....................................;....

1 -5 Ax i al S h a p e ' n dex..........................................

1 -5 Unrodded Planar Radial Peaking Factor - F 1-5 xy. m m. m. m... m.

Reactor Trip System Response T1ne..........................

1-6 Engineered Safety Feature Response Time....................

1 -6 Physics Tests...............................

1 -6 Unrodded Integrated Radial Peaking Factor - F * * * * * * * * * * * *

I '0 r

ALVERT CLIFFS - UNIT 1 1

Amendment No. 23, 94

INDEX SAFETY LIMITS AND LIMITING SAFETY SYSTEM SETTINGS SECTION PAGE 2.1 SAFETY LIMITS i

Reactor Core................................................

2-1 Reactor Coolant System Pressure.............................

2-1 2.2 LIMITING SAFETY SYSTEM SETTINGS Reactor Tri p Se tpoi nts......................................

2-6 BASES SECTION PAGE 2.1 SAFETY LIMITS ReactorCore................................................

B 2-1 Reactor Cool ant System Pres sure.............................

B 2-3 2.2 LIMITING SAFETY SYSTEM SETTINGS Reactor Tri p Setpoi nts......................................

B 2-4 l

CALVERT CLIFFS - UNIT 1 II r

f INDEX i,

ADMINISTRATIVE CONTROLS SECTION PAGE 6.1 RESPONSIBILITY............................................

6-1 6.2 ORGANIZATION 0ffsite...................................................

6-1

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Fa c i l i ty S t a f f............................................

6-1 6.3 FACILITY STAFF 00ALIFICATIONS............................. 6-6

}

6.4 TRAINING..................................................

6-6 i

6.5 REVIEW AND AUDIT 6.5.1 PLANT OPERATIONS AND SAFETY REVIEW COMMITTEE (POSRC)

Function................................................

6-6 1

Composition.............................................

6-6 Al t e rn a t e s..............................................

6-6 Meeting Frequency.......................................

6-7~

l Quorum..................................................

6-7 Re s pon s i b i l i t i e s........................................

6-7 j

Authority...............................................

6-8 Records.................................................

6-8 t

6.5.2 0FF SITE SAFETY REVIEW COMMITTEE (OSSRC)

Function................................................

6-8 i

- C o m po s i t i o n.............................................

6-9 Al t e rn a t e s..............................................

6-9 Co n s u l ta n t s.............................................

6-9 l

Mee ti n g Frequ en cy.......................................

6-9 Qu o r um..................................................

6-9 R e v 1 ew..................................................

6-1 0.

Audits..................................................

6-11 Authority...............................................

6-11 Hecords.................................................

6-12 i

lCALVERT CLIFFS - UNIT 1 XV Amendment No. 26 CALVERT CLIFFS - UNIT 2

- Amendment No.11 w

e INDEX ADMINISTRATIVE CONTROLS SECTION PAGE 6.6 REPORTA8LE EVENT ACTI0N.................................... 6-12 l

6.7 SAFETY LIMIT VIOLATION.....................................

6-13 6.8 P RO C E DU R ES.................................................

6-13 6.9 REPORTING REQUIREMENTS 6.9.1 ROUTINE REP 0RTS..........................................

6-14 l

6.9.2 S P EC I AL RE P0 RTS..........................................

6-18 a

6.10 R E CO RD R ET ENT ION..........................................

6-19 6.11 RADI ATION PROTECTION PR0 GRAM..............................

6-20 6.12 HIGN RADIATION AREA.......................................

6-20 6.13 ENVIRONMENTAL QUALIFICATION:..............................

6-21 6.14 SYSTEM INTEGRITY..........................................

6-21 H6.15 IODINE MONITORING................................'.........

6-22 CALVERT CLIFFS - UNIT 1 XVI Amendment No. 29, 53, 94 O

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e 1.0 DEFINITIONS 4

DEFINED TERMS 1.1 The DEFINED TERMS of this section appear in capitalized type and are applicable throughout these Technical Specifications.

THERMAL POWER l

1.2 THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

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RATED THERMAL POWER 1.3 RATED THERMAL POWER shall be a total reactor core heat transfer rate to the reactor coolant of 2700 MWt.

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5 OPERATIONAL MODE 1.4 An OPERATIONAL MODE shall correspond to any one inclusive combination of core reactivity condition, power level and average reactor coolant temperature s'pecified in Table 1.1.

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ACTION s

i 1.5 ACTION shall be those* additional requirements specified as.corol.lary statements to each principle specification and shall be part of the i

specifications.

OPERABLE - OPERABILITY 1.6 A system, subsystem, train, component or device shall be OPERABLE j

or have OPERABILITY when it is capable of performing its specified function (s).

Implicit in this definition shall be the assumption that all necessary attendant instrumentation, controls, normal and emergency electrical power sources, cooling or seal water, lubrication or other i

required auxiliary equipment that are required for the system, sub-system, train, component or device to perform its function (s) are also capable of performing their related support function (s).

CALVERT CLIFFS-UNIT 1 1-1 Amendment No. 24-S

i DEFINITIONS a

REPORTABLE EVENT I

1.7 A REPORTABLE EVENT shall be any of those conditions specified in Section 50.73 to 10 CFR Part 50.

CONTAINMENT INTEGRITY 1.8 CONTAINMENT INTEGRITY shall exist when:

i 1.8.1 All penetrations required to be closed during accident conditions are either:

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a.

Capable of Neing closed by an OPERABLE containment i

automatic iselation valve system, or b.

Closed by manual valves, blind flanges, or deactivated i

automatic valves secured in their closed positions, j

except as provided in Table 3.6-1 of Specification l

3.6.4.1.

1.8.2 All equipment hatches are closed and sealed.

1.8.3 Each airlock is OPERABLE-pursuant to Specification 3.6.1.3, 1.8.4 The containment leakage rates are within the limits of Specification 3.6.1.2, and 1.8.5 The sealing mechanism associated with each penetration

-(e.g., welds, bellows or 0-rings) is OPERABLE.

i i

CHANNEL CALIBRATION 1.9 A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds with the necessary range and accuracy to known values of the parameter which the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel including the sensor and alarm and/or trip functions, and shall include the CHANNEL FUNCTIONAL l

TEST. The CHANNEL CALIBRATION may be performed by any series of sequen-tial, overlapping or total channel steps such that the entire channel is calibrated.

i CALVERT CLIFFS-UNIT 1 1-2 Amendment No. AA/ 94 9

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INSTRUMENTATION FIRE DETECTION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.7 As a minimum, the fire detection instrumentation for each fire detection zone shown in Table 3.3-11 shall be OPERABLE.

APPLICABILITY: Whenever equipment in that fire detection zone is required to be OPERABLE.

ACTION:

With one or more of the fire detection instrument (s) shown in Table 3.3-11 inoperable:

a.

Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months establish a fire watch patrol to inspect the zone (s) with the inoperable instrument (s) at least once per hour, unless the instrument (s) is located inside the containment, then inspect the containment at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or monitor the contain-ment air temperature at least once per hour at the locations listed in Specification 4.6.1.5; or unless the instrument (s) is, located in fire detection zones equipped with automatic wet pipe sprinkler systems alarmed and supervised to the Control Room, then within i hour and at least per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter, inspect the zone (s) with inoperable instruments and verify that the automatic sprinkler system, including the water ficw alarm and supervisory sjstem, is operable by channel functional test.

b.

Restore the inoperable instrument (s) to OPERABLE status within 14 days or prepare and submit a Special Report to the Commission l

pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the instrument (s) to OPERABLE status.

c.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS

4. 3. 3. 7.1 At least once per 6 months, at least 25% of the above required fire detection instruments which are accessible during plant operation shall be demonstrated OPERABLE by performance of a CHANNEL FUNCTIONAL TEST. Detectors selected for testing shall be selected on a rotating basis such that all detectors will be tested over a two year period.

If in any detection zone there are less than four detectors, at least one different detector in that zone shall be tested every six months. For each detector found inoperable during functi,onal testing, at least an additional 10% of all detectors or 10 detectors, whichever is less, shall also be tested.

Fire detectors which are inaccessible during plant operation shall be demonstrated OPERABLE by the performance of a CHANNEL FUNCTIONAL TEST during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless perfonned during the previous six months.

CALVERT CLIFFS - UNIT 1 3/4 3-43 Amendment No. zg, gJ, 94 L

INSTRUMENTATION SURVEILLANCE RE0VIREMENTS (Continued) 4.3.3.7.2 The NFPA Code 720 Class B supervised circuits supervision associated with the detector alarms of each of the above required fire detection instru-ments shall be demonstrated OPERABLE at least once per 6 months.

4.3.3.7.3 The non-supervised circuits, associated with detector alarms, between l the instrument and the control room shall be demonstrated OPERABLE at least once per 31 days.

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CALVERT CLIFFS - UNIT 1 3/4 3-44 Amendment No. 26, 94 l

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REACTOR COOLANT SYSTEM SURVEILLANCE REOUIREMENTS (Continued) 5.

Defect means an imperfection of such severity that it exceeds the plugging limit. A tube containing a defect is defective. Any tube which does not permit the passage of the eddy-current inspection probe shall be deemed a defective tube.

6.

Plugging Limit means the imperfection depth at or beyond wnich tne tube shall be removed from service because it may become unserviceable prior to the next inspection and is equal to 40% of the nominal tube wall thickness.

7.

Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break as specified in 4.4.5.3.c, above.

8.

Tube Inspection means an inspection of the steam generator tube from the point of entry (hot leg side) completely around the U-bend to the top support of the cold leg.

b.

The steam generator shall be determined OPERABLE after completing the corresponding actions (plug all tubes exceeding the plugging limit and all tubes containing through-wall cracks) required by Table 4.4-2.

4.4.5.5 Reports a.

Following each inservice inspection of steam generator tubes, the number of tubes plugged in each steam generator shall be reported to the Commission within 15 ' days.

b.

The complete results of the steam generator tube inservice inspection shall be included in the Annual Operating Report for the period in which this inspection was completed. This report shall include:

1.

Number and extent of tubes inspected.

2.

Location and percent of wall-thickness penetration for each indication of an imperfection.

3.

Identification of tubes plugged.

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SURVEILLANCE RE0VIREMENTS (Continued)

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'Results of steam generator tube inspections t,hich fall into Categury C-3 and require verbal no'.ifice:1on of the Commission by > telephone within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pursuant tc Sps.cification 6.9.2 prior to resumption of plant operation,. The written followup s

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of this report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrenue ' and shall be sut.mitted within ?the next 30 days.

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TABLE 4.4-2 n.

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STEAM GENERATOR TU8E INSPECTION

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IST SAMPLE INSPECTION 2ND SAMPLE INSPECTION 3RD SAMPLE INSPECTION Sample Site Result Action Required Result Action Required Result Action Required en 8

A minimum of C-1 None N/A N/A N/A N/A c-S Tubes per 3

S. G.

-i-C-2 Plug defective tubes C-1 None N/A N/A and inspect additional Plog defective tufws C-1 None

--e 25 tubes in this S. G.

C-2 and inspect additional C-2 Plug defective tubes 4S tubes in this S. G.

Perform action for C-3 C-3 result of first sample w1-Perform action for C-3 C-3 result of first N/A N/A 1

sample C-3 Inspect all tubes in All other this S. G., plug de-S. G.s are None N/A N/A fective tubes and C-1 inspect 2S tutes in Some S. G.s perform action for N/A N/A each other S. G.

C-2 but no C-2 result et second arklitional sample 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months verMI noti.

S. G. are g

fication to NIIC with C-3 tog written followup

Additional Inspect all tubes in pursuant to speciff-

. G. is C-3 each 5.G. and plug a

to cation 6.9.2.

defective tubes. 24

'5 hour5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months verbal notifica-N/A N/A tion to NRC with written followup pursuant to specifi-to cation 6.9.2.

A S = 3 % Where N is the number of steam generators In the unit. and n is the number of steam generators inspected n

during an inspection

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REACTOR COOLANT SYSTEM SPECIFIC ACTIVITY LIMITING CONDITION FOR OPERATION 3.4.8 The specific activity of the primary coolant shall be limited to:

a.

< l.0 u Ci/ gram DOSE EQUIVALENT I-131, and b.

< 100/E u Ci/ gram.

APPLICABILITY: MODES 1, 2, 3, 4, and 5.

ACTION:

MODES 1, 2 and 3*:

a.

With the specific activity of the primary coolant > 1.0 uCi/ gram DOSE EQUIVALENT I-131 but within the 7.11owable limit (below and to the left of the line) shown on Figure 3.4-1, operation may continue for up to 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months provided that operation under these circumstances shall not exceed 10 percent of the unit's total yearly operating time. The provisions of Specification 3.0.4 are not applicable.

b.

With the specific activity of the primary coolant > 1,0 aci/ gram DOSE EQUIVALENT I-131 for more than 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months during one contin-uous time interval or exceeding the limit line shown on Figure 3.4-1, be in at least HOT STANDBY with Tavg < 500*F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c.

With'the specific activity of the primary coolant > 100/1 ~

uCi/ gram, be in at least HOT STANDBY with T vg = 500*F within a

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

MODES 1, 2, 3, 4 and 5:

d.

With the specific activity of the primary coolant > 1.0 uCi/ gram DOSE EQUIVALENT I-131 or > 100/E uCi/ gram, perform the sampling and analysis requirements of item 4 a) of Table 4.4-4 until the specific activity of the primary coolant is restored to within its limits. Whenever the specific activity of the primary coolant exceeds 1.0 uti/ gram DOSE EQUIVALENT I-131 fer in excess of 50 hours5.787037e-4 days 0.0139 hours 8.267196e-5 weeks 1.9025e-5 months for one continuous time interval or 5 percent of the unit's total yearly operating time pursuant to ACTION a above, a Special Report shall be prepared and submitted to the Commission pursuant te Specification 6.9.2 within the next 30 days. This report shall contain the results of the specific activity analyses together with the following information:

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With Tavg 1. 500*F.

CALVERT CLIFFS - UNIT 1 3/4 4-19 Amendment No. 94 l

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REACTOR COOLANT SYSTEM ACTION:

(Continued) 1.

Reactor power history starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded.

2.

Fuel burnup by core region, 3.

Clean-up flow history starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded, 4.

History of de-gassing operation, if any, starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded, and 5.

The time duration when the specific activity of the pri-mary coolant exceeded 1.0 uCi/ gram DOSE EQUIVALENT I-131.

SURVEILLANCE REQUIREMENTS 4.4.8 The specific activity of the primary coolant shall be determined to be within the limits by performance of the sampling and analysis pro-gram of Table 4.4-4.

CALVERT CLIFFS - UNIT 1 3/4 4-20

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

In addition, determining that the average of the normalized lift-off forces for each sample population (hoop, vertical, dome) is equal to or greater than the required average prestress level; 536 kips for hoop tendons, 622 kips for vertical tendons, and 555 kips for dome tendons (reference Figures 4.6-1, -2, and -3).

If the average is below the required average prestress force, it shall be considered as evidence of possible abnomal degradation of the containment structure.

b.

Removing one wire from each of a dome, vertical and hoop tendon checked for lift off force, and determining over the entire length of the wire:

1.

The extent of corrosion, cracks, or other damage. The presence of abnormal corrosion, cracks or other damage shall be considered evidence of possible abnormal degradation of the containment structure.

2.

A minimum tensile strength value of 240 Ksi (guaranteed ultimate strength of the tendon material) for at least three wire samples (one from each end and one at mid-length) cut from each removed wire.

Failure of any one of the wire samples to meet the minimum tensile strength test is evidence of possible 'abnomal degradation of the containment structure.

c.

Perform a chemical analysis to detect changes in the chemical properties of the sheath filler grease. Any unusual changes in physical appearance or chemical properties that could adversely affect the ability of the filler grease to adhere to the tendon wires or otherwise inhibit corro-sion shall be reported to the Coninission pursuant to Specification 6.9.2 within the next 30 days.

4.6.1.6.2 End Anchorages and Adjacent Concrete Surfaces. The structural integrity of the end anchorages and adjacent concrete surfaces shall be demonstrated by determining through inspection that no apparent changes have occurred in the visual appearance of the end anchorage concrete exterior surfaces or the concrete crack patterns adjacent to the end anchorages.

Inspections of the concrete shall be perfomed during the Type A containment leakage rate tests (reference Specification 4.6.1.2) while the containment is at its maximum test pressure.

4.6.1.6.3 Liner Plate. The structural integrity of the containment liner plate shall be detemined during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2) by a visual inspection of the plate and verifying no apparent changes in appearance or other abnormal degradation.

4.6.1.6.4 Reports. Any abnomal degradation of the containment structure detected during the above required tests and inspections shall be reported to the Conunission pursuant to Specification 6.9.2 within the next 30 days. This report shall include l a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective actions taken.

CALVERT CLIFFS - UNIT 1 3/4 6-9 Amendment No. 86,94 l

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CALVERT CLIFFS - U':IT 1 3/4 6-9a Amendment No. 86

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PLANT SYSTEMS 3/4.7.10 WATERTIGHT DOORS LIMITING CONDITION FOR OPERATION 3.7.10 The following watertight doors shall be closed except when the door is being used for normal entry and exit:

a.

ECCS Pump Room Doors (4).

b.

Service Water Pump Room to Heater Bay Doors (2),

c.

Auxiliary Fcad Pump Room to Heater Bay Doors (2).

d.

Emergency Escape Hatch, Service Water Pump Room from Penetra-tion Room, e.

Miin Steam Piping Area from Piping Penetration Room Door.

f.

Passage to Main Steam Piping Area Door.

g.

Warehouse to Intake Structure Door, Elevation 12'.

h.

Outside to Intake Structure Door.

i.

Warehouse to Intake Structure Door Elevation 29'.

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APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With one or more of the above doors open, restore the door to its closed position within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at'least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUT 00WN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.10 The above watertight doors shall be determined closed at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

._s

.._. _ _.3.

CALVERT. CLIFFS - UNIT 1 3/4 7-65 1

1.

PLANT SYSTEMS 3/4.7.11 FIRE SUPPRESSION SYSTEMS FIRE SUPPRESSION WATER SYSTEM LIMITING CONDITION FOR OPERATION l

l 3.7.11.1 The fire suppression water system shall be OPERABLE with:

f l

Two high pressure pumps, each with a capacity of 2500 gpm, with a.

their discharge aligned to the fire suppression header, l

b.

Two water supr, lies, each with a minimum contained volume of l

300,000 gall',ns, and j

i c.

An OPERABl.E flow path capable of taking suction from the Pretreated Water S+,orage Tanks Numbers 11 and 12 and transferring the water t

l through distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valvet and the first valve ahead of the water flow alarm device on each sprinkler, hose l

standpipe or spray system riser required to be OPERABLE per Specifications 3.7.11.2, 3.7.11.4, and 3.7.11.5.

APPLICABILITY: At all times.

ACTION:

With one pump and/or one water supply' inoperable, restore the a.

inoperable equipment to OPERABLE status within 7 days or prepare l

and submit a Special Report to the Commission pursuant to Specifi.

cation 6.9.2 within the next 30 days outlining the plans and procedures to be used to provide for the loss of redundancy in this system. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

b.

With the fire suppression water system otherwise inoperable:

1.

Establish a backup fire suppression water system within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , and 2.

Submit a Special Report in accordance with Specification 6.9.2:

a)

By telephone within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , b)

Confirmed by telegraph, mailgram or facsimile transmission no later than the first working day followinn the event, and c)

In writing within 14 days following the event, outlining the

action' Gken,- the cause of the inoperability and the plans.

~

and schedule for restoring the system to OPERABLE status.

CALVERT CLIFFS - UNIT I 3/4 7-66 Amendment No. M. M, 94 m

.o PLANT SYSTEMS A

SPRAY AND/OR SPRINKLER SYSTEMS LIMITING CONDITION FOR OPERATION 3.7.11.2 The spray and/or sprinkler systems shown in Table 3.7-5 shall be OPERABLE.

APPLICABILITY: Whenever equipment in the spray / sprinkler protected areas is required to be OPERABLE.

ACTION:

a.

With one or more of the required spray and/or sprinkler systems inoperable, within one hour establish a continuous fire watch with backup fire suppression equipment for those areas in which redundant safe shutdown systems or components could be damaged; j

for other areas, establish an hourly fire watch patrol. Restore the system to OPERABLE status within 14 days or prepare and l

, submit a Special Report to the Commission pursuant to Specifica-tion 6.9.2 within the next 30 days outlining the action.taken, the cause of the'inoperability and the plans and schedule for_ restor-ing the system to OPERABLE status.

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicab'le.

~

SURVEILLANCE REQUIREMENTS 4.7.11.2 Each of the above required spray and/or sprinkler systems shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path, not locked sealed or otherwise secured in position, is in its correct position.

b.

At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.

.c.

At least once per 18 months:

1.

By performing a system functional test which includes simulated automatic actuation of the system, and:

a) Verifying that the automatic valves in the flow path actuate to their correct positions on a simulated test signal, and.

CALVERT CLIFFS - UNITl 3/4 7-69 knendment No. 26,' 5)/,94

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b) Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full' travel.

2.

By a visual inspection of the area in the vicinity of each nozzle (s) to verify the spray pattern will not be obstructed.

1 CALVERT CLIFFS - UNIT 1 3/4 7-70 Amendment No.-t$,61

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- 4

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TABLE 3.7-5 FIRE PROTECTION SPRINKLERS UNIT 1 SPRINKLER LOCATION CONTROL VALVE ELEVATION 11 Diesel Generator 45'-0" 12 Diesei Generator 45'-0" Unit 1 East Pipe Pen Room 227/316*

5'-0" Unit 1 Aux Feed Pump Room 603*

12'-0" Unit 1 East Piping Area Room 428*

45'-0" Unit 1 East Electrical Penetration Room 429*

45'-0" Unit 1 West Electrical Penetration Room 423*

45'-0" Unit I tiain Steam Piping Room 315*

45'-0" Unit 1 Component Cooling Pump Room 228*

5'-0" Unit 1 East Piping Area 224*

5'-0" Unit 1 Radiation Exhaust Vent Equipment Room 225*

5'-0" Unit i Service Water Pump Room 226*

5'-0" Unit i Boric Acid Tank and Pump Room 217*

5 ' _0 "

Unit 1 Reactor Coolant Makeup Pump Room 216*

~

S'-0" Unit 1 Charging Pump Room 115*

(-)10'-0" Unit 1 Misc Waste Mon Room 113*

(-)l0'-0" Cask and Eqpt Loading Area Rooms 419, 420, 425 & 426*

45'-0" Solid Waste Processing

45'-0" Corridors 200, 202, 212 and 219*

5'-0" Corridors 100,103 and 116*

(-)l0'-0" Cable Chase l A*

45'-0" Cable Chase 1B*

45'-0" Unit 1 ECCS Pump Room 119*

(-)l5'-0" Hot Instrument Shop Room 222*

5'-0"

~

Hot Machine Shop Room 223*

5'-0"

Sprinklers required to ensere the OPERABILITY of redundant safe-shutdown-equipment.

CALVERT; CLIFFS - UNIT 1 3/4 7-71 Amendment No. 26, 61 4

0 6_

PLANT SYSTEMS HALON SYSTEMS LIMITING CONDITION FOR OPERATION 3.7.11.3 The following Halon systems shall be OPERABLE with the storage tanks having et least 95% of full charge weight (or level) and 90% of full charge

pressure, a.

Cable spreading rooms total flood system, and associated vertical cable chase IC, Unit 1.

b.

460 volt switchgear rooms 27 & 45' elevation Unit 1.

APPLICABILITY: Whenever equipment protected by the Halon system is required to be OPERABLE.

ACTION:

a.

With both the primary and backup Halon systems protecting the areas inoperable, within one hour establish an hourly fire watch with backup fire suppression equipment for those areas protected by the inoperable Halon system. Restore the system to OPERABLE status within 14 days or prepare and submit a Special Report to the l

l Commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.11.3 Each of the above required Halon systems shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path is in its correct posi tion.

b.

At least once per 6 months by verifying Halon storage tank weight (level) and pressure.

c.

At least once per 18 months by:

1.

Veri'ying the system, including associated ventilation dampers and fire door release mechanisms, actuates manually and auto-matically, upon receipt of a simulated actuation signal,-and 2.

Performance of a flow test through headers and nozzles to assure no blockage.

CALVERT CLIFFS - UNIT 1 3/4 7-72 knendment No. 26, AEE' 94

PLANT SYSTEMS FIRE HOSE STATIONS LIMITING CONDITION FOR OPERATION 3.7.11.4 The fire hose stations shown in Table 3.7-6 shall be OPERABLE.

APPLICABILITY: Whenever equipment in the areas protected by the fire hose stations is required to be OPERABLE.

ACTION:

a.

With one or more of the fire hose stations shown in Table 3.7-6 inoperable, route an additional equivalent capacity fire hose to the unprotected area (s) from an OPERABLE hose station within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Restore the fire hose station (s) to OPERABLE status within 14 days or prepare and submit a Special Report to the Commission pursuant j

' l' to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability)and the plans and schedule for restoring the fire hose station (s to OPERABLE status.

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.11.4 Each of the fire hose stations shown in Table 3.7-6 shall 'be demonstrated OPERABLE; a.

At least once per 31 days by visual inspection of the station to assure all required equipment is at the station. Hose stations located in the containment shall be visually inspected on each scheduled reactor shutdewn, but not nfore frequently than every 31 days.

b.

At least once per 18 months by:

1.

Removing the hose for inspection and re-racking, and 2.

Replacement of all degraded gaskets in couplings.

.c.

At least once per 3 years by:

1.

Partially opening each hose station valve to verify valve OPERABILITY and no flow blockage.

2.

Conducting a hose hydrostatic test at a pressure at least 50 psig greater than the maximum pressure available at that hose station or_ replacement with a new hose.

CALVERT CLIFFS - UNIT 1 3/4 7-73 Amendment No. 26, gy,94

j TABLE 3.7-6 l

FIRE HOSE STATIONS LOCATION ELEVATION NUMBER OF HOSE STATIONS 1.

Containment 10' 2

45' 2

69' 2

2.

Auxiliary Building

-15 '

1 l

-10 '

2 l

5' 6

l 27' 3

45' 5

69'*

4-3.

Turbine Building, Heater Bay Outside Service Water Pump Rooms and Aux Feeder Water Pipe Rooms 12' 3

Outside Switchgear Room 27' 2

Outside,Switchgear Room 45' 3

4.

Intake Structure 10'*

1 j

Fire Hose Stations required for primary protection to ensure the OPERABILITY of safety related equipment.

~

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~

CALVER'T CLIFFS - UNIT 1 3/4 7-74 Amendment No. 26r'6Y# '

4

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PLANT SYSTEMS YARD FIRE HYDRANTS AND HYDRANT HOSE HOUSES LIMITING CONDITION FOR OPERATION 3.7.11.5 The following yard fire hydrants and associated hydrant hose houses shall be OPERABLE.

APPLICABILITY: Whenever equipment in the areas protected by the yard fire hydrants is required to be OPERABLE.

a.

6 yard hydrant and associated hydrant hose house, which provides primary protection for Unit 2 RWT blockhouse.

b.

d7 yard hydrant and associated hydrant hose house, which provides primary protection for Unit 1 RWT blockhouse.

iACTION:

a.

With one or more of the yard fire hydrants or associated hydrant-hose houses inoperable, within I hour have sufficient additional lengths of 2-1/2 inch diameter hose located in an adjacent OPERABLE hydrant hose house to provide service to the unprotected area (s) if the inoperable fire Fjdrant or asscciated hydrant hose house is the primary means of fire suppression. Restore the hydrant or hose house to OPERABLE status within 14 days or prepare and submit a l

Special Report to the Commission pursuant to Specification 6.9.2 l

within the next 30 days outlining the action taken, the cause of i

the inoperability, and the plans and schedule for restoring the hydrant or hose house to OPERABLE status:

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE RE0VIREMENTS 4.7.11.5 Each of the yard fire hydrants and associated hydrant hose houses shall be demonstrated OPERABLE:

a.

At least once per 31 days by visual inspection of the hydrant hose house to assure all required equipment is at the hose house.

b.

At least once per 6 months (once during March, April or May and once during September, October or November) by visually inspecting each yard fire hydrant and verifying that the hydrant barrel is dry and that the hydrant is not damaged.

CALVERT CLIFFS - UNIT 1 3/4 7-75 Amendment No. Eyl, g4 f

9

___A

PLANT SYSTEMS l

SURVEILLANCE REQUIREMENTS (Continued) c.

At least once per 12 months by:

1.

Conducting a hose hydrostatic test at a pressure at least i

50 psig greater than the maximum pressure available at any yard fire hydrant.

2.

Inspecting all the gaskets and replacing any degraded gaskets in the couplings.

3.

Performing a flow check of each hydrant to verify its OPERABILITY.

t f

CALVERT CLIFFS - UNIT 1 3/4 7-76 knendment No. 61

' S

i.

o PLANT SYSTEMS 3/4.7.12 PENETRATION FIRE BARRIERS LIMITING CONDITIONS FOR OPERATION 3.7.12 All fire barrier penetrations (i.e., cable penetration barriers, fire-doors and fire dampers), in fire zone boundaries, protecting safe shutdown areas shall be OPERABLE.

APPLICABILITY: At all times.

ACTION:

a.

With one or more of the above required fire barrier penetrations inoperable within one hour either establish a continuous fire watch on at least one side of the affected penetration, or verify the OPERABILITY of fire detectors on at least one side of the inoperable fire barrier and establish an hourly fire watch patrol; or verify the operability of automatic sprinkler systems (including the water flow alarm and supervisory system) on both sides of the 4

INOPERABLE fire barrier. Restore the inoperable fire barr i

penetration (.s) to operable status within 7 days or prepare,ier submit a Special Report to the Commission pursuant to Specifica-l and tion 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperable penetration and plans and schedulec for restoring the fire barrier penetration (s) to OPERABLE status, b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

f SURVEILLANCE REQUIREMENTS 3

4.7.12 Each of the above required fire barrier penetrations shall be verified to be OPERABLE:

a.

At least once per 18 months by a visual inspection.

b.

Prior to returning.a fire barrier penetration to functional status following repairs or maintenance by performance of a visual inspec-tion of the affected fire barrier penetration (s).

CALVERT CLIFFS - UNIT 1 3/4 7-77 Amendment No. AA/, 94

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4 f

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4 9

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4 ADMINISTRATIVE CON'TROLS MEETING FRE0VENCY 6.5.1.4 The POSRC shall meet at least once per calendar month and as convened by the POSRC Chairman or his designated alternate.

000 RUM 6.5.1.5 A quorum of the POSRC shall consist of the Chairman or his designated alternate and four members including alternates.

RESPONSIBILITIES 6.5.1.6 The POSRC shall be responsible for:

a.

Review of 1) all procedures required by Specification 6.8 and changes thereto, 2) any other proposed procedures or changes thereto as determined by the Plant Superintendent to affect nuclear safety.

b.

Review of all proposed tests and experiments that affect--

nuclear safety.

Review of all proposed changes to Appendix "A" Technidii c.

Specifications.

d.

Review of all proposed changes or modifications to plant systems or equipment that affect nuclear safety.

e.

Investigation of all violations of the Techr.ical Specifications including the preparation and forwarding of reports covering evaluation and reccmmendations to prevent recurrence to the Manager - Nuclear Power Department and to the Chairman of the Off Site Safety Review Committee.

f.

Review of all REPORTABLE EVENTS.

[

g.

Review of facility operations to detect potential safety hazards.

h.

Performance of special reviews, investigations or analyses and reports thereon as requested by the Chairman of the Off Site Safety Review Committee.

1.

Review of the Plant Security Plan and implemen;ing procedures and shall submit recommended changes to the Off Site Safety Review Committee.

j.

Review of the Dnergency Plan and implementing procedures and shall submit recommended changes to the Off Site Safety Review Committee.

~

CALVERT CLIFFS - UNIT 1 6-7 Amendment No. 26, 39, #3, ne 4

r-

ADMINISTRATIVE CONTROLS AUTHORITY j

6.5.1.7 The Plant Operations and Safety Review Committee shall:

a.

Recommend to the Plant Superintendent written approval or l

disapproval of,ttems considered under 6.5.1.6(a) through (d) above.

b.

Render determinations in writing with regard to whether or not each item considered under 6.5.1.6(a) through (e) above constitutes an unreviewed safety question.

Provide written notification within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to the Manager -

c.

Nuclear Power Department and the Off Site Safety Review Committee of disagreement between the POSRC and the Plant Superintendent; however, the Plant Superintendent shall have l

responsibility for resolution of such disagreements pursuant to 6.1.1 above.

RECORDS 6.5.1.8 The POSRC shall naintain written minutes of each meeting;and copies shall be provided to the Manager - N.uclear Power Department and l

Chairman of the Off Site Safety Review Committee.

~

6.5.2 0FF SITE SAFETY REVIEW COMMITTEE (OSSRC)

FUNCTION 6.5.2.1 The Off Site Safety Review Committee shall function to provide independent review and audit of designated activities in the i

areas of:

a.

nuclear power plant operations b.

nuclear engineering c.

chemistry and radiochemistry d.

metallurgy and non-destructive examination e.

instrumentation and control f.

radiological safety

'g.

~ mechanical and electrical engineering

~"

h.

quality assurance practices j

CALVERT CLIFFS - UNIT 1 6-8 Amendment No.43 I

l

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ADMINISTRATIVE CONTROLS COMPOSITION 6.5.2.2 The OSSRC shall be composed of at least seven members, including the Chairman. Members of the OSSRC may be from the Supply Division or other BGAE organization or from orgainizations external to BG&E and shall collectively have expertise in all of the areas of 6.5.2.1.

OUALIFICATIONS 6.5.2.3 The Chairman, members and alternate members of the OSSRC shall t

be appointed in writing by the Vice President - Supply and shall have an academic degree in engineering or a physical science, or the equiva-lent, and in addition shall have a minimum of five years technical experience in one or more areas given in 6.5.2.1.

No more than two alternates shall participate as voting members in OSSRC activities at I

any one time.

l

=-

CON 9ULTANTS 6.5.2.4 Consultants'shall be utilized as determined by the OSSRC Chairman to provide expert advice to the OSSRC.

MEETING FRE0llENCY 6.5.2.5 The OSSRC shall meet at least once per six months.

}

QUORUM 6.5.2.6 The quorum of the OSSRC necessary for the performance of the OSSRC review and audit functions of these Technical Specifications shall consist l

of more than half the OSSRC membership or at least four members, whichever 1

is greater. This quorum shall include the Chairman or his appointed alternate' end the OSSRC members, including appointed alternates, meeting the require-l ments.of Specification-6.5.2.3.

No more 65an a minority of the. quorum.shall l

~~

have line responsib'ility for operatien of the plant.

CALVERT CLIFFS - UNIT 1 6-9 Amendment No.43 1

ADMINISTRATIVE CONTROLS REVIEW 6.5.2.7 The OSSRC shall review:

a.

The safety evaluations for 1) changes to procedures, equipment or systens and 2) tests or experiments completed under the provisions of Section 50.59, 10 CFR, to verify that such actions did not constitute an unreviewed safety question.

b.

Proposed changes to procedures, equipment or systems which involve an unreviewed safety question as defined in Section 50.59, 10 CFR.

c.

Proposed tests or experiments which involve an unreviewed safety question as defined in Section 50.59, 10 CFR.

d.

Proposed changes in Technical Specifications or this Operating License.

Violations of codes, regulations, orders, Technical Specifications, e.

license requirements, or of internal procedures or instructions having nuclear safety significance;.'

f.

Significant operating abnormalities or deviations from normal and expected performance of plant equipment that affect nuclear safety.

g.

All REPORTABLE EVENTS.

h.

All recognized indications of an unanticipated deficiency in some aspect of design or operation of safety related structures, systems, or components.,

i.

Reports and meetings minutes of the POSRC.

CALVERT CLIFFS - UNIT 1 6-10 Amendment No. 94

4 ADrilNISTRATIVE CONTROLS AUDITS 6.5.2.8.1 Audits of facility activities shall be performed under the cognizance I of the OSSRC. These audits shall encompass:

a.

The conformance of facility operation to provisions contained within the Technical Specifications and applicable license conditions at least once per 12 months.

b.

The performance, training and qualification of the entire facility staff at least once per 12 months.

c.

The results of actions taken to correct deficiencies occurring in facility equipment, structures, systems or method of operation that affect nuclear safety at least once per 6 months.

d.

The performance of activities required by the Quality Assurance Program to meet the criteria of. Appendix "B",10 CFR 50, at least once per 24 months.

e.

Deleted f.

The Safeguards Contingency Plan and implementing procedurei, at least once per 12 months in-accordance.wi,th 10 CFR 73.40(d).

g.

Any other area of facility operation considered appropriate by the OSSRC or the Vice President-Supply.

h.

The Facility Fire Protection Program and implementing procedures at least once per 24 months.

1.

An independent fire protection and loss prevention program inspection and audit shall be performed at least once per 12 months utilizing either qualified offsite licensee personnel or an outside fire protection firm.

j.

An inspection and audit of the fire protection and loss prevention program shall be performed by a qualified outside fire consultant at least once per 36 months.

6.5.2.8.2 - Review of facility activities shall be performed under the cognizance

~

of the OSSRC. These reviews shall encompass:

a.

The Facility Emergency Plan and implementing procedures at least once per 12 months in accordance with 10 CFR Part 50.54(t).

AUTHORITY 1.

6.5.2.9 The OSSRC shall report to and advise the Vice President-Supply on those areas of responsibility specified in Sections 6.5.2.7 and 6.5.2.8.

CALVERT CLIFFS - UNIT 1 6-11 Amendment No. 25,82 '

ADMINISTRATIVE CONTROLS RECORDS 6.5.2.10 Records of OSSRC activities shall be prepared, approved and distributed as indicated below:

a.

Mjnutes of each OSSRC meeting shall be prepared, approved and forwarded to the Vice President-Supply within 14 days following each meeting, b.

Reports of reviews encompassed by Section 6.5.2.7 above, shall be prepared, approved and forwarded to the Vice President-Supply within 14 days following completion of the review.

c.

Audit reports encompassed by Section 6.5.2.8 above, shall be forwarded to the Vice President-Supply and to the management positions responsible for the areas audited within 30 days after completion of the audit.

6.6 REPORTABLE EVENT ACTION

[,

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6.6.1 The following actions shall be taken far REPORTABLE EVENTS:.

I

~

a.

The Commission shall be notified and a report submitted pursuant to the requirements of Section 50.73 to 10 CFR Part 50, and b.

Each REPORTABLE EVENT shall be reviewed by the POSRC and the results of this review shall be submitted to the OSSRC and the Manager - Nuclear Power Department.

.._r...

CALVERT CLIFFS - UNIT 1 6-12 Amendment No. (S, $2, 94

ADMIrllSTRATIVE CONTROLS 6.7 SAFETY LIMIT VIOLATION 6.7.1 The following actions shall be taken in the event a Safety Limit is violated:

a.

The facility shall be placed in at least HOT STAf!DBY within one hour.

b.

The ilRC Operations Center shall be notified by telephone as soon as possible and in ali cases within one hour.

The Manager - Nuclear Power Department and the OSSRC shall be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

j c.

A Safety Limit Violation Report shall be prepared.

The report shall be reviewed by the POSRC. This report shall describe (1) applicable circumstances preceding the violation, (2) effects of the violation upon facility components, systems or structures, and (3) corrective action taken to prevent recurrence.

d.

The Safety Limit Violation Report shall be submitted to the Commission, the OSSRC and the Manager - fluclear Power Department withi;.14 days of the violation.

,6.8 PROCEDURES 6.8.1 Written procedures shall be established; implemented and maintained covering the activities referenced below:

a.

The applicable procedures recommended in Appendix "A" of Regulatory Guide 1.33, Ravision 2, February 1973.

b.

Refueling operations.

c.

Surveillance and test activities of safety related equipnent.

d.

Security ' Plan implementation.

e.

Emergency Plan implementation, f.

Fire Protection Program implementation.

g.

The amount of overtime worked by plant staff members performing safety related functions must be limited in accordance with the NRC Policy Statement on working hours (Generic Letter No. 82-12).

6.8.2 Each procedure and administrative policy of 6.8.1 above and changes thereto shall be reviewed by the POSRC and approved by the Plant Superin-tendent prior to implementati.on and reviewed periodically as set forth in

~- '

administrati've procedures.

CALVERT CLIFFS - UNIT 1 6-13 knendment No.26, A3, 75,82 i-

ADMINISTRATIVE CONTROLS 6.8.3 Temporary changes to procedures of 6.8.1 above may be made pro-vided:

a.

The intent of the originial procedure is not altered, b.

The change is aporoved by two members of the olant management staff, at least one of whom holds a Senior Reactor Operator's License on the unit affected.

c.

The change is documented, reviewed by the POSRC and approved by the Plant Superintendent within 14 days of implementation.

6.9 REPORTING REnUIREMENTS ROUTINE REPORTS 6.9.1 In addition to the applicable reporting requirements of Title 10, Code of Federal Regulations, the followi.ng reports shall be submi.tted to the Director of the Regional Office of Inspection and Enforcement unless otherwise noted.

~ J li.

STARTUP REPORT

~I 6.9.1.1 A summary report of plant startup and power escalation testin shall be submitted following (1) receipt of an operating license, (2) g amendment to the license involving a planned increase in oower level, (3) installation of fuel that has a different design or has been manu-factured by a different fuel supplier, and (4) modifications that may have significantly altered the nuclear, thermal, or hydraulic perfor-mance of the plant.

6~9.1.2 The startuo report shall address each of the tests identified in the FSAR and shall include a description of the measured values of the operating conditions or characteristics obtained during the test orogram and a comoarison of these values with design credictions and specifications. Any corrective actions that were required to obtain satisfactory operation shall also be described. Any additional specific detafis required in license conditions based;on other connitments shall be included in this report.

.__.a.

CALVERT CLIFFS - UNIT 1 6-14 Amendment No. pf, fy,82,94 m

e-

k ADMINISTRATIVE CONTROLS 6.9.1.3 Startup reports shall be submitted within (1) 90 days following completion of the startup test program, (2) 90 days following resumption or commencement of commercial power operation, or (3) 9 months following initial criticality, whichever is earliest.

If the Startup Report does not cover all three events (i.e., initial criticality, completion of startup test program, and resumption or commencement of commercial power operation), supplementary reports shall be submitted at least every three months until all three events have been completed.

ANNUAL rep 0RTS 1/

6.9.1.4 Annual reports covering the activities of the unit as described below for the previous calendar year shall be submitted prior to March 1 of each year. The initial report shall be submitted prior to March I of the year following initial criticality.

6.9.1.5 Reports required on an annual basis shall include:

a.

A tabulation on an annual basis of the number of station, utility, and other personnel (including contractors) receiving exposures greater than 100 mrem /yr and their a according to work and job functions,gfociated man rem exposure e.g., reactor operatiq_ns and surveillance, inservice inspection, routine maintenance, special maintenance (describe maintenance), waste processing, and refueling. The dose assignment to va,rious duty functions may be estimates based on pocket dosimeter, TLD, or film badge measure-ments. Small exposures totalling less than 20% of the individual total dose need not be accounted for.

In the aggregate..at least 80% of the total whole body dose received from external sources shall be assigned to specific major work functions.

b.

The complete results of steam generator tube inservice inspections performed during the report period (reference Specification 4.4.5.5.b).

c.

Documentation of all failures and challenges to the pressurizer PORVs or safety valves.

J 1/ A single submittal may be made 'for a multiple unit station ' The submittal should combine those sections that are connon to all unitsat the ststion.

2/ This tabulation supplements the requirements of 220.407 of 10 CFR Part 20.

CALVERT CLIFFS - UNIT 1 6-15 Amendment No. 29,6 8 e

ADMINISTRATIVE CONTROLS MONTHLY OPERATING REPOST 6.9.1.6 Routine reports of cperating statistics and shutdown experience shall be submitted on a monthly basis to the Director, Office of Inspection and Enforcement, U. S. Nuclear Regulatory Cormission, Washington, D. C.

2055E, ATTN: Document Control Desk, with a copy to the Regional Adminis-trator and to the NRC Resident Inspector, no later than the 15th of each month following the calendar month covered by the report.

l l

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CALVERT CLIFFS - UNIT 1 6-16 Amendment No. 29, 68, g4

AOMINISTRATIVE CONTROLS DELETED THIS PAGE DELIBERATELY LEFT BLANK CALVERT CLIFFS - UNIT 1 6-17

' Amendment No. 29, 94

ADMINISTRATIVE CONTROLS SPECIAL REPORTS

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6.9.2 Special reports shall be submitted to the Director of the Office of Inspection and Enforcement Regional Office Within the time period specified for each report. These reports shall be submitted cove' ing the activities r

identified below pursuant to the requirements of the applicable reference specification:

a.

ECCS Actuation, Specifications 3.5.2 and 3.5.3.

b.

Inoperable Seismic Monitoring Instrumentation, Specification 3.3.3.3.

c.

Inoperable Meteorological Monitoring' Instrumentation, Specifica-tion 3.3.3.4.

d.

Seismic event analysis, Specification 4.3.3.3.2.

.e.

. Core Barrel Movement, Specification 3.4.11.

f.

Fire Detection Instrumentation, Specification 3.3.3.7.

g.

Fire Suppression Systems, Specifications 3.7.11.1, 3.7.11.2, 3.7.11.3, 3.7.11.4 and 3.7.11.5.

h.

Penetration Fire. Barriers, Specification 3.7.12.

j i.

Steam Generator Tube Inspection Results, Specification 4.4.5.5.

j.

Specific Activity of Primary Coolant, Specification 3.4.8.

k.

Containment Structural Integrity, Specification 4.6.1.6.

CALVERT CLIFFS - UNIT 1 6-18 Amendment No. 29, 94

1 ADMINISTRATIVE CONTROLS 6.10 RECORD RETENTION 6.10.1 The following records shall be retained for at least five years:

a.

Recorcs and logs of facility operation covering time interval at each power level, b.

Records and logs of principal maintenance activities, inspections, repair and replacement of principal items of eauipment related to nuclear safety.

c.

All REPORTABLE EVENTS.

d.

Records of surveillance activities, inspections and calibrations required by these Technical Specifications.

e.

Records of reactor tests and experiments, f.

Records of changes made to Operating Procedures.

g.

Records of radioactive shipments..

h.

Records of sealed source and fission. detector leak tests and results.

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i.

Records of annual physical inventory of all sealed source material of record.

6.10.2 The following records shall be retained for the duration of the Facility Operating License:

a.

Records and drawing changes reflecting facility design modifi-cations made to systems and equipment described in the Final Safety Analysis Report.

b.

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

c.

Records of facility radiation and contamination surveys.

CALVERT CLIFFS - UNIT l 6-19 Amendment No. 29, 94 1

I ADMINISTRATIVE CONTROLS d.

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

e.

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

f.

Records of transient or operational cycles for those facility components identified in Table 5.7.1.

g.

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

h.

Records of in-service inspections performed pursuant to these Technical Specifications.

i. Records of Quality Assurance activities identified in the NRC approved QA Manual as lifetime records.

J.

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

k.

Records of meetings of the POSRC and the OSSRC.

1.

Records of Environmental Qualificatio'n which are covered under the provisions of paragraph 6.13.

m.

Records of the service lives of all snubbers listed on Table 3.7-4 including the date at which the service life commences and associated installation and maintenance records.

i 6.11 RADIATION PROTECTION PROGRAM Procedures for personnel radiation protection shall be prepared consistent with the requirements of 10 CFR Part 20 and shall be approved,' maintained and adhered to for all operations involving personnel radiation exposure.

6.12 HIGH RADIATION AREA 6.12.1 In lieu of the " control device" or " alarm signal" required by paragraph 20.203(c)(2) of 10 CFR Part 20:

a.

A high radiation area in which the intensity of radiation is I

greater than 100 mrem /hr but less than 1000 mrem /hr shall be barricaded and conspicuously posted as a High Radiation Area and entrance thereto shall be controlled by issuan:e of a Special or l

Radi,ation Work Permit and any individual or group of individug.ls permitted to enter such areas shall be provided with a radia'ti6n monitoring device which continuously indicates the radiation l

dose rate in the area.

l CALVERT CLIFFS - UNIT 1 6-20 Amendment No. 6 4

,(

fo, UNITED ST ATEs

+

j NUCLEAR REGULATORY COMMISSION

( ) ){W

.g,

.p WASHINGTON, D. C. 20555

\\f.'.us,f BALTIMORE GAS AND ELECTRIC COMPANY DOCKET NO. 50-318 CALVERT CLIFFS NUCLEAR POWER PLANT UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 75 License No. DPR-69 1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Baltimore Gas & Electric Company (the licensee) dated January 27 and March 26, 1984, complies with as amended (the Act)quirements of the Atomic Energy Act of 1954, the standards and re ar.d the

.smission's rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity.with the application, the provisions of the Act, and the rules and regulations of--

the Commission;

-( '-

C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conduc'ed in compliance with the Commission's regulations; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

~

~ - '

, _.- e - ---;

i g

. 2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.2 of Facility Operating License No. DPR-69 is hereby amended to read as follows:

2.

Technical Scecifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No. 75, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifica-tions.

3.

This license amendment is effective as of the date of its issuance.

FOR THE t;UCLEAR REGULATORY COMMISSION

..es R. Miller, Chief Operating Reactors Branch #3 Division of. Licensing

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Attachment:

~

Changes to the Technical Specifications Date of Issuance: June 6, 1984 e,

,y e

- l 1

ATTACHMENT TO LICENSE AMENDMENT NO. 7s FACILTIY OPERATING LICENSE NO. DPR-69 DOCKET NO. 50-318 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by Amendment number and contain vertical lines indicating the areas of change. The corresponding overleaf pages are provided to maintain document completeness.

Pages I

VI VIII XVI 1-2 3/4 3-38 3/4 3-43 3/4 4-10 3/4 4-12 3/4 4-19 3/4 6-9 3/4 6-9b 3/4 6-23 3/4 6-25 3/4 6-58 3/4 6-61 3/4 6-64 3/4 6-65 3/4 6-67 3/4 6-69 3/4 9-17 6-7 6-10 6-12 6-14 6-16 6-17 6-18 6-19

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a 4

. Q

INDEX DEFINITIONS SECTION PAGE 1.0 DEFINITIONS D e f i n e d Te rm s..............................................

1 -1 Th e rm a l P ow e r..............................................

1-1 Ra te d Th e rma l Powe r........................................

1-1 Goerational Mode.............

1-1 Action.....................................................

1-1 Operable - Operability.....................................

1-1 Reportable Event...........................................

1-2 l

Containment Integrity......................................

1-2 Channel Calibra+. ion........................................

1-2 2

Channel Check..............................................

13 C h a nn el Fu n ctio n al Te s t....................................

1-3 Core Alteration.....................l!.....................

1-3 Shutdown Margin............................................

1-3 Identified leakage..........................

1-4 Unidentified Leakage.......................................

1-4 P res su re B oun da ry Leakage..................................

1-4 Controlled leakage.........................................

1-4 Azimuthal Power Ti1t.......................................

1-4 Dose Equivalent I-131......................................

1-4 E-Average Di sintegration Energy............................

1-5 Staggered Test Basis.......................................

1-5 Frequency Notation.........................................

1-5 Axial Shape Index..........................................

1-5 Unrodded Planar. Radial Peaking Factor - F 1-5 xy................

Reactor Trip Sys tem Response Time..........................

1-6 Engineered Safety Feature Response Time...................

1-6 Phys i c s Te s t s....... 7.....................................

- T-6 Unrodded -Integrated Radial Peaking Factor - F.............

1-6 r

CALVERT CLIFFS - UNIT 2 I

Amendment No. 9, 78, 14, 75 '

l

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INDEX SAFETY LIMITS AND LIMITING SAFEiY SYSTEM SETTINGS SECTION PAGE 2.1 SAFETY LIMITS Reactor Core................................................

2-1 I;eactor Coola nt System Pressure.............................

2-1 2.2 LIMITING SAFETY SYSTEM SETTINGS Rea cto r T ri p Se tpoi nts......................................

2-6 BASES SECTION PAGE 2.1 SAFETY LIMITS Reactor Core................................................

B 2-1 Reactor Coolant System Pressure.............................

B 2-3 2.2 LIMITING SAFETY SYSTEM SETTINGS Reactor Trip Setpoints......................................

B 2-4 CALVERT CLIFFS - UNIT 2 II

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v

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS SECTION AGE

{

1 3/4.4.4 PRES 5URIZER..........................................

3/4 4-5 3/4.4.5 STEAM GENERATORS.....................................

3/4 4-6 1

3/4.4.6 REACTOR COOLANT SYSTEM LEAKAGE Leakage Detection Systems............................

3/4 4-13 Reactor Coolant System Leakage.......................

3/4 4-14 3/4.4.7 CHEMISTRY...............,............................

3/4 4-16 l

3/4.4.8 SPECIFIC ACTIVITY....................................

3/4 4-19 3/4.4.9 PRESSURE / TEMPERATURE LIMITS Reactor Cool ant Sys tem...............................

3/4 4-23 Pressurizer.....................7..

3/4 4-27 Overpressure Protection Systems......................

3/4 4-27a l

3/4.4.10 STRUCTURAL INTEGRITY ASME Code Class - 1, 2 and 3 Components................

3/4 4-28 3/4.4.11 CORE BARREL M0VEMENT.................................

3/4 4-30 3/4.4.12 LETDOWN LINE EXCESS FL0W.............................

3/4 4-32 3/4.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3/4.5.1 SAFETY INJECTION TANKS................................

3/4 5-1 3/4.5.2 ECCS SUBSYSTEMS - Tavg 300*F.......................

3/4 5-3 3/4.5.3 ECCS SUBSYSTEMS - T,yg <300*F.......................

3/4 5-6 3/4.5.4 REFUELING WATER STORAGE TANK.........................

3/4 5-7 CALVERT CLIFFS - UNIT 2 V

Amendment No. 6, 16' Y.

X-

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Conta i nment Integri ty............................... 3/4 6-1 Contai nment Lea ka ge................................. 3/4 6-2 Contai nment Air Locks............................... 3/4 6-4 I nte rnal ' Pres s u re................................... 3/4 6-6 Ai r Tempe ra tu re.....................................

3/ 4 6-7 Containment Structural Integrity.................... 3/4 6-8 Containment Purge System............................

3/4 6-9a Containment Vent System.............................

3/4 6-9b 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS Containment Spray System..........g. ;;.............. 3/4-6-10 Containment Cooling System..........................

3/4 6-12 3/4.6.3 IODINE REMOVAL SYSTEM...............................

3/4 6-13 3/4.6.4 CONTAINMENT ISOLATION VALVES........................ 3/4 6,17 3/4.6.5 COMBUSTIBLE GAS CONTROL Hyd ro gen Analyzers.................................. 3/4 6-26 El ectric Hydrogen Recombiners - W................... 3/4 6-27 3/4.6.6 PENETRATION ROOM EXHAUSE AIR FILTRATION SYSTEM......

3/4 6-28 3/4.7 M. ANT SYSTEMS 3/4.7.1 TURBINE CYCLE Sa fe ty Va 1 ves....................................... 3/4 7-1 Auxili ary Feedwater System.......................... 3/4 7-5 Condensate Storage" Tank.............................

3/4 7-E/

Ac t i v i ty............................................ 3 / 4 7-7 Main Steam Line Isolation Valves.................... 3/4 7-9 Secondary Water Chemi stry........................... 3/4 7-10 CALVERT CLIFFS - UNIT 2 VI Amendment No. 75

)

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.7.2 STEAM GENERATOR PRESSURE / TEMPERATURE LIMITATION...........

3/4 7-13 3/4.7.3 COMPONENT COOLING WATER SYSTEM............................

3/4 7-14 3/4.7.4 SERVICE WATER SYSTEM............................

3 /4 7 -15 3/4.7.5 S ALT W AT E R S Y S T EM.........................................

3 / 4 7 - 1 6

,3/a.7.6 CONTROL ROOM EMERGENCY VENTILATION SYSTEM.................

3/4 7-17 3/4.7.7 ECCS PUMP ROOM EXHAUST AIR FILTRATION SYSTEM..............

3/4 7-21 3/4.7.8 SNUCBERS.....................................

3/4 7-25

l 3/4.7.9 SEALED SOURCE CONTAMINATION...............................

3/4 7-55 t

j'3/a.7.10 WATERTIGHT 000RS..........................................

3/4 7-57 3/4.7.11 FIRE SUPPRESSION SYSTEMS Fire Suppression Wa ter Sys tem.............................

3/4 7-58 S pray a nd/or S pri nkl er Sys t ems............................

3 /_4 7-61 l

Halon System..

3/4 7-64 l

Fi re Ho s e S ta ti o ns.......................................i. 3/4 7-65 Yard Fire Hydrants and Hydrant Hose Hous es................

3/4 7-67 3/4.7.12 PENETRATION FIRE BARRIERS.................................

3/4 7-69 J/4.8 ELECTRICAL POWER SYSTEMS 3/ 4. 8.1 A.C. SOURCES O p e r a ti n g.................................................

3 / 4 8 -1 Shutdown.....................

3/4 8-5 3/4.8.2 ONSITE POWER DISTRIBUTION SYSTEMS A.C. Di s tri buti on - Operati ng.............................

3/4 8-6 A.C. Di s tri bution - Shutdown..............................

3/4 8-7 D.C. Di s tri bution - Opera ti ng............................. 3/4 8-8 D.C. Distribution - Shutdown..............................

3/4 8-11 3/4.9 REFUELING OPERATIONS 3/4.9.1 BORON CONCENTRATION........................................ 3/4 9-1 3/4.9.2 INSTRUMENTATION...........................................

3/4 9-2 3/4.9.3 DECAY TIME................................................

3/4 9-3 CALVERT CLIFFS - UNIT 2 VII Amendment No. 6, 77, A3, i g a

J

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.9.4 CONTAINMENT PENETRATIONS.............................. 3/4 9-4 4

3/4.9.5 COMMUNICATIONS........................................

3/4 9-5 3/4.9.6 REFUELING MACHINE OPERABILITY......................... 3/4 9-6 3/4.9.7 CRANE TRAVEL - SPENT FUEL STORAGE POOL BUILDING....... 3/4 9-7 3/4.9.8 SHUTDOWN COOLING AND COOLANT CIRCULATION.............. 3/4 9-8 3/4.3.9 CONTAINMENT PURGE VALVE ISOLATION SYSTEM..............

3/4 9-9 l

3/4.9.10 WATER LEVEL - REACTOR VESSEL..........................

3/4 9-10 3/4.9.11 SPENT FUEL POOL WATER LEVEL........................... 3/4 9-11 3/4.9.12 SPENT FUEL POOL VENTILATION SYSTEM....................

3/4 9-12

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3/4.9.13 SPENT FUEL CAS K HANDLING CRANE........................

3/4 9-16 3/4.9.14 CONTAINMENT VENT ISOLATION VALVES..................... 13/4 9-17 l

3/4.10 SPECIAL TEST EXCEPTIONS 3/4.10.1 9H UT DOWN MARGI N....................................... 3/ 4 10- 1 3/4.10.2 MODERATOR TEMPERATURE COEFFICIENT, CEA INSERTION AND POWER DISTRIBUTION LIMITS....................... 3/4 10-2 3/4.10.3 NO FLOW TESTS......................................... 3/4 10-3 3/4.10.4 CENTER CEA MISALIGNMENT...............................

3/4 10-4 3/4.10.5 COOLANT CIRCULATION...................................

3/4 10-5 i

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. - r-CALVERT CLIFFS - UNIT 2 VIII

_ Amendment No. $, JJ, 38, 75 S

b

1 INDEX ACMINISTRATIVE CONTROLS SECTION PAGE 6.1 RESPONSIBILITY........................................

6-1 6.2 ORGANIZATION 0ffsite...................................................6-1 Fa c i.l i ty S ta f f.......

6-1 6.3 FA C ILITY STA FF 00AL I FI CATIONS.............................

6-6 6.4 TRAINING..................................................

6-6 6.5 REVIEW AND AUDIT 6.5.1 PLANT OPERATIONS AND SAFETY REVIEW COMMITTEE (POSRC)

Function................................................. E-6, Composition.............................................

6-6 Alternates..............................................

5-6 M e e t i n g F r e q u e n cy.................... -...-...............

6 - F l

Quorum..................................................

6-7 Responsibilities.......................~................

6-7 Authority...............................................

6-8 Records.................................................

6-8 6.5.2 0FF SITE SAFETY REVIEW COMMITTEE (OSSRC)

Function................................................

6-8 Composition.............................................

6-9 Alternates..............................................6-9 Consultants.............................................

6-9 Meeting Frequency.......................................

6-9 Quorum..................................................6-9 Review..................................................

6-10 Audits..................................................6-11 Authority...............................................

6-11 R e c o r d s'.................................................

6 - 1 2 * '

XV CALVERT CLIFFS -' UNIT 2 Amendment No. 11

.I

INDEX ADMINISTRATIVE CONTROLS SECTION PAGE 6.6 REPORTA9LE EVENT ACTI0N.................................

6-12 l

6.7 S A F ETY L I MIT V IOLATI ON..................................

6-13 6.8 PROCEDURES..............................................

6-13 6.9 REPORTING REQUIREMENTS 6.9.1 ROUTINE REP 0RTS.......................................

6-14 6.9.2 S P E C I AL RE P0 RTS.......................................

6-18' 6.10 R E CO RD R ETE NT I O N.......................................

6-19 6.11 RADIATION PROTECTION PR0 GRAM...........................

6-20 6.12 HIGH RADIATION AREA....................................

6-20 6.13 ENVIRONMENTAL QUALIFICATION............................

6-21 6.14 SYSTEM INTEGRITY.......................................

6-21 6.15 IODINE MONITORING......................................

6-22 4

CALVERT CLIFFS - UNIT 2 XVI Amendment No. Jf. 36, 75

'O e

1.0 DEFINITIONS DEFINED TERMS 1.1 The DEFINED TERMS of this section appear in capitalized type and are applicable throughout these Technical Specifications.

THERMAL POWER 1.2 THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

RATED THERMAL POWER 1.3 RATED THERMAL POWER shall be a total reactor core heat transfer rate to the reactor coolant of 2700 MWt.

l OPERATIONAL MODE 1.4 An OPERATIONAL MODE shall correspond to any one inclusive combination of core reactivity condition, power level and average reactor coolant temperature specified in Table 1.1.

7 ACTION 1.5 ACTION shall be those additional requirements specified as corollary statements to each principle specification and shall be part of the specifications.

OPERABLE - OPERABILITY

- 1.6 A systen., subsystem, train, component or device shall be OPERABLE or Save OPERABILITY when it is capable of performing its specified function (s). Implicit in this definition shall be the assumption that all necessary attendant instrumentation, controls, normal and emergency,

electrical power sources, cooling or seal water, lubrication or other required auxiliary equipment that are required for the system, sub-system, train, component or device to perform its function (s) are also capable of performing their related support function (s).

~~

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i CALVERT CLIFFS-UNIT 2 1-1 Amendment No. 9 l

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o

. l DEFINITIONS REPORTABLE EVENT 1.7 A REPORTABLE EVENT shall be any of those conditions specified in Section 50.73 to 10 CFR Part 50.

CONTAINMENT INTEGRITY 1.8 CONTAINMENT INTEGRITY shall exist when:

1. 8.1 All penetrations required to be closed during accident conditions are either:

a.

Capable of being closed by an OPERABLE containment automatic isolation v 've system, or b.

Closed by manual valves, blind flanges, or deactivated automatic valves secured in their closed positions, except as provided in Table 3.6-1 of Specification ___

3.6.4.1.

1.8.2 Allequipmenthatchesareclosed_andsealed, 1.8.3 Each airlock is OPERABLE pursuant to Specification 3.6.1.3, 1.8.4 The containment leakage rates are within the limits of Specification 3.6.1.2, and 1.8.5 The sealing mechanism associated with each penetration (e.g., welds, bellows or 0-r.ings) is OPERABLE.

1 CHANNEL CALIBRATION 1.9 A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds with the necessary range and accuracy to known values of the parameter which the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel including the sensor and alarm and/or trip functions, and shall include the CHANNEL FUNCTIONAL TEST. The CHANNEL CALIBRATION may be performed by any series of sequen-tial, overlapping or total channel steps such that the entire channel is calibrated.

r.

4 CALVERT CLIFFS-UNIT 2 1-2 Amendment No. fd, 75

e INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.5 The remote shutdown monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE with readouts displayed external to the control room.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a.

With the number of OPERABLE remote shutdown monitoring channels less than required by Table 3.3-9, either restore the inoperable channel to OPERABLE status within 30 days, or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

b.

The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.5 Each remote shutdown monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECX and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-6.

4 e

9 CALVERT CLIFFS - UNIT 2 3/4 3-37

s t

h TABLE 3.3-9 MQ REMOTE SHUTDOWN MONITORING INSTRUMENTATION n"

MINIMUM Q

READOUT MEASUREMENT CHANNELS INSTRtMENT LOCATION RANGE OPERABLE e

2C43 0.1 cps-200%

1 E

1.

Wide Range Neutron Flux 4

2.

Reactor Trip Breaker Cable Spreading m

l Indication Room OPEN-CLOSE 1/ trip breaker 3.

Reactor Coolant Cold Leg Temperature 2C43 212-7050F 1

4.

Pressurizer Pressure 2C43 0-1600 psia 1

5.

-Pressurizer Level 2043 0-360 inches 1

Y M

6.

Steam Generator Pressure 2C43 0-1200 psig 1/ steam generator

3 7.

Steam Generator Level 2043

-401 to 463.5 inches 1/ steam generator i

3 a

(

h

e O

INSTRUMENTATION FIRE DETECTION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.7 As a minimum, the fire detection instrumentation for each fire detection zone shown in Table 3.3-11 shall be OPERABLE.

APPLICABILITY: Whenever equipment in that fire detection zone is required to be OPEP;BLE.

ACTION:

With one or more or the fire detection instrument (s) shown in Table 3.3-11 inoperable:

l a.

Within I hour establish a fire watch patrol to inspect the zone (s) with the inoperable instrument (s) at least once per hour, unless the instrument (s) is located inside the containment, then inspect the containment at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or monitor the contain-ment air temperature at least once per hour at the locations listed in Specification 4.5.1.5; or unless the instrument (s) is located in fire detection zones equipped with automatic wet pipe sprinkler systems alarmed and supervised to the Control Room, then within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ther,eaf ter, inspect the zone (s) with inoperable instruments and verify that the automatic sprinkler system, including the water flow alarm-and supervisory system, is operable by channel functional test.'

b.

Restore the inoperable instrument (s) to OPERABLE status within 14 days or prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability ard the plans and schedule for restoring the instrument (s) to OPERABLE status.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

C.

SURVEILLANCE REQUIREMENTS 4.3.3.7.1 At least once per 6 months, at least 25% of the above required fire detection instruments which are accessible during plant operation shall be demonstrated OPERABLE by performance of a CHANNEL FUNCTIONAL TEST. Detectors selected for testing shall be selected on a rotating basis such that all detectors will be tested over a two year period.

If in any detection zone there are less than four detectors, at least one different detector in that zone shall be tested every six months.

For each detector found inoperable during functional testing, at least an additional 10% of all detectors or 10 detectors, whichever is less, shall also be tested.

Fire detectors whith are inaccessible during plant operation shall be denonstrated OPERABLE by the performance of a CHANNEL FUNCTIONAL TEST during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless performed during the previous six months.

CALVERT CLIFFS - UNIT 2 3/4 3-43 Amendment No. 77,43,75

INSTRUMENTATION SURVEILLANCE RE0VIREMENTS (Continued) 4.3.3.7.2 The NFPA Code 72D Class B supervised circuits supervision associated with the detector alarms of each of the above required fire detection instru-ments shall be demonstrated OPERABLE at lease once per 6 months.

4.3.3.7.3 The non-supervised circuits, associated with detector alarms, between l the instrument and the control room shall be demonstrated OPERABLE at least once per 31 days.

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CALVERT CLIFFS - UNIT 2 3/4 3-44 Amendment No. 77, 43 e

4

REACTOR C00LAtlT SYSTEM SURVE!LLANCE REOUIREMEtiTS (Centinued) a 5.

Defect means an imperfection of such severity that it j-exceecs the plugging limit. A tube containing a defect is defective. Any tube which does not permit the passage of i

the eddy-current inspection probe shall be deemed a i

defective tube.

6.

Plugaing Limit means the imperfection depth at or beyond wnich the tube shall be removed from service because it may become unserviceable prior to the next inspection and is equal to 40*,' of the nominal tube wall thickness.

7.

Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break as specified in 4.4.5.3.c, above.

8.

Tube Insoection means an inspection of the steam generator tuoe from the point of entry (hot leg side) completely around the U-bend to the top support of the cold leg.

i~

b.

The steam generator shall be dete7 mined OPERABLE after completing the corresponding actions (plug all tubes exceeding the plugging limit and all tubes containing through-wall cracks) required by Table 4.4-2.

4.4.5.5 Reports j

Following each inservice inspection of steam generator tubes, a.

the number of tubes plugged in each steam generator shall be reported to the Commission within 15 days.

b.

The complete results of the steam generator tube inservice inspection shall be included in the Annual Operating Report for the period in which this inspection was completed. This report shall include:

1.

Number and extent of tubes inspected.

2.

Location and percent of wall-thickness penetration for each indication of an imperfection.

3.

Identification of tubes plugged.

CALVERT CLIFFS-UNIT 2 3/4 4-9 4

9 m

~. - -.

4

REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued)

C.

Results of steam generator tube inspections which fall into Category C-3 and require verbal notification of the Commission by telephone within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pursuant to Specification 6.9.2 prior to resumption of plant operation. The written followup of this report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrence and shall be submitted within the next 30 days.

. r,;

CALVERT CLIFFS - UNIT 2 3/4 4-10 Amendment No. 75

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TABLE 4.4-2 n>

r-Q STEAM GENERATOR TUDE INSPECTION a

IST SAMPLE INSPECTION 2ND SAMPt.E INSPECTION 3RD SAMPLE INTECTION Sample Size Retuft Action Required Result Action Required Result Action Required to eg A minimum of C-1 None N/A N/A N/A N/A

~

S Tutes per w

d S. G.

m C-2 Plug defective tubes C-3 None N/A N/A and inspect additional Plug defective tulws C-1 None 2S tubes in this S. G.

C-2 and inspect additional C-2 Plug defective tubes 4S tubes in this S. G.

Perform action for C-3 C-3 result of first sample Perform action for C-3 C-3 result of first N/A N/A M

sample u

C-3 Inspect all tubes in Alt other 7

this S. G., plug de S. G.s ase None N/A N/A fective tules and C-l_ i S*

G5 Perform action for N/A N/A c oth C-2 no C-2 result of second athlitinnal uniple 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months verbal noti-S. G. are fication to NRC with C-3

"'I I I'" IO I I" Acklitional Inspect all tubes in t n 2

S. G. is C-3 each S.G.,and plug defective tubes. 24 g

hour verbal notifica-ft "A

"A E

tion to NRC with B

written followup pursuant to specifi-cation 6.9.2.

r+

z r

O S = 3 % Where N is the number of steam generators in the unit, and n is the number of steam generators inspected t

y 9

n during an inspection l

c.n s.*

9 e

REACTOR COOLANT SYSTEM SPECIFIC ACTIVITY LIMITING CONDITION FOR OPERATION 3.4.8 The specific activity of the primary coolant shall be limited to:

a.

3,1.0 uCi/ gram DOSE EQUIVALENT I-131, and b.

3.100/E u Ci/ gram.

APPLICABILITY: MODES 1, 2, 3, 4 and 5.

ACTION:

MODES 1, 2 and 3*:

a.

With the specific activity of the primary coolant > 1.0 uCi/ gram DOSE EQUIVALENT I-131 but within the allowable limit (below and to the left of the line) shown on Figure 3.4-1, operation may continue for up to 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months provided that operation under these circum-stances shall not exceed 10 percent of the unit's total yearly operating time. The provisions of Specification 3.0.4 are not applicable.

b.

With the specific activity of the primary coolant > 1.0 uCi/ gram DOSE EQUIVALENT I-131 for more than 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months during one contin-uous time interval or exceeding the limit line shown on Figure 3.4-1, be in at least HOT STANDBY with Tavg < 500*F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

c.

With the specific activity of the primary coolant > 100/E uCi/

gram, be in at least HOT STANDBY with Tavg < 500*F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l400ES 1, 2, 3, 4 and 5:

d.

With the specific activity of the primary coolant > 1.0 uCi/ gram DOSE EQUIVALENT I-131 or > 100/E uCi/ gram, perform the sangling and analysis requirements of item 4 a) of Table 4.4-4 until the specific activity of the primsry coolant is restored to within its limits. Whenever the spec 3t tetivity of the primary coolant exceeds 1.0 uCi/ gram DOSE 6;L4 VALENT I-131 for in excess of 50 hours5.787037e-4 days 0.0139 hours 8.267196e-5 weeks 1.9025e-5 months for one continuous time interval or 5 percent of the unit's total yearly operating time pursuant to Action a above, a Special Report shall be prepared and submitted to the Commission pursuant to Specification 6.9.2 within the next 30 days. This report shall contain the results of the specific activity analyses together with the following information:

With Tavg 1.500*F.

CALVERT CLIFFS - UNIT 2 3/4 4-19 Amendment No. 75

--1

REACTOR COOLANT SYSTEM ACTION:

(Continued) 1.

Reactor power history starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded, 2.

Fuel burnup by core region, 3.

Clean-up flow history starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded, 4

History of de-gassing operation, if any, starting 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months prior to the first sample in which the limit was exceeded, and 5.

The time duration when the specific activity of the pri-mary coolant exceeded 1.0 uCi/ gram DOSE EQUIVALENT I-131.

~

SURVEILLANCE RE0VIREMENTS 4.4.8 The specific activity of the primary coolant shall be determined to be within the limits by performance of the sampling and analysis pro-gram of Table 4.4-4 I

e I

CALVERT CLIFFS-UNIT 2 3/4 4-20 e

~j s

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 4.6.1.6.3 Liner Plate The structural integrity of the containment liner plate shall be determined during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2) by a visual inspection of the plate and verifying no apparent changes in appearance or other abnormal degradation.

4.6.1.6.4 Reoorts Any abnormal degradation of the containment structure

,; detected during the above required tests and inspections shall be reported j o the Commission pursuant to Specification 6.9.2 within the next 30 days.

t j;This report shall include a description of the tendon condition, the

' condition of the concrete (especially at tendon anchorages), the inspec-tion procedure, the tolerances on cracking, and the corrective actions taken.

CALVERT CLIFFS - UNIT 2 3/4 6-9 Amendment No.

75 J

5-F CONTAINMENT SYSTEMS CONTAINMENT PURGE SYSTEM LIMITING CONDIT:0N FOR OPERATION 3.6.1.7 The containment purge supply and exhaust isolation valves shall be L

closed by i;31ating air to the air operator and maintaining the solenoid air supply valve deenergized.

APPLICABILITY:

MODES 1, 2, 3 and 4 i

1 i

ACTION:

a.

With one containment purge supply and/or one exhaust isolation valve open.

close the open valve (s) within one hour or be in at least HOT STANDSY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , b.

With one containment purge supply and/or one exhaust isolation valve

.l inoperab.le due to high leakage, repair the valve (s) within ~24 Hours or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

_~

}

1 I

SURVEILLANCE REQUIREMENTS 4

i

4. 6.1. 7 The 48-inch containment purge supply and exhaust isolation valves shall be determined closed at least once per 31 days, by verifying'that power to the solenoid valve is removed.

t

,i I

I I

CALVERT CLIFFS - UNIT 2 3/4 6-9a Amerdment No. 4/f, 7.0

CONTAINMENT SYSTEMS CONTAINMENT VENT SYSTEM LIMITING CONDITION FOR OPERATION 3.6.1.8 The containment vent isolation valves MOV 6900 and MOV 6901 shall be maintained closed by tagging the motor power supply breakers open and maintaining the keyed hand switches locked in the closed position.

APPLICABILITY: MODES 1, 2, 3 and 4 ACTION:

With one or both containment vent isolation valves open, close the open valve (s) within one hour or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REOUIREMENTS 4.6.1.8 The containment vent isolation valves shall be determined closed at least once per 31 days by verifying that power to the motor operators is removed and the valves indicate shut.

5 i

n, -

CALVERT CLIFFS - UNIT 2 3/4 6-9b Amendment No.

l e

t.

np TABLE 3.6-1 (Continued) h CONTAINMENT ISOLATI0tl VALVES P

PENETRATION ISOLATION ISOLATION VALVE ISOLATION NO.

CHANNEL IDENTIFICATION NO.

filNCTION TIME (SECONDS) i 44 NA 238-1 fire Protection NA c

NA 238-1 NA

{

NA H0Y-6200

NA m

47A NA SV-6540A

llydrogen Sample Outlet NA NA SV-6507A

NA 478 NA SV-6540E

liydrogen Sample Outlet NA NA SV-6507E

NA s"

a e

47C NA SV-6540F

llydrogen Sample Outlet NA L

NA SV-6507f

NA w

1 47D NA SV-6540G

ilydrogen Sample Return NA NA SV-6507G

NA F

48A SIAS A MOV-6900 Containment Vent isolation

< 20**

3 SIAS B MOV-6901 7 20**

~

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9 TABLE 3.6-1 (Continued)

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CONTAINMENT ISOLATION VALVES p

PENETRATION ISOLATION ISOLATION VALVE ISOLATION q

NO.

CHANNEL IDENTIFICATION NO.

FUNCTION TINE (SECONDS) 0 488 NA 238-1 Ilydrogen Purge Inlet NA NA MOV-6903 NA c5

-4 49A NA SV-65408

liydrogen Sample NA NA SV-65078

NA 498 NA SV-6540C

llydrogen Sample NA NA SV-6507C

NA R

=

49C MA SV-65400

Ilydrogen Sample NA o,

4, MA SV-65070

NA

=

)

50 NA Blind Flange

,ILRT NA NA Blind Flange NA 59 NA 29M3-1 Refueling Pool Inlet NA f

PfA 29N3-1 NA

s t

I-60 NA 130-2 Steam to Reactor llead Laydown NA

{

NA 19-1 NA e

M e

a

l TABLE 3.6-1] Continued) 9 CON.TAINNENT ISOLATION VALVES 9

PENETRATION ISOLATION ISOLATION VALVE ISOLATION NO.

CHANNEL IDENTIFICATION NO.

FUNCTION TIME (SECONPS)

E M

61 NA 76Y-1 Refueling Pool Outlet NA G

MA 293M-1 NA NA 293M-1 NA c

NA 293f t-1 flA 5

r

-i 62 SIAS A MOV-6579 Containment llea ting Ou tlet

<13 64 NA 238-1 Contairanent lleating inlet NA (1) Manual or remote manual valve which is closed during plant operation.

g

~

(2) May be opened below 300*F to establish shutdown cooling flow.

(3) Containment purge and containment vent isolation yalves will be shut in N0 DES 1, 2, 3 and 4 per l

TS 3/4 6.1.7 and TS 3/4 6.1.8, respectively. 3 1

May be open on an intenaittent basis under admin lstrative control.

- Containment purge isolation valves isolation times will only apply for MODES 5 and 6 during which time these valves may be opened.

Isolation tine for containment purge and containment vent isola-E tion valves is MA for MODES 1, 2, 3 and 4 per TS 3/4 6.1.7 and TS 3/4 6.1.8, respectively, during I

which time these valves must remain closed.

t l

e l.

h N

l 4

I 3

V

CONTAINMENT SYSTEMS 4

3/4.6.5 COMBUSTIBLE GAS CONTROL 4

HYDROGEN ANALYZERS LIMITING CONDITION FOR OPERATION

3. 6. 5.1 Two independent containment hydrogen analyzers shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTION:

With one hydrogen analyzer inoperable *, restore the inoperable analyzer to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS

4. 6. 5.1 Each hydrogen analyzer shall be demonstrated OPERABLE at least once per 92 days on a STAGGERED TEST BASIS by performing a CHANNEL CALIBRATION using sample gases in act'ordance with manufacturers' recommenda tions.

I i

l

0uring the period from May 15 to July 15, 1983, one hydrogen analyzer may j

be made inoperable, at any given time, for the purpose of replacing system solenoid valve, with' environmentally qualified valves.

During this time, i

l Specification 3.0.4 is not applicable to this requirement.

(

CALVERT CLIFFS - UNIT 2 3/4 6-26 Amendment No. 42, 55, E G l

l 4

PLANT SYSTEMS 3/4.7.10 WATERTIGHT DOORS LIMITING CONDITION FOR OPERATION 3.7.10 The following watertight doors shall be closed except when the door is being used for normal entry and exit:

a.

ECCS Pump Room Doors (4).

b.

Service Water Pump Room to Heater Bay Doors (2).

c.

Auxiliary Feed Pump Room to Heater Bay Doors (2).

d.

Emergency Escape Hatch, Service Water Pump Room from Oenetra-tion Room.

e.

Main Steam Piping Area from Piping Penetration Room Door, f.

Passage to Main Steam Piping Area Door.

g.

Warehouse to Intake Structure Door, Elevation 12'.

h.

Outside to Intake Structure Door.

e 1.

Warehouse to Intake Structure Door Elevation 29'.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With one or more of the above doors open, restore the door to its closed position within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.10' The above watertight doors shall be determined closed at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

a

e l

CALVERT CLIFFS - UNIT 2 3/4 7-57 Amendment No. 6 A

PLANT SYSTEMS 3/4.7.11 FIRE SUPPRESSION SYSTEMS FIRE SUPPRESSION WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.11.1 The fire suppression water system shall be OPERABLE with:

i a.

Two high pressure pumps, each with a capacity of 2500 gpm, with their discharge aligned to the fire suppression header, b.

Two water supplies, each with a minimum contained volume of 300,000 gallons, and c.

An OPERABLE flow path capable of taking suction from the Pretreated j

l Water Storage Tanks Numbers 11 and 12 and transferring the water through distribution piping with OPERABLE sectionalizing control or isolation valves to the yard hydrant curb valves and the first valve ahead of the water flow alarm device on each sprinkler, hose standpipe or spray system riser required to be OPERABLE per l

Specifications 3.7.11.2, 3.7.11.4, and 3.7.11. 5.

APPLICABILITY: At all times.

ACTION:

a.

With one pump and/or one water supply inoperable, restore the i

inoperable equipment to OPERABLE status within 7 days or prepare and submit a Special Report to the Commission pursuant to Speci-fication 6.9.2 within the next 30 days outlining the plans and procedures to be used to provide for the loss of redundancy in this system. The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

b.

With the fire suppression water system otherwise inoperable:

i 1.

Establish a backup fire suppression water system within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , and 2.

Submit a Special Report in accordance with Specification 6.9.2:

a) By telephone within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , b) Confirmed by telegraph, mailgram or facsimile transmission l

no later than the first working day following the event, and l

c)

In writing within 14 days following the event, outlining the action taken, the cause of the inoperability and the " plans l

and schedule for restoring the system to OPERABLE status.

CALVERT CLIFFS - UNIT 2 3/4 7-58 Amendment No. 77, ff, 75 l

PLANT SYSTEMS l

SPRAY AND/OR SPRINKLER SYSTEMS LIMITING CONDITION FOR OPERATION 3.7.11.2 The spray and/or sprinkler systems shown in Table 3.7-5 shall be OPERABLE.

APPLICABILITY: Whenever equipment in the spray / sprinkler protected areas is requireo to be OPERABLE.

ACTION:

a.

With one or more of the required spray and/or sprinkler systems inoperable, within one hour establish a continuous fire watch with backup fire suppression equipment for those areas in which redundant safe shutdown systems or components could be damaged; for other areas, establish an hcurly fire watcn catrol.

D.e s t are I

the system to OPERABLE status witnin 14 days or prepare and submit a Special Report to the Commission pursuant to Specifica-tion 6.9.2 within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

~'

SURVEILLANCE REOUIREMENTS 4.7.11.2 Each of the above required spray and/or sprinkler systems shall be demonstrated OPERABLE:

~

a.

At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow patN not locked sealed or otherwise secured in position, is in its. correct position.

b.

At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.

I c.

At least once per 18 months:

1.

By performing a system functional test which includes simulated automatic actuation of the system, and:

a) Verifying that the automatic valves in the flow path actuate to their correct positions on a simulated test signal, and CALVERT CLIFFS - UNIT 2 3/4 7-61 Amendment No. $Y

75 L

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b) Cycling each valve in the flow path that-is not testable during plant operation through at least one complete cycle of full travel.

l 2.

By a visual inspection of the area in the vicinity of each nozzle (s) to verify the spray pattern will not be obstructed, i

b 1

e t

i

~

CALVERT CLIFFS - UNIT 2 3/4 7-62 Amendment No. 43

~

w

.c w

TABLE 3.7-5 FIRE PROTECTION SPRINKLERS UNIT 2 SPRINKLER LOCATION CONTROL VALVE ELEVATION Unit 2 Aux Feed Pump Room 605*

12'-0" Unit 2 East Piping Area Roon 408*

45'-0" Unit 2 East Elec Pen Room 409*

45'-0"

' Unit 2 West Elec Pen Room 414*

45'-0" Cable Chase 2A*

45'-0" Cable Chase 25*

45'-0" Unit 2 :.iain Steam Piping Room 309*

45'-0" Unit 2 Component Cooling Pp Room 201 5'-0" Unit 2 East Piping Area 203*

5'-0" Unit 2 Rad Exh Vent Equip Room 204*

5'-0" i

Unit 2 Service Water Pp Room 205*

5' 0" Unit 2 Boric Acid TK and Pp Room 215*

5'-0" Unit 2 Reactor Coolant fiakeup Pump Room 216A*

5'-0" Unit 2 Charging Pump Room 105*

(-)10'-0" Unit 2 Misc Waste fionitor TK Room 106*

(-)10'-0" Unit 2 ECCS Pump Room 101*

(-)15'-0" l

l 21 Diesel Generator 45'-0" Unit 2 East Pipe Pen Room 206/310*

5'-0" NOTE: Sprinklers protecting all rooms listed under heading " Unit 2" will be made operational later in 1981 except for "21 Diesel Generator" which is now operational.

Sprinklers required to ensure the OPERABILITY of redundant safe shutdown equipment.

CALVERT CLIFFS - UNIT 2 3/4 7-63 Amendment No.17, 43 l

1 (l'

.1

PLANT SYSTEMS HALON SYSTEM >

LIMITING CONDITION FOR OPERATION 3.7.11.3 The following Halon systems shafl be OPERABLE with the storage tanks having at least 95% of full charge weight (or level) and 90% of full charge pressure.

a.

Cable spreading rooms total flood system, and associated vertical cable chase 1C, Unit 2 -

b.

460 volt switchgear rooms 27 & 45' elevation Unit 2 APPLICABILITY: Whenever equipment protected by the Halon system is required

~

to be OPERABLE.

ACTION:

a.

With both the primary and backup Halon systems protecting the areas inoperable, within one nour establish an hourly fire watch with backup fire suppression ecuipment for those areas protected by the inoperable Halon system. Restore the system to OPERABLE status within 14 days or prepare and submit a Special Report to the l

Commission pursuant to Specification.6.9.E within the next 30 days outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the Aystem to OPERAELE status, b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.11.3 Each of the above required Halon systems shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path is in its correct position.

b.

At least once per 6 months by verifying Halon < torage tank weight (level) and pressure.

c.

At least once per 18 months by:

1.

Verifying the system, including associated ventilation dampers and fire door release mechanisms, actuates manually and auto-matically, upon receipt of a simulated actuation signal, and 2.

Performance of a flow test through headers and nozzles to assure no blockage.

CALVERT CLIFFS - UNIT 2 3/4 764 Amendment No. yy, A/j, 75 h

PLANT SYSTEMS FIRE HOSE STATIONS LIMITING CONDITION FOR OPERATION 3.7.11.4 The fire hose stations shown in Table 3.7-6 shall be OPERABLE.

APPLICABILITY: Whenever equipment in the areas protected by the fire hose stations is required to be OPERABLE.

ACTION:

a.

With one or more of the fire hose stations shown in Table 3.7-6 inoperable, route an additional equivalent capacity fire hose to the unprotected area (s) from an OPERABLE hose station within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

Restore the fire hose station (s) to OPERABLE status within 14 days, or crepare and submit a Special Report to the Commission pursuant to l

Specification 6.9.2 witnin the next 30 days outlining the action taken, the cause of the inoperability anc t9e plans anc sctedule for restoring the fire hose station (s) to OPERABLE status.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

b.

SURVEILLANCE REQUIREMENTS 4.7.11.4 Each of the fire hose stations shown in Table 3.7-6 shall be demonstrated OPERABLE;

~

a.

At least once per 31 days by visual inspection of the station to assure all required equipment is at the station. Hose stations located in the containment shall be visually inspected on each scheduled reactor shutdown, but not more frequently than every 31 days.

b.

At least once per 18 months by:

1.

Removing the hose for inspection and re-racking, and 2.

Replacement of all degraded gaskets in couplings.

c.

At least once per 3 years by:

1.

Partially opening each hose station valve to verify valve OPERABILITY and no flow blockage.

2.

Conducting a hose hydrostatic test at a pressure at least 50 psig greater than the maximum pressure available at that hose station or replacement with a new hose.

CALVERT CLIFFS - UNIT 2 3/4 745 Amendment No. JJ. 29. 4Y. 75 a

TABLE 3.7-6 l

FIRE HOSE STATIONS UNIT 2 LOCATION ELEVATION NUMBER OF HOSE STATIONS 1.

Containnent 10' 2

45' 2

69' 2

2.

Auxiliary Building

-15'*

1 l

-10 '

2 l

5' 3

27' 2

45' 4

69P*

3 3.

Turbine Building, Heater Bay

~~

Outside Service Water Pump Rooms and Aux Feeder Water Pipe Rooms 12' 2

i j

Outside Switchgear Room 27' 1

Outside Switchgear Room 45' 2

4.

Intake Structure 10'*

1 4

i i

Fire Hose Stations required for primary protection to ensure the OPERABILITY of safety related equipment.

CALVERT CLIFFS - UNIT 2 3/4 7-6G Amendment No. 77, 43 S

e e

y

I PLANT SYSTEMS 3

YARD FIRE HYORANTS AND HYORANT HOSE HOUSES 4

LIMITING CONDITION FOR OPERATION 3:7:11.5 [hefollowingyardfirehydrantsandassociatedhydranthosehouses shall be OPERABLE.

[

APPLICABILITY: Whenever equipment in the areas protected by the yard fire hydrants is required to be OPERABLE.

j a.

6 yard hydrant and associated hydrant hose house, which provides primary protection for Unit 2 RWT blockhouse.

b.

7 yard hydrant and associated hydrant hose house, which provides l

primary protection for Unit 1 RWT blockhouse.

l ACTION:

a.

With one or more of the yard fire hydrants or associated hydrant hose houses inoperable, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months have sufficient additional lengths of 2-1/2 inch diameter hose located in an adjacent OPERABLE j

hydrant hose house to provide service to the unprotected area (s),,1f the inoperable fire hydrant or associated hydrant hose house is the I

{

primary means of fire suppression. Restore the hydrant or hose house to OPERABLE status within 14 days.or prepare and submit a l

Special Report to the Commission purstant to Specification 6.9.2 within the next 30 days outlining the action taken, the cause of i

the inoperability, and the plans and schedule for restoring the j

hydrant or hose house to OPERABLE status.

j The provisions of Specifications 3.0.3 and 3.0.4 are not appl.icable.

i b.

i SURVEILLANCE REQUIREMENTS i

4.7.11.5 Each of the yard fire hydrants and associated hydrant hose houses shall be demonstrated OPERABLE:

a.

At least once per 31 days by visual inspection of the hydrant hose house to assure all required equipment is at the hose house.

b.

At least once per 6 months (once during March, April or May and once during September,' October or November) by visually inspecting each yard fire hydrant and verifying that the hydrant barrel is dry I

and that the hydrant is not damaged.

i l

CALVERT CLIFFS - UNIT 2 3/4 767 Amendment No. 4,75 l

a0 L._

y

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) c.

At least once per 12 months by:

1.

Conducting a hose hydrostatic test at a pressure at least 50 psig greater than the maximum pressure available at any yard fire hydrant.

2.

Inspecting all the gaskets and replacing any degraded gaskets in the couplings.

3.

Performing a flow check of each hydrant to verify its OPERABILITY.

i 4

f l

l l

l i

i l

l CALVERT CLIFFS - UNIT 2 3/4 7-68 Amendment No. 43

\\

e REFUELING OPERATIONS CONTAINMENT VENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.9.14 The containment vent isolation valves shall be closed.

APPLICABILITY: During CORE ALTERATIONS or movement of irradiated fuel witnin the containment.

ACTION:

With one or more containment vent isolation valves open, shut the valve (s) within one hour or suspend all operations involving CORE ALTERATIONS or movement of irradiated fuel within the containment. The provisions of Specification 3.0.3 are not applicable.

SURVEILLANCE RE0VIREMENTS 4.9.14 The containment vent isolation valves shall be determined to be closed within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months prior to the start of and at least once per 7 days during CORE ALTERATIONS or movement of irradiated fuel within the contain-ment.

i a

i I

CALVERT CLIFFS - UNIT 2 3/4 9-17 Amendment No. 75 4

~AW

(

l PLANT SYSTEMS 3/4.7.12 PENETRATION FIRE BARRIERS LIMITING CONDITIONS FOR OPERATION 3.7.12 All fire barrier penetrations (i.e., cable penetration barriers, fire-doorsi and fire dampers), in fire zone boundcries, protecting safe shutdown areas shall be OPERABLE.

I l

APPLICABILITY: At all times.

ACTION:

a.' With one or more of the above required fire barrier penetrations inoperable within one hour either establish a continuous fire watch on at least one side of the affected penetration, or verify the OPERABILITY of fire detectors on at least one side of the inoperable fire barrier and establish an hourly fire watch patrol; or verify the operability of automatic sprinkler systems (including the water flow alarm and supervisory system) on both sides of the INOPERABLE fire barrier. Restore the inoperable fire barrier penetration (s) to operable status within 7 days or prepare and submit a Special Report to the Comission pursuant to Specifica -

tion 6.9.2 witnin the next 30 days outlining the action taken, the cause of the inoperable penetration.and plans and schedule for restoring the fire barrier penetration (s) to operable sfatus.

The provisiens of Specifications 3.0.3 and 3.0.4 are not applicable.

b.

SURVEILLANCE REQUIREMENTS 4.7.12 Each of the above required fire barrier penetrations shall be verified to be OPERABLE:

a.

At least once per 18 months by a visual inspection.

b.

Prior to returning a fire barrier penetration to functional status following repairs or maintenance by perfomance of a visual inspec-l tion of the affected fire barrier penetration (s).

l 1

l

~

l l

CALVERT CLIFFS - UNIT 2 3/4 7-69 Amendment No. II, 4, 75 l

L

9 0

e REFUELING OPERATIONS CONTAINMENT VENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.9.14 The containment vent isolation valves shall be closed.

APPLICABILITY: During CORE ALTERATIONS or movement of irradiated fuel witnin the containment.

ACTION:

With one or more containment vent isolation valves open, shut the valve (s) i within one hour or suspend all operations involving CORE ALTERATIONS or movement of irradiated fuel within the containment. The provisions of Specification 3.0.3 are not applicable.

l l

l SURVEILLANCE REOUIREMENTS 4.9.14 The containment vent isolation valves shall be determined to be closed within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months prior to the start of and at least once per 7 deys during CORE ALTERATIONS or movement of irradiated fuel within the contain-l ment.

l l

l CALVERT CLIFFS - UNIT 2

~ 3/4 9-17 Amendment No. 75 i

A..

I ADMINISTRATIVE CONTROLS MEETING FREQUENCY 6.5.1.4 The POSRC shall meet at least once per calendar month and as convened by the POSRC Chairman or his designated alternate.

OUORUM 6.5.1.5 A quorum of the POSRC shall consist of the Chainnan or his designated alternate and four members including alternates.

RESPONSIBILITIES 6.5.1.6 The POSRC shall be responsible for:

a.

Review of 1) all procedures required by Specification 6.8 and changes thereto, 2) any other proposed procedures or changes thereto as determined by the Plant Superintendent to affect nuclear safety.

I b.

Review of all proposed tests and experiments that affect nuclear

safety, c.

Review of all proposed changes to Appendix "A" Technical.Specifica-tions.

d.

Review of all proposed changes or modifications to plant systems or equipment that affect nuclear safety.,

e.

Investigation of all violations of the Technical Soecifications including the preparation and forwarding of reports covering evalua-tion and recommendations to prevent recurrence to the Manager -

Nuclear Power Department and to the Chairman of the Off Site Safety Review Comittee.

f.

Review of all REPORTABLE EVENTS.

g.

Review of facility operations to detect potential safety hazards, h.

Performance of special reviews, investigations or analyses and reports thereon as requested by the Chairman of the Off Site Safety Review Committee.

i.

Review of the Plant Security Plan and implementing procedures and shall submit recomended changes to the Off Site Safety Review Comittee.

j.

Review of the Emergency Plan and implementing procedures and shall submit recomended changes to the Off Site Safety Review Comittee.

lCALVERT CLIFFS - UNIT 2 6-7 Amendment No. JJ, 75, 26, 75

ADMINISTRATIVE CONTROLS AUTHORITY 6.5.1.7 The Plant Operations and Safety Review Committee shall:

a.

Recommend to th'e Plant Superintendent written approval or disap-l preval of items considered under 6.5.1.6(a) through (d) above.

b.

Render determinations in writing with regard to whether or not each item considered under 6.5.1.6(a) through (e) above constitutes an unreviewed safety question.

c.

Provide written notification within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to the Manager -

Nuclear Power Department and the Off Site Safety Review Comi.ittee of disagreement between the POSRC and the Plant Superintendent; however, the Plant Superintendent shall have responsibility for resolution of such disagreements pursuant to 6.1.1 above.

RECORDS

6. 5.1. 8 The POSRC shall maintain written minutes of each meeting and copies shall be provided to the Manager

. Nuclear Power Depar.tpent

}

and Chairman of the Off Site Safety Re73ew Committee.

6.5.2 0FF SITE SAFETY REVIEW COMMITTEE (OSSRC)

FUNCTION 6.5.2.1 The Off Site Safety Review Committee shall function to provide independent review and audit of designated activities in the areas of:

a.

nuclear power plant operations b.

nuclear engineering c.

chemistry and radiochemistry d.

metallurgy and non-destructive examination e.

instrumentation and control f.

radiological safety

~~

g.'

mechanical and electrical engineering h.

quality assurance practices CALVERT CLIFFS - UNIT 2 6-8 Amendment No.26 e

8

ADMINISTRATIVE CONTROLS COMPOSITION 6.

2.2 The OSSRC shall be composed of at least seven members, including the Chairman. Members of the OSSRC may be from the Supply Division or other SG&E organi:ation or from organi:ations external to BGSE.

OUALIFICATIONS l

6.5.2.3 The Chairman, members and alternate members of the OSSRC shall be appointed in writing by the Vice President - Sucply and shall have an academic degree in engineering or a physical science, or the equivalent, and in addition shall have a minimum of five years technical experience in one or more areas given in 6.5.2.1.

No more than two alternates shall carticipite as voting members in OSSRC activities at any one time.

l l

CONSULTANTS 6.5.2.4 Consultants shall be utilized as determined by the OSSRC Chairwan to provide expert advice to the OSSRC.

MEETING FRE0VENCY 6.5.2.5 The OSSRC shall meet at least once per six months.

QUORUM 6.5.2.6 The quorum of the OSSRC necessary for the performance of the OSSRC review and audit functions of these Technical Specifications shall consist of more than half the OSSRC membership or at least four members, whichever is greater. This quorum shall include the Chairman or his appointed alternste and the OSSRC members, including appointed alternates, meeting the requirements of Specification 6.$.2.3.

No more than a minority of the quorum shall have line responsibility for operation of'the plant.

CALVERT CLIFFS - UNIT 2 6-9 Amendment No. 26 S

t l

i ADMINISTRATIVE CONTROLS i

r REVIEW 6.5.2.7 The OSSRC shall review:

a.

The safety evaluations for 1) changes to procedures, equipment or t

systems and 2) tests or experiments completed under the provision i

of Section 50.59, 10 CFR, to verify that such actions did not constitute an unreviewed safety question, j

b.

Proposed changes to procedures, equipment or systems which involve an unreviewed safety question as defined in Section 50.59, 10 CFR.

c.

Proposed tests or experiments which involve an unreviewed safety J

question as defined in Section 50.59,10 CFR.

d.

Proposed changes in Technical Specifications or this Operating

License, e.

Violations of codes, regulations, orders, Technical Specifications, i

license requirements, or of internal procedures or instructions--

having nuclear safety significance, i

f.

Significant operating abnorralities_or-deviations from normal and i

expected performance of plant equipment that affect nuclear safety.

l g.

All REPORTABLE EVENTS.

h.

All recognized indications of an unanticipated deficiency in some aspect of design or operation of safety related structures, systems, or components.

1.

Reports and meetings minutes of the POSRC.

1 CALVERT CLIFFS. - UNIT 2 6-10 Amendment No. 75 e

0 0-ADMIN!STRAT!VE CONTROLS AUDITS 6.5.2.3.1 Audits of facility activitics shall be performed under the cognizance of the OSSRC. These audits shall encompass:

a.

The confornance of facility c eration to provisions c:ntained within l

the Technical Specifications and applicable license c:nditions at least once :er 12 months, b.

The performance, training and qualifications of the entire facility staff at least once per 12 months.

c.

The results of actions taken to correct deficiencies occurring in facility equipment, structures, systeus or method of operation that I

affect nuclear safet/ at least snce per 6 nontns, l

6 c.

The performance of activities required by the Quality Assurance Program l

to meet the criteria of Appendix "B",10 CFR 50, at least once per l

24 months.

l e.

Deleted The Safeguards Contingency Plan and implementing procedures at5 east l

l f.

once per 12 e.onths in accordance with 10 CFlt 73.40(d).

l g.

Any other area of facility operation considered appropriate by the OSSRC or the Vice President-Supply, h.

The Facility Fire Protection Program and implementing procedures at least once per 24 months.

l l

1.

An independent fire protection and loss prevention program inspection and audit shall be performed at least once per 12 months utilizing l

either qualified offsite licensee personnel or an outside fire protection firm.

J.

An inspection and audit of the fire protection and loss prevention program shall be performed by a qualified outside fire consultant at least once per 36 montns.

6.5.2.8.2 Review of facility activities shall be performed under the cognizance of the OSSRC. These reviews shall encompass:

a.

The Facility Emergency Plan and implementing procedures at least once per 12 months in accordance with 10 CFR 50.54(t).

AUTHOR!TY 6.5.2.9 The OSSRC shall report to and advise the Vice President-Supply on those areas of responsibility specified in Sections 6.5.2.7 and 6.5.2.8.

CALVERT CLIFFS - UNIT 2 6-11 Amendment No.11, 65 i

l ADMIN!$TRATIVE CONTROLS RECOR05 6.5.2.10 Records of OSSRC activities shall be prepared, approved and l

distributed as indicated below:

s.

Minutes of each 055RC meeting shall be prepared, approved and femarded to the Vice President-Supply within 14 days following each meeting.

b.

Reports of reviews encompassed by Section 6.5.2.7 above, shall t

be prepared, approved and forwarded to the Vice President-j Supply within 14 days following completion of the review, r

l c.

Audit reports encompassed by Section 6.5.2.8 above, shall be fomarded to the Vice President Supply and to the management positions responsible for the areas audited within 30 days after completion of the audit.

I 6,6 REPORTABLE EVENT ACT!0N 6.6.1 The following actions shall be taken for REPORTA8LE EVENTS:

l

[

a.

The Comission shall be notified and a report submitted pursuant to the requirements of Section 50.73 to 10 CFR Part 50, and b.

Each REPORTA8LE EVENT shall be reviewed by the P05RC and the results of this review shall be submitted to the 055AC and the Manager - Nuclear Power Department.

l 1

CALVERT CLIFFS UNIT 2 6-12 Amendment No. !$, 88, 75 E

C

o e

ADMIN!STRAT!VE CONTROLS 6,7 SAFETY LIMIT V!OLATION 6.7.1 The following actions shall be taken in the event a Safety Limit is violated:

a.

ine facility sna11 be placed in at least HOT STAZBy sitnin one nour.

D.

The NRC Operations Center shall be notified by telephone as soon as possible and in all cases within one hour. The Manager Nuclear Power Oscart. ment and the 055AC shall be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

c.

A Safety Limit violation Report shall be prepared.

The report shall se reviewed by the POSRC. This report shall describe (1) applicable circumstances preceding tne violation. (2) effects of the violation acon facility c:r :enents, syste s or structures. and (3) torrective action taken to prevent re:u rrence, c.

The Safety Limit Violation Report shall be submitted to the Comission, the 055RC and the Manager Nuclear Power Decartment witnin 14 days of the violation.

6.9 020CE0V8E5 6.8.1 Written procedures small be estabitsned, implemented and maintained covering the activities refe enced belows a.

The applicable procedures recomended ;n Appendix "As of l

Regulatory Guide 1.33. Revision 2. February 1978.

b.

Refueling operations.

c.

Survet11ance and test activities of safety related equipment, d.

Security Plan implementation, e.

Emergency Plan implementation.

f.

Fire Protection Program implementation.

g.

The amount of overtime worked by plant staff members performing safety related functions must be limited in accordance with the NRC Policy Statement on working hours (Generic Letter No. 8212).

6.8.2 Each procedure and administrative policy of 6.8.1 above, and changes lthereto, shall be reviewed by the P05RC and approved by the Plant Superin-ltendent prior to implementation and reviewed periodically as set forth in administrative procedures.

CALVERT CLIFF 5 UNIT 2 6 13 Amendment No.11, 28, 9We65

ADMINISTRATIVE CONTROLS 6.8.3 Temporary changes to procedures of 6.8.1 above may be made pro-vided:

a.

The intent of the originial procedure is not altered.

b.

The change is approved by two meners of the plant management staff, at least one of whom holds a Senior Reactor Operator's License on the unit affected.

c.

The change is documented, reviewed by the POSRC and acoroved by the Plant Superintendent within 14 days of implementation.

6.9 REPORTING REQU!REMENTS ROUTINE REPORT 5

6. 9.1 In addition te the applicable reporting requirements of Title 10 Code of Federal ",egulations, the following reports shall be submi.tted to the Director of the Regional Office of Inspection and Enforcement unless otherwise noted.

STARTUP REDORT 6. 9.1.1 A su riary report of plant startup and power escalation testin shall be submitted following (1) receipt of an operating license. (2) g amendment to the license involving a planned increase in power level.

(3) installation of fuel that has a different design or has been manu.

factured by a different fuel supplier, and (4) modifications that may have significantly altered the nuclear, thertnal, or hydraulic perfor-mance of the plant.

6. 9.1. 2 The startup report shall address each of the tests identified in the FSAR and shall include a description of the measured values of the operating conditions or characteristics obtained during the test program and a comparison of these values with design predictions and specifications. Any corrective actions that were required to obtain satisfactory operation shall also be described. Any additional specific detpils required in license conditions based on other commitments shall be included in this report.

CALVERT CLIFF 5 = UNIT 2 6 14 Amendment No./[ fd. H.75 e

~

ADMINISTRATIVE CONTROLS 6.9.1.3 Startup reports shall be submitted within (1) 90 days following completion of tra startup test program, (2) 90 days following resumption or commencement of commercial power operation, or (3) 9 months following initial criticality, whichever is earliest.

If the Startup Report does not cover all three events (i.e., initial criticality, completion of rtartup test program, and resumption or commencement of commercial power operation), supplementary reports shall be submitted at least every three months until all three events have been completed, ANNUAL REPORTS 1/

6.9.1.4 Annual reports covering the activities of the unit as described below for the previous calendar year shall be submitted prior to March 1 of each yecr. The initial report shall be submitted prior to March 1 of the year following initial criticality.

6.9.i.5 Reports requiret on an annual basis shall include:

a.

A tabulation on an annual basis of the number of station, utility, and other personnel (including contractors) receiving exposures greater than 100 mrem /yr and their a according to work and job functions,ggociated man rem exposure e.g., reactor operations and surveillance, inservice inspection, routine maintenance, special maintenance (describe maintenance), waste processing, and refueling. The dose assignment to various duty functions,may be estimates based on pocket dosimeter, TLD, or film badge measure-ments. 'Small exposures totalling less than 20% of the individual total dose need not be accounted for.

In the aggregate, at least 80% of the total whole body dose received frcm external sources shall be assigned to specific major work functions.

b.

The complete results of steam generator tube inservice inspections performed during the report period (reference Specification 4.4.5.5.b).

c.

Documentation of all failures and challenges to the pressurizer PORVs or safety valves.

i 1/ A single submittal may be made for a multiple unit station. The submittal should combine those sections that are common to all units at the station, i

2/ 'This tabulation supplements the requirements of $20.407 of 10 CFR Part 20.

CALVERT CLIFFS - UNIT 2 6-15 Amendment No. If, 5A 4 '

4 m..

e

ADMINISTRATIVE CONTROLS MONTHLY OPERATING REPORT 6.9.1.6 Routine reports of operating statistics and shutdown experience shall be submitted on a monthly basis to the Director, Office of Inspection and Enforcement, U. S. Nuclear Regulatory Commission, Washington, D. C.

20555, ATTN: Document Control Desk, with a copy to the Regional Adminis-trator and to the NRC Resident Inspector, no later than the 15th of each-month following the calendar month covered by the report.

l CALVERT CLIFFS - UNIT 2.

6-16 AmendmentNo.H,kh,75 W

4

THIS PAGE DELIBERATELY LEFT BLANK s.

CALVERT CLIFFS - UNIT 2 6-17 Amendment No. J#, 75 0

9 ADMINISTRATIVE CONTROLS SPECIAL REPORTS 6.9.2 Special reports shall be submitted to the Director of the Office of Inspection and Enforcement Regional Office within the time period specified for each report. These reports shall be submitted covering the activities -

identified below pursuant to the requirements of the applicable refbrence specification:

-~

a.

ECCS Actuation, Specifications 1.5.2 and 3.5.3.

b.

Incperable Seismic Monitoring, Instrumentation, Specification 3.3.3.3.

c.

Inoperable Meteorological Monitoring Instrumentation, Specification 3.3.3.4.

d.

Seismic event analysis, Specification 4.3.3.3.2.

e.

Core Barrel Movement, Specification 3.4.11.

f.

Fire Detection Instrumentation, Specification 3.3.3.7.

g.

Fire Suppression Systems, Specifications 3.7.11.1, 3.7.11.2, 3.7.11.3, 3.7.11.4 and 3.7.11.5.

,h.

Penetration Fire Barriers, Specification 3.7.12.

1.

Steam Generator Tube Inspection Results, Specification 4.4.5.5.

j.

Specific Activity of Primary Coolant, Specification 3.4.8.

k.

Containment Structural Integrity, Specification 4.6.1.6.

CALVERT CLIFFS - UNIT 2 6-18 Amendment No. JJ, 75

ADMINISTRATIVE CONTROLS 6.10 RECORD RETENTION 6.10.1 The following records shall be retained for at least five years:

a.

Records and logs of facility operation covering time interval at each power level.

b.

Records and logs of principal maintenance activities, inspections, repair and replacement of principal items of ecuipment related to nuclear safety.

c.

All REPORTABLE EVENTS.

d.

Records of surveillance activities, inspections and calibrations required by these Technical Specifications.

e.

Records of reactor tests and experiments.

f.

Records of changes made to Operating Procedures.

~~

g.

Records of radioactive shipments.

h.

Records of sealed source and fission detector leak tests and results.

1.

Records of annual physical inventory of all-sealed source material of record.

6.10.2 The following records shall be retained for the duration of the Facility Operating License:

Records and drawing changes reflecting facility design modifi-a.

cations made to systems and equipment described in the Final Safety Analysis Report.

b.

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

c.

Records of facility radiation and contamination surveys.

CALVERT CLIFFS - UNIT 2 6-19 Amendment No./A, 75 u

m

+

i ADMINISTRATIVE CONTROLS d.

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

e.

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

f.

Records of transient or operational cycles for those facility components identified in Table 5.71.

g.

Records of training and qualification for current members of the plant staff, h.

Records of in-service inspections performed pursuant to these Technical Specifications.

i. Records of Quality Assurance activities identified in the NRC approved QA Manual as lifetime records.

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

k.

Records of meetings of the POSRC and the OSSRC.

1.

Records of. Environmental Qualificat4on" which are covered' ~

under the provisions of paragraph 6.13.

m.

Records of the service lives of all snubbers listed on Table 3.7-4 i

including the date at which the service life commences and associated installation and maintenance records.

l 6.11 RADIATION PROTECTION PROGRAM Procedures for personnel radiation protection shall be prepared consistent with the requirements of 10 CFR Part 20 and shall be appr'oved, maintained and adhered to for all operations involving personnel radiation exposure.

6.12 HIGH RADIATION AREA 4

6.12.1 In lieu of the " control device" or " alarm signal" required by j

paragraph 20.203(c)(2) of 10 CFR Part 20:

A high radiation area inwhich the intensity of radiation is a.

greater than 100 mrem /hr but less than 1000 mrem /hr shall ben barricaded and conspicuously posted as a High Radiation Area and entrance thereto shall be centrolled by issuance of a Sracial or Radiation Work Permit and any individual or group of individuals permitted to enter such areas shall be provided with a radiation monitoring device which continuously indicates the radiation dose rate in the area.

CALVERT ' CLIFFS - UNIT 2 6-20~

Amendment No. 4 6 i

Lt r

ML20092C375

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