Text

R.E.Ginna - Application for Technical Specification Change Regarding Mode Change Limitations
	ML040680907
Person / Time
Site:	Ginna
Issue date:	03/01/2004
From:	Mecredy R; Rochester Gas & Electric Corp
To:	Clark R; Document Control Desk, Office of Nuclear Reactor Regulation
References
	Download: ML040680907 (93)
	v • d • e

Robert C. Mecredy Vice President Always at Your Service Nuclear Operations March 1, 2004 Mr. Robert L. Clark Office of Nuclear Regulatory Regulation U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555

Subject:

Application For Technical Specification Change Regarding Mode Change Limitations R. E. Ginna Nuclear Power Plant Docket No. 50-244

Dear Mr. Clark:

In accordance with the provisions of 10 CFR 50.90 of Title 10 of the Code of Federal Regulations (10 CFR), Rochester Gas & Electric (RG&E) is submitting a request for an amendment to the technical specifications (TS) for the R. E. Ginna Nuclear Power Plant.

The proposed amendment would modify TS requirements for mode change limitations in LCO 3.0.4 and SR 3.0.4. The availability of this technical specification improvement was announced in the Federal Register on April 4, 2003 as part of the consolidated line item improvement process (CLIIP).

Enclosure 1 provides a description of the proposed change (including a table of affected TS with a brief descriptor of the change), the requested confirmation of applicability, and plant-specific verifications. Enclosure 2 provides the existing TS pages marked-up to show the proposed change. Enclosure 3 provides the revised (clean) TS pages. Enclosure 4 provides the existing TS Bases pages marked up to reflect the proposed change (for information only). Changes to the TS Bases will be provided in a future update in accordance with the Bases Control Program.

Enclosure 5 provides a summary of the regulatory commitments made in this submittal.

RG&E requests approval of the proposed license amendment by December 3, 2004 with the amendment being implemented within 60 days.

In accordance with 10 CFR 50.91, a copy of this application, with enclosures, is being provided to the designated New York State Official.

An equal opportunity employer Al 89 East Avenue I Rochester, NY 14649 tel (585) 546-2700 wwwnrgeEcom nborq E t An Energy East Comparry

I declare under penalty of perjury under the laws of the United States of America that I am authorized by RG&E to make this submittal and that the foregoing is true and correct.

Any questions concerning this submittal should be directed to Tom Harding, Nuclear Safety and Licensing at (585) 771-3384.

Very truly yours, Executed on March 1, 2004 Robert C.Mecredy

Enclosures:

1. Description and Assessment

2. Proposed Technical Specification Changes (markup)

3. Revised Technical Specification Pages

4. Planned Technical Specification Bases Changes (for information only)

5. List of Regulatory Commitments xc: Mr. Robert L. Clark (Mail Stop 0-8-C2)

Project Directorate I Division of Licensing Project Management Office of Nuclear Regulatory Regulation U.S. Nuclear Regulatory Commission One White Flint North 11555 Rockville Pike Rockville, MD 20852 Regional Administrator, Region I U.S. Nuclear Regulatory Commission 475 Allendale Road King of Prussia, PA 19406 U.S. NRC Ginna Senior Resident Inspector Mr. Peter R. Smith New York State Energy, Research, and Development Authority 17 Columbia Circle Albany, NY 12203-6399 Mr. Paul Eddy NYS Department of Public Service 3 Empire Plaza, 10th Floor Albany, NY 12223

Enclosure 1 R.E. Ginna Nuclear Power Plant Description and Assessment

1.0 DESCRIPTION

The proposed amendment would modify the R. E. Ginna Nuclear Power Plant technical specification (TS) requirements for mode change limitations in Limiting Condition for Operation (LCO) 3.0.4 and Surveillance Requirement (SR) 3.0.4. The affected TS and a summary of proposed changes are included in Table 1.

The changes are consistent with Nuclear Regulatory Commission (NRC) approved Industry/Technical Specification Task Force (TSTF) Standard TS (STS) change TSTF-359 Revision 8, as modified by the notice in the Federal Register published on April 4, 2003. That Federal Register Notice (FRN) announced the availability of this TS improvement through the consolidated line item improvement process (CLIIP). TSTF-359, Revision 8, was subsequently revised to incorporate the modifications discussed in the April 4, 2003, FRN and other minor changes, and was submitted to the NRC on April 28, 2003, as TSTF-359, Revision 9.

The R. E. Ginna Nuclear Power Plant Technical Specifications are based on the Improved Standard Technical Specifications and contain a Technical Specification Bases Control Program and the plant-specific SR 3.0.1 and SR 3.0.1 Bases are equivalent to those in the Improved Standard Technical Specifications.

2.0 ASSESSMENT 2.1 Applicability of Published Safety Evaluation Rochester Gas & Electric (RG&E) has reviewed the safety evaluation published on April 4, 2003 (68 FR 16584) as part of the CLIIP. This review included a review of the NRC staff's evaluation, as well as the supporting information provided to support TSTF-359 Revision 8, and included the updates made in TSTF-359, Revision 9. RG&E has concluded that the justifications presented in the TSTF proposal and the safety evaluation prepared by the NRC staff are applicable to the R. E. Ginna Nuclear Power Plant and justify this amendment for the incorporation of the changes to the TS.

2.2 Optional Changes and Variations RG&E is not proposing any variations and deviations from the technical specification changes described in TSTF-359 Revision 9 and the NRC staff's model safety evaluation published on April 4, 2003, with the following two exceptions.

A. LCO 3.1.3, Moderator Temperature Coefficient (MTC)

Description:

The R. E. Ginna TS LCO 3.1.3, Moderator Temperature Coefficient (MTC), differs significantly from the STS. Currently the R. E. Ginna TS include a Note in LCO 3.1 .3 Condition C, which states that LCO 3.0.4 does not apply. With the revised LCO 3.0.4, RG&E proposes to include a similar Note in LCO 3.1.3 Condition C, which states that LCO 3.0.4.c applies.

Justification: R. E. Ginna TS include SR 3.1.3.3, which requires verification that the MTC will be within limits at the core end of cycle life (EOL). This SR must be performed prior to entering Mode 1 after each refueling outage. If the SR is performed and subsequently not met, then LCO 3.1.3, Condition C would be entered. Condition C allows operation to continue, but the Required Action requires the core design to be re-evaluated prior to reaching an all rods out boron concentration of 300 ppm. Thus, absent relief from LCO 3.0.4, power ascension would not be allowed. Because this is a variable or parameter that does not lend itself readily to the use of the new LCO 3.0.4.b, RG&E proposes to include a Note invoking LCO 3.0.4.c in Required Action C. 1 of LCO 3.1.3 in the R. E. Ginna TS.

As discussed in the Bases to LCO 3.1.3, the MTC lower limit is only of concern at EOL.

For this reason the Completion Time allows plant operation to continue until "reaching the equivalent of an equilibrium RTP all rods out boron concentration of 300 ppm." This Completion Time defines the core "end of cycle life" at which the lower MTC limit is of concern. Prior to this point in the core operating cycle, the plant can operate safely without concern for the MTC lower limit.

The wording of Required Action C.1 and the associated Completion Time are clearly intended to allow plant operation to continue. The current Note intended power ascension to be allowed if Condition C was entered prior to entering a higher Mode of Applicability. The plant can continue to operate safely until the limit in the Completion Time is reached. If the Required Action C.1 is not completed by this time, Condition D would be entered, and the Mode of Applicability would be exited. Re-entering the Mode of Applicability is not allowed (neither currently nor with the proposed new LCO 3.0.4.c allowance) without completing the reevaluation, as the Completion Time for Condition C would have already expired. Thus, the proposed LCO 3.0.4.c allowance will preclude an unintended hardship with the adoption of TSTF-359, is consistent with the current licensing basis, and will not allow any undue relaxation in current operation.

B. LCO 3.7.5, Auxiliary Feedwater (AFW) System

==

Description:==

The R. E. Ginna TS LCO 3.7.5, Auxiliary Feedwater (AFW) System, differs significantly from the STS (LCO 3.7.4). R. E. Ginna has five sources of safety related auxiliary feedwater (as compared to three in the STS) including: two Motor Driven Auxiliary Feedwater (MDAFW) Pumps, one Turbine Driven Auxiliary Feedwater (TDAFW) Pump, and two Standby Auxiliary Feedwater (SAFW) Pumps. With the revised LCO 3.0.4, RG&E proposes to include Notes in LCO 3.7.5 Conditions C and D, which state that LCO 3.0.4.b is not applicable to the specific combinations of inoperable equipment covered by those Conditions.

Justification: The AFW System is a safety-related system that provides at least the minimum required flow rate to the steam generators (SGs) when the main feedwater pumps are unavailable, to remove decay heat and other residual heat. The R. E. Ginna sources of safety related auxiliary feedwater include: two MDAFW Pumps rated at 200 GPM each, one TDAFW Pump rated at > 400 GPM, and two SAFW Pumps rated at 200 GPM each. The minimum auxiliary feedwater flow for the most limiting accident is 200 GPM within 10 minutes. In an accident situation, the MDAFW Pumps and the TDAFW Pump will automatically start and supply flow which far exceeds the required amount of flow. In addition, the SAFW pumps would be manually started if required by Emergency Operating Procedures. The total available auxiliary feedwater flow is approximately six times the minimum required for postulated at power events. The decay heat level is much less during a startup from a lower Mode than the decay heat level following a reactor trip.

The specific combinations of inoperable equipment covered by LCO 3.7.5 Conditions C and D for which LCO 3.0.4.b is not applicable are:

a TDAFW train inoperable, or

both MDAFW trains inoperable, or

one TDAFW train flow path and one MDAFW train inoperable to opposite SGs, or

all AFW trains to one or both SGs inoperable.

The Westinghouse Owners Group (WOG) qualitative risk assessment contained within TSTF-359, Revision 9, states that for plants not starting up on AFW, that there should be no limitations for startup with inoperable AFW equipment. The SAFW system is not normally used for startup and clearly meets the WOG assessment criteria for removing any LCO 3.0.4 restrictions. Given the significant amount of redundancy available, allowing a mode change with a single MDAFW train or a single TDAFW flowpath to or from a SG inoperable is also acceptable. At least two trains of AFW must be operable to a single SG, with one train operable to the opposite SG, to allow a mode change. In addition, one of these two trains must be comprised of the TDAFW pump with the second comprised of a MDAFW pump. This ensures the reliability of the AFW system with diverse sources of power. Therefore, there is no increase in the probability of an accident during lower modes, even assuming a loss of offsite power.

Due to differences between the R. E. Ginna TS and TS Bases and their corresponding model STS (NUREG-1431) in several cases variances from the TSTF marked-up changes are made. These variances are discussed below and do not affect the adoption or application of TSTF-359, Revision 9.

1. In the TSTF mark-ups, STS 3.3.4, Remote Shutdown System, is modified. R. E.

Ginna TS do not include this TS, therefore no changes are needed.

2. In the R. E. Ginna TS 3.4.5, RCS Loops - MODES 1

8.5% RTP, 2, and 3, the Note in Condition A stating "LCO 3.0.4 is not Applicable" is deleted.

3. In the TSTF mark-ups, STS 3.4.15, RCS Leakage Detection Instrumentation, the Actions Note is being deleted. In the R. E. Ginna TS the equivalent Note is being deleted from Conditions A, B, C, and D.

4. In the TSTF mark-ups, STS 3.5.3, ECCS - Shutdown, an Actions Note is added stating that "LCO 3.0.4.b is not applicable to ECCS high head subsystem." The equivalent R. E. Ginna TS 3.5.3 is labeled ECCS - Mode 4 and the Note is being added to Condition B with the terminology "Safety Injection" or "SI" for the high head subsystem.

5. In the TSTF mark-ups, STS 3.6.9, Hydrogen Mixing System (HMS), is modified.

R. E. Ginna TS do not include this TS, therefore no changes are needed.

6. In the TSTF mark-ups, STS 3.7.4, Atmospheric Dump Valves (ADVs), is modified. The equivalent R. E. Ginna TS 3.7.4 is labeled Atmospheric Relief Valves (ARVs).

7. In the TSTF mark-ups, STS 3.8.1, AC Sources - Operating, is modified. The equivalent R. E. Ginna TS 3.8.1 is labeled AC Sources - MODES 1, 2, 3, and 4.

In addition, changes to the R. E. Ginna TS Bases are being made for consistency with the above TS changes, as allowed by the TS Bases Control Program of TS 5.5.13.

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Determination RG&E has reviewed the proposed no significant hazards consideration determination (NSHCD) published in the Federal Register as part of the CLIIP. RG&E has concluded that the proposed NSHCD presented in the Federal Register notice is applicable to the R. E. Ginna Nuclear Power Plant and is hereby incorporated by reference to satisfy the requirements of 10 CFR 50.91(a).

3.2 Verification and Commitments As discussed in the notice of availability published in the Federal Register on April 4, 2003 (68 FR 16584) for this TS improvement, plant-specific verifications were performed as follows:

RG&E has established TS Bases for LCO 3.0.4 and SR 3.0.4 which state that use of the TS mode change limitation flexibility established by LCO 3.0.4 and SR 3.0.4 is not to be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to operable status before entering an associated mode or other specified condition in the TS Applicability.

The proposal also includes changes to the bases for LCO 3.0.4 and SR 3.0.4 that provide details on how to implement the new requirements. The bases changes provide guidance for changing Modes or other specified conditions in the Applicability when an LCO is not met. The bases changes describe in detail how: LCO 3.0.4.a allows entry into a MODE or other specified condition in the Applicability with the LCO not met when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; LCO 3.0.4.b allows entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; and LCO 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met based on a Note in the Specification, which is typically applied to Specifications which describe values and parameters (e.g., Moderator Temperature Coefficient, RCS Specific Activity), and may be applied to other Specifications based on NRC plant-specific approval. The bases will also state that any risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide 1.182. "Assessing and Managing Risks Before Maintenance Activities at Nuclear Power Plants," and that the results of the risk assessment shall be considered in determining the acceptability of entering the MODE or other specified condition in the Applicability, and any corresponding risk management actions.

In addition, the bases will state that upon entry into a MODE or other specified condition in the Applicability with the LCO not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the unit is not within the Applicability of the Technical Specification. The bases will also state that SR 3.0.4 does not restrict changing MODES or other specified conditions of the Applicability when a Surveillance has not been performed within the specified Frequency, provided the requirement to declare the LCO not met has been delayed in accordance with SR 3.0.3. Finally, RG&E currently has in place a bases control program consistent with Section 5.5 of the STS, and the equivalent of STS SR 3.0.1 and associated bases.

4.0 ENVIRONMENTAL EVALUATION RG&E has reviewed the environmental evaluation included in the model safety evaluation published on April 4, 2003 (68 FR 16584) as part of the CLIIP. RG&E has concluded that the NRC staff's findings presented in that evaluation are applicable to the R. E. Ginna Nuclear Power Plant and the evaluation is hereby incorporated by reference for this application.

Table 1 Proposed Technical Specification (TS) Changes Affected TS Description of Change LCO 3.0.4 Addition of risk-informed evaluation of Mode changes.

SR 3.0.4 Clarification of relationship to SR 3.0.3.

3.1.3 Moderator Temperature Coefficient Addition of Note stating applicability of LCO 3.0.4.c to (MTC) Condition C.

3.3.3 Post Accident Monitoring (PAM) Deletion of Note exempting TS from LCO 3.0.4.

Instrumentation 3.4.5 RCS Loops - MODES 1

8.5% Deletion of Note exempting Condition A from LCO 3.0.4.

RTP, 2, and 3 3.4.11 Pressurizer Power Operated Relief Deletion of Note exempting TS from LCO 3.0.4.

Valves (PORVs) 3.4.12 Low Temperature Overpressure Addition of Note stating that LCO 3.0.4.b is not applicable Protection (LTOP) System when entering Mode 4.

3.4.15 RCS Leakage Detection Deletion of Notes exempting Conditions A, B, C, and D from Instrumentation LCO 3.0.4.

3.4.16 RCS Specific Activity Deletion of Note exempting Condition A from LCO 3.0.4.

Addition of Note stating applicability of LCO 3.0.4.c to Condition A.

3.5.3 ECCS - MODE 4 Addition of Note stating that LCO 3.0.4.b is not applicable to Condition B.

3.6.7 Hydrogen Recombiners Deletion of Note exempting Condition A from LCO 3.0.4.

3.7.4 Atmospheric Relief Valves Deletion of Note exempting Condition A from LCO 3.0.4.

3.7.5 Auxiliary Feedwater (AFW) System Addition of Notes stating that LCO 3.0.4.b is not applicable to Conditions C and D.

3.8.1 AC Sources - MODES 1, 2, 3, and 4 Addition of Note stating that LCO 3.0.4.b is not applicable to the diesel generators (DGs).

Enclosure 2 R.E. Ginna Nuclear Power Plant Proposed Technical Specification Changes (markup)

ITS Mode Change LCO Inserts LCO Insert 1 (LCO 3.0.4)

When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time;

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO Insert 2 (SR 3.0.4)

Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO Insert 3 (LCO 3.4.12, LTOP System)

-Note-LCO 3.0.4.b is not applicable when entering MODE 4.

LCO Insert 4 (LCO 3.5.3, ECCS - MODE 4)

(LCO 3.7.5, Auxiliary Feedwater (AFW) System)

-Note-LCO 3.0.4.b is not applicable.

LCO Insert 5 (LCO 3.8.1, AC Sources - MODES 1, 2,3, and 4)

-Note-LCO 3.0.4.b is not applicable to DGs.

LCO Applicability 3.0 LCO 3.0.4 Wen an 10 is no t, entry nto a MODE or o specified conditi in the Applicability all not be made except whe he associated ACTIONS to be e ered permit continued operatin in the MODE or other L ~specified

\_ condV n in the Applicability for an up imited period of time.

This Specifi on shall not prevent changes* MODES or other specified conditions the Applicability that are req ed to comply with ACTIONS.

Excep ns to this Specification are s d nthe individual Specificatios LCO 3.0.5 Equipment removed from service or declared inoperable to comply with

-ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to determine OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, additional evaluations and limitations may be required in accordance with Specification 5.5.14, "Safety Function Determination Program (SFDP)."

If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

R.E. Ginna Nuclear Power Plant 3.0-2 Amendment)

SR Applicability 3.0 SR 3.0.4 Entry into a MODE r other specified conditio in the Applicability of an LCO shall not bedade unless the LCO's S iellances have been met within their spe ied Frequency. This pro ion shall not prevent entry t-CO into MODES other specified condition in the Applicability that are 2a required to amply with ACTIONS.

R.E. Ginna Nuclear Power Plant 3.0-5 AmendmentIml ---m V--7

MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1. 3 The MTC shall be maintained within the limits specified in the COLR.

The maximum upper limit shall be less than or equal to 5 pcmPF for power levels below 70% RTP and less than or equal to 0 pcm/OF at or above 70% RTP.

APPLICABILITY: MODE I and MODE 2 with keff 2 1.0 for the upper MTC limit, MODES 1,2, and 3 for the lower MTC limit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. MTC not within upper A.1 Establish administrative 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit. withdrawal limits for control banks to maintain MTC within limit.

B. Required Action and B.1 Be in MODE 2 with kf 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion < 1.0.

Time of Condition A not met.

C.

-NOTE-Required Action C.1 must be completed whenever

\

C.1

_3 LCO is oapplicable.

Re-evaluate core design Once prior to I

Condition C is entered. and safety analysis, and reaching the

._ __ _-- determine that the reactor equivalent of an Projected end of cycle life core is acceptable for equilibrium RTP all ProLeeM ndoty wihife continued operation. rods out (ARO)

(EOL) MTC not within boron concentration lower limit. oof 300 0 ppmp D. Required Action and D.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition C not met.

R.E. Ginna Nuclear Power Plant 3.1 .3-1 Amendmentip

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.Z The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-NOTE-Separate Condition entry is allowed for each Function.

I CONDITION REQUIRED ACTION COMPLETION TIME A. A.1 Restore required channel to 30 days

-- _ OPERABLE status.

- NOTE-Not applicable to Functions 3 and 4.

One or more Functions with one required channel inoperable.

B. Required Action and B.1 Initiate action to prepare Immediately associated Completion and submit a special report.

Time of Condition A not met.

C. C.1 Restore required channel to 7 days

_--___-__-________.OPERABLE status.

-NOTE-Only applicable to Functions 3 and 4.

One or more Functions with required channel inoperable.

R.E. Ginna Nuclear Power Plant 3.3.3-1 Amendmento

RCS Loops - MODES 1

8.5% RTP, 2, and 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops - MODES 1 5 8.5% RTP, 2, and 3 LCO 3.4.A Two RCS loops shall be OPERABLE and one loop shall be in operation.

- NOTE -

Both reactor coolant pumps may be de-energized in MODE 3 for < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and

b. Core outlet temperature is maintained at least 100 F below saturation temperature.

APPLICABILITY: MODES 1 < 8.5% RTP, MODES 2 and 3.

ACTIONS CONDITION I REQUIRED ACTION I COMPLETION TIME A. One RCS loop inoperable.

A.1 L

/-

NNOTE- ap-/

is itaplcbe te.

Verify SDM is within limits specified in the COLR.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months I

AND A.2 Restore inoperable RCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months loop to OPERABLE status.

B. Required Action and B.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

R.E. Ginna Nuclear Power Plant 3.4.5-1 Amendment$

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-NOTE-

1. Separate entry into Condition A is allowed for each PORV.

2. Separate entry into Condition C is allowed for each block valve.

3.0.4_ _ _ __is_ __ota_ _ _ _ _ _ _ _ _ __c_ _b_ _ _ _ _

l CONDITION REQUIRED ACTION COMPLETION TIME A. One or both PORVs A.1 Close and maintain power 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE and not to associated block valve.

capable of being automatically controlled. OR A.2 Place associated PORV in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months manual control.

B. One PORV inoperable. B.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months valve.

AND B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valve.

AND B.3 Restore PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

C. One block valve C.1 Place associated PORV in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. manual control.

AND R.E. Ginna Nuclear Power Plant 3.4.11-1 Amendments)

LTOP System 3.4.12 ACTIONS CONDITION REQUIRED ACTION ICOMPLETION TIME A. A.1 Initiate action to verify no SI Immediately

.__ __---. __ pump is capable of injecting

- NOTE - into the RCS.

Only applicable to LCO 3.4.12.a.

One or more SI pumps capable of injecting into the RCS.

B. B.1 Restore required PORV to 7 days

___ -- ___ - -_ OPERABLE status.

-NOTE-Only applicable to LCO 3.4.12.a.

One required PORV inoperable in MODE 4.

C. C.1 Restore required PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

______ -- - -_ OPERABLE status.

- NOTE -

Only applicable to LCO 3.4.12.a.

One required PORV inoperable in MODE 5 or MODE 6.

D. D.1 Initiate action to verify a Immediately

- maximum of one SI pump is

- NOTE- capable of injecting into the Only applicable to LCO RCS.

3.4.12.b.

Two or more SI pumps capable of injecting into the RCS.

R.E. Ginna Nuclear Power Plant 3.4.12-2 Amendmento

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump A monitor (level or pump actuation);

b. Gaseous containment atmosphere radioactivity monitor; and

c. Particulate containment atmosphere radioactivity monitor.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required containment sump monitor inoperable. L 3.0.4 is t applicable A.1.1 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR A.1 .2 Verify containment air 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months cooler condensate collection system is OPERABLE.

AND A.2 Restore required 30 days containment sump monitor to OPERABLE status.

I B. Gaseous containment atmosphere radioactivity L 3.0.4 is ot applicable.

monitor inoperable. - =

B.1 Verify particulate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months containment atmosphere radiaoctivity monitor OPERABLE.

R.E. Ginna Nuclear Power Plant 3.4.15-1 Amendment 0

RCS Leakage Detection Instrumentation 3.4.15 CONDITION REQUIRED ACTION COMPLETION TIME C. Particulate containment - -

atmosphere radioactivity NOTE 4

monitor inoperable. C_ . i n pplicae OR C.1 Analyze grab samples of the Once within 12 containment atmosphere. hours and every 12 Required Action and hours thereafter associated Completion Time of Condition B not OR met.

C.2 Perform SR 3.4.13.1. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter D. Gaseous containment --

atmosphere radioactivity LCO .0.4 is not applicable.

monitor inoperable. - --

AND D.1 Restore gaseous 30 days containment atmosphere Particulate containment radioactivity monitor to atmosphere radioactivity OPERABLE status.

monitor inoperable.

OR D.2 Restore particulate 30 days containment atmosphere radioactivity monitor to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Conditions A, C, AND or D not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. All required monitors F.1 Enter LCO 3.0.3. Immediately inoperable.

R.E. Ginna Nuclear Power Plant 3.4.1 5-2 Amendmentts

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY: MODES I and 2, MODE 3 with RCS average temperature (Tavg) ; 500 0F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT _--___ _____-----

1-131 specific activity not 0ic within limit. ----------

II A.1 Verify DOSE EQUIVALENT Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 1-131 within the acceptable region of Figure 3.4.16-1.

AND A.2 Restore DOSE 7 days EQUIVALENT 1-131 to within limit.

B. Required Action and B.1 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion < 500°1.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 specific activity in the unacceptable region of Figure 3.4.16-1.

C. Gross specific activity not C.1 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months within limit. < 5000F.

R.E. Ginna Nuclear Power Plant 3.4.16-1 Amendment

ECCS - MODE 4 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS - MODE 4 LCO 3.5.3 One ECCS train shall be OPERABLE.

.-I APPLICABILITY: MODE 4.

ACTIONS V-CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status.

B. Required ECCS Safety Injection (SI) subsystem B.1 Restore required ECCS SI subsystem to OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months I inoperable. status.

C. Required Action and C.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months associated Completion Time of Condition B not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 ---- -NOTE-An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

SR 3.5.2.4 is applicable for all equipment required to In accordance with be OPERABLE. applicable SR R.E. Ginna Nuclear Power Plant 3.5.3-1 Amendment

Hydrogen Recombiners 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Hydrogen Recombiners LCO 3.6. 7 Two hydrogen recombiners shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One hydrogen A.1 recombiner inoperable. ---

( LC 3.0.4 is no applicable.

Restore hydrogen recombiner to OPERABLE 30 days I

status.

B. Two hydrogen B.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months recombiners inoperable. means that the hydrogen control function is AND maintained.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Restore one hydrogen 7 days recombiner to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

R.E. Ginna Nuclear Power Plant 3.6.7-1 Amendment

ARVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Relief Valves (ARVs)

LCO 3.7.4 Two ARV lines shall be OPERABLE.

APPLICABILITY: MODES 1 and 2, MODE 3 with Reactor Coolant System average temperature (Tavg)

Ž5000F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ARV line inoperable. A.1 ca e (LCO .0.4 is not, pplicable.

Restore ARV line to 7 days OPERABLE status.

B. Required Action and B.1 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion < 500°1 Time of Condition A not met.

C. Two ARV lines C.A Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Perform a complete cycle of each ARV. 24 months SR 3.7.4.2 Verify one complete cycle of each ARV block valve. 24 months R.E. Ginna Nuclear Power Plant 3.7.4-1 Amendment?)

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Two motor driven AFW (MDAFW) trains, one turbine driven AFW (TDAFW) train, and two standby AFW (SAFW) trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION [ REQUIRED ACTION COMPLETION TIME A. One TDAFW train A.1 Restore TDAFW train 7 days flowpath inoperable. flowpath to OPERABLE status.

B. One MDAFW train B.1 Restore MDAFW train to 7 days inoperable. OPERABLE status.

TDAFW train inoperable. Restore one MDAFW train 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or TDAFW train flowpath to OR OPERABLE status.

Two MDAFW trains inoperable.

OR One TDAFW train flowpath and one MDAFW train inoperable to opposite steam generators (SGs).

I All AFW trains to one or D.1 'Restore one AFW train or 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months more SGs inoperable. TDAFW flowpath to each affected SG to OPERABLE status.

E. One SAFW train E.1 Restore SAFW train to 14 days inoperable. OPERABLE status.

R.E. Ginna Nuclear Power Plant 3.7.5-1 Amendment 80

AC Sources - MODES 1, 2, 3, and 4 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - MODES 1, 2, 3, and 4 LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. One qualified Independent offsite power circuit connected between the offsite transmission network and each of the onsite 480 V safeguards buses required by LCO 3.8.9, "Distribution Subsystems

- MODES 1, 2, 3, and 4"; and

b. Two emergency diesel generators (DGs) capable of supplying their respective onsite 480 V safeguards buses required by LCO 3.8.9.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME I

A. Offsite power to one or A.1 - Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from more 480 V safeguards inoperable when its discovery of bus(es) inoperable. redundant required Condition A feature(s) is inoperable. concurrent with inoperability of redundant required feature(s)

AND A.2 Restore offsite circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. One DG inoperable. B.1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months offsite circuit.

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND R.E. Ginna Nuclear Power Plant 3.8.1 -1 Amendment(8

Enclosure 3 R.E. Ginna Nuclear Power Plant Revised Technical Specification Pages

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) AND SUHVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.0 Limiting Condition For Operation (LCO) Applicability LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2 and LCO 3.0.7.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated.

LCO 3.0.3 When an LCO is not met and (1) the associated ACTIONS are not met, (2) an associated ACTION is not provided, or (3) if directed by the associated ACTIONS, the plant shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated to place the plant, as applicable, in:

a. MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ;

b. MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; and

c. MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4.

R.E. Ginna Nuclear Power Plant 3.0-1 Amendment

LCO Applicability 3.0 I LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time;

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified I conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to determine OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, additional evaluations and limitations may be required in accordance with Specification 5.5.14, "Safety Function Determination Program (SFDP)."

If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

R.E. Ginna Nuclear Power Plant 3.0-2 Amendment

LCO Applicability 3.0 LCO 3.0.7 Test Exception LCO 3.1.8, "PHYSICS TEST Exceptions - MODE 2,"

allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

R.E. Ginna Nuclear Power Plant 3.0-3 Amendment

SR Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) AND SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.0 Surveillance Requirement (SR) Applicability SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR.

Failure to meet a SR, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

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

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

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

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

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

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

R.E. Ginna Nuclear Power Plant 3.0-4 Amendment

SR Applicability 3.0 SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

R.E. Ginna Nuclear Power Plant 3.0-5 Amendment

MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1.' 3 The MTC shall be maintained within the limits specified in the COLR.

The maximum upper limit shall be less than or equal to 5 pcm/OF for power levels below 70% RTP and less than or equal to 0 pcm/OF at or above 70% RTP.

APPLICABILITY: MODE 1 and MODE 2 with keff 2 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. MTC not within upper A.1 Establish administrative 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit. withdrawal limits for control banks to maintain MTC within limit.

B. Required Action and B.1 Be in MODE 2 with keff 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion < 1.0.

Time of Condition A not

- met.

C. C.1

-NOTE- -NOTE-I Required Action C.1 must LCO 3.0.4.c is applicable.

be completed whenever _- -----------

Condition C is entered.

__ _ _--- Re-evaluate core design Once prior to and safety analysis, and reaching the Projected end of cycle life determine that the reactor equivalent of an (EOL) MTC not within core is acceptable for equilibrium RTP all lower limit. continued operation. rods out (ARO) boron concentration of 300 ppm D. Required Action and D.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition C not met.

R.E. Ginna Nuclear Power Plant 3.1 .3-1 Amendment

MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE 1 after each refueling SR 3.1.3.2 Confirm that MTC will be within limits at 70% RTP. Once prior to entering MODE 1 after each refueling SR 3.1.3.3 Confirm that MTC will be within limits at EOL. Once prior to entering MODE 1 after each refueling.

R.E. Ginna Nuclear Power Plant 3.1 .3-2 Amendment

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3I The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS -

-NOTE-Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. A.1 Restore required channel to 30 days

___ ____--- OPERABLE status.

- NOTE -

Not applicable to Functions 3 and 4.

One or more Functions with one required channel inoperable.

B. Required Action and B.1 Initiate action to prepare Immediately associated Completion and submit a special report.

Time of Condition A not met.

C. C.1 Restore required channel to 7 days

-- _ _____________. OPERABLE status.

-NOTE-Only applicable to Functions 3 and 4.

One or more Functions with required channel inoperable.

R.E. Ginna Nuclear Power Plant 3.3.3-1 Amendment

PAM Instrumentation 3.3.3 CONDITION REQUIRED ACTION COMPLETION TIME D. D.1 Restore one channel to 7 days

.______ ---- _ OPERABLE status.

- NOTE -

Not applicable to Function 11.

One or more Functions with two required channels inoperable.

E. Two hydrogen monitor E.1 Restore one hydrogen 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months channels inoperable. monitor channel to OPERABLE status.

F. Required Action and F.1 Enter the Condition Immediately associated Completion referenced in Table 3.3.3-1 Time of Condition C, D, or for the channel.

E not met.

G. As required by Required G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action F.1 and referenced in Table 3.3.3-1. AND G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months H: As required by Required H.1 Initiate action to prepare Immediately Action F.1 and referenced and submit a special report.

in Table 3.3.3-1.

SURVEILLANCE REQUIREMENTS

-NOTE-SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE I FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 Perform CHANNEL CALIBRATION. 24 months R.E. Ginna Nuclear Power Plant 3.3.3-2 Amendment

PAM Instrumentation 3.3.3 Table 3.3.3-1 Post Accident Monitoring Instrumentation FUNCTION REQUIRED CONDITION CHANNELS

1. Pressurizer Pressure 2 G

2. Pressurizer Level 2 G

3. Reactor Coolant System (RCS) Hot Leg Temperature 1 per loop G

4. RCS Cold Leg Temperature 1 per loop G

5. RCS Pressure (Wide Range) 2 G

6. RCS Subcooling Monitor 2 G

7. Reactor Vessel Water Level 2 H

8. Containment Sump B Water Level 2 G

9. Containment Pressure (Wide Range) 2 G

10. Containment Area Radiation (High Range) 2 H

11. Hydrogen Monitors 2 G

12. Condensate Storage Tank Level 2 G

13. Refueling Water Storage Tank Level 2 G

14. Residual Heat Removal Flow 2 G

15. Core Exit Temperature-Quadrant 1 2(a) G

16. Core Exit Temperature-Quadrant 2 2(a) G

17. Core Exit Temperature-Quadrant 3 2 (a) G

18. Core Exit Temperature-Quadrant 4 2(a) G

19. Auxiliary Feedwater (AFW) Flow to Steam Generator (SG) A 2 G

20. AFW Flow to SG B 2 G

21. SG A Water Level (Narrow Range) 2 G

22. SG B Water Level (Narrow Range) 2 G R.E. Ginna Nuclear Power Plant 3.3.3-3 Amendment

PAM Instrumentation 3.3.3 Table 3.3.3-1 Post Accident Monitoring Instrumentation FUNCTION REQUIRED CONDITION CHANNELS

23. SG A Water Level (Wide Range) 2 G

24. SG B Water Level (Wide Range) 2 G

25. SG A Pressure 2 G

26. SG B Pressure 2 G (a) A channel consists of two core exit thermocouples (CETs).

R.E. Ginna Nuclear Power Plant 3.3.3-4 Amendment

RCS Loops - MODES 1 < 8.5% RTP, 2, and 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops - MODES 1 < 8.5% RTP, 2, and 3 LCO 3.4.E Two RCS loops shall be OPERABLE and one loop shall be in operation.

-NOTE-Both reactor coolant pumps may be de-energized in MODE 3 for

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and

b. Core outlet temperature is maintained at least 10 0F below saturation temperature.

APPLICABILITY: MODES 1 < 8.5% RTP, MODES 2 and 3.

ACTIONS CONDITION J REQUIRED ACTION COMPLETION TIME I A; One RCS loop A.1 Verify SDM is within limits Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months inoperable. specified in the COLR.

AND A.2 Restore inoperable RCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months loop to OPERABLE status.

B. Required Action and B.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

R.E. Ginna Nuclear Power Plant 3.4.5-1 Amendment

RCS Loops - MODES 1 < 8.5% RTP, 2, and 3 3.4.5 CONDITION REQUIRED ACTION COMPLETION TIME C. Both RCS loops C.1 De-energize all CRDMs. Immediately inoperable.

AND OR C.2 Suspend all operations Immediately No RCS loop in operation. involving a reduction of RCS boron concentration.

AND C.3 Initiate action to restore one Immediately RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.5.2 Verify steam generator secondary side water levels 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months are 2 16% for two RCS loops.

SR 3.4.5.3 Verify correct breaker alignment and indicated power 7 days are available to the required RCP that is not in operation.

R.E. Ginna Nuclear Power Plant 3.4.5-2 Amendment

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-NOTE-

1. Separate entry into Condition A is allowed for each PORV.

2. Separate entry into Condition C is allowed for each block valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or both PORVs A.1 Close and maintain power 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE and not to associated block valve.

capable of being automatically controlled. OR A.2 Place associated PORV in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months manual control.

B. One PORV inoperable. B.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months valve.

AND B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valve.

AND B.3 Restore PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

C. One block valve C.1 Place associated PORV in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. manual control.

AND R.E. Ginna Nuclear Power Plant 3.4.1 1-1 Amendment

Pressurizer PORVs 3.4.11 CONDITION REQUIRED ACTION COMPLETION TIME C.2 Restore block valve to 7 days OPERABLE status.

D. Both block valves D.1 Place associated PORVs in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. manual control.

AND D.2 Restore at least one block 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months valve to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, C, AND or D not met.

E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. Two PORVs inoperable. F.1 Initiate action to restore one Immediately PORV to OPERABLE status.

AND F.2 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months valves.

AND F.3 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

AND F.4 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

< 500TF.

R.E. Ginna Nuclear Power Plant 3.4.1 1-2 Amendment

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 -NOTE-Not required to be performed with block valve closed per LCO 3.4.13.

Perform a complete cycle of each block valve. 92 days SR 3.4.11.2 Perform a complete cycle of each PORV. 24 months R.E. Ginna Nuclear Power Plant 3.4.11 -3 Amendment

LTOP System 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12 An LTOP System shall be OPERABLE with the Emergency Core Cooling System (ECCS) accumulators isolated and either a or b below.

a. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR and no safety injection (SI) pump capable of injecting into the RCS.

b. The RCS depressurized and an RCS vent of 2 1.1 square inches and a maximum of one SI pump capable of injecting into the RCS.

-NOTE-

1. The PORVs and an RCS vent 2 1.1 square inches are not required to be OPERABLE during performance of the secondary side hydrostatic tests. However, no SI pump may be capable of injecting into the RCS during this test.

2. ECCS accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

APPLICABILITY: MODE 4 when any RCS cold leg temperature is less than or equal to the LTOP enable temperature specified in the PTLR or when the RHR system is in the RHR mode of operation, MODE 5 when the SG primary system manway and pressurizer manway are closed and secured in position, MODE 6 when the reactor vessel head is on and the SG primary system manway and pressurizer manway are closed and secured in position.

R.E. Ginna Nuclear Power Plant 3.4.12-1 Amendment

LTOP System 3.4.12 ACTIONS

-NOTE-LCO 3.0.4.b is not applicable when entering MODE 4.

CONDITION REQUIRED ACTION COMPLETION TIME A. A.1 Initiate action to verify no Si Immediately

.___ --__ pump is capable of injecting

- NOTE - into the RCS.

Only applicable to LCO 3.4.1 2.a.

One or-more SI pumps capable of injecting into the RCS.

B. B.1 Restore required PORV to 7 days

-- _ OPERABLE status.

-NOTE-Only applicable to LCO 3.4.12.a.

One required PORV inoperable in MODE 4.

C. C.1 Restore required PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

-- __ OPERABLE status.

- NOTE-Only applicable to LCO 3.4.1 2.a.

One required PORV inoperable in MODE 5 or MODE 6.

D. D.1 Initiate action to verify a Immediately

- maximum of one Si pump is

- NOTE- capable of injecting into the Only applicable to LCO RCS.

3.4.1 2.b.

Two or more Si pumps capable of injecting into the RCS.

R.E. Ginna Nuclear Power Plant 3.4.1 2-2 Amendment

LTOP System 3.4.12 CONDITION REQUIRED ACTION COMPLETION TIME E. An ECCS accumulator E.1 Isolate affected ECCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not isolated when the accumulator.

accumulator pressure is greater than or equal to the maximum RCS pressure for the existing cold leg temperature allowed in the PTLR.

F. Required Action and F.1 Increase RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion temperature to greater than Time of Condition E not the LTOP enable met. temperature specified in the PTLR.

OR F.2 Depressurize affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

S Two required PORVs ai Verify at least one charging 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable for LCO pump is in the pull-stop 3.4.1 2.a. position.

OR AND Required Action and G2 Depressurize RCS and 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion establish RCS vent of 2 1.1 Time of Condition A, B, C, square inches.

or F not met.

OR LTOP System inoperable for any reason other than Condition A, B, C, or E.

R.E. Ginna Nuclear Power Plant 3.4.1 2-3 Amendmeht

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 - NOTE--

Only required to be performed when complying with LCO 3.4.12.a.

Verify no SI pump is capable of injecting into the RCS. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.12.2 - NOTE -

Only required to be performed when complying with LCO 3.4.12.b.

Verify a maximum of one SI pump is capable of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months injecting into the RCS.

5R 3.4.12.3 -NOTE-Only required to be performed when ECCS accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed in the PTLR.

Verify each ECCS accumulator motor operated Once within 12 isolation valve is closed. hours and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter SR 3.4.12.4 ----

-NOTE-Only required to be performed when complying with LCO 3.4.12.b.

Verify RCS vent 2 1.1 square inches open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked open vent valve(s)

AND 31 days for locked open vent valve(s)

SR 3.4.12.5 Verify PORV block valve is open for each required 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months PORV.

R.E. Ginna Nuclear Power Plant 3.4.12-4 Amendment

LTOP System 3.4.12 SURVEILLANCE [ FREQUENCY SR 3.4.12.6 ----

-NOTE-Required to be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to less than or equal to the LTOP enable temperature specified in the PTLR.

Perform a COT on each required PORV, excluding 31 days actuation.

SR 3.4.12.7 --- - -

-NOTE-Only required to be performed when ECCS accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed in the PTLR.

Verify power is removed from each ECCS Once within 12 accumulator motor operated isolation valve operator. hours and every 31 days thereafter SR 3.4.12.8 Perform CHANNEL CALIBRATION for each required 24 months PORV actuation channel.

R.E. Ginna Nuclear Power Plant 3.4.12-5 Amendment

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump A monitor (level or pump actuation);

b. Gaseous containment atmosphere radioactivity monitor; and

c. Particulate containment atmosphere radioactivity monitor.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required containment A.1.1 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months sump monitor inoperable.

OR A.1.2 Verify containment air 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months cooler condensate collection system is OPERABLE.

AND A.2 Restore required 30 days containment sump monitor to OPERABLE status.

B. Gaseous containment B.1 Verify particulate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months atmosphere radioactivity containment atmosphere monitor inoperable. radiaoctivity monitor OPERABLE.

R.E. Ginna Nuclear Power Plant 3.4.15-1 Amendment

RCS Leakage Detection Instrumentation 3.4.15 CONDITION l REQUIRED ACTION COMPLETION TIME C. Particulate containment C.1 Analyze grab samples of the Once within 12 atmosphere radioactivity containment atmosphere. hours and every 12 monitor inoperable. hours thereafter OR OR Required Action and C.2 Perform SR 3.4.13.1. Once within 12 associated Completion hours and every 12 Time of Condition B not hours thereafter met.

D. Gaseous containment D.1 Restore gaseous 30 days atmosphere radioactivity containment atmosphere monitor inoperable. radioactivity monitor to OPERABLE status.

AND OR Particulate containment atmosphere radioactivity D.2 Restore particulate 30 days monitor inoperable. containment atmosphere radioactivity monitor to OPERABLE status.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Conditions A, C, AND or D not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months F. All required monitors F.1 Enter LCO 3.0.3. Immediately inoperable.

R.E. Ginna Nuclear Power Plant 3.4.1 5-2 Amendment

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of containment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months atmosphere radioactivity monitors.

SR 3.4.15.2 Perform COT of containment atmosphere radioactivity 92 days monitors.

SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required 24 months containment sump monitor.

SR 3.4.15.4 - Perform CHANNEL CALIBRATION of containment 24 months atmosphere radioactivity monitors.

R.E. Ginna Nuclear Power Plant 3.4.15-3 Amendment

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS average temperature (Tavg) Ž5000F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT -------

1-131 specific activity not LCO - NOTE -

l within imit.O-within limit. 3.0.4.c----------___

is applicable.

A.1 Verify DOSE EQUIVALENT Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 1-131 within the acceptable region of Figure 3.4.16-1.

AND A.2 Restore DOSE 7 days EQUIVALENT 1-131 to within limit.

B. Required Action and B.1 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion < 500'F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 specific activity in the unacceptable region of Figure 3.4.16-1.

C. Gross specific activity not C.1 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months within limit. < 500'F.

R.E. Ginna Nuclear Power Plant 3.4.1 6-1 Amendment

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity

100/E 7 days pCi/gm.

SR 3.4.16.2 - NOTE -

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 14 days specific activity

1.0 gCi/gm.

AND Between 2 and 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months after a THERMAL POWER change of 2 15%

RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period SR 3.4.16.3 - NOTE -

Only required to be performed in MODE 1.

Determine E from a reactor coolant sample. Once within 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for > 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

AND Every 184 days thereafter R.E. Ginna Nuclear Power Plant 3.4.1 6-2 Amendment

RCS Specific Activity 3.4.16 300

-4 Li a 250 1I A

Fe 200 ac Few U

I 150 I'

100 r-

~nmCaPTARIM ori l OPEWATZON .

i !

AKcZPTABIZ Ii II Ii II Ii OPERATION E 50 26 'iCi/gi

-4

-4 n) 20 30 40 50 60 70 sD 90 100 PERCflfl Co RATED T oL POWsER Figure 3.4.16-1 Reactor Coolant DOSE EQUIVALENT 1-131 Specific Activity Limit Versus Percent of RATED THERMAL POWER R.E. Ginna Nuclear Power Plant 3.4.1 6-3 Amendment

ECCS - MODE 4 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS - MODE 4 LCO 3.5.3 One ECCS train shall be OPERABLE.

APPLICABILITY: MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. subsystem to OPERABLE status.

B. Required ECCS Safety B.1 Injection (SI) subsystem ----------------

inoperable. - NOTE -

inopeable.LCO 3.0.4.b is not I applicable.

Restore required ECCS SI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months associated Completion Time of Condition B not met.

R.E. Ginna Nuclear Power Plant 3.5 .3-1 Amendment

ECCS - MODE 4 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 -NOTE-An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

SR 3.5.2.4 is applicable for all equipment required to In accordance with be OPERABLE. applicable SR R.E. Ginna Nuclear Power Plant 3.5.3-2 Amendment

Hydrogen Recombiners 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Hydrogen Recombiners LCO 3.6.77 Two hydrogen recombiners shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME I A. One hydrogen A.1 Restore hydrogen 30 days recombiner inoperable. recombiner to OPERABLE status.

B. Two hydrogen B.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months recombiners inoperable. means that the hydrogen control function is AND maintained.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Restore one hydrogen 7 days recombiner to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Perform a system functional check for each hydrogen 24 months recombiner.

SR 3.6.7.2 Perform CHANNEL CALIBRATION for each hydrogen 24 months recombiner actuation and control channel.

R.E. Ginna Nuclear Power Plant 3.6.7-1 Amendment

ARVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Relief Valves (ARVs)

LCO 3.7.44 Two ARV lines shall be OPERABLE.

APPLICABILITY: MODES 1 and 2, MODE 3 with Reactor Coolant System average temperature (Tavg)

Ž 5000F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME I A. One ARV line inoperable. A.1 Restore ARV line to 7 days OPERABLE status.

B. Required Action and B.1 Be in MODE 3 with Tavg 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months associated Completion < 500'F.

Time of Condition A not met.

C. Two ARV lines C.1 Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Perform a complete cycle of each ARV. 24 months SR 3.7.4.2 Verify one complete cycle of each ARV block valve. 24 months R.E. Ginna Nuclear Power Plant 3.7.4-1 Amendment

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.E Two motor driven AFW (MDAFW) trains, one turbine driven AFW (TDAFW) train, and two standby AFW (SAFW) trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One TDAFW train A.1 Restore TDAFW train 7 days flowpath inoperable. flowpath to OPERABLE status.

B. One MDAFW train B.1 Restore MDAFW train to 7 days inoperable. OPERABLE status.

C. TDAFW train inoperable. C.1 OR - NOTE -

LCO 3.0.4.b is not I Two MDAFW trains applicable.

inoperable.

Restore one MDAFW train 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR or TDAFW train flowpath to OPERABLE status.

One TDAFW train flowpath and one MDAFW train inoperable to opposite steam generators (SGs).

R.E. Ginna Nuclear Power Plant 3.7.5-1 Amendment

AFW System 3.7.5 CONDITION REQUIRED ACTION COMPLETION TIME D. All AFW trains to one or D.1 more SGs inoperable. -- NOT -- -

- NOTE -

LCO 3.0.4.b is not I applicable.

Restore one AFW train or 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months TDAFW flowpath to each affected SG to OPERABLE status.

E. One SAFW train E.1 Restore SAFW train to 14 days inoperable. OPERABLE status.

F. Both SAFW trains F.1 Restore one SAFW train to 7 days inoperable. OPERABLE status.

G Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A, B. AND C, D, E, or F not met.

G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months H. Three AFW trains and H.1 both SAFW trains ------------------

inoperable. -NOTE-LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one MDAFW, TDAFW, or SAFW train is restored to OPERABLE status.

Initiate action to restore one Immediately MDAFW, TDAFW, or SAFW train to OPERABLE status.

R.E. Ginna Nuclear Power Plant 3.7.5-2 Amendment

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW and SAFW manual, power operated, 31 days and automatic valve in each water flow path, and in both steam supply flow paths to the turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.5.2 - NOTE -

Required to be met prior to entering MODE 1 for the TDAFW pump.

Verify the developed head of each AFW pump at the In accordance with flow test point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.7.5.3 Verify the developed head of each SAFW pump at the In accordance with flow test point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.7.5.4 Perform a complete cycle of each AFW and SAFW In accordance with motor operated suction valve from the Service Water the Inservice System, each AFW and SAFW discharge motor Testing Program operated isolation valve, and each SAFW cross-tie motor operated valve.

SR 3.7.5.5 Verify each AFW automatic valve that is not locked, 24 months sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.5.6 - - -

-NOTE-Required to be met prior to entering MODE 1 for the TDAFW pump.

Verify each AFW pump starts automatically on an 24 months actual or simulated actuation signal.

SR 3.7.5.7 Verify each SAFW train can be actuated and 24 months controlled from the control room.

R.E. Ginna Nuclear Power Plant 3.7.5-3 Amendment

AC Sources - MODES 1, 2, 3, and 4 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - MODES 1, 2, 3, and 4 LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. One qualified independent offsite power circuit connected between the offsite transmission network and each of the onsite 480 V safeguards buses required by LCO 3.8.9, "Distribution Subsystems

- MODES 1, 2, 3, and 4"; and

b. Two emergency diesel generators (DGs) capable of supplying their

- respective onsite 480 V safeguards buses required by LCO 3.8.9.

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

ACTIONS

- NOTE-LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION JCOMPLETION TIME A. Offsite power to one or A.1 Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from more 480 V safeguards inoperable when its discovery of bus(es) inoperable. redundant required Condition A feature(s) is inoperable. concurrent with inoperability of redundant required feature(s)

AND A.2 Restore offsite circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. One DG inoperable. B.1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months offsite circuit.

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND R.E. Ginna Nuclear Power Plant 3.8.1 -1 Amendment

AC Sources - MODES 1, 2, 3, and 4 3.8.1 CONDITION REQUIRED ACTION COMPLETION TIME B.2 Declare required feature(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from supported by the inoperable discovery of DG inoperable when its Condition B required redundant concurrent with feature(s) is inoperable. inoperability of redundant required feature(s)

AND B.3.1 Determine OPERABLE DG 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE DG.

AND B.4 Restore DG to OPERABLE 7 days status.

C. Offsite power to one or -- - - --

more 480 V safeguards Enter a bNOTE bus~s) noprabl. Eterapplicable and Required Actions Conditions of bus(es) inoperable, AND LCO 3.8.9, "Distribution Systems - MODES 1, 2, 3, and 4," when Condition C is One DG inoperable, entered with no AC power source to one distribution train.

C.1 Restore required offsite 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months circuit to OPERABLE status.

OR C.2 Restore DG to OPERABLE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months status.

R.E. Ginna Nuclear Power Plant 3.8.1 -2 Amendment

AC Sources - MODES 1, 2, 3, and 4 3.8.1 CONDITION I REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, or AND C not met.

D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Two DGs inoperable. E.1 Enter LCO 3.0.3. Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power 7 days availability for the offsite circuit to each of the 480 V safeguards buses.

SR 3.8.1.2 -NOTE-

1. Performance of SR 3.8.1.9 satisfies this SR.

2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

Verify each DG starts from standby conditions and 31 days achieves rated voltage and frequency.

R.E. Ginna Nuclear Power Plant 3.8.1 -3 Amendment

AC Sources - MODES 1, 2, 3, and 4 3.8.1 T

SURVEILLANCE FREQUENCY SR 3.8.1.3 -NOTE-

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.9.

Verify each DG is synchronized and loaded and 31 days operates for 2 60 minutes and < 120 minutes at a load 2 1950 kW and < 2250 kW.

SR 3.8.1.4 Verify the fuel oil level in each day tank. 31 days SR 3.8.1.5 Verify the DG fuel oil transfer system operates to 31 days transfer fuel oil from each storage tank to the associated day tank.

SR 3.8.1.6 Verify transfer of AC power sources from the 50/50 24 months mode to the 100/0 mode and 0/100 mode.

SR 3.8.1.7 -NOTE-

1. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

2. Credit may be taken for unplanned events that satisfy this SR.

Verify each DG does not trip during and following a 24 months load rejection of 2 295 kW.

R.E. Ginna Nuclear Power Plant 3.8.1 -4 Amendment

AC Sources - MODES 1, 2, 3, and 4 3.8.1 SURVEILLANCE FREQUENCY

_________________________ I SR 3.8.1.8 -NOTE-

1. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

2. Credit may be taken for unplanned events that satisfy this SR.

Verify each DG automatic trips are bypassed on an 24 months actual or simulated safety injection (SI) signal except:

a. Engine overspeed;

b. Low lube oil pressure; and

c. Start failure (overcrank) relay.

SR 3.8.1.9 -NOTE-

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1, 2, 3, or4.

3. Credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite power 24 months signal in conjunction with an actual or simulated SI actuation signal:

a. De-energization of 480 V safeguards buses;

b. Load shedding from 480 V safeguards buses; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads,

2. energizes auto-connected emergency loads through the load sequencer, and

3. supplies permanently and auto-connected emergency loads for > 5 minutes.

R.E. Ginna Nuclear Power Plant 3.8.1 -5 Amendment

Enclosure 4 R.E. Ginna Nuclear Power Plant Planned Technical Specification Bases Changes (for information only)

ITS Mode Change Bases Inserts Bases Insert 1 (LCO 3.0.4 Bases)

LCO 3.0.4 establishes limitations on changes in MODES or other specified conditions in the Applicability when an LCO is not met. It allows placing the plant in a MODE or other specified condition stated in that Applicability (e.g., the Applicability desired to be entered) when plant conditions are such that the requirements of the LCO would not be met, in accordance with LCO 3.0.4.a, LCO 3.0.4.b, or LCO 3.0.4.c.

LCO 3.0.4.a allows entry into a MODE or other specified condition in the Applicability with the LCO not met when the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time.

Compliance with Required Actions that permit continued operation of the plant for an unlimited period of time in a MODE or other specified condition provides an acceptable level of safety for continued operation. This is without regard to the status of the plant before or after the MODE change. Therefore, in such cases, entry into a MODE or other specified condition in the Applicability may be made in accordance with the provisions of the Required Actions.

LCO 3.0.4.b allows entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate.

The risk assessment may use quantitative, qualitative, or blended approaches, and the risk assessment will be conducted using the plant program, procedures, and criteria in place to implement 10 CFR 50.65(a)(4), which requires that risk impacts of maintenance activities to be assessed and managed. The risk assessment, for the purposes of LCO 3.0.4.b, must take into account all inoperable Technical Specification equipment regardless of whether the equipment is included in the normal 10 CFR 50.65(a)(4) risk assessment scope. The risk assessments will be conducted using the procedures and guidance endorsed by Regulatory Guide 1.182, "Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants."

Regulatory Guide 1.182 endorses the guidance in Section 11 of NUMARC 93-01, Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants." These documents address general guidance for conduct of the risk assessment, quantitative and qualitative guidelines for establishing risk management actions, and example risk management actions. These include actions to plan and conduct other activities in a manner that controls overall risk, increased risk awareness by shift and management personnel, actions to reduce the duration of the condition, actions to minimize the magnitude of risk increases (establishment of backup success paths or compensatory measures), and determination that the proposed MODE change is acceptable. Consideration should also be given to the probability of completing restoration such that the requirements of the LCO would be met prior to the expiration of ACTIONS Completion Times that would require exiting the Applicability.

LCO 3.0.4.b may be used with single, or multiple systems and components unavailable.

NUMARC 93-01 provides guidance relative to consideration of simultaneous unavailability of multiple systems and components.

The results of the risk assessment shall be considered in determining the acceptability of entering the MODE or other specified condition in the Applicability, and any corresponding risk management actions. The LCO 3.0.4.b risk assessments do not have to be documented.

The Technical Specifications allow continued operation with equipment unavailable in MODE 1 for the duration of the Completion Time. Since this is allowable, and since in general the risk impact in that particular MODE bounds the risk of transitioning into and through the applicable MODES or other specified conditions in the Applicability of the LCO, the use of the LCO 3.0.4.b allowance should be generally acceptable, as long as the risk is assessed and managed as stated above. However, there is a small subset of systems and components that have been determined to be more important to risk and use of the LCO 3.0.4.b allowance is prohibited. The LCOs governing these system and components contain Notes prohibiting the use of LCO 3.0.4.b by stating that LCO 3.0.4.b is not applicable.

LCO 3.0.4.c allows entry into a MODE or other specified condition in the Applicability with the LCO not met based on a Note in the Specification which states LCO 3.0.4.c is applicable.

These specific allowances permit entry into MODES or other specified conditions in the Applicability when the associated ACTIONS to be entered do not provide for continued operation for an unlimited period of time and a risk assessment has not been performed. This allowance may apply to all the ACTIONS or to a specific Required Action of a Specification. The risk assessments performed to justify the use of LCO 3.0.4.b usually only consider systems and components. For this reason, LCO 3.0.4.c is typically applied to Specifications which describe values and parameters (e.g., Moderator Temperature Coefficient, RCS Specific Activity), and may be applied to other Specifications based on NRC plant-specific approval.

The provisions of this Specification should not be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.

The provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of LCO 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that result from any plant shutdown. In this context, a plant shutdown is defined as a change in MODE or other specified condition in the Applicability associated with transitioning from MODE 1 to MODE 2, MODE 2 to MODE 3, MODE 3 to MODE 4, and MODE 4 to MODE 5.

Upon entry into a MODE or other specified condition in the Applicability with the LCO not met, LCO 3.0.1 and LCO 3.0.2 require entry into the applicable Conditions and Required Actions until the Condition is resolved, until the LCO is met, or until the plant is not within the Applicability of the Technical Specification.

Surveillances do not have to be performed on the associated inoperable equipment (or on variables outside the specified limits), as permitted by SR 3.0.1. Therefore, utilizing LCO 3.0.4 is not a violation of SR 3.0.1 or SR 3.0.4 for any Surveillances that have not been performed on inoperable equipment. However, SRs must be met to ensure OPERABILITY prior to declaring the associated equipment OPERABLE (or variable within limits) and restoring compliance with the affected LCO.

Bases Insert 2 (SR 3.0.4 Bases)

SR 3.0.4 establishes the requirement that all applicable SRs must be met before entry into a MODE or other specified condition in the Applicability.

This Specification ensures that system and component OPERABILITY requirements and variable limits are met before entry into MODES or other specified conditions in the Applicability for which these systems and components ensure safe operation of the plant. The provisions of this Specification should not be interpreted as endorsing the failure to exercise the good practice of restoring systems or components to OPERABLE status before entering an associated MODE or other specified condition in the Applicability.

A provision is included to allow entry into a MODE or other specified condition in the Applicability when an LCO is not met due to Surveillance not being met in accordance with LCO 3.0.4.

However, in certain circumstances, failing to meet an SR will not result in SR 3.0.4 restricting a MODE change or other specified condition change. When a system, subsystem, division, component, device, or variable is inoperable or outside its specified limits, the associated SR(s) are not required to be performed, per SR 3.0.1, which states that surveillances do not have to be performed on inoperable equipment. When equipment is inoperable, SR 3.0.4 does not apply to the associated SR(s) since the requirement for the SR(s) to be performed is removed.

Therefore, failing to perform the Surveillance(s) within the specified Frequency does not result in an SR 3.0.4 restriction to changing MODES or other specified conditions of the Applicability.

However, since the LCO is not met in this instance, LCO 3.0.4 will govern any restrictions that may (or may not) apply to MODE or other specified condition changes. SR 3.0.4 does not restrict changing MODES or other specified conditions of the Applicability when a Surveillance has not been performed within the specified Frequency, provided the requirement to declare the LCO not met has been delayed in accordance with SR 3.0.3.

The provisions of SR 3.0.4 shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS. In addition, the provisions of SR 3.0.4 shall not prevent changes in MODES or other specified conditions in the Applicability that result from any plant shutdown. In this context, a plant shutdown is defined as a change in MODE or other specified condition in the Applicability associated with transitioning from MODE 1 to MODE 2, MODE 2 to MODE 3, MODE 3 to MODE 4, and MODE 4 to MODE 5.

The precise requirements for performance of SRs are specified such that exceptions to SR 3.0.4 are not necessary. The specific time frames and conditions necessary for meeting the SRs are specified in the Frequency, in the Surveillance, or both. This allows performance of Surveillances when the prerequisite condition(s) specified in a Surveillance procedure require entry into the MODE or other specified condition in the Applicability of the associated LCO prior to the performance or completion of a Surveillance. A Surveillance that could not be performed until after entering the LCO's Applicability, would have its Frequency specified such that it is not "due" until the specific conditions needed are met. Alternately, the Surveillance may be stated in the form of a Note, as not required (to be met or performed) until a particular event, condition, or time has been reached. Further discussion of the specific formats of SRs' annotation is found in Section 1.4, Frequency.

Bases Insert 3 (LCO 3.4.12 Bases, LTOP System)

A Note prohibits the application of LCO 3.0.4.b to an inoperable LTOP system. There is an increased risk associated with entering MODE 4 from MODE 5 with LTOP inoperable and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

Bases Insert 4 (LCO 3.4.16 Bases, RCS Specific Activity)

A Note permits the use of the provisions of LCO 3.0.4.c. This allowance permits entry into the applicable MODE(S) while relying on the ACTIONS.

Bases Insert 5 (LCO 3.5.3 Bases, ECCS - MODE 4)

Condition B is modified by a Note which prohibits the application of LCO 3.0.4.b to an inoperable ECCS Si subsystem when entering MODE 4. There is an increased risk associated with entering MODE 4 from MODE 5 with an inoperable ECCS Si subsystem and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

Bases Insert 6 (LCO 3.7.5, Auxiliary Feedwater (AFW) System)

Condition C is modified by a Note which prohibits the application of LCO 3.0.4.b with a TDAFW train inoperable, or both MDAFW trains inoperable, or one TDAFW train flow path and one MDAFW train inoperable to opposite SGs. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with a TDAFW train inoperable, or both MDAFW trains inoperable, or one TDAFW train flow path and one MDAFW train inoperable to opposite SGs consequently the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in these circumstances.

Bases Insert 7 (LCO 3.7.5, Auxiliary Feedwater (AFNNW) System)

Condition D is modified by a Note which prohibits the application of LCO 3.0.4.b with all AFW trains to one or both SGs inoperable. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with all AFW trains to one or both SGs inoperable and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in these circumstances.

Bases Insert 8 (LCO 3.8.1, AC Sources - MODES 1, 2, 3, and 4)

A Note prohibits the application of LCO 3.0.4.b to an inoperable DG. There is an increased risk associated with entering a MODE or other specified condition in the Applicability with an inoperable DG and the provisions of LCO 3.0.4.b, which allow entry into a MODE or other specified condition in the Applicability with the LCO not met after performance of a risk assessment addressing inoperable systems and components, should not be applied in this circumstance.

LCO Applicability B3.0 Required Action of LCO 3.7.11 of "Suspend movement of irradiated fuel assemblies in the SFP" is the appropriate Required Action to complete in lieu of the actions of LCO 3.0.3. These exceptions are addressed in the individual Specifications.

LCO 3.0.4 LCO 3.0.4 establishes limitations on ch es in MODES or other specified conditions in the Applicabili hen an LCO is not met. It f A precludes placing the plant in a diff ent MODE or other specified condition stated in the Applicabi when the following exist:

a. Plant conditions are ch that the requirements of an LCO would not be met in the DE or other specified condition in the /

J Applicability d toesied n be entered; lconditig zn the Applicability desired to be entere iorer to comr with the Required Actions of the affected 0. )

Co nce with Required Actions that permit continued operation of the PI for an unlimited period of time in a MOD!zo' other specified ndition provides an acceptable level of safety for continued operation.

is is without regard to the status of the nt before or after the MODE d-. 'J....,- change. Therefore, in such cases, ent Into a MODE or other specified v condition in the Applicability may be oade in accordance with the

( provisions of the Required Action he provisions of this Specification should not be interpreted as end orsing the failure to exercise the good practice of restoring systems components to OPERABLE status before entering an associated M0DE or other specified condition in the Applicability.

The provisions of 0 3.0.4 shall not prevent changes in MODES r other specified nditions in the Applicability that are required t omply )

with ACTION In addition, the provisions of LCO 3.0.4 shall ot prevent changes i ODES or other specified conditions in the Ap cability that (

result fr a shutdown performed in response to the ex cted failure to '

com with ACTIONS.

ceptions to LCO 3.0.4 are stated in the indiv l Specifications. The exceptions allow entry into MODES or other ecified conditions in the Applicability when the associated ACTION to be entered do not provide for continued operation for an unlimited eriod of time. Exceptions may apply to all the ACTIONS or to a spe ic Required Action of a Specification.

R.E. Ginna Nuclear Power Plant B 3.0-5 Revision@>

LCO Applicability B 3.0 LCO 3.0.4 is applicable when enteri MODES (e.g., MODE 5 to MOD IMODES, whether increasing in or decreasing in MODES (e.g.,

MODE 4 to MODE 5). This r irement precluding entry into ano er MODE when the associa ACTIONS do not provide for cont ed operation for an unli d period of time ensures that the p t maintains sufficient equipm OPERABILITY and redundancy a ssumed in the K/

accident analIs.

Survei ces do not have to be performed o e associated inoperable e ment (or on variables outside the spified limits), as permitted by 3.0.1. Therefore, changing MOD or other specified conditions while in an ACTIONS Condition, ompliance with LCO 3.0.4 or where an exception to LCO 30.4 is s ed, is not a violation of SR 3.0.1 or SR 3.0.4 for those Surveillance at do not have to be performed due to the associated inoperable epment. However, SRs must be met to ensure OPERABILITY priordeclaring the associated equipment OPERABLE (or variable wit mits) and restoring compliance with the affected LCO. I LCO 3.0.5 LCO 3.0.5 establishes the allowance for restoring equipment to service under administrative controls when it has been removed from service or declared inoperable to comply with ACTIONS. The sole purpose of this LCO is to provide an exception to LCO 3.0.2 (e.g., to not comply with the applicable Required Action(s)) to allow the performance of SRs to demonstrate:

a. The OPERABILITY of the equipment being returned to service; or

b. The OPERABILITY of other equipment.

The administrative controls ensure the time the equipment is returned to service in conflict with the requirements of the ACTIONS is limited to the time absolutely necessary to perform the allowed SRs. This Specification does not provide time to perform any other preventive or corrective maintenance.

An example of demonstrating the OPERABILITY of the equipment being returned to service is reopening a containment isolation valve that has been closed to comply with Required Actions and must be reopened to perform the SRs.

R.E. Ginna Nuclear Power Plant B 3.0-6 Revision 0

SR Applicability B 3.0 reasonable opportunity should include consideration of the impact on plant risk (from delaying the Surveillance as well as any plant configuration changes required or shutting the plant down to perform the Surveillance) and impact on any analysis assumptions, in addition to unit conditions, planning, availability of personnel, and the time required to perform the Surveillance. This risk impact should be managed through the program in place to implement 10 CFR 50.65(a)(4) and its implementation guidance, NRC Regulatory Guide 1.182, 'Assessing and Managing Risk Before Maintenance Activities at Nuclear Power Plants.'

This Regulatory Guide addresses consideration of temporary and aggregate risk impacts, determination of risk management action thresholds, and risk management action up to and including plant shutdown. The missed Surveillance should be treated as an emergent condition as discussed in the Regulatory Guide. The risk evaluation may use quantitative, qualitative, or blended methods. The degree of depth and rigor of the evaluation should be commensurate with the importance of the component. Missed Surveillances for important components should be analyzed quantitatively. If the results of the risk evaluation determine the risk increase Is significant, this evaluation should be used to determine the safest course of action. All missed Surveillances will be placed within the Corrective Action Program.

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

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

SR 3.0.4 .4 establishes e equrement that all appl aable SRs must be met before entry into a MOSE or other specified co ition in the Applicability.

This Specification sures that system and omponent OPERABILITY requirements an variable limits are met fore entry into MODES or other specified/onditions in the Applica ity for which these systems and components nsuresafeoperationof eplant. This Specification applies to anges in MODES or oter specified conditions in the

\ApplicaWty associated with plant utdown as well as startup.

R.E. Ginna Nuclear Power Plant B 3.0-12 Revision(9

SR Applicability B 3.0 The provisions of this specification should not be irpreted as endorsing the failure to exercise the good practi of restoring systems or components to OPERABLE status before e ring an associated MODE

( or other specified condition in the Appli ity.

The provisions of SR 3.0.4 shall no revent changes in MODES or other specified conditions in the Appli ility that are required to comply with ACTIONS. In addition, the p isions of SR 3.0.4 shall not prevent changes in MODES or ot specified conditions in the Applicability that result from a shutdown erfomed in response to the expected failure to comply with ACTIO I However, in c amcircumstances, failing to meet an SR will not result SR 3.0.4 re ricting a MODE change or other specified condition chan When a stem, subsystem, train, component, device, or variable*

inopble or outside its specified limits, the associated SR(s) not re ired to be performed, per SR 3.0.1, which states that s eillances s donot have to be performed on inoperable equipment. gln equipmet is inoperable, SR 3.0.4 does not apply to the associate SR(s) since the requirement for the SR(s) to be performed is remo Therefore, failing to perform the Surveillance(s) within the specifi Frequency, on equipment that is inoperable, does not resul an SR 3.0.4 restriction to l changing MODES or other specified consltons of the Applicability.

However, since the LCO is not met in s instance, LCO 3.0.4 will govern any restrictions that may (or may npt5apply to MODE or other specified condition changes.

The precise requiremen rperformance of SRs are specified such that exceptions to SR 3.0. re not necessary. The specific time frames and conditions necess for meeting the SRs are specified in the Frequency, in the Surveilla , or both. This allows performance of Surveillances when the pr quisite condition(s) specified in a Surveillance procedur require e into the MODE or other specified condition in the Applic lity of the associated LCO prior to the performance or

' co etion of a Surveillance. A Surveillance that could not b erformed

til after entering the LCO Applicability, would have its F quency

' specified such that it is not "due" until the specific con ons needed are met. Alternately, the Surveillance may be stated in e form of a Note as not required (to be met or performed) until a partilar event, condition, or

' time has been reached. Further discussion Hhe specific formats of

SRs' annotation is found in Section 1.4, F quency.

SR 3.0.4 is applicable when enterin all MODES, whether increasing in MODES (e.g., MODE 5 to MODS) or decreasing in MODES (e.g.,

MODE 4 to MODE 5). This r uirement precluding entry into another MODE when the associat ACTIONS do not provide for continued operation for an unlimi period of time ensures that the plant maintains R. lt.0.3ev -i*nn P ... .,,o R.E. Ginna Nuclear Power Plant B 3.0-13 Revision3

SR Applicability B 3.0 R.E. Ginna Nuclear Power Plant B 3.0-14 Revisiong

MTC B 3.1.3 Condition C has been modified by a Note that requires that Required Action C.1 must be completed whenever this Condition is entered. This is necessary to ensure that the plant does not operate at conditions where the MTC would be below the most negative limit specified in the COLR.

Required Action C.1 is modified by a Note which states that LCO 3.0.4 is

(~applicable. This Note is provided since the requirement to re-evaluate the core design and safety analysis prior to reaching an equivalent RTP ARO boron concentration of 300 ppm is adequate action without restricting entry into MODE 1.

D.1 If the re-evaluation of the accident analysis cannot support the predicted EOL MTC lower limit, or if the Required Actions of Condition C are not completed within the associated Completion Time the plant must be brought to a MODE or Condition in which the LCO requirements are not applicable. To achieve this status, the plant must be brought to MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Time is reasonable, based on operating experience, for reaching the required MODE from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.1.3.1 REQUIREMENTS This SR requires measurement of the MTC at BOL prior to entering MODE 1 in order to demonstrate compliance with the most positive MTC LCO. Meeting the limit prior to entering MODE 1 ensures that the limit will also be met at higher power levels.

The BOL MTC value for ARO will be inferred from isothermal temperature coefficient (ITC) measurements obtained during the physics tests after refueling. The ARO value can be directly compared to the BOL MTC limit of the LCO. If required, measurement results and predicted design values can be used to establish administrative withdrawal limits for control banks.

The measurement of the MTC at the beginning of the fuel cycle is adequate to confirm that the MTC remains within its upper limits and will be within limits at 70% RTP, full power and at EOL, since this coefficient changes slowly, due principally to the reduction in RCS boron concentration associated with fuel burnup. This measurement is consistent with the recommendations detailed in Reference 4.

R.E. Ginna Nuclear Power Plant B 3.1.3-5 Revision 0

PAM Instrumentation B 3.3.3 APPLICABILITY The PAM instrumentation LCO is applicable in MODES 1, 2, and 3.These variables are related to the diagnosis and pre-planned actions required to mitigate DBAs.The applicable DBAs are assumed to occur in MODES 1, 2, and 3. In MODES 4, 5, and 6, the PAM instrumentation is not required to be OPERABLE because plant conditions are such that the likelihood of an event that would require PAM instrumentation is low.

ACTIONS The ACTIONS are modified by two Notes.

Note 1has been added oexclude the MODE chang ofCostmpction oTim l3.0.4.This exceptions entry into the applicabl ODE while relying

{on the ACTIONS en tough the ACTIONS may Sentually require plant shutdown. Thison lption is acceptable due to passive function of the instruments, t operator's ability to respondto an accident using alternate in neluments and methods, and tredow probability of an event (9F Note ohas been added to clarify the application of CompletionTime rules. The Conditions of this Specification may be entered independently for each Function listed on Table 3.3.3-1 .The Completion Time(s) of the inoperable channel(s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function.

Condition A applies when one or more Functions have one required channel that is inoperable. Required Action A.1 requires restoring the inoperable channel to OPERABLE status within 30 days. The 30 day Completion Time is based on operating experience and takes into account the remaining OPERABLE channel, the passive nature of the instrument (no critical automatic action is assumed to occur from these instruments), and the low probability of an event requiring PAM Instrumentation during this interval.

Condition A is modified by a Note which states that the Condition is not applicable to Table 3.3.3-1 Functions 3 and 4. These Functions are addressed by Condition Cwhich provides the necessary required actions for these single channel Functions.

R.E. Ginna Nuclear Power Plant B 3.3.3-14 Revision

RCS Loops - MODES 1

8.5% RTP, 2, and 3 B 3.4.5 APPLICABILITY In MODES 1 < 8.5% RTP, 2, and 3, this LCO ensures forced circulation of the reactor coolant to remove reactor and decay heat from the core and to provide proper boron mixing.

Operation in other MODES is covered by:

LCO 3.4.4, "RCS Loops - MODE 1 > 8.5% RTP";

LCO 3.4.6, "RCS Loops - MODE 4";

LCO 3.4.7, "RCS Loops - MODE 5, Loops Filled";

LCO 3.4.8, 'RCS Loops - MODE 5, Loops Not Filled";

LCO 3.9.4, 'Residual Heat Removal (RHR) and Coolant Circulation-Water Level 2 23 Ft' (MODE 6); and LCO 3.9.5, *Residual Heat Removal (RHR) and Coolant Circulation-Water Level < 23 Ft' (MODE 6).

ACTIONS A.1 and A.2 If one RCS loop is inoperable, redundancy for heat removal is lost. The Required Actions are to verify that the SDM is within limits specified in the COLR. This action is required to ensure that adequate SDM exists in the event of a main steam line break with only one RCS loop in operation.

The Completion Time of once per 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months considers the time required to obtain RCS boron concentration samples and the low probability of a main steam line break during this time period.

The inoperable RCS loop must be restored to OPERABLE status within the Completion Time of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . This time allowance is a justified period to be without the redundant, nonoperating loop because a single loop in operation has a heat transfer capability greater than that needed to remove the reactor and decay heat produced in the reactor core and because of the low probability of a failure in the remaining loop occurring

(

during this period.

Required Action A.1 is'odified by a Note that in cates that the provisions of LCO 3. .4 are not applicable. As result, a MODE change is allowed when o RCS loop is inoperable/This allowance is provided because a sin RCS loop can provide t required cooling to remove reactor and cay heat consistent wit afety analysis assumptions.

R.E. Ginna Nuclear Power Plant B 3.4.5-4 Revisioro

Pressurizer PORVs B 3.4.11 APPLICABILITY In MODES 1,2, and 3, the PORV is required to be OPERABLE to mitigate the effects associated with an SGTR and its block valve must be OPERABLE to limit the potential for a small break LOCA through the flow path. The most likely cause for a PORV small break LOCA is a result of a pressure increase transient that causes the PORV to automatically open with a subsequent failure to close. Imbalances in the energy output of the core and heat removal by the secondary system can cause the RCS pressure to increase to the PORV opening setpoint. The most rapid increases will occur at the higher operating power and pressure conditions of MODES I and 2. Pressure increases are less prominent in MODE 3 because the core input energy is reduced, but the RCS pressure is high.

The PORVs are also required to be OPERABLE in MODES 1, 2, and 3 to minimize challenges to the pressurizer safety valves by manually opening the PORVs. Therefore, the LCO is applicable in MODES 1, 2, and 3.

The LCO is not applicable in MODE 4 when both pressure and core energy are decreased and the pressure surges become much less significant. The PORV setpoint is reduced for LTOP in MODES 4, 5, and 6with the reactor vessel head in place. LCO 3.4.12 addresses the PORV requirements in these MODES.

ACTIONS Note I has been added to clarify that both pressurizer PORVs are treated as separate entities, each with separate Completion Times (i.e., the Completion Time is on a component basis) for Condition A. Note 2 has been added to clarify that both block valves are treated as separate entities, each with separate Completion Times, for, gl i_ ~ ~~~

g M DS 2, and 3to\

perform cycling ofw ORVs or block valv to verify their 0PRBE status. Testinno performed in lowe ODESdutoIT rconsideration A.1 and A.2 With the PORVs OPERABLE and not capable of being automatically controlled, either the PORVs must be restored or the flow path isolated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . Although a PORV may not be capable of being automatically controlled, it may be able to be manually opened and closed, and therefore, able to perform its function. A PORV is considered not capable of being automatically controlled for any problem which prevents the PORV from automatically closing once it has automatically opened. This may be due to instrumentation problems. Not capable of automatic control does not include problems which only prevent the PORV from automatically opening (e.g., loss of instrument air to the R.E. Ginna Nuclear Power Plant B 3.4.11-3 Revisiong

LTOP System B 3.4.12 The second Note only requires an ECCS accumulator to be isolated when the accumulator pressure is greater than or equal to the maximum pressure for the existing RCS cold leg temperature allowed in the PTLR.

Accumulator pressure below this limit will not overpressurize the RCS beyond analyzed conditions. The accumulator is isolated when the discharge motor operated valve is closed and its associated power supply is removed.

APPLICABILITY This LCO Is applicable in MODE 4 when any RCS cold leg temperature is less than or equal to the LTOP enable temperature specified in the PTLR or the RHR system is in the RHR operating mode, in MODE 5 when the SG primary system manway and pressurizer manway are closed and secured in position, and in MODE 6 when the reactor vessel head is on and the SG primary system manway and pressurizer manway are closed and secured in position. The pressurizer safety valves provide overpressure protection that meets the Reference 1 P/T limits above the LTOP enable temperature specified in the PTLR. When the reactor vessel head is off or the SG primary system manway or pressurizer manway are open, overpressurization cannot occur.

LCO 3.4.3 provides the operational P/T limits for all MODES. LCO 3.4.10, "Pressurizer Safety Valves," requires the OPERABILITY of the pressurizer safety valves that provide overpressure protection during MODES 1, 2, and 3, and MODE 4 above the LTOP enable temperature specified in the PTLR.

Low temperature overpressure prevention is most critical during shutdown when the RCS is water solid, and a mass or heat input transient can cause a very rapid increase in RCS pressure when little or no time allows operator action to mitigate the event.

ACTIONS A.1 With one or more Si pumps capable of injecting into the RCS and the 3.e 0f 13 PORVs provide the RCS vent path, RCS overpressurization is possible.

To immediately initiate action to restore restricted coolant input capability TP to the RCS reflects the urgency of taking action to remove the RCS from this potential condition.

Condition A is modified by a Note which states that this condition is only applicable to LCO 3.4.12.a (i.e., when the PORVs provide the RCS vent path).

R.E. Ginna Nuclear Power Plant B 3.4.12-7 Revision(o

RCS Leakage Detection Instrumentation B 3.4.15 The containment air cooler condensate collection system is OPERABLE if the flow paths from all four containment air coolers to their respective collection tanks are available and a CHANNEL CALIBRATION of the monitor has been performed within the last 24 months. The containment air cooler condensate collection system is provided as an option for detecting RCS leakage since SR 3.4.13.1 is not performed until after 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation. Therefore, this collection system can be used during MODE changes if the containment sump monitor is inoperable to meet the LCO.

Restoration of the required sump monitor to OPERABLE status within a Completion Time of 30 days is required to regain the function after the monitor's failure. This time is acceptable, considering the Frequency and adequacy of the RCS water inventory balance required by Required Action A.1.

equire on A.1.2, and . are oed by a Note a indicates that t provisions of LCO 3.0.4 re not applicable. As a result, a MODE cha e is allowed when the c tainment sump monitor is inoperable. his allowance is provide because other instrumentation is avilable t monitor RCS leakage./

B.1 With the gaseous (R-12) containment atmosphere radioactivity monitoring instrumentation channel inoperable (and its alternate R-14), a verification that the particulate (R-1 1)containment atmosphere radioactivity monitor is OPERABLE is required. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time is based on the low probability of a RCS leak occurring during this time frame.

Required Acti B.1 is modified by a ote that indicates that the provisions of CO 3.0.4 are not appl' ble. As a result, a MODE change is allowed en the gaseous cont ment atmosphere radioactivity monitor is noperable. This allow ce is provided because other

_ tblebinstrm to nitor for RCS LEAKAGE.

C.1 and C.2 With the particulate (R-11) containment atmosphere radioactivity monitoring instrumentation channel inoperable (and its alternate R-13) or Required Action B.1 not met, alternative action is required. Either grab samples of the containment atmosphere must be taken and analyzed or water inventory balances, in accordance with SR 3.4.13.1, must be performed to provide alternate periodic information as the gaseous (R-

12) containment atmosphere radioactivity monitor can only measure between a 2.0 and 10.0 gpm leak within one hour and the containment sump monitor can only measure a 2.0 gpm leak within one hour.

R.E. Ginna Nucleair Power Plant B 3.4.15-4 Revision~p

RCS Leakage Detection Instrumentation B 3.4.15 The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval provides periodic information that is adequate to detect leakage and recognizes that at least one other form of leakage detection is available.

Required Actions .and 0.2 are modified b Note that indicates that the provisions of L 3.0.4 are not applicabl . As a result, a MODE change is allowe when the particulate con inment atmosphere radioactivity mpitor is inoperable. This owance is provided because other instrunination is available to mo or for RCS LEAKAGE.

D.1 and D.2 With the gaseous (R-12) and the particulate (R-11) containment atmosphere radioactivity monitors inoperable, the only installed means of detecting leakage is the containment sump monitor. This condition does not provide a diverse means of leakage detection. Also, the sump monitor can only measure a 2.0 gpm leak within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

In addition to the Required Actions of Conditions B and C, restoration of either of the inoperable monitors to OPERABLE status within 30 days is required to regain the intended leakage detection diversity. The 30 day Completion Tlime ensures that the plant will not be operated in a reduced configuration for a lengthy period of time.

Required Actions D and D.2 are modified by Note that indicates that the provisions of 0 3.0.4 are not applicabl . As a result, a MODE change is allowe when the gaseous and p iculate containment atmosphere ra oactivity monitors are inop rable. This allowance is provided be - se other instrumentationi available to monitor RCS E.1 and E.2 If a Required Action of Condition A, C, or D cannot be met, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and to MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.

F.1 With all required monitors inoperable, no automatic means of monitoring leakage are available, and immediate plant shutdown in accordance with LCO 3.0.3 is required.

R.E. Ginna Nuclear Power Plant B 3.4.15-5 Revision

RCS Specific Activity B 3.4.16 (3 c;~u Required Action A.1 i odified by a Note tha ndicates that the provisions of LCO 3 .4 are not applicable. s a result, a MODE change is allowed whente DOSE EQUIVALENT 131 is greater than th limit and within e acceptable range of igure 3.4.16-1. This allowance isprovde rvatsm included in the LCO limit. Also, reducing the DOSE EQUIVALENT 1-131 to within limits is accomplished through use of the Chemical and Volume Control System (CVCS) demineralizers. This cleanup operation parallels plant restart following a reactor trip which frequently results in iodine spikes due to the large step decrease in reactor power level and RCS pressure excursion.

The cleanup operation can normally be accomplished within the LCO Completion lime of 7 days.

B.1 If a Required Action and the associated Completion Time of Condition A is not met or if the DOSE EQUIVALENT 1-131 specific activity is in the unacceptable region of Figure 3.4.16-1, the reactor must be brought to MODE 3 with RCS average temperature < 500 0F within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . The change within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to MODE 3 and RCS average temperature

< 500OF lowers the saturation pressure of the reactor coolant below the setpoints of the main steam safety valves and prevents automatically venting the SG to the environment in an SGTR event. The Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is reasonable, based on operating experience, to reach MODE 3 below 500OF from full power conditions in an orderly manner and without challenging plant systems.

C.1 If the gross specific activity is not within limit, the change within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to MODE 3 and RCS average temperature < 500OF lowers the saturation pressure of the reactor coolant below the setpoints of the main steam safety valves and prevents automatically venting the SG to the environment in an SGTR event. The allowed Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is reasonable, based on operating experience, to reach MODE 3 below 500 0F from full power conditions in an orderly manner and without challenging plant systems.

SURVEILLANCE SR 3.4.16.1 REQUIREMENTS This SR requires performing a gamma isotopic analysis as a measure of the gross specific activity of the reactor coolant at least once every 7 days. While basically a quantitative measure of radionuclides with half lives longer than 15 minutes, excluding iodines, this measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken. This Surveillance provides an indication of any increase in gross specific activity.

R.E. Ginna Nuclear Power Plant B 3.4.16-4 Revisiong)

ECCS - MODE 4 B 3.5.3 With no ECCS SI subsystem OPERABLE, due to the inoperability of the SI pump or flow path from the RWST, the plant is not prepared to provide high pressure response to an accident requiring SI. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion lime to restore at least one SI subsystem to OPERABLE status ensures that prompt action is taken to provide the required cooling capacity or to initiate actions to place the plant in MODE 5, where an ECCS train is not required.

C.1 When the Required Actions of Condition B cannot be completed within the required Completion Time, a controlled shutdown should be initiated.

Twenty-four hours Is a reasonable time, based on operating experience, to reach MODE 5 In an orderly manner and without challenging plant systems or operators.

SURVEILLANCE SR 3.5,3.1 REQUIREMENTS The applicable Surveillance description from Bases 3.5.2 apply. This SR is modified by a Note that allows an RHR train to be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned (remote or local) to the ECCS mode of operation and not otherwise inoperable. This allows operation in the RHR mode during MODE 4, if necessary.

REFERENCES 1. None.

R.E. Ginna Nuclear Power Plant B 3.5.3-4 Revision .0

Hydrogen Recombiners B 3.6.7 ACTIONS A.1 With one containment hydrogen recombiner inoperable, the inoperable recombiner must be restored to OPERABLE status within 30 days. In this condition, the remaining OPERABLE hydrogen recombiner is adequate to perform the hydrogen control function. However, the overall reliability is reduced because a single failure in the OPERABLE recombiner could result in reduced hydrogen control capability. The 30 day Completion Time is based on the availability of the other hydrogen recombiner, the small probability of a LOCA or SLB occurring (that would generate an amount of hydrogen that exceeds the flammability limit), and the amount of time available after a LOCA or SLB (should one occur) for operator action to prevent hydrogen accumulation from exceeding the flammability limit.

provisions of LC 3.0.4 are not applicable As a result, a MODE change is allowed whe one recombiner is inoper ble. This allowance is based on the availa tity of the other hydrogen ecombiner, the small probability of aLOCAoo~LB occurring (that woul dgenerate an amrount of hydrogen that excee s the flammability limit), a the amount of time available after a LOCA or SLB (should one occur) f r operator action to prevent hydrogen accumulation from exce ing the flammability limit.

B.1 and B.2 With two hydrogen recombiners inoperable, the ability to perform the hydrogen control function via alternate capabilities must be verified by administrative means within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The alternate hydrogen control capabilities are provided by the Mini-Purge System which consists of two isolation valves per penetration flow path that are capable of opening and a supply fan capable of performing purging functions. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion lime allows a reasonable period of time to verify that a loss of hydrogen control function does not exist. In addition, the alternate hydrogen control system capability must be verified once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter to ensure its continued availability. Both the initial verification and all subsequent verifications may be performed as an administrative check by examining logs or other information to determine the availability of the alternate hydrogen control system. It does not mean to perform any Surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control system (e.g., opening of mini-purge valves). If the ability to perform the hydrogen control function is maintained, continued operation is permitted with two hydrogen recombiners inoperable for up to 7 days. Seven days is a reasonable time to allow two hydrogen recombiners to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of a R.E. Ginna Nuclear Power Plant B 3.6.7-4 Revisiong

ARVs B 3.7.4 APPLICABILITY In MODES 1 and 2, and in MODE 3 with RCS average temperature 2 5000F, the ARV lines are required to be OPERABLE.

In MODE 3 with RCS average temperature < 5001F, and in MODE 4, the ARVs are not required since the saturation pressure of the reactor coolant is below the lift settings of the MSSVs. In MODE 5or 6, an SGTR is not a credible event since the water in the SGs is below the boiling point and RCS pressure is low.

ACTIONS A.1 With one ARV line inoperable, ACTION must be taken to restore the valve to OPERABLE status within 7 days. The 7 day Completion Time allows for the redundant capability afforded by the remaining OPERABLE ARV line and a nonsafety. grade backup in the steam dump system.

Required Action A. is modified by a Note in icating that LCO 3.0.4 does not apply since t steam dump system wrld normally be in service during lower M ES of operation and provide an acceptable alternative to noperable ARV line.7" 8.1 If the ARV line cannot be restored to OPERABLE status within the associated Completion Time, the plant must be placed in a MODE in which the LCO does not apply. To achieve this status, the plant must be placed in at least MODE 3 with RCS average temperature < 500 0F within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months . The allowed Completion Time is reasonable, based on operating experience, to reach the required plant conditions from full power conditions In an orderly manner and without challenging plant systems.

C.1 If both ARV lines are inoperable, the plant is in a condition outside of the accident analyses for a SGTR event; therefore, LCO 3.0.3 must be entered immediately.

R.E. Ginna Nuclear Power Plant B 3.7.4-3 Revision o

AFW System B 3.7.5 A TDAFW train flow path is defined as the steam supply line and SG injection line from/to the same SG.

B.1 If one MDAFW train is inoperable, action must be taken to restore the train to OPERABLE status within 7 days. The 7 day Completion Time is reasonable, based on the following reasons:

a. The redundant OPERABLE MDAFW train;

b. The availability of redundant OPERABLE TDAFW and SAFW pumps; and

c. The low probability of an event occurring that requires the inoperable MDAFW train.

C.1 With the TDAFW train inoperable, or both MDAFW trains inoperable, or one TDAFW train flow path and one MDAFW train inoperable to opposite SGs, action must be taken to restore OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

If the inoperable MDAFW train supplies the same SG as the inoperable TDAFW flow path, Condition D must be entered.

The combination of failures which requires entry into this Condition all result in the loss of one train (or one flow path) of preferred AFW cooling to each SG such that redundancy is lost. The 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Completion Time is reasonable, based on redundant capabilities afforded by the SAFW System, time needed for repairs, and the low probability of a DBA occurring during this time period.

D.1 With all AFW trains to one or both SGs inoperable, action must be taken to restore at least one train or TDAFW flow path to each affected SG to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

The combination of failures which require entry into this Condition all result in the loss of preferred AFW cooling to at least one SG. If a SGTR were to occur in this condition, preferred AFW is potentially unavailable to the unaffected SG. If AFW is unavailable to both SGs, the accident analyses for small break LOCAs and loss of MFW would not be met.

R.E. Ginna Nuclear Power Plant B 3.7.5-6 Revision 9)

AFW System B 3.7.5 The two MDAFW trains of the preferred AFW System are normally used for decay heat removal during low power operations since air operated bypass control valves are installed in each train to better control SG level (see Figure B 3.7.5-1). Since a feedwater transient is more likely during reduced power conditions, 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is provided to restore at least one train of additional preferred AFW before requiring a controlled cooldown. This will also provide time to find a condensate source other than the SW System for the SAFW System if all three AFW trains are inoperable. The 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Completion Time is reasonable, based on redundant capabilities afforded by the SAFW System, time needed for repairs, and the low probability of a DBA occurring during this time period.

E.1 With one SAFW train inoperable, action must be taken to restore OPERABLE status within. 14 days. This Condition includes the inoperability of one of the two SAFW cross-tie valves which requires declaring the associated SAFW train inoperable (e.g., failure of 9703B would result in declaring SAFW train D inoperable). The 14 day Completion Time is reasonable, based on redundant capabilities afforded by the AFW System, time needed for repairs, and the low probability of a HELB or other event which would require the use of the SAFW System during this time period.

F.1 With both SAFW trains inoperable, action must be taken to restore at least one SAFW train to OPERABLE status within 7 days. This Condition includes the inoperability of the SAFW cross-tie. The 7 day Completion Time is reasonable, based on redundant capabilities afforded by the AFW System, time needed for repairs, and the low probability of a HELB or other event which would require the use of the SAFW System during this time period.

G.1 and G.2 When Required Action A.1, B.1, C.1, D.1, E.1, or F.1 cannot be completed within the required Completion Time, the plant must be placed in a MODE in which the LCO does not apply. To achieve this status, the plant must be placed in at least MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in MODE 4 within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . The allowed Completion Times are reasonable, based on operating experience, to reach the required plant condition from full power conditions in an orderly manner and without challenging plant systems.

R.E. Ginna Nuclear Po wer Plant B 3.7.5-7 Revision

AC Sources - MODES 1,2, 3, and 4 B 3.8.1 Any 480 V bus fault which opens and/or prevents closure of the breakers from offsite power or the DGs requires declaring the offsite power source or DG inoperable, as applicable.

The AC sources Inone train must be separate and independent of the AC sources in the other train. For the DGs, separation and independence must be complete assuming a single active failure. For the independent offsite power source, separation and independence are to the extent practical (i.e., operation is preferred in the 50150 mode, but may also exist in the 100/0 or 0/100 mode).

APPLICABILITY The AC sources are required to be OPERABLE in MODES 1, 2, 3, and 4 to ensure that:

a. Acceptable fuel design limits and reactor coolant pressure boundary limits are not exceeded as a result of AQOs or abnormal transients; and

b. Adequate core cooling is provided and containment OPERABILITY and other vital functions are maintained in the event of a postulated DBA.

The AC power requirements for MODES 5 and 6 are covered in LCO 3.8.2, "AC Sources - MODES 5 and 6."

ACTIONS A.1 and A.2 With offsite power to one or more 480V safeguard bus(es) inoperable,

{e x assurance must be provided that a coincident single failure will not result in a complete loss of required safety features. If the redundant safety feature to the component or train affected by the loss of offsite power is also unavailable, the assumption that two complete safety trains are OPERABLE may no longer exist. As an example, if offsite power were unavailable to 480 V Bus 14, DG A could supply the necessary power to the bus. If residual heat removal pump (RHR) B (supplied power by Bus

16) were inoperable at the same time, or at any time after the loss of offsite power to Bus 14, a loss of redundant required safety features exists since a failure of DG A would result in the loss of emergency core cooling. Therefore, RHR pump A on Bus 14 would have to be declared inoperable within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after RHR pump B and offsite power to Bus 14 were declared unavailable.

R.E. Ginna Nuclear Power Plant B 3.8.1-7 Revision 25

Enclosure 5 R.E. Ginna Nuclear Power Plant List of Regulatory Commitments The following table identifies those actions committed to by Rochester Gas & Electric (RG&E) in this document. Any other statements in this submittal are provided for information purposes and are not considered to be regulatory commitments. Please direct questions regarding these commitments to Tom Harding, Nuclear Safety and Licensing at (585) 771-3384.

REGULATORY COMMITMENT DUE DATE RG&E will establish the Technical Specification Implemented with the amendment.

Bases as adopted with the applicable license amendment.

ML040680907

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3.0 REGULATORY ANALYSIS

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ML040680907

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Subject:

Dear Mr. Clark:

Enclosures:

1.0 DESCRIPTION

Description:

3.0 REGULATORY ANALYSIS

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