RENEWED FACILITY OPERATING LICENSE DPR-22 

FOR 

MONTICELLO NUCLEAR GENERATING PLANT 

UNIT 1 

MONTICELLO, MINNESOTA 

NORTHERN STATES POWER COMPANY 

DOCKET NO. 50-263 

November 8, 2006 
NORTHERN STATES POWER COMPANY

 |

DOCKET NO. 50-263

MONTICELLO NUCLEAR GENERATING PLANT, UNIT NO. 1

RENEWED FACILITY OPERATING LICENSE

License No. DPR-22

1. The Nuclear Regulatory Commission (NRC or the Commission), having previously made

the findings set forth in License No. DPR-22 issued on January 9, 1981, has now found

that:

A. The application to renew operating License No. DPR-22 filed by Nuclear

Management Company, LLC* (NMC) complies with the standards and

requirements of the Atomic Energy Act of 1954, as amended (the Act), and the

Commission’s rules and regulations set forth in 10 CFR Chapter I, and all required

notifications to other agencies or bodies have been duly made;

B. Construction of the Monticello Nuclear Generating Plant, Unit No. 1 (the facility),

has been completed in conformity with Construction Permit No. CPPR-31 and the

application, the provisions of the Act, and the regulations of the Commission;

C. Actions have been identified and have been or will be taken with respect to

(1) managing the effects of aging during the period of extended operation on the

functionality of structures and components that have been identified to require

review under 10 CFR 54.21(a)(1), and (2) time-limited aging analyses that have

been identified to require review under 10 CFR 54.21(c), such that there is

reasonable assurance that the activities authorized by this renewed operating

license will continue to be conducted in accordance with the current licensing

basis, as defined in 10 CFR 54.3, for the facility, and that any changes made to

the facility’s current licensing basis in order to comply with 10 CFR 54.29(a) are 

in accordance with the Act and the Commission’s regulations;

D. The facility will operate in conformity with the application, the provisions of the 

Act, and regulations of the Commission;

E. There is reasonable assurance: (i) that the activities authorized by this renewed

operating license can be conducted without endangering the health and safety of

the public, and (ii) that such activities will be conducted in compliance with the

Commission’s regulations set forth in 10 CFR Chapter I;

|

 *NMC is maintained as historical information. |

|

Corrected by letter dated 2/23/07

Amendment No. 156 

 
- 2 -

F. Northern States Power Company (NSPM) is technically and financially qualified to |

engage in the activities authorized by this renewed operating license in

accordance with the Commission’s regulations set forth in 10 CFR Chapter I;

G. NSPM has satisfied the applicable provisions of 10 CFR Part 140, “Financial |

Protection Requirements and Indemnity Agreements,” of the Commission’s

regulations;

H. The issuance of this renewed operating license will not be inimical to the 

common defense and security or to the health and safety of the public;

I. After weighing the environmental, economic, technical, and other benefits of the

facility against environmental and other costs and considering available

alternatives, the issuance of this renewed Facility Operating License No. 

DPR-22, subject to the conditions for protection of the environment set forth

herein, is in accordance with 10 CFR Part 51 (formerly Appendix D to Part 50), of

the Commission’s regulations and all applicable requirements have been satisfied;

and

J. The receipt, possession, and use of source, byproduct, and special nuclear

material as authorized by this renewed operating license will be in accordance 

with the Commission’s regulations in 10 CFR Parts 30, 40, and 70.

2. The Facility Operating License No. DPR-22 dated January 9, 1981, is superseded by

Renewed Facility Operating License No. DPR-22, hereby issued to NSPM1

 to read as |

follows: 

A. This renewed operating license applies to the Monticello Nuclear Generating 

Plant, Unit No. 1, a single cycle, forced circulation, boiling water nuclear reactor

and electric generating equipment (the facility). The facility is located in Wright

County on the Northern States’ site in Wright and Sherburne Counties, 

Minnesota, and is described in the “Final Safety Analysis Report,” as

supplemented and amended (Amendment Nos. 9 through 28) and in its

Environmental Report, as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission

hereby licenses:

1. Pursuant to Section 104(b) of the Act, and 10 CFR Part 50, “Licensing of

Production and Utilization Facilities,” NSPM to possess, use, and operate |

the facility as a utilization facility at the designated location in Wright

County, Minnesota, in accordance with the procedures and limitation set

forth in this license;

1 Northern States Power Company was incorporated in Minnesota as a wholly owned subsidiary of Xcel Energy, Inc.

effective August 18, 2000. This license, as amended, was amended effective this date to reflect the Commission’s

consent per 10 CFR Part 50, Section 50.80 to the license transfer approved by Order dated May 12, 2000.

Renewed License No. DPR-22 

Corrected by letter dated 2/23/07

 Amendment No. 156 
- 3 - 

Amendment No. 210 

2. Pursuant to the Act and 10 CFR Part 70, NSPM to receive, possess, and 

use at any time special nuclear material as reactor fuel, in accordance 

with the limitations for storage and amounts required for reactor 

operations, as described in the Final Safety Analysis Report, as 

supplemented and amended, and the licensee’s filings dated August 16, 

1974 (those portions dealing with handling of reactor fuel); 

3. Pursuant to the Act and 10 CFR Parts 30, 40 and 70, NSPM to receive, 

possess, and use at any time any byproduct, source and special nuclear 

material as sealed neutron sources for reactor startup, sealed sources for 

reactor instrumentation and radiation monitoring equipment calibration, 

and as fission detectors in amounts as required; 

4. Pursuant to the Act and 10 CFR Parts 30, 40 and 70, NSPM to receive, 

possess, and use in amounts as required any byproduct, source or 

special nuclear material without restriction to chemical or physical form, 

for sample analysis or instrument calibration or associated with 

radioactive apparatus or components; and 

5. Pursuant to the Act and 10 CFR Parts 30 and 70, NSPM to possess, but 

not separate, such byproduct and special nuclear material as may be 

produced by operation of the facility. 

C. This renewed operating license shall be deemed to contain and is subject to the 

conditions specified in the Commission’s regulations in 10 CFR Chapter I and is 

subject to all applicable provisions of the Act and to the rules, regulations, and 

orders of the Commission, now or hereafter in effect; and is subject to the 

additional conditions specified or incorporated below: 

1. Maximum Power Level 

NSPM is authorized to operate the facility at steady state reactor core 

power levels not in excess of 2004 megawatts (thermal). 

2. Technical Specifications 

The Technical Specifications contained in Appendix A, as revised through 

Amendment No. 210, are hereby incorporated in the license. NSPM shall 

operate the facility in accordance with the Technical Specifications. 

3. Physical Protection 

NSPM shall implement and maintain in effect all provisions of the 

Commission-approved physical security, guard training and qualification, 

and safeguards contingency plans including amendments made pursuant 

to provisions of the Miscellaneous Amendments and Search 
-4-

Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to 

the authority of 10 CFR 50.90 and 10 CFR 50.54(p)(2). The combined 

set of plans which contain Safeguards Information protected under 

10 CFR 73.21, are entitled: "Monticello Nuclear Generating Plant 

Physical Security, Training and Qualification, and Safeguards 

Contingency Plan," with revisions submitted through May 12, 2006. 

NSPM shall fully implement and maintain in effect all provisions of the 

Commission-approved Northern States Power Company - Minnesota 

(NSPM) Cyber Security Plan (CSP), including changes made pursuant to 

the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The NSPM CSP 

was approved by License Amendment No. 166 and supplemented by 

License Amendment No. 186. 

4. Fire Protection 

NSPM shall implement and maintain in effect all provisions of the 

approved fire protection program as described in the Updated Safety 

Analysis Report for the facility and as approved in the SER dated 

August 29, 1979, and supplements dated February 12, 1981 and 

October 2, 1985, subject to the following provision: 

NSPM may make changes to the approved fire protection program 

without prior approval of the Commission only if those changes 

would not adversely affect the ability to achieve and maintain safe 

shutdown in the event of a fire. 

5. Emergency Preparedness Plan 

NSPM shall follow and maintain in effect emergency plans which meet the 

standards of 10 CFR 50.47(b) and the requirements in 10 CFR 50, 

Appendix E, including amendments and changes made pursuant to the 

authority of 10 CFR 50.54(q). The licensee shall meet the requirements 

of 10 CFR 50.54(s), 50.54(t), and 50.54(u). 

6. TMI Action Plan 

NSPM has satisfactorily met all TMI-2 Lessons Learned Category "A" 

requirements applicable to the facility. NSPM shall make a timely 

submittal in response to the letter dated October 31, 1980 regarding postTMI requirements from Darrell G. Eisenhut, Director, Division of 

Licensing, Office of Nuclear Reactor Regulation to All Licensees of 

Operating Plants and Applicants for Operating Licenses and Holders of 

Construction Permits (NUREG-0737). 

7. Repairs to the Recirculation System Piping 

The repairs to the recirculation system piping are approved and the unit is 

hereby authorized to return to power operation, subject to the following 

condition: 

Prior to the startup of Cycle 11 , NSPM shall submit by August 1 , 

1983 for the Commission's review and approval, a program for 

inspection and/or modification of the recirculation system piping. 

Renewed License No. DPR-22 

Amendment No. 166, 175, 186 
- 5 -

8. Additional Conditions

The Additional Conditions contained in Appendix C, as revised through

Amendment No. 110, are hereby incorporated into this license. NSPM |

shall operate the facility in accordance with the Additional Conditions.

9. Implementation of New and Revised Surveillance Requirements

For surveillance requirements that are new in Amendment No. 146, the

first performance is due at the end of the first surveillance interval, which

begins on the date of implementation of this amendment.

For surveillance requirements that existed prior to Amendment No. 146,

whose intervals of performance are being reduced, the first reduced

surveillance interval begins upon completion of the first surveillance

performed after implementation of this amendment.

For surveillance requirements that existed prior to amendment No. 146

that have modified acceptance criteria, the first performance is due at the

end of the first surveillance interval that began on the date the

surveillance was last performed prior to the implementation of this

amendment.

For surveillance requirements that existed prior to Amendment No. 146,

whose intervals of performance are being extended, the first extended

surveillance interval begins upon completion of the last surveillance

performed prior to implementation of this amendment.

10. Removed Details and Requirements Relocated to Other Controlled 

Documents

License Amendment No. 146 authorizes the relocation of certain

technical specifications to other licensee-controlled documents. 

Implementation of this amendment shall include relocation of these

requirements to the specified documents, as described in (1) Section 5.0

of the NRC staff’s Safety Evaluation, and (2) Table LA, Removed Detail

Changes, and Table R, Relocated Specifications, attached to the NRC

staff’s Safety Evaluation.

11. Mitigation Strategy License Condition

Develop and maintain strategies for addressing large fires and explosions

and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and 

guidance

2. Assessment of mutual aid fire fighting assets

Renewed License No. DPR-22

Revised by letter dated August 23, 2007

Amendment No. 156
- 6 -

3. Designated staging areas for equipment and materials 

4. Command and control 

5. Training of response personnel 

(b) Operations to mitigate fuel damage considering the following: 

1. Protection and use of personnel assets 

2. Communications 

3. Minimizing fire spread 

4. Procedures for implementing integrated fire response 

strategy 

5. Identification of readily-available pre-staged equipment 

6. Training on integrated fire response strategy 

7. Spent fuel pool mitigation measures 

(c) Actions to minimize release to include consideration of: 

1. Water spray scrubbing 

2. Dose to onsite responders 

12. The licensee shall implement and maintain all Actions required by 

Attachment 2 to NRC Order EA-06-137, issued June 20, 2006, except the 

last action that requires incorporation of the strategies into the site 

security plan, contingency plan, emergency plan and/or guard training and 

qualification plan, as appropriate. 

13. The current licensing basis is revised to remove the capability to 

automatically transfer to the 1AR Transformer as a source of power to the 

essential buses on degraded voltage and instead directly transfer to the 

Emergency Diesel Generators. 

) 

14. Leak rate tests required by surveillance requirements (SR) 3.6.1.1.1, 

SR 3.6.1.2.1, SR 3.6.1.3.11, SR 3.6.1.3.12, and SR 3.6.1.3.13 are not 

required to be performed until their next scheduled performance. The 

next scheduled performance is due at the end of the first surveillance 

interval that begins on the date the SR was last performed prior to 

implementation of Amendment No. 176.· 

15. In conjunction with the license amendment to revise paragraph 2.C.1 of 

Renewed Facility Operating License No. DPR-22 to reflect the new 

maximum licensed reactor core power level of 2004 megawatts thermal 

(MWt), the license is also amended to add the following license 

conditions. These license conditions provide for monitoring, evaluating, 

and taking prompt action in response to potential adverse flow effects as a 

result of power uprate operation on plant structures, systems, and 

components (including verifying the continued structural integrity of the 

steam dryer). These license conditions are applicable to the initial power 

ascension from 1775 MWt to 2004 MWt (EPU) conditions: 

' Renewed License No. DPR-22 

Revised by letter dated August 23, 2007 

Amendment No. 156, 169, 176 
-7-

(a) The following requirements are placed on the initial operation of 

the facility above the thermal power level of 1775 MWt for the 

power ascension to 2004 MWt. These conditions are applicable 

until the first time full EPU conditions (2004 MWt) are achieved. If 

the number of active strain gauges is less than two strain gauges 

(180 degrees apart) at any of the eight MSL locations, NSPM will 

stop power ascension and repair/replace thedamaged·strain 

gauges and only then resume power ascension. 

1. NSPM shall monitor the MNGP main steam line (MSL) 

strain gauges during power ascension above 1775 MWt for . 

increasing pressure fluctuations in the steam lines. Upon 

the initial increase of power above 1775 MWt until reaching 

2004 MWt, NSPM shall collect data from the MSL strain 

gauges at nominal 2.5 percent thermal power increments 

and evaluate steam dryer performance based on this data. 

2. During power ascension at each nominal 2.5 percent 

power level above 1775 MWt, the licensee shall compare 

the MSL data to the approved limit curves and determine 

the minimum alternating stress ratio. A summary of the 

results shall be provided for NRC review at approximately 

105 percent and 110 percent of 1775 MWt. 

3. NSPM shall hold the facility at approximately 105 percent 

and 11 0 percent of 1775 MWt to perform the following: 

a. Collect strain data from the MSL strain gauges; 

b. Collect vibration data from the accelerometers in the 

following locations: MSLs (including those in the 

drywell, turbine building and in the steam tunnel), 

Feedwater Lines (FWLs) (including those in the 

drywell and turbine building), Safety Relief Valves 

(SRVs), Main Steam Isolation Valves (MSIVs) in the 

drywell, and Turbine Stop Valves (TSVs); 

c. Evaluate steam dryer performance based on MSL 

strain gauge data; 

d. Evaluate the measured :vibration data collected from 

the vibration monitoring instruments at that power 

level, data projected to EPU conditions, trends, and to 

the acceptance limits; 

e. Provide the steam dryer evaluation and the vibration 

evaluation, including the data collected, to the NRC 

staff by facsimile or electronic transmission to the NRC 

project manager upon completion of the evaluation; 

f. NSPM shall not increase power above each hold point 

until 96 hours after the NRC project manager confirms 

receipt of the evaluations transmission or until verbal 

approval by NRC to increase power is provided, 

whichever comes first. 

Renewed License No. DPR-22 

Amendment No. 176 
- 8 -

4. If any frequency peak from the MSL strain gauge data 

exceeds the Level1 limit curves, NSPM shall return the 

facility to a power level at which the limit curve is not 

exceeded. NSPM shall resolve the discrepancy, evaluate 

and document the continued structural integrity of the 

steam dryer, and provide that documentation by facsimile 

or electronic transmission to the NRC project manager 

prior to further increases in reactor power. If a revised 

stress analysis is required to be performed and new limit 

curves are developed, then NSPM shall not further 

increase power above each hold point until 96 hours after 

the NRC project manager confirms receipt of the 

transmission or until verbal approval by NRC to increase 

power is provided, whichever comes first. 

5. In addition to evaluating the MSL strain gauge data, NSPM 

shall monitor reactor pressure vessel water level 

instrumentation, and MSL piping accelerometers when 

power levels are increasing. If resonance frequencies are 

identified as increasing above nominal levels in proportion 

to strain gauge instrumentation data, NSPM shall stop 

power ascension, evaluate and document the continued 

structural integrity of the steam dryer, and provide that 

documentation to NRC staff by facsimile or electronic 

transmission to the NRC project manager prior to further 

increases in reactor power. 

(b) NSPM shall implement the following actions for the initial power 

ascension from 1775 MWt to 2004 MWtcondition. 

1. In the event that acoustic ·signals (in MSL strain gauge 

signals) are identified that exceed the Level 1 limit curves 

during power ascension above 1775 MWt, NSPM shall 

evaluate dryer loads, and stresses, and re-establish the 

limit curves. In the event that stress analyses are 

re-performed based on new strain gauge data to address 

paragraph 15(a)4. above, the revised load definition, stress 

analysis, and limit cur\ies shall include: 

a. 

b. 

c. 

Application of the ACE-2.0 and ACE 2.0-SPM values 

for percent bias error and for percent uncertainty to all 

the SRV acoustic resonances. 

Use of bump-up factors associated with all the SRV 

acoustic resonances as determined from the scale 

model test results. 

Evaluation of the effects of± 10 percent frequency 

shifts in increments of 2.5 percent. 

Renewed License No. DPR-22 

Amendment No. 176 
- 9-

2. After reaching 2004 MWt, NSPM shall obtain 

measurements from the MSL strain gauges and establish 

the steam dryer flow-induced vibration load fatigue margin 

for the facility, update the dryer stress report, and 

re-establish the limit curves with the updated load 

definition. This data will be provided to the NRC staff as 

described in license condition 15(e). 

(c) NSPM shall prepare the EPU power ascension test procedure to 

include: 

1. The stress limit curves to be applied for evaluating steam 

dryer performance; 

2. Specific hold points and their duration during EPU power 

ascension; 

3. Activities to be accomplished during the hold points; 

4. Plant parameters to be monitored; 

5. Inspections and walkdowns to be conducted for steam, 

feedwater, and condensate systems and components 

during the hold points; 

6. Methods to be used to trend plant parameters; 

7. Acceptance criteria for monitoring and trending plant 

parameters, and conducting the walkdowns ·and 

inspections; 

8. Actions to be taken if acceptance criteria are not satisfied; 

and 

9. Verification of the completion of commitments and planned 

actions specified in its application and all supplements to 

the application in support of the EPU license amendment \ 

request pertaining to the steam dryer prior to power 

increase above 1775 MWt. NSPM shall provide the related 

EPU startup test procedure sections to the NRC by 

facsimile or electronic transmission to the NRC project 

manager prior to increasing power above 1775 MWt. 

(d) The following key attributes of the program for verifying the 

continued structural integrity of the steam dryer shall not be made 

less restrictive without prior NRC approval: 

1. During initial power ascension testing above 1775 MWt, 

each test plateau increment shall be approximately 

5 percent of 1775 MWt. 

Renewed License No. DPR-22 

Amendment No. 176 
-10-

2. Level 1 performance criteria; and 

3. The methodology for establishing the limit curves used for 

the Level 1 and Level 2 performance. 

( e) The results of the power ascension testing to verify the continued 

structural integrity of the steam dryer shall be submitted to the 

NRC staff in a report that includes a final load definition and stress 

report of the steam dryer, including the results of a complete 

re-analysis using the ACE 2.0 and ACE2.0-SPM specific bias and 

uncertainties. The report will be provided within 90 days of the 

completion of EPU power ascension testing. 

(f) During the first two scheduled refueling outages after reaching 

EPU conditions, a visual inspection shall be conducted of all 

accessible, susceptible locations of the steam dryer in accordance 

with the inspection guidelines provided to the NRC. 

(g) The results of the visual inspections of the steam dryer shall be 

reported to the NRC staff within 90 days following startup from the 

respective refueling outage. 

(h) At the end of the second refueling outage, following the 

implementation of the EPU, the licensee shall submit a long-term 

steam dryer inspection plan based on industry operating 

experience along with the baseline inspection results for NRC 

review and approval. 

The license conditions described above shall expire ( 1) upon satisfaction of the 

requirements in Paragraphs 15(f) and 15(g), provided that a visual inspection of 

the steam dryer does not reveal any new unacceptable flaw(s) or unacceptable 

flaw growth that is due to fatigue, and (2) upon satisfaction of the requirements 

specified in Paragraph 15(h). 

16. Adoption of 10 CFR 50.691 "Risk-informed categorization and treatment of 

structures, systems, and components for nuclear power plants" 

NSPM is approved to implement 10 CFR 50.69 using the approaches for 

categorization of Risk Informed Safety Class (RISC}-1, RISC-2, RISC-3, 

and RISC-4 structures, systems, and components (SSCs) using: 

Probabilistic Risk Assessment (PRA) models to evaluate risk associated 

with internal events, including internal flooding and internal fire, with the 

shutdown safety assessment process to assess shutdown risk; the 

Arkansas Nuclear One, Unit 2 (AN0-2) passive categorization method to 

assess passive component risk for Class 2 and Class 3 SSCs and their 

associated supports; and the results of non-PRA evaluations that are 

based on the IPEEE Screening Assessment for External Hazards, i.e., 

seismic margin analysis (SMA) to evaluate seismic risk, and a screening 

of other external hazards (e.g., external flooding and high winds) updated 

using the external hazard screening significance criteria identified in 

Renewed License No. DPR-22 

Amendment No. 203 
- 11 -

ASME/ANS PRA Standard RA-Sa-2009, as endorsed in RG 1.200, 

Revision 2; as specified in MNGP License Amendment No. 203 dated 

August 29, 2019. 

Prior NRC approval, under 10 CFR 50.90, is required for a change to the 

categorization approach specified above (e.g., change from a seismic 

margins approach to a seismic probabilistic risk assessment approach). 

D. NSPM shall immediately notify the NRC of any accident at this facility which 

could result in an unplanned release of quantities of fission products in excess of 

allowable limits for normal operation established by the Commission. 

E. NSPM shall have and maintain financial protection of such type and in such 

amounts as the Commission shall require in accordance with Section 170 of the 

Atomic Energy Act of 1954, as amended, to cover public liability claims. 

F. NSPM shall observe such standards and requirements for the protection of the 

environment as are validly imposed pursuant to authority established under 

Federal and State law and as determined by the Commission to be applicable to 

the facility covered by this renewed facility operating license. 

G. The Updated Safety Analysis Report supplement, as revised, submitted pursuant 

to 10 CFR 54.21(d), shall be included in the next scheduled update to the 

Updated Safety Analysis Report required by 10 CFR 50.71(e)(4) following the 

issuance of this renewed operating license. Until that update is complete, NSPM 

may make changes to the programs and activities described in the supplement 

without prior Commission approval, provided that NSPM evaluates such changes 

pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the 

requirements in that section. 

H. The Updated Safety Analysis Report supplement, as revised, describes certain 

future activities to be completed prior to the period of extended operation. NSPM 

shall complete these activities no later than September 8, 2010, and shall notify 

the NRC in writing when implementation of these activities is complete and can 

be verified by NRC inspection. 

I. All capsules in the reactor vessel that are removed and tested must meet the test 

procedures and reporting requirements of the most recent NRG-approved 

version of the Boiling Water Reactor Vessels and Internals Project (BWRVIP) 

Integrated Surveillance Program (ISP) appropriate for the configuration of the 

specimens in the capsule. All capsules placed in storage must be maintained for 

future insertion. Any changes to storage requirements must be approved by the 

NRC, as required by 10 CFR Part 50, Appendix H. 

J. Upon implementation of Amendment No. 160 adopting TSTF-448, Revision 3, 

the determination of control room envelope (CRE) unfiltered air inleakage as 

required by SR 3. 7.4.4, in accordance with TS 5.5.13.c(i), the assessment of 

CRE habitability as required by Specification 5.5.13.c(ii), and the measurement 

Renewed License No. DPR-22 

Amendment No. 203 
-12-

of CRE pressure as required by Specification 5.5.13.d, shall be considered met. 

Following implementation: 

(a) The first performance of SR 3.7.4.4, in accordance with Specifications 

5.5.1.3.c(i), shall be within the specified frequency of 6 years, plus the 

18-month allowance of SR 3.0.2, as measured from June 4, 2004, the 

date of the most recent successful tracer gas test, as stated in the 

letter (L-MT-04-049, dated November 18, 2004) in response to Generic 

Letter 2003-01, or within the next 18 months if the time period since 

the most recent successful tracer gas test is greater than 6 years. 

(b) The first performance of the periodic assessment of CRE habitability, 

Specifications 5.5.13.c{ii), shall be within 3-years, plus the 9-month 

allowance of SR 3.0.2, as measured from June 4, 2004, the date of the 

most recent successful tracer gas test, as stated in the letter (L-MT-04-

049, dated November 18, 2004) in response to Generic Letter 2003-

01, or within the next 9 months if the time period since the most recent 

successful tracer gas test is greater than 3 years. 

(c) The first performance of the periodic measurement of CRE pressure, 

Specification 5.5.13.d, shall be within 24 months, plus the 184 days 

allowed by SR 3.0.2, as measured from October 17, 2008, the date of 

the most recent pressure measurement test, or within 184 days if not 

performed previously. 

K. This renewed operating license is effective as of the date of issuance and shall 

expire at midnight, September 8, 2030. 

FOR THE NUCLEAR REGULATORY COMMISSION 

/RA/ 

J. E. Dyer, Director 

Office of Nuclear Reactor Regulation 

Attachments: 1. Appendix A - Technical Specifications 

2. Appendix B - (Deleted per Amendment 15, 12/17 /82) 

3. Appendix C - Additional Conditions 

Date of Issuance: November 08, 2006 

Amendment No. 203 
APPENDIX A 

TO 

RENEWED FACILITY OPERATING LICENSE DPR-22 

TECHl~ICAL SPECIFICATIONS 

FOR 

MONTICELLO NUCLEAR GENERATING PLANT 

UNIT 1 

MONTICELLO, MINNESOTA 

NORTHERN STATES POWER COMPANY 

DOCKET NO. 50-263 

October 29,2006 
Definitions

1.1

1.0 USE AND APPLICATION

1.1 Definitions

------------ .---------- .------------- NOTE-----------------

The defined terms of this section appear in capitalized type and are applicable throughout these

Technical Specifications and Bases.

Term Definition

ACTIONS

AVERAGE PLANAR LINEAR

HEAT GENERATION RATE

(APLHGR)

CHANNEL CALIBRATION

CHANNEL CHECK

CHANNEL FUNCTIONAL

TEST

ACTIONS shall be that part of a Specification that prescribes

Required Actions to be taken under designated Conditions

within specified Completion Times.

The APLHGR shall be applicable to a specific planar height

and is equal to the sum of the LHGRs for all the fuel rods in

the specified bundle at the specified height divided by the

number of fuel rods in the fuel bundle at the height.

A CHANNEL CALIBRATION shall be the adjustment, as

necessary, of the channel output such that it responds within

the necessary range and accuracy to known values of the

parameter that the channel monitors. The CHANNEL

CALIBRATION shall encompass all devices in the channel

required for channel OPERABILITY and the CHANNEL

FUNCTIONAL TEST. Calibration of instrument channels with

resistance temperature detector (RTD) or thermocouple

sensors may consist of an inplace qualitative assessment of

sensor behavior and normal calibration of the remaining

adjustable devices-in the channel. The CHANNELCALIBRATION may be performed by means of any series of

sequential, overlapping, or total channel steps.

A CHANNEL CHECK shall be the qualitative assessment, by

observation, of channel behavior during operation. This

determination shall include, where possible, comparison of the

channel indication and status to other indications or status

derived from independent instrument channels measuring the

same parameter.

A CHANNEL FUNCTIONAL TEST shall be the injection of a

simulated or actual signal into the channel as close to the

sensor as practicable to verify OPERABILITY of all devices in

the channel required for channel OPERABILITY. The

CHANNEL FUNCTIONAL TEST may be performed by means

of any series of sequential, overlapping, or total channel steps.

Monticello 1.1-1 Amendment No. 146

Monticello 1.1-1 Amendment No. 146
Definitions

1.1

Monticello 1.1-2 Amendment No. 205

1.1 Definitions

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, 

sources, or reactivity control components, within the reactor 

vessel with the vessel head removed and fuel in the vessel. 

The following exceptions are not considered to be CORE 

ALTERATIONS:

a. Movement of source range monitors, local power range 

monitors, intermediate range monitors, traversing incore 

probes, or special movable detectors (including 

undervessel replacement); and

b. Control rod movement, provided there are no fuel 

assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude 

completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that provides cycle

REPORT (COLR) specific parameter limits for the current reload cycle. These 

cycle specific limits shall be determined for each reload cycle 

in accordance with Specification 5.6.3. Plant operation within 

these limits is addressed in individual Specifications.

DOSE EQUIVALENT I-131 DOSE EQUIVALENT I-131 shall be that concentration of I-131 

(microcuries/gram) that alone would produce the same dose 

as the quantity and isotopic mixture of I-131, I-132, I-133, 

I-134, and I-135 actually present. The dose conversion factors

used for this calculation shall be those listed in Federal

Guidance Report (FGR)-11, "Limiting Values of Radionuclide

Intake and Air Concentration Factors for Inhalation,

Submersion and Ingestion," September 1988, and FGR-12,

"External Exposure to Radionuclides in Air, Water and Soil,"

September 1993. 

DRAIN TIME The DRAIN TIME is the time it would take for the water 

inventory in and above the Reactor Pressure Vessel (RPV) to 

drain to the top of the active fuel (TAF) seated in the RPV 

assuming:

a) The water inventory above the TAF is divided by the 

limiting drain rate;

b) The limiting drain rate is the larger of the drain rate 

through a single penetration flow path with the highest 

flow rate, or the sum of the drain rates through multiple 

penetration flow paths susceptible to a common mode 
Definitions

1.1

Monticello 1.1-3 Amendment No. 205

1.1 Definitions

DRAIN TIME (continued) failure, for all penetration flow paths below the TAF 

except:

 1. Penetration flow paths connected to an intact 

closed system, or isolated by manual or automatic 

valves that are closed and administratively 

controlled in the closed position, blank flanges, or 

other devices that prevent flow of reactor coolant 

through the penetration flow paths; 

2. Penetration flow paths capable of being isolated by 

valves that will close automatically without offsite 

power prior to the RPV water level being equal to

the TAF when actuated by RPV water level 

isolation instrumentation; or

3. Penetration flow paths with isolation devices that 

can be closed prior to the RPV water level being 

equal to the TAF by a dedicated operator trained in 

the task, who in continuous communication with the 

control room, is stationed at the controls, and is 

capable of closing the penetration flow path 

isolation device without offsite power.

c) The penetration flow paths required to be evaluated per 

paragraph b) are assumed to open instantaneously and 

are not subsequently isolated, and no water is assumed 

to be subsequently added to the RPV water inventory; 

d) No additional draining events occur; and

e) Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated 

value.

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee 

PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f)

.
1.1 Definitions 

LEAKAGE 

LINEAR HEAT GENERATION 

RATE (LHGR) 

LOGIC SYSTEM 

FUNCTIONAL TEST 

MINIMUM CRITICAL POWER 

RA TIO (MCPR) 

Monticello 

LEAKAGE shall be: 

a. Identified LEAKAGE 

Definitions 

1.1 

1. LEAKAGE into the drywell, such as that from pump 

seals or valve packing that is captured and 

conducted to a sump or collecting tank; or 

2. LEAKAGE into the drywell atmosphere from 

sources that are both specifically located and 

known either not to interfere with the operation of 

leakage detection systems or not to be pressure 

boundary LEAKAGE; 

b. Unidentified LEAKAGE 

All LEAKAGE into the drywell that is not identified 

LEAKAGE; 

C. Total LEAKAGE 

Sum of the identified and unidentified LEAKAGE; and 

d. Pressure Boundary LEAKAGE 

LEAKAGE through a nonisolable fault in a Reactor 

Coolant System (RCS) component body, pipe wall, or 

vessel wall. 

The LHGR shall be the heat generation rate per unit length of 

fuel rod. It is the integral of the heat flux over the heat transfer 

area associated with the unit length. 

A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all 

logic components required for OPERABILITY of a logic circuit, 

from as close to the sensor as practicable up to, but not 

including, the actuated device, to verify OPERABILITY. The 

LOGIC SYSTEM FUNCTIONAL TEST may be performed by 

means of any series of sequential, overlapping, or total system 

steps so that the entire logic system is tested. 

The MCPR shall be the smallest critical power ratio (CPR) that 

exists in the core for each class of fuel. The CPR is that 

power in the assembly that is calculated by application of the 

appropriate correlation(s) to cause some point in the assembly 

to experience boiling transition, divided by the actual assembly 

operating power. 

1.1-4 Amendment No. 146,172, 175, 175, 198 I 
1.1 Definitions 

MODE 

OPERABLE - OPERABILITY 

PRESSURE AND 

TEMPERATURE LIMITS 

REPORT (PTLR) 

RATED THERMAL POWER 

(RTP) 

REACTOR PROTECTION 

SYSTEM(RPS)RESPONSE 

TIME 

SHUTDOWN MARGIN (SOM) 

Monticello 

Definitions 

1.1 

A MODE shall correspond to any one inclusive combination of 

mode switch position, average reactor coolant temperature, 

and reactor vessel head closure bolt tensioning specified in 

Table 1.1-1 with fuel in the reactor vessel. 

A system, subsystem, division, component, or device shall be 

OPERABLE or have OPERABILITY when it is capable of 

performing its specified safety function(s) and when all 

necessary attendant instrumentation, controls, normal or 

emergency electrical power, cooling and seal water, 

lubrication, and other auxiliary equipment that are required for 

the system, subsystem, division, component, or device to 

perform its specified safety function(s) are also capable of 

performing their related support function(s). 

The PTLR is the unit specific document that provides the 

reactor vessel pressure and temperature limits, including 

heatup and cooldown rates, for the current reactor vessel 

fluence period. These pressure and temperature limits shall 

be determined for each fluence period in accordance with 

Specification 5.6.5. 

RTP shall be a total reactor core heat transfer rate to the 

reactor coolant of 2004 MWt. 

The RPS RESPONSE TIME shall be that time interval from 

initiation of any RPS channel trip to the de-energization of the 

scram pilot valve solenoids. The response time may be 

measured by means of any series of sequential, overlapping, 

or total steps so that the entire response time is measured. 

SOM shall be the amount of reactivity by which the reactor is 

subcritical or would be subcritical throughout the operating 

cycle assuming that: 

a. The reactor is xenon free; 

b. The moderator temperature is ~ 68°F corresponding to 

the most reactive state; and 

c. All control rods are fully inserted except for the single 

control rod of highest reactivity worth, which is assumed 

to be fully withdrawn. With control rods not capable of 

being fully inserted, the reactivity worth of these control 

rods must be accounted for in the determination of SOM. 

1.1-5 Amendment No. 1<16, 175, 198 I 
1.1 Definitions 

STAGGERED TEST BASIS 

THERMAL POWER 

TURBINE BYPASS SYSTEM 

RESPONSE TIME 

Monticello 

Definitions 

1.1 

A STAGGERED TEST BASIS shall consist of the testing of 

one of the systems, subsystems, channels, or other 

designated components during the interval specified by the 

Surveillance Frequency, so that all systems, subsystems, 

channels, or other designated components are tested during 

n Surveillance Frequency intervals, where n is the total 

number of systems, subsystems, channels, or other 

designated components in the associated function. 

THERMAL POWER shall be the total reactor core heat 

transfer rate to the reactor coolant. 

The TURBINE BYPASS SYSTEM RESPONSE TIME shall be 

that time interval from when the main turbine trip solenoid is 

activated until 80% of the turbine bypass capacity is 

established. The response time may be measured by means 

of any series of sequential, overlapping, or total steps so that 

the entire response time is measured. 

1.1-6 Amendment No. 446, 198 I 
MODE TITLE 

1 Power Operation 

2 Startup 

3 Hot Shutdown<aJ 

4 Cold Shutdown<aJ 

5 Refueling(b) 

Table 1.1-1 (page 1 of 1) 

MODES 

REACTOR MODE 

SWITCH POSITION 

Run 

Refue1<aJ or Startup/Hot Standby 

Shutdown 

Shutdown 

Shutdown or Refuel 

(a) All reactor vessel head closure bolts fully tensioned. 

Definitions 

1.1 

AVERAGE REACTOR 

COOLANT 

TEMPERATURE 

(OF) 

NA 

NA 

> 212 

::;; 212 

NA 

(b) One or more reactor vessel head closure bolts less than fully tensioned. 

Monticello 1.1-7 Amendment No. 198 I 
Logical Connectors

1.2

1.0 USE AND APPLICATION

1.2 Logical Connectors

PURPOSE The purpose of this section is to explain the meaning of logical

connectors.

Logical connectors are used in Technical Specifications (TS) to

discriminate between, and yet connect, discrete Conditions, Required

Actions, Completion Times, Surveillances, and Frequencies. The only

logical connectors that appear in TS are AND and OR. The physical

arrangement of these connectors constitutes logical conventions with

specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These

levels are identified by the placement (or nesting) of the logical

connectors and by the number assigned to each Required Action. The

first level of logic is identified by the first digit of the number assigned to a

Required Action and the placement of the logical connector in the first

level of nesting (i.e., left justified with the number of the Required Action).

The successive levels of logic are identified by additional digits of the

Required Action number and by successive indentions of the logical

connectors.

When logical connectors are used to state a Condition, Completion Time,

Surveillance, or Frequency, only the first level of logic is used, and the

logical connector is left justified with the statement of the Condition,

Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical, connectors.

EXAMPLE 1.2-1

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. LCO not met. A.1 Verify....

AND

A.2 Restore...

In this example the logical connector AND is used to indicate that when in

Condition A, both Required Actions A.1 and A.2 must be completed.

Monticello 1.21-1 Amendment No. 146
Logical Connectors

1.2

1.2 Logical Connectors

EXAMPLES (continued)

EXAMPLE 1.2-2

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. LCO not met. A.1 Trip ...

OR

A.2.1 Verify...

AND

A.2.2.1 Reduce...

OR

A.2.2.2 Perform...

OR

A.3 Align...

This example represents a more complicated use of logical connectors.

Required Actions A.1, A.2, and A.3 are alternative choices, only one of

which must be performed as indicated by the use of the logical connector

OR and the left justified placement. Any one of these three Actions may

be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be

performed as indicated by the logical connector AND. Required

Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented

position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are

alternative choices, only one of which must be performed.

Monticello 1.2-2 Amendment No. 146
Completion Times 

1.3 

Monticello 1.3-1 Amendment No. 204 

1.0 USE AND APPLICATION 

1.3 Completion Times 

PURPOSE The purpose of this section is to establish the Completion Time 

convention and to provide guidance for its use. 

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements 

for ensuring safe operation of the unit. The ACTIONS associated with an 

LCO state Conditions that typically describe the ways in which the 

requirements of the LCO can fail to be met. Specified with each stated 

Condition are Required Action(s) and Completion Time(s). 

DESCRIPTION The Completion Time is the amount of time allowed for completing a 

Required Action. It is referenced to the discovery of a situation 

(e.g., inoperable equipment or variable not within limits) that requires 

entering an ACTIONS Condition unless otherwise specified, providing the 

unit is in a MODE or specified condition stated in the Applicability of the 

LCO. 

 

 Unless otherwise specified, the Completion Time begins when a senior 

licensed operator on the operating shift crew with responsibility for plant 

operations makes the determination that an LCO is not met and an 

ACTIONS Condition is entered. The "otherwise specified" exceptions are 

varied, such as a Required Action Note or Surveillance Requirement Note 

that provides an alternative time to perform specific tasks, such as 

testing, without starting the Completion Time. While utilizing the Note, 

should a Condition be applicable for any reason not addressed by the 

Note, the Completion Time begins. Should the time allowance in the Note 

be exceeded, the Completion Time begins at that point. The exceptions 

may also be incorporated into the Completion Time. For example, LCO 

3.8.1, "AC Sources - Operating," Required Action B.2, requires declaring 

required feature(s) supported by an inoperable diesel generator, 

inoperable when the redundant required feature(s) are inoperable. The 

Completion Time states, "4 hours from discovery of Condition B 

concurrent with inoperability of redundant required feature(s)." In this 

case the Completion Time does not begin until the conditions in the 

Completion Time are satisfied. 

 Required Actions must be completed prior to the expiration of the 

specified Completion Time. An ACTIONS Condition remains in effect and 

the Required Actions apply until the Condition no longer exists or the unit 

is not within the LCO Applicability. 

 If situations are discovered that require entry into more than one 

Condition at a time within a single LCO (multiple Conditions), the 

Required Actions for each Condition must be performed within the 

associated Completion Time. When in multiple Conditions, separate 

Completion Times are tracked for each Condition starting from the 

 
Completion Times 

1.3 

Monticello 1.3-2 Amendment No. 204 

1.3 Completion Times 

DESCRIPTION (continued) 

 discovery of the situation that required entry into the Condition, unless 

otherwise specified. 

 Once a Condition has been entered, subsequent divisions, subsystems, 

components, or variables expressed in the Condition, discovered to be 

inoperable or not within limits, will not result in separate entry into the 

Condition, unless specifically stated. The Required Actions of the 

Condition continue to apply to each additional failure, with Completion 

Times based on initial entry into the Condition, unless otherwise 

specified. 

 However, when a subsequent division, subsystem, component, or 

variable expressed in the Condition is discovered to be inoperable or not 

within limits, the Completion Time(s) may be extended. To apply this 

Completion Time extension, two criteria must first be met. The 

subsequent inoperability: 

 a. Must exist concurrent with the first inoperability; and 

 b. Must remain inoperable or not within limits after the first inoperability 

is resolved. 

 The total Completion Time allowed for completing a Required Action to 

address the subsequent inoperability shall be limited to the more 

restrictive of either: 

 a. The stated Completion Time, as measured from the initial entry into 

the Condition, plus an additional 24 hours; or 

 b. The stated Completion Time as measured from discovery of the 

subsequent inoperability. 

 The above Completion Time extensions do not apply to those 

Specifications that have exceptions that allow completely separate reentry into the Condition (for each division, subsystem, component, or 

variable expressed in the Condition) and separate tracking of Completion 

Times based on this re-entry. These exceptions are stated in individual 

Specifications. 

 The above Completion Time extension does not apply to a Completion 

Time with a modified "time zero." This modified "time zero" may be 

expressed as a repetitive time (i.e., "once per 8 hours," where the 

Completion Time is referenced from a previous completion of the 

Required Action versus the time of Condition entry) or as a time modified 

by the phrase "from discovery . . ." 

 
Completion Times 

1.3 

Monticello 1.3-3 Amendment No. 204 

1.3 Completion Times 

EXAMPLES The following examples illustrate the use of Completion Times with 

different types of Conditions and changing Conditions. 

 EXAMPLE 1.3-1 

 ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

B. Required 

Action and 

associated 

Completion 

Time not met. 

B.1 Be in MODE 3. 

AND 

B.2 Be in MODE 4. 

12 hours 

36 hours 

 Condition B has two Required Actions. Each Required Action has its own 

separate Completion Time. Each Completion Time is referenced to the 

time that Condition B is entered. 

 The Required Actions of Condition B are to be in MODE 3 within 12 hours 

AND in MODE 4 within 36 hours. A total of 12 hours is allowed for 

reaching MODE 3 and a total of 36 hours (not 48 hours) is allowed for 

reaching MODE 4 from the time that Condition B was entered. If MODE 3 

is reached within 6 hours, the time allowed for reaching MODE 4 is the 

next 30 hours because the total time allowed for reaching MODE 4 is 

36 hours. 

 If Condition B is entered while in MODE 3, the time allowed for reaching 

MODE 4 is the next 36 hours. 
Completion Times

1.3

1.3 Completion Times

EXAMPLES (continued)

EXAMPLE 1.3-2

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One pump A.1 Restore pump to 7 days

inoperable. OPERABLE status.

B. Required B-1 Be in MODE 3. 12 hours

Action and

associated AND

Completion

Time not met. B.2 Be in MODE 4. 36 hours

When a pump is declared inoperable, Condition A is entered. If the pump

is not restored, to OPERABLE status within 7 days, Condition B is also

entered and the Completion Time clocks for Required Actions B.1

and B.2 start. If the inoperable pump is restored to OPERABLE status

after Condition B is entered, Conditions A and B are exited, and therefore,

the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still

inoperable, Condition A is not re-entered for the second pump.

LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for

more than one inoperable pump. The Completion Time clock for

Condition A does not stop after LCO 3.0.3 is entered, but continues to be

tracked from the time Condition A was initially entered.

While in LCO 3.0.3, if one of the inoperable pumps is restored to

OPERABLE status and the Completion Time for Condition A has not

expired, LCO 3.0.3 may be exited and operation continued in accordance

with Condition A.

While in LCO 3.0.3, if one of the inoperable pumps is restored to

OPERABLE status and the Completion Time for Condition A has expired,

LCO 3.0.3 may be exited and operation continued in accordance with

Condition B. The Completion Time for Condition B is tracked from the

time the Condition A Completion Time expired.

Monticello 1.3-4 Amendment No. 146
Completion Times

1.3

1,3 Completion Times

EXAMPLES (continued)

On restoring one of the pumps to OPERABLE status, &e Condition A

Completion Time is not reset, but continues from the time the first pump

was declared inoperable. This Completion Time may be extended if the

pump restored to OPERABLE status was the first inoperable pump. A

24 hour extension to the stated 7 days is allowed, provided this does not

result in the second pump being inoperable for > 7 days.

EXAMPLE 1.3-3

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One A.1 Restore Function X 7 days

Function X subsystem to

subsystem OPERABLE status.

inoperable.

B. One B.1 Restore Function Y 72 hours

Function Y subsystem to

subsystem OPERABLE status.

inoperable.

C. One C.A Restore Function X 72 hours

Function X subsystem to

subsystem OPERABLE status.

inoperable.

OR

AND

C.2 Restore Function Y 72 hours

One subsystem to

Function Y OPERABLE status.

subsystem

inoperable.

Monticello 1.3-5 Amendment No. 146

Monticello 1.3-5 A

Amendrnent No. 146
Completion Times

1.3

1.3 Completion Times

EXAMPLES (continued)

When one Function X subsystem and one Function Y subsystem are

inoperable, Condition A and Condition B are concurrently applicable. The

Completion Times for Condition A and Condition B are tracked separately

for each subsystem starting from the time each subsystem was declared

inoperable and the Condition was entered. A separate Completion Time

is established for Condition C and tracked from the time the second

subsystem was declared inoperable (i.e., the time the situation described

in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time,

Conditions B and C are exited. If the Completion Time for Required

Action A.1 has not expired, operation may continue in accordance with

Condition A. The remaining Completion Time in Condition A is measured

from the time the affected subsystem was declared inoperable (i.e., initial

entry into Condition A).

It is possible to alternate between Conditions A, B, and C in such a

manner that operation could continue indefinitely without ever restoring

systems to meet the LCO. However, doing so would be inconsistent with

the basis of the Completion Times. Therefore, there shall be

administrative controls to limit the maximum time allowed for any

combination of Conditions that result in a single contiguous occurrence of

failing to meet the LCO. These administrative controls shall ensure that

the Completion Times for those Conditions are not inappropriately

extended.

Monticello 1.3-6 Amendment No. 146
Completion Times

1.3

1.3 Completion Times

EXAMPLES (continued)

EXAMPLE 1.3-4

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more A.1 Restore valve(s) to 4 hours

valves OPERABLE status..

inoperable.

B. Required B.1 Be in MODE 3. 12 hours

Action and

associated AND

Completion

Time not met. B.2 Be in MODE 4. 36 hours

A single Completion Time is used for any number of valves inoperable at

the same time. The Completion Time associated with Condition A is

based on the initial entry into Condition A and is not tracked on a per

valve basis. Declaring subsequent valves inoperable, while Condition A

is still in effect, does not trigger the tracking of separate Completion

Times.

Once one of the valves has been restored to OPERABLE status, the

Condition A Completion Time is not reset, but continues from the time the

first valve was declared inoperable. The Completion Time may be

extended if the valve restored to OPERABLE status was the first

inoperable valve. The Condition A Completion Time may be extended for

up to 4 hours provided this does not result in any subsequent valve being

inoperable for > 4 hours.

If the Completion Time of 4 hours (plus the extension) expires while one

or more valves are stillinoperable, Condition B is entered.

Monticello 1.3-7 Amendment No. 146

Monticello 1.3-7 Amendment No. 146
Completion Times

1.3

1.3 Completion Times

EXAMPLES (continued)

EXAMPLE 1.3-5

ACTIONS

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more A.1 Restore valve to 4 hours

valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 12 hours

Action and

associated AND

Completion

Time not met. B.2 Be in MODE 4. 36 hours

The Note above the ACTIONS Table is a method of modifying how the

Completion Time is tracked. If this method of modifying how the

Completion Time is tracked was applicable only to a specific Condition,

the Note would appear iri that Condition rather than at the top of the

ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable

valve, and Completion Times tracked on a per valve basis. When a valve

is declared inoperable, Condition A is entered and its Completion Time

starts. If subsequent valves are declared inoperable, Condition A is

entered for each valve and separate Completion Times start and are

tracked for each valve.

If the Completion Time associated with a valve in Condition A expires,

Condition B is entered for that valve. If the Completion Times associated

with subsequent valves in Condition A expire, Condition B is entered

separately for each valve and separate Completion Times start and are

tracked for each valve. If a valve that caused entry into Condition B is

restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and

tracking of separate Completion Times, Completion Time extensions do

not apply.

Monticello 1.31-8 Amendment No. 146
Completion Times

1.3

1.3 Completion Times

EXAMPLES (continued)

EXAMPLE 1.3-6

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One channel A.1 Perform SR 3.x.x.x. Once per 8 hours

inoperable.

OR

A.2 Reduce THERMAL 8 hours

POWER to

•50% RTP.

B. Required B.1 Be in MODE 3. 12 hours

Action and

associated

Completion

Time not met.

Entry into Condition A offers a choice between Required Action A.1

or A.2. Required Action A.1 has a "once per" Completion Time, which

qualifies for the 25% extension, per SR 3.0.2, to each performance after

the initial performance. The initial 8 hour interval of Required Action A.1

begins when Condition A is entered and the initial performance of

Required Action A.1 must be complete within the first 8 hour interval. If

Required Action A.1 is followed and the Required Action is not met within

the Completion Time (plus the extension allowed by SR 3.0.2),

Condition.B is entered. If Required Action A.2 is followed and the

Completion Time of 8 hours is not met, Condition B is entered.

If after entry into Condition B, Required Action A.1 or A.2 is met,

Condition B is exited and operation may then continue in Condition A.

Monticello 1.3-9 Amendment No. 146

Monticello 1.3-9 Amendment No. 146
Completion Times

1.3

1.3 Completion Times

EXAMPLES (continued)

EXAMPLE 1.3-7

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One A.1 Verify affected 1 hour

subsystem subsystem isolated.

inoperable. AND

Once per 8 hours

thereafter

AND

A.2 Restore subsystem 72 hours

to OPERABLE

status.

B. Required B.1 Be in MODE 3. 12 hours

Action and

associated AND

Completion

Time not met. B.2 Be in MODE 4. 36 hours

Required Action A.1 has two Completion Times. The 1 hour Completion

Time begins at the time the Condition is entered and each "Once per

8 hours thereafter" interval begins upon performance of Required

Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either

the initial 1 hour or any subsequent 8 hour interval from the previous

performance (plus the extension allowed by SR 3.0.2), Condition B is

entered. The Completion Time clock for Condition A does not stop after

Condition B is entered, but continues from the time Condition A was

initially entered. If Required Action A. I is met after Condition B is

entered, Condition B is exited and operation may continue in accordance

with Condition A, provided the Completion Time for Required Action A.2

has not expired.

Monticello 1.13-10 Amendment No. 146
Completion Times 

1.3 

Monticello 1.3-11 Amendment No. 206 

1.3 Completion Times 

EXAMPLES (continued) 

EXAMPLE 1.3-8 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One

subsystem

inoperable.

A.1 Restore subsystem

to OPERABLE

status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Required

Action and

associated

Completion

Time not met.

B.1 Be in MODE 3. 

AND 

B.2 Be in MODE 5.

6 hours 

36 hours 

When a subsystem is declared inoperable, Condition A is entered. The 

7 day Completion Time may be applied as discussed in Example 1.3-2. 

However, the licensee may elect to apply the Risk Informed Completion 

Time Program which permits calculation of a Risk Informed Completion 

Time (RICT) that may be used to complete the Required Action beyond 

the 7 day Completion Time. The RICT cannot exceed 30 days. After the 

7 day Completion Time has expired, the subsystem must be restored to 

OPERABLE status within the RICT or Condition B must also be entered. 

The Risk Informed Completion Time Program requires recalculation of the 

RICT to reflect changing plant conditions. For planned changes, the 

revised RICT must be determined prior to implementation of the change 

in configuration. For emergent conditions, the revised RICT must be 

determined within the time limits of the Required Action Completion Time 

(i.e., not the RICT) or 12 hours after the plant configuration change, 

whichever is less. 

If the 7 day Completion Time clock of Condition A has expired and 

subsequent changes in plant condition result in exiting the applicability of 

the Risk Informed Completion Time Program without restoring the 

inoperable subsystem to OPERABLE status, Condition B is also entered 

and the Completion Time clocks for Required Actions B.1 and B.2 start. 
Completion Times 

1.3 

Monticello 1.3-12 Amendment No. 206 

1.3 Completion Times 

EXAMPLES (continued) 

 If the RICT expires or is recalculated to be less than the elapsed time 

since the Condition was entered and the inoperable subsystem has not 

been restored to OPERABLE status, Condition B is also entered and the 

Completion Time clocks for Required Actions B.1 and B.2 start. If the 

inoperable subsystems are restored to OPERABLE status after Condition 

B is entered, Condition A is exited, and therefore, the Required Actions of 

Condition B may be terminated. 

IMMEDIATE When "Immediately" is used as a Completion Time, the Required Action 

COMPLETION TIME should be pursued without delay and in a controlled manner. 

 
Frequency

1.4

1.0 USE AND APPLICATION

1.4 Frequency

PURPOSE The purpose of this section is to define the proper use and application of

Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which

the Surveillance must be met in order to meet the associated LCO. An

understanding of the correct application of the specified Frequency is

necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each

of the Specifications of Section 3.0, "Surveillance Requirement (SR)

Applicability." The "specified Frequency" consists of the requirements of

the Frequency column of each SR as well as certain Notes in the

Surveillance column that modify performance requirements.

Sometimes special situations dictate when the requirements of a

Surveillance are to be met. They are "otherwise stated" conditions

allowed by SR 3.0.1. They may be stated as clarifying Notes in the

Surveillance, as part of the Surveillance, or both.

Situations where a Surveillance could be required (i.e., its Frequency

could expire), but where it is not possible or not desired that it be

performed until sometime after the associated LCO is within its

Applicability, represent potential SR 3.0.4 conflicts. To avoid these

conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such

that it is only "required" when it can be and should be performed. With an

SR satisfied, SR 3.0.4 imposes no restriction.

The use of "met" or "performed" in these instances conveys specific

meanings. A Surveillance is "met" only when the acceptance criteria are

satisfied. Known failure of the requirements of a Surveillance, even

without a Surveillance specifically being "performed," constitutes a

Surveillance not "met." "Performance" refers only to the requirement to

specifically determine the ability to meet the acceptance criteria.

Some Surveillances contain Notes that modify the Frequency of

performance or the conditions during which the acceptance criteria must

be satisfied. For these Surveillances, the MODE-entry restrictions of

SR 3.0.4 may not apply. Such a Surveillance is not required to be

performed prior to entering a MODE or other specified condition in the

Applicability of the associated LCO if any of the following three conditions

are satisfied:

Monticello 1.4-1 Amendment No. 146

Monticello 1.4-1 Amendment No. 146
Frequency

1.4

1.4 Frequency

DESCRIPTION (continued)

a. The Surveillance is not required to be met in the MODE or other

specified condition to be entered;

b. The Surveillance is required to be met in the MODE or other

specified condition to be entered, but has been performed within the

specified Frequency (i.e., it is current) and is known not to befailed;

or

c. The Surveillance is required to be met, but not performed, in the

MODE or other specified condition to be entered, and is known not

to be failed.

Examples 1.4-3, 1.4-4, 1.4-5, and 1.4-6 discuss these special situations.

EXAMPLES The following examples illustrate the various ways that Frequencies are

specified. In these examples, the Applicability of the LCO (LCO not

shown) is MODES 1,-2, and 3.

EXAMPLE 1.4-1

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

Perform CHANNEL CHECK. 12 hours

Example 1.4-1 contains the type of SR most often encountered in the

Technical Specifications (TS). The Frequency specifies an interval

(12 hours) during which the associated Surveillance must be performed at

least one time. Performance of the Surveillance initiates the subsequent

interval. Although the Frequency is stated as 12 hours, an extension of

the time interval to 1.25 times the interval specified in the Frequency is

allowed by SR 3.0.2 for operational flexibility. The measurement of this

interval continues at all times, even when the SR is not required to be met

per SR 3.0.1 (such as when the equipment is inoperable, a variable is

outside specified limits, or the unit is outside the Applicability of the LCO).

If the interval specified by SR 3.0.2 is exceeded while the unit is in a

MODE or other specified condition in the Applicability of the LCO, and the

performance of the Surveillance is not otherwise modified (refer to

Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable.

Monticello 1.4-2 Amendment No. 146
Frequency

1.4

1.4 Frequency

EXAMPLES (continued)

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in

a MODE or other specified condition in the Applicability of the LCO for

which performance of the SR is required, then SR 3.0.4 becomes

applicable. The Surveillance must be performed within the Frequency

requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the

MODE or other specified condition or the LCO is considered not met (in

accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.

EXAMPLE 1.4-2

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

Verify flow is within limits. Once within

12 hours after

_ 25% RTP

AND

24 hours thereafter

Example 1.4-2 has two Frequencies. The first is a one time performance

Frequency, and the second is of the type shown in Example 1.4-1. The

logical connector "AND" indicates that both Frequency requirements must

be met. Each time reactor power is increased from a power level

< 25% RTP to Ž_25% RTP, the Surveillance must be performed within

12 hours.

The use of "once" indicates a single performance will satisfy the specified

Frequency (assuming no other Frequencies are connected by "AND").

This type of Frequency does not qualify for the 25% extension allowed by

SR 3.0.2. "Thereafter" indicates future performances must be established

per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to

< 25% RTP, the measurement of both intervals stops. New intervals start

upon reactor power reaching 25% RTP.

Monticello 1.4-3 Amendment No. 146

Monticello 1.4-3 Amendment No. 146
Frequency 

1.4 

1.4 Frequency 

EXAMPLES (continued) 

EXAMPLE 1.4-3 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

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

Not required to be performed until 12 hours after 

225% RTP. 

Perform channel adjustment. 7 days 

The interval continues, whether or not the unit operation is < 25% RTP 

between performances. 

As the Note modifies the required performance of the Surveillance, it is 

construed to be part of the "specified Frequency." Should the 7 day 

interval be exceeded while operation is < 25% RTP, this Note allows 

12 hours after power reaches 2 25% RTP to perform the Surveillance. 

The Surveillance is still considered to be within the "specified Frequency." 

Therefore, if the Surveillance was not performed within the 7 day interval 

(plus the extension allowed by SR 3.0.2), but operation was < 25% RTP, 

it would not constitute a failure of the SR or failure to meet the LCO. 

Also, no violation of SR 3.0.4 occurs when changing MODES, even with 

the 7 day Frequency not met, provided operation does not exceed 

12 hours (pius the extension allowed by SR 3.0.2) with power 

225% RTP. 

Once the unit reaches 25% RTP, 12 hours would be allowed for 

completing the Surveillance. If the Surveillance was not performed within 

this 12 hour interval (pius the extension allowed by SR 3.0.2), there would 

then be a failure to perform a Surveillance within the specified Frequency. 

and the provisions of SR 3.0.3 would apply. 

Monticello 1.4-4 Amendment No.~, 158 
Frequency1.4

1.4 Frequency

EXAMPLES (continued)

EXAMPLE 1.4-4

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

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

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours

Example 1.4-4 specifies that the requirements of this Surveillance do not

have to be met until the unit is in MODE 1. The interval measurement for

the Frequency of this Surveillance continues at all times, as described in

Example 1.4-1. However, the Note constitutes an "otherwise stated"

exception to the Applicability of this Surveillance. Therefore, if the

Surveillance was not performed within the 24 hour interval (plus the

extension allowed by SR 3.0.2), but the unit was not in MODE 1, there

would be no failure of the SR nor failure to meet the LCO. Therefore, no

violation of SR 3.0.4 occurs when changing MODES, even with the

24 hour Frequency exceeded, provided the MODE change was not made

into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour

Frequency was not met), SR 3.0.4 would require satisfying the SR.

Monticello 1.4-5 Amendment No. 146

Monticello 1.4-5 Amendment No. 146
Frequency

1.4

1.4 Frequency

EXAMPLES (continued)

EXAMPLE 1.4-5

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

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

Only required to be performed in MODE 1.

Perform complete cycle of the valve. 7 days

The interval continues, whether or not the unit operation is in MOPE 1, 2,

or 3 (the assumed Applicability of the associated LCO) between

performances.

As the Note modifies the required performance of the Surveillance, the

Note is construed to be part of the "specified Frequency." Should the

7 day interval be exceeded while operation is not in MODE 1, this Note

allows entry into and operation in MODES 2 and 3 to perform the

Surveillance. The Surveillance is still considered to be performed within

the "specified Frequency" if completed prior to entering MODE 1.

Therefore, if the Surveillance was not performed within the 7 day (plus the

extension allowed by SR 3.0.2) interval, but operation was not in

MODE 1, it would not constitute a failure of the SR or failure to meet the

LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even

with the 7 day Frequency not met, provided operation does not result in

entry into MODE 1.

Once the unit reaches MODE 1, the requirement for the Surveillance to

be performed within its specified Frequency applies and would require

that the Surveillance had been performed. If the Surveillance was not

performed prior to entering MODE 1, there would then be a failure to

perform a Surveillance within the specified Frequency, and the provisions

of SR 3.0.3 would apply.

Monticello 1.4-6 Amendment No. 146

Monticello 1.4-6 Amendment No. 146
Frequency

1.4

1.4 Frequency

EXAMPLES (continued)

EXAMPLE 1.4-6

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

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

Not required to be met in MODE 3.

Verify parameter is within limits. 24 hours

Example 1.4-6 specifies that the requirements of this Surveillance do not

have to be met while the unit is in MODE 3 (the assumed Applicability of

the associated LCO is MODES 1, 2, and 3). The interval measurement

for the Frequency of this Surveillance continues at all times, as described

in Example 1.4-1. However, the Note constitutes an "otherwise stated"

exception to the Applicability of this Surveillance. Therefore, if the

Surveillance was not performed within the 24 hour interval (plus the

extension allowed by SR 3.0.2), and the unit was in MODE 3, there would

be no failure of the SR nor failure to meet the LCO. Therefore, no

violation of SR 3.0.4 occurs when changing MODES to enter MODE 3,

even with the 24 hour Frequency exceeded, provided the MODE change

does not result in entry into MODE 2. Prior to entering MODE 2

(assuming again that the 24 hour Frequency was not met), SR 3.0.4

would require satisfying the SR.

Monticello 1.4-7 Amendment No. 146
SLs

2.0

Monticello 2.0-1 Amendment No. 207 

2.0 SAFETY LIMITS (SLs)

2.1 SLs

2.1.1 Reactor Core SLs

 2.1.1.1 With the reactor steam dome pressure < 586 psig or core flow 

< 10% rated core flow: 

 THERMAL POWER shall be ≤ 25% RTP.

 2.1.1.2 (Deleted)

 2.1.1.3 With the reactor steam dome pressure ≥ 586 psig and core flow 

≥ 10% rated core flow:

 MCPR shall be ≥ 1.05.

 2.1.1.4 Reactor vessel water level shall be greater than the top of active 

irradiated fuel.

2.1.2 Reactor Coolant System Pressure SL

 Reactor steam dome pressure shall be ≤ 1332 psig.
2.0 SAFETY LIMITS (SLs) 

2.2 SL VIOLATIONS 

SLs 

2.0 

With any SL violation, the following actions shall be completed within 2 hours: 

2.2.1 Restore compliance with all SLs; and 

2.2.2 Insert all insertable control rods. 

Monticello 2.0-2 Amendment No. 191 
LCO Applicability 

3.0 

Monticello 3.0-1 Amendment No. 204 

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, LCO 3.0.7, LCO 3.0.8, and 

LCO 3.0.9. 

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 the associated ACTIONS are not met, an 

associated ACTION is not provided, or if directed by the associated 

ACTIONS, the unit shall be placed in a MODE or other specified condition 

in which the LCO is not applicable. Action shall be initiated within 1 hour 

to place the unit, as applicable, in: 

 a. MODE 2 within 7 hours; 

 b. MODE 3 within 13 hours; and 

 c. MODE 4 within 37 hours. 

 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, and 3. 

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. 
LCO Applicability

3.0

LCO Applicability

LCO 3.0.4 (continued)

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 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 demonstrate 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, an evaluation shall

be performed in accordance with Specification 5.5.10, "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.

LCO 3.0.7 Special Operations LCOs in Section 3.10 allow specified Technical

Specifications (TS) requirements to be changed to permit performance of

special tests and operations. Unless otherwise specified, all other TS

requirements remain unchanged. Compliance with Special Operations

LCOs is optional. When a Special Operations LCO is desired to be met

but is not met, the ACTIONS of the Special Operations LCO shall be met.

When a Special Operations LCO is not desired to be met, entry into a

MODE or other specified condition in the Applicability shall only be made

in accordance with the other applicable Specifications.

LCO 3.0.8 When one or more required snubbers are unable to perform their

associated support function(s), any affected supported LCO(s) are not

required to be declared not met solely for this reason if risk is assessed

and managed, and:

Monticello 3.0-2 Amendment No. 146

Monticello 3.0-2 Amendment No. 146
3.0 

LCD Applicability 

LCO Applicability 

LCO 3.0.8 (continued) 

a.	 The snubbers not able to perform their associated support function(s) 

are associated with only one subsystem of a multiple subsystem 

supported system or are associated with a single subsystem 

supported system and are able to perform their associated support 

function within 72 hours; or 

b.	 The snubbers not able to perform their associated support function(s) 

are associated with more than one subsystem of a multiple subsystem 

supported system and are able to perform their associated support 

function within 12 hours. 

At the end of the specified period the required snubbers must be able to 

perform their associated support function(s), or the affected supported 

system LCO(s) shall be declared not met. 

LCO 3.0.9	 When one or more required barriers are unable to perform their related 

support function(s), any supported system LCO(s) is/are not required to 

be declared not met solely for this reason for up to 30 days provided that 

at least one division or subsystem of the supported system is OPERABLE 

and supported by barriers capable of providing their related support 

function(s), and risk is assessed and managed. This specification may be 

concurrently applied to more than one division or SUbsystem of a multiple 

division or subsystem supported system prOVided at least one division or 

subsystem of the supported system is OPERABLE and the barriers 

supporting each of these divisions or subsystems provide their related 

support function(s) for different categories of initiating events. 

For the purposes of this specification, the High Pressure Coolant Injection 

(HPCI) system, the Reactor Core Isolation Cooling (RCIC) system, and 

the Automatic Depressurization System (ADS) are considered 

independent subsystems of a single system. 

If the required OPERABLE division or SUbsystem becomes inoperable 

while this specification is in use, it must be restored to OPERABLE status 

within 24 hours or the provisions of this specification cannot be applied to 

the divisions or subsystems supported by the barriers that cannot perform 

their related support function(s). 

At the end of the s'pecified period, the reqUired barriers must be able to 

perform their related support function(s) or the supported system LCO(s) 

shall be declared not met. 

Monticello	 3.0-3 Amendment No. -14e,l...5.1. 
SR Applicability 

3.0 

Monticello 3.0-4 Amendment No. 204 

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 Surveillance, 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 hours 

or up to the limit of the specified Frequency, whichever is greater. This 

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

delay period is only applicable when there is a reasonable expectation the 

surveillance will be met when performed. A risk evaluation shall be 

performed for any Surveillance delayed greater than 24 hours and the risk 

impact shall be managed. 

 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. 

 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. 

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. 
SR Applicability

3.0

SR Applicability

SR 3.0.4 (continued)

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.

Monticello 3.0-5 Amendment No. 146
SDM

3.1.1

3.1 REACTIVITY CONTROL SYSTEMS

3.1.1

LCO 3.1.1

SHUTDOWN MARGIN (SDM)

SDM shall be:

a. _ 0.38% Ak/k, with the highest worth control rod analytically

determined; or

b. _Ž 0.28% Ak/k, with the highest worth control rod determined by test.

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

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. SDM not within limits in A.1 Restore SDM to within 6 hours

MODE 1 or 2. limits.

B. Required Action and B.1 Be in MODE 3. 12 hours

associated Completion

Time of Condition A not

met.

C. SDM not within limits in C.1 Initiate action to fully insert Immediately

MODE 3. all insertable control rods.

D. SDM not within limits in D.1 Initiate action to fully insert Immediately

MODE 4. all insertable control rods.

'AND

D.2 Initiate action to restore 1 hour

secondary containment to

OPERABLE status.

AND

Monticello 3.1.1-1 Amendment No. 146
SDM

3.1.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D.3 Initiate action to restore one 1 hour

standby gas treatment

(SGT) subsystem to

OPERABLE status.

AND

D.4 Initiate action to restore 1 hour

isolation capability in each

required secondary

containment penetration

flow path not isolated.

E. SDM not within limits in E.1 Suspend CORE Immediately

MODE 5. ALTERATIONS except for

control rod insertion and

fuel assembly removal.

AND

E.2 Initiate action to fully insert Immediately

all insertable control rods in

core cells containing one or

more fuel assemblies.

AND

E.3 Initiate action to restore 1 hour

secondary containment to

OPERABLE status.

AND

E.4 Initiate action to restore one 1 hour

SGT subsystem to

OPERABLE status.

AND

Monticello 3.1.1-2 Amendment No. 146
SDM

3.1.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E.5 Initiate action to restore 1 hour

isolation capability in each

required secondary

containment penetration

flow path not isolated.

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.1.1 Verify SDM to be within limits. Prior to each

in vessel fuel

movement during

fuel loading

sequence

AND

Once within

4 hours after

criticality following

fuel movement

within the reactor

pressure vessel or

control rod

replacement

Monticello 3.1.1-3 Amendment No. 146
Reactivity Anomalies

3.1.2

3.1 REACTIVITY CONTROL SYSTEMS

3.1.2 Reactivity Anomalies

LCO 3.1.2 The reactivity difference between the monitored control rod inventory and

the predicted control rod inventory shall be within ± 1% Ak/k.

APPLICABILITY: MODES 1 and 2.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Core reactivity difference A.1 Restore core reactivity 72 hours

not within limit, difference to within limit.

B. Required Action and B.1 Be in MODE 3. 12,hours

associated Completion

Time not met.

Monticello 3.1.2-1 Amendment No. 146
Reactivity Anomalies

3.1.2

Monticello 3.1.2-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.2.1 Verify core reactivity difference between the 

monitored control rod inventory and the predicted 

control rod inventory is within ± 1% Δk/k.

Once within 24 

hours after 

reaching 

equilibrium 

conditions 

following startup 

after fuel 

movement within 

the reactor 

pressure vessel or 

control rod 

replacement

AND

In accordance with 

the Surveillance 

Frequency Control 

Program
Control Rod OPERABILITY

3.1.3

3.1 REACTIVITY CONTROL SYSTEMS

3.1.3 Control Rod OPERABILITY

LCO 3.1.3 Each control rod shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

Separate Condition entry is allowed for each control rod.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One withdrawn control -NOTE-------- ----------

rod stuck. Rod worth minimizer (RWM) may

be bypassed as allowed by

LCO 3.3.2.1, "Control Rod Block

Instrumentation," if required, to

allow continued operation.

A.1 Verify stuck control rod Immediately

separation criteria are met.

AND

A.2 Disarm the associated 2 hours

control rod drive (CRD).

AND

Monticello 3.1.3-1 Amendment No. 146
--------- --

-----------------------------------

3.1.3 

Control Rod OPERABILITY 

ACTIONS (continued) 

CONDITION 

B.	 Two or more withdrawn 

control rods stuck. 

C.	 One or more control 

rods inoperable for 

reasons other than 

Condition A or B. 

,..---- ._-~-_._- _. 

REQUIRED ACTION 

A.3	 Perform SR 3.1.3.2 for 

each withdrawn 

OPERABLE control rod. 

AND 

A.4	 Perform SR 3.1.1.1. 

B.1	 Be in MODE 3. 

C.1	 ---------------NOTE--------------

RWM may be bypassed as 

allowed by LCO 3.3.2.1, if 

required, to allow insertion 

of inoperable control rod 

and continued operation. 

FUlly insert inoperable 

control rod. 

AND 

C.2	 Disarm the associated 

CRD. 

- --------~---

COMPLETION TIME 

24 hours from 

discovery of 

Condition A 

concurrent with 

THERMAL POWER 

greater than the low 

power setpoint 

(LPSP) of the RWM 

72 hours 

12 hours 

3 hours 

4 hours 

Monticello	 3.1.3-2 Amendment No. 44G, 158 
Control Rod OPERABILITY

3.1.3

Monticello 3.1.3-3 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. -------------NOTE-------------

Not applicable when 

THERMAL POWER 

> 10% RTP.

----------------------------------

Two or more inoperable 

control rods not in 

compliance with banked 

position withdrawal 

sequence (BPWS) and 

not separated by two or 

more OPERABLE 

control rods.

D.1 Restore compliance with 

BPWS. 

OR

D.2 Restore control rod to 

OPERABLE status. 

4 hours

4 hours

E. Required Action and 

associated Completion 

Time of Condition A, C, 

or D not met.

OR

Nine or more control 

rods inoperable. 

E.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.3.1 Determine the position of each control rod. In accordance with 

the Surveillance 

Frequency Control 

Program
Control Rod OPERABILITY

3.1.3

Monticello 3.1.3-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.1.3.2 -------------------------------NOTE-------------------------------

Not required to be performed until 31 days after the 

control rod is withdrawn and THERMAL POWER is 

greater than the LPSP of RWM.

----------------------------------------------------------------------

Insert each withdrawn control rod at least one notch. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.1.3.3 Verify each control rod scram time from fully 

withdrawn to notch position 06 is ≤ 7 seconds. 

In accordance 

with SR 3.1.4.1, 

SR 3.1.4.2, 

SR 3.1.4.3, and 

SR 3.1.4.4

SR 3.1.3.4 Verify each control rod does not go to the withdrawn 

overtravel position. 

Each time the 

control rod is 

withdrawn to “full 

out” position

AND

Prior to declaring 

control rod 

OPERABLE after 

work on control rod 

or CRD System 

that could affect 

coupling.
Control Rod Scram Times

3.1.4

Monticello 3.1.4-1 Amendment No. 200

3.1 REACTIVITY CONTROL SYSTEMS

3.1.4 Control Rod Scram Times

LCO 3.1.4 a. No more than 8 OPERABLE control rods shall be "slow," in 

accordance with Table 3.1.4-1, and

b. No more than 2 OPERABLE control rods that are "slow" shall 

occupy adjacent locations.

APPLICABILITY: MODES 1 and 2.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the 

LCO not met.

A.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

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

During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be 

isolated from the associated scram accumulator. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.1.4.1 Verify each control rod scram time is within the limits 

of Table 3.1.4-1 with reactor steam dome pressure 

≥ 800 psig.

Prior to exceeding 

40% RTP after 

each reactor 

shutdown 

≥ 120 days 

SR 3.1.4.2 Verify, for a representative sample, each tested 

control rod scram time is within the limits of 

Table 3.1.4-1 with reactor steam dome pressure 

≥ 800 psig.

In accordance with 

the Surveillance 

Frequency Control 

Program 
Control Rod Scram Times

3.1.4

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3-1.4.3 Verify each affected control rod scram time is within Prior to declaring

the limits of Table 3.1.4-1 with any reactor steam control rod

dome pressure. OPERABLE after

work on control

rod or CRD

System that could

affect scram time

SR 3.1.4.4 Verify each affected control rod scram time is within Prior to exceeding the limits of Table 3.1.4-1 with reactor steam dome 40% RTP after

pressure _ 800 psig. fuel movement

within the affected

core cell

AND

Prior to exceeding

40% RTP after

work on control

rod or CRD

System that could

affect scram time

Monticello 3.1.4 -2 Amendment No. 146
Control Rod Scram Times 

3.1.4 

Table 3.1.4-1 (page 1 of 1) 

Control Rod Scram Times 

-----------------------------------------------------NOTES---------------------------------------------------

1.	 OPERABLE control rods with scram times not within the limits of this Table are considered 

"slow." 

2.	 Enter applicable Conditions and Required Actions of LCO 3.1.3, "Control Rod 

OPERABILITY," for control rods with scram times> 7 seconds to notch position 06. These 

control rods are inoperable, in accordance with SR 3.1.3.3 and are not considered "slow." 

NOTCH POSITION 

46 

36 

26 

06 

SCRAM TIMES(a)(b) (seconds) 

WHEN REACTOR STEAM DOME 

PRESSURE;:> 800 psig 

0.44 

1.08 

1.83 

3.35 

(a)	 Maximum scram time from fully withdrawn position based on de-energization of scram pilot 

valve solenoids at time zero. 

(b)	 Scram times as a function of reactor steam dome pressure when < 800 psig are within 

established limits. 

Monticello	 3.1.4-3 Amendment No. 446;- 158 
Control Rod Scram Accumulators

3.1.5

3.1 REACTIVITY CONTROL SYSTEMS

3.1.5 Control Rod Scram Accumulators

LCO 3.1.5

APPLICABILITY:

Each control rod scram accumulator shall be OPERABLE.

MODES 1 and 2.

ACTIONS

........ ------------------------------. NOTE.------.----------OE----

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One control rod scram A.1 ---------- NOTE- -

accumulator inoperable Only applicable if the

with reactor steam dome associated control rod

pressure _ 900 psig. scram time was within the

limits of Table 3.1.4-1

during the last scram time

Surveillance.

Declare the associated 8 hours

control rod scram time

"slow."

OR

A.2 Declare the associated 8 hours

control rod inoperable.

B. Two or more control rod B.1 Restore charging water 20 minutes from

scram accumulators header pressure to discovery of

inoperable with reactor >_ 940 psig. Condition B

steam dome pressure concurrent with

Ž 900 psig. charging water

header pressure

< 940 psig

AND

Monticello 3.1.5-1 MAmendment No. 146
Control Rod Scram Accumulators

3.1.5

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2.1 NOTE-------

Only applicable if the

associated control rod

scram time was within the

limits of Table 3.1.4-1

during the last scram time

Surveillance.

Declare the associated 1 hour

control rod scram time

"slow."

OR

B.2.2 Declare the associated 1 hour

control rod inoperable.

C. One or more control rod C.1 Verify all control rods Immediately upon

scram accumulators associated with inoperable discovery of charging

inoperable with reactor accumulators are fully water header

steam dome pressure inserted, pressure < 940 psig

< 900 psig.

AND

C.2 Declare the associated 1 hour

control rod inoperable.

D. Required Action B.1 or D.1 ----- NOTE -------

C.1 and associated Not applicable if all

Completion Time not inoperable control rod

met. scram accumulators are

associated with fully

inserted control rods.

Place the reactor mode Immediately

switch in the shutdown

position.

Monticello 3.1.5-2 Amendment No. 146
Control Rod Scram Accumulators

3.1.5

Monticello 3.1.5-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.5.1 Verify each control rod scram accumulator pressure 

is ≥ 940 psig.

In accordance with 

the Surveillance 

Frequency Control 

Program
Rod Pattern Control

3.1.6

3.1 REACTIVITY CONTROL SYSTEMS

3.1.6 Rod Pattern Control

LCO 3.1.6

APPLICABILITY:

OPERABLE control rods shall comply with the requirements of the

banked position withdrawal sequence (BPWS).

MODES 1 and 2 with THERMAL POWER < 10% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more A.1 ----------- NOTE-------

OPERABLE control rods Rod worth minimizer

not in compliance with (RWM) may be bypassed

BPWS. as allowed by LCO 3.3.2.1,

"Control Rod Block

Instrumentation."

Move associated control 8 hours

rod(s) to correct position.

OR

A.2 Declare associated control 8 hours

rod(s) inoperable.

B. Nine or more B.1 ----------- NOTE-------

OPERABLE control rods Rod worth minimizer

not in compliance with (RWM) may be bypassed

BPWS. as allowed by LCO 3.3.2.1.

Suspend withdrawal of Immediately

control rods.

AND

B.2 Place the reactor mode 1 hour

switch in the shutdown

position.

Monticello 3.1.6-1 Amendment No. 146
Rod Pattern Control

3.1.6

Monticello 3.1.6-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.6.1 Verify all OPERABLE control rods comply with 

BPWS.

In accordance with 

the Surveillance 

Frequency Control 

Program
SLC System 

3.1.7 

Monticello 3.1.7-1 Amendment No. 206 

3.1 REACTIVITY CONTROL SYSTEMS 

3.1.7 Standby Liquid Control (SLC) System 

LCO 3.1.7 Two SLC subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. Concentration of sodium 

pentaborate in solution 

not within limits of 

Figure 3.1.7-1 and 

Table 3.1.7-1 

Equation 2, but available 

volume of sodium 

pentaborate solution is 

within limits of 

Table 3.1.7-1 

Equation 1. 

A.1 Restore concentration of 

sodium pentaborate in 

solution to within limits. 

7 days 

B. One SLC subsystem 

inoperable for reasons 

other than Condition A. 

B.1 Restore SLC subsystem to 

OPERABLE status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

C. Two SLC subsystems 

inoperable for reasons 

other than Condition A. 

C.1 Restore one SLC 

subsystem to OPERABLE 

status. 

8 hours 
SLC System 

3.1.7 

Monticello 3.1.7-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

D. Required Action and 

associated Completion 

Time not met. 

D.1 Be in MODE 3. 

AND 

D.2 Be in MODE 4. 

12 hours 

36 hours 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.1.7.1 Verify available volume of sodium pentaborate 

solution is within the limits of Figure 3.1.7-1 or 

Equation 1 of Table 3.1.7-1. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

SR 3.1.7.2 Verify temperature of sodium pentaborate solution is 

within the limits of Figure 3.1.7-2. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

SR 3.1.7.3 Verify temperature of room in the vicinity of the SLC 

pumps is within the solution temperature limits of 

Figure 3.1.7-2 or verify SLC pump suction lines heat 

tracing is OPERABLE. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

SR 3.1.7.4 Verify continuity of explosive charge. In accordance 

with the 

Surveillance 

Frequency 

Control Program 
SLC System 

3.1.7 

Monticello 3.1.7-3 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.1.7.5 Verify the concentration of sodium pentaborate in 

solution is within the limits of Figure 3.1.7-1 or within 

the limits of Equation 2 of Table 3.1.7-1. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

AND 

Once within 

24 hours after 

water or sodium 

pentaborate is 

added to solution 

AND 

Once within 

24 hours after 

solution 

temperature is 

restored within 

the limits of 

Figure 3.1.7-2 

SR 3.1.7.6 Verify each SLC subsystem manual valve in the flow 

path that is not locked, sealed, or otherwise secured 

in position is in the correct position, or can be 

aligned to the correct position. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

SR 3.1.7.7 Verify each pump develops a flow rate ≥ 24 gpm at a 

discharge pressure ≥ 1275 psig. 

In accordance 

with the 

INSERVICE 

TESTING 

PROGRAM 
SLC System 

3.1.7 

Monticello 3.1.7-4 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.1.7.8 Verify flow through one SLC subsystem from pump 

into reactor pressure vessel. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

SR 3.1.7.9 Verify all heat traced piping between storage tank 

and pump suction is unblocked. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program 

AND 

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

Only required if 

SLC pump 

suction lines heat 

tracing is 

inoperable. 

------------------------ 

Once within 

24 hours after 

room temperature 

in the vicinity of 

the SLC pumps is 

restored within 

the solution 

temperature limits 

of Figure 3.1.7-2 

SR 3.1.7.10 Verify sodium pentaborate enrichment is 

≥ 55.0 atom percent B-10. 

Prior to addition 

to SLC tank 
SLC System 

3.1.7 

Monticello 3.1.7-5 Amendment No. 206 

Figure 3.1.7-1 (page 1 of 1) 

Sodium Pentaborate Solution Volume Versus Concentration Requirements

Sodium Pentaborate Concentration (Weight Percent, wt%) 

Allowed Operation 

(1167,13.0) 

(1404,10.7) 

Indicated Tank Volume (Gallons)
SLC System 

3.1.7 

Monticello 3.1.7-6 Amendment No. 206 

Sodium Pentaborate in Solution (Weight Percent, wt%) 

Figure 3.1.7-2 (page 1 of 1) 

Sodium Pentaborate Solution Temperature Versus Concentration Requirements

Allowed Operation 

Measured Solution Temperature (F) 
SLC System 

3.1.7 

Monticello 3.1.7-7 Amendment No. 206 

Table 3.1.7-1 (page 1 of 1) 

Equations for Required Sodium Pentaborate Tank Volume and Concentration 

Equation 1 

                   

71.18 4821 19.8 100 V 1 128 gal 0.0051 C + 0.998 1101 E E C

Where: 

C = measured boron solution concentration (wt%) 

E = measured boron solution enrichment (atom%) 

V = indicated boron solution tank volume (gal) 

Equation 2 

         

86 19.8 C 8.28

Q E

Where: 

C = measured boron solution concentration (wt%) 

E = measured boron solution enrichment (atom%) 

Q = measured pump flow rate (gpm) at 1275 psig 
SDV Vent and Drain Valves

3.1.8

3.1 REACTIVITY CONTROL SYSTEMS

3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves

LCO 3.1.8 Each SDV vent and drain valve shall be OPERABLE.

APPLICABILITY:

ACTIONS

MODES I and 2.

------------------------------.------------NOTES --------------------------------------- - 1. Separate Condition entry is allowed for each SDV vent and drain line.

2. An isolated line may be unisolated under administrative control to allow draining and

venting of the SDV.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more SDV vent A.1 Isolate the associated line. 7 days

or drain lines with one

valve inoperable.

B. One or more SDV vent B.1 Isolate the associated line. 8 hours

or drain lines with both

valves inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours

associated Completion

Time not met.

Monticello 3.1.8-1 Amendment No. 146
SDV Vent and Drain Valves

3.1.8

Monticello 3.1.8-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.1.8.1 ------------------------------NOTE-------------------------------

Not required to be met on vent and drain valves 

closed during performance of SR 3.1.8.2.

---------------------------------------------------------------------

Verify each SDV vent and drain valve is open. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully 

closed and fully open position. 

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.1.8.3 Verify each SDV vent and drain valve:

a. Closes in ≤ 30 seconds after receipt of an 

actual or simulated scram signal; and

b. Opens when the actual or simulated scram 

signal is reset. 

In accordance with 

the Surveillance 

Frequency Control 

Program
APLHGR

3.2.1

Monticello 3.2.1-1 Amendment No. 200

3.2 POWER DISTRIBUTION LIMITS

3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the 

COLR.

APPLICABILITY: THERMAL POWER ≥ 25% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Any APLHGR not within 

limits.

A.1 Restore APLHGR(s) to 

within limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.2.1.1 Verify all APLHGRs are less than or equal to the 

limits specified in the COLR.

Once within 

12 hours after 

≥ 25% RTP

AND

In accordance with 

the Surveillance 

Frequency Control 

Program
MCPR

3.2.2

Monticello 3.2.2-1 Amendment No. 200

3.2 POWER DISTRIBUTION LIMITS

3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits 

specified in the COLR.

APPLICABILITY: THERMAL POWER ≥ 25% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Any MCPR not within 

limits.

A.1 Restore MCPR(s) to within 

limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.2.2.1 Verify all MCPRs are greater than or equal to the 

limits specified in the COLR.

Once within 

12 hours after 

≥ 25% RTP

AND

In accordance with 

the Surveillance 

Frequency Control 

Program
MCPR

3.2.2

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.2.2.2 Determine the MCPR limits. Once within

72 hours after

each completion

of SR 3.1.4.1

AND

Once within

72 hours after

each completion

of SR 3.1.4.2

AND

Once within

72 hours after

each completion

of SR 3.1.4.4

Monticello 3.2.2-2 Amendment No. 146
LHGR

3.2.3

Monticello 3.2.3-1 Amendment No. 200

3.2 POWER DISTRIBUTION LIMITS

3.2.3 LINEAR HEAT GENERATION RATE (LHGR)

LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY: THERMAL POWER ≥ 25% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Any LHGR not within 

limits.

A.1 Restore LHGR(s) to within 

limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits 

specified in the COLR.

Once within 

12 hours after 

≥ 25% RTP

AND

In accordance with 

the Surveillance 

Frequency Control 

Program
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.1.1 Reactor Protection System (RPS) Instrumentation 

LCO 3.3.1.1 The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be 

OPERABLE. 

APPLICABILITY: According to Table 3.3.1.1-1. 

ACTIONS 

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

1. Separate Condition entry is allowed for each channel. 

2. When the Function 2.b and 2.c channels are not within the limit of SR 3.3.1.1.2 due to 

APRM indication not within limits, entry into associated Conditions and Required Actions 

may be delayed for up to 2 hours if the APRM is indicating a lower power value than the 

calculated power, and for up to 12 hours if the APRM is indicating a higher power value 

than the calculated power. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more required 

channels inoperable. 

A.1 Place channel in trip. 

OR 

12 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-2 Amendment No. 210 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

A.2 --------------NOTE------------- 

 Not applicable for 

Functions 2.a, 2.b, 2.c, 2.d, 

or 2.f. 

 ------------------------------------ 

 Place associated trip 

system in trip. 

12 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. -----------NOTE------------ 

 Not applicable for 

Functions 2.a, 2.b, 2.c, 

2.d, or 2.f. 

 ------------------------------- 

 One or more Functions 

with one or more 

required channels 

inoperable in both trip 

systems. 

B.1 Place channel in one trip 

system in trip. 

OR 

B.2 Place one trip system in 

trip. 

6 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

6 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

C. One or more Functions 

with RPS trip capability 

not maintained. 

C.1 Restore RPS trip capability. 1 hour 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-3 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

D. Required Action and 

associated Completion 

Time of Condition A, B, 

or C not met. 

D.1 Enter the Condition 

referenced in 

Table 3.3.1.1-1 for the 

channel. 

Immediately 

E. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1. 

E.1 Reduce THERMAL 

POWER to  40% RTP. 

4 hours 

F. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1. 

F.1 Be in MODE 2. 

AND 

F.2 --------------NOTE------------- 

 Only applicable to 

Function 5. 

 ------------------------------------ 

 Reduce reactor pressure to 

< 600 psig. 

6 hours 

12 hours 

G. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1. 

G.1 Be in MODE 3. 12 hours 

H. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1. 

H.1 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies. 

Immediately 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-4 Amendment No. 210 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

I. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.1.1-1. 

I.1 Initiate alternate method to 

detect and suppress 

thermal hydraulic instability 

oscillations. 

AND 

I.2 -------------NOTE----------------

LCO 3.0.4 is not applicable 

------------------------------------- 

Restore required channels 

to OPERABLE. 

12 hours 

120 days 

J. Required Action and 

associated Completion 

Time of Condition I 

not met. 

J.1 Reduce THERMAL 

POWER to < 20% RTP. 

4 hours 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-5 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

-----------------------------------------------------------NOTES---------------------------------------------------------- 

1. Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function. 

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for 

up to 6 hours provided the associated Function maintains RPS trip capability. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY 

SR 3.3.1.1.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.2 --------------------------------NOTE------------------------------- 

Not required to be performed until 12 hours after 

THERMAL POWER ≥ 25% RTP. 

------------------------------------------------------------------------ 

Verify the absolute difference between the average 

power range monitor (APRM) channels and the 

calculated power is ≤ 2% RTP while operating at 

≥ 25% RTP. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.3 --------------------------------NOTE------------------------------- 

 Not required to be performed when entering 

MODE 2 from MODE 1 until 12 hours after entering 

MODE 2. 

------------------------------------------------------------------------ 

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-6 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.1.1.4 Perform a functional test of each RPS automatic 

scram contactor. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.6 Calibrate the local power range monitors. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.7 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.8 Calibrate the trip units. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.9 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.10 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-7 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.1.1.11 -------------------------------NOTES------------------------------ 

1. Neutron detectors are excluded. 

2. For Function 1, not required to be performed 

when entering MODE 2 from MODE 1 until 

12 hours after entering MODE 2. 

3. For Functions 2.b and 2.f, the recirculation flow 

transmitters that feed the APRMs are included. 

------------------------------------------------------------------------ 

Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.12 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.13 Verify Turbine Stop Valve - Closure and Turbine 

Control Valve Fast Closure, Acceleration Relay Oil 

Pressure - Low Functions are not bypassed when 

THERMAL POWER is > 40% RTP. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.14 Verify the RPS RESPONSE TIME is within limits. In accordance with 

the Surveillance 

Frequency Control 

Program 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-8 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.1.1.15 -------------------------------NOTES------------------------------ 

1. For Function 2.a, not required to be performed 

when entering MODE 2 from MODE 1 until 

12 hours after entering MODE 2. 

2. For Functions 2.b and 2.f, the CHANNEL 

FUNCTIONAL TEST includes the recirculation 

flow input processing, excluding the flow 

transmitters. 

------------------------------------------------------------------------ 

 

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.1.1.16 Verify the oscillation power range monitor (OPRM) 

function is not bypassed when APRM Simulated 

Thermal Power is ≥ 25% RTP and drive flow 

is ≤ 60% of rated drive flow. 

 

In accordance with 

the Surveillance 

Frequency Control 

Program 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-9 Amendment No. 206 

Table 3.3.1.1-1 (page 1 of 4) 

Reactor Protection System Instrumentation 

FUNCTION 

APPLICABLE 

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 1. Intermediate Range 

Monitors 

 a. Neutron Flux – High 

High 

2 3 G SR 3.3.1.1.1 

SR 3.3.1.1.3 

SR 3.3.1.1.4 

SR 3.3.1.1.11 

SR 3.3.1.1.12 

SR 3.3.1.1.14 

 122/125 

divisions of full 

scale 

 

5(a) 3 H SR 3.3.1.1.1 

SR 3.3.1.1.3 

SR 3.3.1.1.4 

SR 3.3.1.1.11 

SR 3.3.1.1.12 

SR 3.3.1.1.14 

 122/125 

divisions of full 

scale 

 

 b. Inop. 2 3 G SR 3.3.1.1.3 

SR 3.3.1.1.4 

SR 3.3.1.1.12 

NA 

 

5(a) 3 H SR 3.3.1.1.3 

SR 3.3.1.1.4 

SR 3.3.1.1.12 

NA 

 

 2. Average Power Range 

Monitors 

 a. Neutron Flux – High, 

(Setdown) 

2 3(c) G SR 3.3.1.1.1 

SR 3.3.1.1.4 

SR 3.3.1.1.6 

SR 3.3.1.1.11 

SR 3.3.1.1.15 

 20% RTP 

 b. Simulated Thermal 

Power – High 

1 3(c) F SR 3.3.1.1.1 

SR 3.3.1.1.2 

SR 3.3.1.1.4 

SR 3.3.1.1.6 

SR 3.3.1.1.11 

SR 3.3.1.1.15 

 0.61W 

+ 67.2% RTP(b) 

and  116% RTP 

 

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. 

(b)  0.55 (W – Delta W) + 61.5% RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops 

Operating." The cycle-specific value for Delta W is specified in the COLR. 

(c) Each APRM / OPRM channel provides inputs to both trip systems. 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-10 Amendment No. 210 

Table 3.3.1.1-1 (page 2 of 4) 

Reactor Protection System Instrumentation 

FUNCTION 

APPLICABLE 

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 

 c. Neutron Flux – High 1 3

(c) F SR 3.3.1.1.1 

SR 3.3.1.1.2 

SR 3.3.1.1.4 

SR 3.3.1.1.6 

SR 3.3.1.1.11(f)(g)

SR 3.3.1.1.15 

 122% RTP 

 

 d. Inop. 1, 2 3(c) G SR 3.3.1.1.4 

SR 3.3.1.1.15 

NA 

 

 e. 2-Out-Of-4 Voter 1, 2 2 G SR 3.3.1.1.1 

SR 3.3.1.1.4 

SR 3.3.1.1.12 

SR 3.3.1.1.14 

SR 3.3.1.1.15 

NA 

 

 f. OPRM Upscale ≥ 20% RTP 3(c) I SR 3.3.1.1.1 

SR 3.3.1.1.4 

SR 3.3.1.1.6 

SR 3.3.1.1.11 

SR 3.3.1.1.15 

SR 3.3.1.1.16 

As specified in 

COLR 

 

 3. Reactor Vessel Steam 

Dome Pressure – High 

1, 2 2 G SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

SR 3.3.1.1.14 

 1075 psig 

 

(c) Each APRM / OPRM channel provides inputs to both trip systems. 

(f) If the as-found channel setpoint is not the Nominal Trip Setpoint but is conservative with respect to the Allowable 

Value, then the channel shall be evaluated to verify that it is functioning as required before returning the channel 

to service. 

(g) The instrument channel setpoint shall be reset to the Nominal Trip Setpoint (NTSP) at the completion of the 

surveillance; otherwise, the channel shall be declared inoperable. The NTSP and the methodology used to 

determine the NTSP are specified in the Technical Requirements Manual. 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-11 Amendment No. 206 

Table 3.3.1.1-1 (page 3 of 4) 

Reactor Protection System Instrumentation 

FUNCTION 

APPLICABLE 

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 

 4. Reactor Vessel Water 

Level – Low 

1, 2 2 G SR 3.3.1.1.1 

SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.8 

SR 3.3.1.1.11 

SR 3.3.1.1.12 

SR 3.3.1.1.14 

 7 inches 

 

 5. Main Steam Isolation 

Valve – Closure 

1, 2(d) 8 F SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.11 

SR 3.3.1.1.12 

SR 3.3.1.1.14 

 10% closed 

 

 6. Drywell Pressure – High 1, 2 2 G SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

 2.0 psig 

 

 7. Scram Discharge 

Volume Water Level – 

High 

 

 

 a. Resistance 

Temperature 

Detector 

1, 2 2 G SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

 56.0 gallons 

 

 5(a) 2 H SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

 56.0 gallons 

 

 b. Float Switch 1, 2 2 G SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

 56.0 gallons 

 

5(a) 2 H SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

 56.0 gallons 

 

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. 

(d) With reactor pressure ≥ 600 psig. 
RPS Instrumentation 

3.3.1.1 

Monticello 3.3.1.1-12 Amendment No. 206 

Table 3.3.1.1-1 (page 4 of 4) 

Reactor Protection System Instrumentation 

FUNCTION 

APPLICABLE 

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER TRIP 

SYSTEM 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION D.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 

 8. Turbine Stop Valve – 

Closure 

> 40% RTP 4 E SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.11 

SR 3.3.1.1.12 

SR 3.3.1.1.13 

SR 3.3.1.1.14 

 10% closed 

 

 9. Turbine Control Valve 

Fast Closure, 

Acceleration Relay Oil 

Pressure – Low 

> 40% RTP 2 E SR 3.3.1.1.4 

SR 3.3.1.1.7 

SR 3.3.1.1.9 

SR 3.3.1.1.12 

SR 3.3.1.1.13 

SR 3.3.1.1.14 

 167.8 psig 

 

 10. Reactor Mode Switch – 

Shutdown Position 

1, 2 1 G SR 3.3.1.1.10 

SR 3.3.1.1.12 

NA 

 

5(a) 1 H SR 3.3.1.1.10 

SR 3.3.1.1.12 

NA 

 

 11. Manual Scram 1, 2 1 G SR 3.3.1.1.5 

SR 3.3.1.1.12 

NA 

 

 5(a) 1 H SR 3.3.1.1.5 

SR 3.3.1.1.12 

NA 

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies. 
SRM Instrumentation

3.3.1.2

3.3 INSTRUMENTATION

3.3.1.2 Source Range Monitor (SRM) Instrumentation

LCO 3.3.1.2

APPLICABILITY:

The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

According to Table 3.3.1.2-1.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more required A.1 Restore required SRMs to 4 hours

SRMs inoperable in OPERABLE status.

MODE 2 with

intermediate range

monitors (IRMs) on

Range 2 or below.

B. Three required SRMs B.1 Suspend control rod Immediately

inoperable in MODE 2 withdrawal.

with IRMs on Range 2 or

below.

C. Required Action and C.1 Be in MODE 3. 12 hours

associated Completion

Time of Condition A or B

not met.

D. One or more required D.1 Fully insert all insertable 1 hour

SRMs inoperable in control rods.

MODE 3 or 4.

AND

D.2 Place reactor mode switch 1 hour

in the shutdown position.

Monticello 3.3.1.2-1 Amendment No. 146
SRM Instrumentation

3.3.1.2

Monticello 3.3.1.2-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. One or more required 

SRMs inoperable in 

MODE 5.

E.1 Suspend CORE 

ALTERATIONS except for 

control rod insertion.

AND

E.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other 

specified conditions.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.1.2.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program
SRM Instrumentation

3.3.1.2

Monticello 3.3.1.2-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.1.2.2 -------------------------------NOTES------------------------------

1. Only required to be met during CORE 

ALTERATIONS.

2. One SRM may be used to satisfy more than one 

of the following.

------------------------------------------------------------------------

Verify an OPERABLE SRM detector is located in:

a. The fueled region;

b. The core quadrant where CORE 

ALTERATIONS are being performed, when the 

associated SRM is included in the fueled 

region; and

c. A core quadrant adjacent to where CORE 

ALTERATIONS are being performed, when the 

associated SRM is included in the fueled 

region. 

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.1.2.3 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.1.2.4 --------------------------------NOTE-------------------------------

Not required to be met with less than or equal to two 

fuel assemblies adjacent to the SRM and no other 

fuel assemblies in the associated core quadrant.

------------------------------------------------------------------------

Verify count rate is ≥ 3.0 cps with a signal to noise 

ratio ≥ 3:1.

In accordance with 

the Surveillance 

Frequency Control 

Program
SRM Instrumentation

3.3.1.2

Monticello 3.3.1.2-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.1.2.5 --------------------------------NOTE-------------------------------

The determination of signal to noise ratio is not 

required to be met with less than or equal to two fuel 

assemblies adjacent to the SRM and no other fuel 

assemblies in the associated core quadrant.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST and 

determination of signal to noise ratio. 

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.1.2.6 --------------------------------NOTE-------------------------------

Not required to be performed until 12 hours after 

IRMs on Range 2 or below.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST and 

determination of signal to noise ratio.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.1.2.7 -------------------------------NOTES------------------------------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours 

after IRMS on Range 2 or below.

------------------------------------------------------------------------

Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program 
SRM Instrumentation

3.3.1.2

Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentation

APPLICABLE

MODES OR OTHER

SPECIFIED REQUIRED SURVEILLANCE

FUNCTION CONDITIONS CHANNELS REQUIREMENTS

1. Source Range Monitor 2(a) 3 SR 3.3.1.2.1

SR 3.3.1.2.4

SR 3.3.1-2.6

SR 3.3.1.2.7

3, 4 2 SR 3.3.1-2.3

SR 3.3.124

SR 3.3.1-2.6

SR 3.3.1.2.7

2 (b), (c) SR 3.3.1-2.1,

SR 3.3.1-2.2

SR 3.3.1.2.4

SR 3.3.1.2.5

SR 3.3.1.2.7

(a) With IRMs on Range 2 or below.

(b) Only one SRM channel is required to be OPERABLE during spiral offload or reload when the fueled region

includes only that SRM detector.

(c) Special movable detectors may be used in place of SRMs if connected to normal SRM circuits.

Monticello 3.3.1.2-5 Amendment No. 146
Control Rod Block Instrumentation

3.3.2.1

3.3 INSTRUMENTATION

3.3.2.1 Control Rod Block Instrumentation

LCO 3.3.2.1

APPLICABILITY:

The control rod block instrumentation for each Function in Table 3.3.2. 1-1

shall be OPERABLE.

According to Table 3.3.2.1-1.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One rod block monitor A.1 Restore RBM channel to 24 hours

(RBM) channel OPERABLE status.

inoperable.

B. Required Action and B.1 Place one RBM channel in 1 hour

associated Completion trip.

Time of Condition A not

met.

OR

Two RBM channels

inoperable.

C. Rod worth minimizer C.1 Suspend control rod Immediately

(RWM) inoperable movement except by

during reactor startup. scram.

OR

C.2.1.1 Verify 12 rods withdrawn. Immediately

OR

Monticello 3.3.2.1-1 Amendment No. 146
Control Rod Block Instrumentation

3.3.2.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2.1.2 Verify by administrative Immediately

methods that startup with

RWM inoperable has not

been performed in the last

12 months.

AND

C.2.2 Verify movement of control During control rod

rods is in compliance with movement

banked position withdrawal

sequence (BPWS) by a

second licensed operator or

other qualified member of

the technical staff.

D. RWM inoperable during D.1 Verify movement of control During control rod

reactor shutdown. rods is in compliance with movement

BPWS by a second

licensed operator or other

qualified member of the

technical staff.

E. One or more Reactor E.1 Suspend control rod Immediately

Mode Switch - Shutdown withdrawal.

Position channels

inoperable. AND

E.2 Initiate action to fully insert Immediately

all insertable control rods in

core cells containing one or

more fuel assemblies.

Monticello 3.3.2.1-2 Amendment No. 146
Control Rod Block Instrumentation

3.3.2.1

Monticello 3.3.2.1-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block 

Function.

2. When an RBM channel is placed in an inoperable status solely for performance of 

required Surveillances, entry into associated Conditions and Required Actions may be 

delayed for up to 6 hours provided the associated Function maintains control rod block 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.2.1.2 --------------------------------NOTE-------------------------------

Not required to be performed until 1 hour after any 

control rod is withdrawn at ≤ 10% RTP in MODE 2.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.2.1.3 --------------------------------NOTE-------------------------------

Not required to be performed until 1 hour after 

THERMAL POWER is ≤ 10% RTP in MODE 1.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
Control Rod Block Instrumentation

3.3.2.1

Monticello 3.3.2.1-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.2.1.4 --------------------------------NOTE-------------------------------

Neutron detectors are excluded.

------------------------------------------------------------------------

Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.2.1.5 --------------------------------NOTE-------------------------------

Neutron detectors are excluded.

------------------------------------------------------------------------

Verify the RBM:

a. Low Power Range - Upscale Function is not 

bypassed when THERMAL POWER is ≥ 30% 

and < 65% RTP;

b. Intermediate Power Range - Upscale Function 

is not bypassed when THERMAL POWER is 

≥ 65% and < 85% RTP; and

c. High Power Range – Upscale Function is not 

bypassed when THERMAL POWER is 

≥ 85% RTP.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.2.1.6 Verify the RWM is not bypassed when THERMAL 

POWER is ≤ 10% RTP.

In accordance with 

the Surveillance 

Frequency Control 

Program
Control Rod Block Instrumentation

3.3.2.1

Monticello 3.3.2.1-5 Amendment No. 200 

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.2.1.7 --------------------------------NOTE-------------------------------

Not required to be performed until 1 hour after 

reactor mode switch is in the shutdown position.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.2.1.8 Verify control rod sequences input to the RWM are 

in conformance with BPWS.

Prior to declaring 

RWM OPERABLE 

following loading 

of sequence into 

RWM
Control Rod Block Instrumentation

3.3.2.1

Monticello 3.3.2.1-6 Amendment No. 200

Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED

CHANNELS

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Rod Block Monitor

 a. Low Power Range - Upscale (a) 2 SR 3.3.2.1.1

SR 3.3.2.1.4(h)(i)

SR 3.3.2.1.5

As specified in 

COLR

 b. Intermediate Power Range - 

Upscale

(b) 2 SR 3.3.2.1.1

SR 3.3.2.1.4(h)(i)

SR 3.3.2.1.5

As specified in 

COLR

 c. High Power Range - Upscale (c), (d) 2 SR 3.3.2.1.1

SR 3.3.2.1.4(h)(i)

SR 3.3.2.1.5

As specified in 

COLR

d. Inop (d), (e) 2 SR 3.3.2.1.1 NA

2. Rod Worth Minimizer 1(f), 2(f) 1 SR 3.3.2.1.2

SR 3.3.2.1.3

SR 3.3.2.1.6

SR 3.3.2.1.8

NA

3. Reactor Mode Switch - Shutdown 

Position

(g) 2 SR 3.3.2.1.7 NA

(a) THERMAL POWER ≥ 30% and < 65% RTP and MCPR is below the limit specified in COLR.

(b) THERMAL POWER ≥ 65% and < 85% RTP and MCPR is below the limit specified in COLR.

(c) THERMAL POWER ≥ 85% and < 90% RTP and MCPR is below the limit specified in COLR.

(d) THERMAL POWER ≥ 90% RTP and MCPR is below the limit specified in COLR.

(e) THERMAL POWER ≥ 30% and < 90% RTP and MCPR is below the limit specified in COLR.

(f) With THERMAL POWER ≤ 10% RTP, except during the reactor shutdown process if the coupling of each 

withdrawn control rod has been confirmed.

(g) Reactor mode switch in the shutdown position. 

(h) If the as-found channel setpoint is not the Nominal Trip Setpoint (NTSP) but is conservative with respect to the 

Allowable Value, then the channel shall be evaluated to verify that it is functioning as required before returning 

the channel to service.

(i) The instrument channel setpoint shall be reset to the Nominal Trip Setpoint at the completion of the 

surveillance; otherwise, the channel shall be declared inoperable. The NTSP shall be specified in the COLR. 

The methodology used to determine the NTSP is specified in the Technical Requirements Manual.
Feedwater Pump and Main Turbine High Water Level Trip Instrumentation 

3.3.2.2 

Monticello 3.3.2.2-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.2.2 Feedwater Pump and Main Turbine High Water Level Trip Instrumentation 

LCO 3.3.2.2 Four channels of Feedwater Pump and Main Turbine High Water Level 

Trip Instrumentation shall be OPERABLE. 

APPLICABILITY: THERMAL POWER  25% RTP. 

ACTIONS 

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

Separate Condition entry is allowed for each channel. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more feedwater 

pump and main turbine 

high water level trip 

channels inoperable. 

A.1 Place channel in trip. 7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Feedwater pump and 

main turbine high water 

level trip capability not 

maintained. 

B.1 Restore feedwater pump 

and main turbine high water 

level trip capability. 

2 hours 
Feedwater Pump and Main Turbine High Water Level Trip Instrumentation 

3.3.2.2 

Monticello 3.3.2.2-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

C. Required Action and 

associated Completion 

Time not met. 

C.1 ----------NOTE------------------- 

 Only applicable if 

inoperable channel is the 

result of inoperable 

feedwater pump breaker or 

main turbine stop valve. 

 ------------------------------------- 

 Remove affected feedwater 

pump(s) and main turbine 

valve(s) from service. 

OR 

C.2 Reduce THERMAL 

POWER to < 25% RTP. 

4 hours 

4 hours 

SURVEILLANCE REQUIREMENTS 

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

When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 

6 hours provided feedwater pump and main turbine high water level trip capability is maintained. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY 

SR 3.3.2.2.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.2.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 
Feedwater Pump and Main Turbine High Water Level Trip Instrumentation 

3.3.2.2 

Monticello 3.3.2.2-3 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.2.2.3 Calibrate the trip units. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.2.2.4 Perform CHANNEL CALIBRATION. The Allowable 

Value shall be ≤ 49 inches. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.2.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST 

including valve and breaker actuation. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
PAM Instrumentation

3.3.3.1

3.3 INSTRUMENTATION

3.3.3.1 Post Accident Monitoring (PAM) Instrumentation

LCO 3.3.3.1

APPLICABILITY:

The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be

OPERABLE.

MODES 1 and 2.

ACTIONS --M-- r

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more Functions A.1 Restore required channel to 30 days

with one required OPERABLE status.

channel inoperable.

B. Required Action and B.1 Initiate action in accordance Immediately

associated Completion with Specification 5.6.4.

Time of Condition A not

met.

C. One or more Functions C.1 Restore one required 7 days

with two required channel to OPERABLE

channels .inoperable. status.

D. Required Action and D.1 Enter the Condition Immediately'

associated Completion referenced in

Time of Condition C not Table 3.3.3.1-1 for the

met. channel.

Monticello 3.3.3.1-1 Amendment No. 146
PAM Instrumentation

3.3.3.1

Monticello 3.3.3.1-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

E. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.3.1-1.

E.1 Be in MODE 3. 12 hours

F. As required by Required 

Action D.1 and 

referenced in 

Table 3.3.3.1-1.

F.1 Initiate action in accordance 

with Specification 5.6.4.

Immediately

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. These SRs apply to each Function in Table 3.3.3.1-1.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed 

for up to 6 hours provided the other required channel in the associated Function is 

OPERABLE.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.3.1.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.3.1.2 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program
PAM Instrumentation

3.3.3.1

Table 3.3.3.1-1 (page 1 of 1)

Post Accident Monitoring Instrumentation

CONDITIONS

REFERENCED

REQUIRED FROM REQUIRED

FUNCTION CHANNELS ACTION D.1

1. Reactor Vessel Pressure 2 E

2. Reactor Vessel Water Level 2 E

3. Suppression Pool Water Level 2 E

4. Drywell Pressure 2 E

5. Primary Containment Area Radiation 2 F

6. Penetration Flow Path PCIV Position 2 per penetration flow E

path(a) (b)

7. Suppression Pool Water Temperature 2 F

(a) Not required for isolation valves whose associated penetration flow path is isolated by at least one closed and

deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve

secured.

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

indication channel.

Monticello 3.3.3.1-3 Amendment No. 146
Alternate Shutdown System

3.3.3.2

Monticello 3.3.3.2-1 Amendment No. 200

3.3 INSTRUMENTATION

3.3.3.2 Alternate Shutdown System

LCO 3.3.3.2 The Alternate Shutdown System Functions shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each Function.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more required 

Functions inoperable.

A.1 Restore required Function 

to OPERABLE status.

30 days

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.3.3.2.1 Perform CHANNEL CHECK for each required 

instrumentation channel that is normally energized.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.3.2.2 Verify each required control circuit and transfer 

switch is capable of performing the intended 

function.

In accordance with 

the Surveillance 

Frequency Control 

Program
Alternate Shutdown System

3.3.3.2

Monticello 3.3.3.2-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each 

required instrumentation channel.

In accordance with 

the Surveillance 

Frequency Control 

Program
ATWS-RPT Instrumentation 

3.3.4.1 

Monticello 3.3.4.1-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.4.1 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) 

Instrumentation 

LCO 3.3.4.1 Two channels per trip system for each ATWS-RPT instrumentation 

Function listed below shall be OPERABLE: 

 a. Reactor Vessel Water Level - Low Low; and 

 b. Reactor Vessel Steam Dome Pressure - High. 

APPLICABILITY: MODE 1. 

ACTIONS 

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

Separate Condition entry is allowed for each channel. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more channels 

inoperable. 

A.1 Restore channel to 

OPERABLE status. 

OR 

14 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

 
ATWS-RPT Instrumentation 

3.3.4.1 

Monticello 3.3.4.1-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

 

A.2 ---------------NOTE-------------- 

 Not applicable if inoperable 

channel is the result of an 

inoperable breaker. 

 ------------------------------------- 

 Place channel in trip. 14 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. One Function with 

ATWS-RPT trip 

capability not 

maintained. 

B.1 Restore ATWS-RPT trip 

capability. 

72 hours 

C. Both Functions with 

ATWS-RPT trip 

capability not 

maintained. 

C.1 Restore ATWS-RPT trip 

capability for one Function. 

1 hour 

D. Required Action and 

associated Completion 

Time not met. 

D.1 ---------------NOTE-------------- 

 Only applicable if 

inoperable channel is the 

result of an inoperable 

breaker. 

 ------------------------------------- 

 Remove the affected 

recirculation pump from 

service. 

OR 

D.2 Be in MODE 2. 

6 hours 

6 hours 
ATWS-RPT Instrumentation 

3.3.4.1 

Monticello 3.3.4.1-3 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

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

When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 

6 hours provided the associated Function maintains ATWS-RPT trip capability. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY 

SR 3.3.4.1.1 --------------------------------NOTE------------------------------- 

 Not required for the time delay portion of the 

Reactor Vessel Water Level - Low Low Function. 

----------------------------------------------------------------------- 

Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.4.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.4.1.3 Calibrate the trip units. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.4.1.4 Perform CHANNEL CALIBRATION of Reactor 

Vessel Water Level - Low Low time delay relays. 

The Allowable Value shall be ≥ 6 seconds and 

≤ 8.6 seconds. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
ATWS-RPT Instrumentation 

3.3.4.1 

Monticello 3.3.4.1-4 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.4.1.5 Perform CHANNEL CALIBRATION. The Allowable 

Values shall be: 

a. Reactor Vessel Water Level – Low Low 

≥ -48 inches; and 

b. Reactor Vessel Steam Dome Pressure - High 

≤ 1155 psig. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.4.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST 

including breaker actuation. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
3.3 INSTRUMENTATION 

3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation 

ECCS Instrumentation 

3.3.5.1 

LCO 3.3.5.1 The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be 

OPERABLE. 

APPLICABILITY: According to Table 3.3.5.1-1. 

ACTIONS 

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

Separate Condition entry is allowed for each channel. 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more channels A.1 Enter the Condition Immediately 

inoperable. referenced in 

Table 3.3.5.1-1 for the 

channel. 

B. As required by Required B.1 --------------NOTE-------------

Action A.1 and Only applicable for 

referenced in Functions 1.a, 1.b, 2.a, 2.b, 

Table 3.3.5.1-1. 2.f, 2.h, and 2.k. 

-------------------------------------

Declare supported 1 hour from discovery 

feature(s) inoperable when of loss of initiation 

its redundant feature ECCS capability for 

initiation capability is feature(s) in both 

inoperable. divisions 

AND 

Monticello 3.3.5.1-1 Amendment No. 44e, 198 I 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B.2 ---------------NOTE-------------- 

 Only applicable for 

Functions 3.a and 3.b. 

 ------------------------------------- 

 Declare High Pressure 

Coolant Injection (HPCI) 

System inoperable. 

AND 

B.3 Place channel in trip. 

1 hour from discovery 

of loss of HPCI 

initiation capability 

24 hours 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1. 

C.1 --------------NOTE------------- 

 Only applicable for 

 Functions 1.c, 1.d, 1.e, 1.f, 

 2.c, 2.d, 2.e, 2.i, 2.j, 2.l, 

 and 2.m. 

 ------------------------------------- 

 Declare supported 

feature(s) inoperable when 

its redundant feature ECCS 

initiation capability is 

inoperable. 

AND 

1 hour from discovery 

of loss of initiation 

capability for 

feature(s) in both 

divisions 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-3 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

 

C.2 Restore channel to 

OPERABLE status. 

24 hours 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1. 

D.1 ---------------NOTE-------------- 

 Only applicable if HPCI 

pump suction is not aligned 

to the suppression pool. 

 ------------------------------------- 

 Declare HPCI System 

inoperable. 

AND 

D.2.1 Place channel in trip. 

 OR 

1 hour from discovery 

of loss of HPCI 

initiation capability 

24 hours 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-4 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

 

D.2.2 Align the HPCI pump 

suction to the suppression 

pool. 

24 hours 

E. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1. 

E.1 --------------NOTE------------- 

 Only applicable for 

 Function 2.g. 

 ------------------------------------ 

 Declare supported 

feature(s) inoperable when 

its redundant feature 

ECCS initiation capability is 

inoperable. 

AND 

E.2 Restore channel to 

OPERABLE status. 

1 hour from discovery 

of loss of initiation 

capability for 

subsystems in both 

divisions 

7 days 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-5 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

F. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1. 

F.1 Declare Automatic 

Depressurization System 

(ADS) valves inoperable. 

AND 

F.2 Place channel in trip. 

1 hour from discovery 

of loss of ADS 

initiation capability in 

both trip systems 

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

Risk Informed 

Completion Time 

Program not 

applicable to loss of 

function. 

----------------------------- 

96 hours or in 

accordance with 

the Risk Informed 

Completion Time 

Program from 

discovery of 

inoperable channel 

concurrent with HPCI 

or reactor core 

isolation cooling 

(RCIC) inoperable 

AND 

8 days or in 

accordance with 

the Risk Informed 

Completion Time 

Program 

G. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.1-1. 

G.1 Declare ADS valves 

inoperable. 

AND 

1 hour from discovery 

of loss of ADS 

initiation capability in 

both trip systems 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-6 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

 

G.2 Restore channel to 

OPERABLE status. 

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

Risk Informed 

Completion Time 

Program not 

applicable to loss of 

function. 

----------------------------- 

96 hours or in 

accordance with 

the Risk Informed 

Completion Time 

Program from 

discovery of 

inoperable channel 

concurrent with HPCI 

or RCIC inoperable 

AND 

8 days or in 

accordance with 

the Risk Informed 

Completion Time 

Program 

H. Required Action and 

associated Completion 

Time of Condition B, C, 

D, E, F, or G not met. 

H.1 Declare associated 

supported feature(s) 

inoperable. 

Immediately 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-7 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

-----------------------------------------------------------NOTES---------------------------------------------------------- 

1. Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function. 

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed as 

follows: (a) for up to 6 hours for Functions 3.c and 3.f; and (b) for up to 6 hours for 

Functions other than 3.c and 3.f provided the associated Function or the redundant 

Function maintains ECCS initiation capability. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY 

SR 3.3.5.1.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.3 Calibrate the trip unit. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.5 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.6 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-8 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.5.1.7 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.8 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.5.1.9 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-9 Amendment No. 206 

Table 3.3.5.1-1 (page 1 of 6) 

Emergency Core Cooling System Instrumentation 

FUNCTION 

APPLICABLE 

MODES 

OR OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER 

FUNCTION 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 1. Core Spray System 

 a. Reactor Vessel 

Water Level - Low 

Low 

1, 2, 3 4(a) B SR 3.3.5.1.1 

SR 3.3.5.1.2 

SR 3.3.5.1.3 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 -48 inches 

 b. Drywell Pressure - 

High 

1, 2, 3 4(a) B SR 3.3.5.1.2 

SR 3.3.5.1.4 

SR 3.3.5.1.8 

 2 psig 

 c. Reactor Steam 

Dome Pressure - 

Low (Injection 

Permissive) 

1, 2, 3 2 C SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 397 psig and 

 440 psig 

 d. Reactor Steam 

Dome Pressure 

Permissive - Low 

(Pump Permissive) 

1, 2, 3 2 C SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 397 psig 

 e. Reactor Steam 

Dome Pressure 

Permissive - Bypass 

Timer (Pump 

Permissive) 

1, 2, 3 2 C SR 3.3.5.1.7 

SR 3.3.5.1.8 

 18 minutes 

(a) Also required to initiate the associated emergency diesel generator (EDG). 

(b) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 

as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before 

returning the channel to service. 

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the nominal trip 

setpoint; otherwise, the channel shall be declared inoperable. The nominal trip setpoint and the methodology 

used to determine the as-found tolerance and the as-left tolerance are specified in the Technical Requirements 

Manual (TRM). 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-10 Amendment No. 206 

Table 3.3.5.1-1 (page 2 of 6) 

Emergency Core Cooling System Instrumentation 

FUNCTION 

APPLICABLE 

MODES 

OR OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER 

FUNCTION 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 1. Core Spray System 

 f. Core Spray Pump 

Start - Time Delay 

Relay 

1, 2, 3 1 per pump C SR 3.3.5.1.7 

SR 3.3.5.1.8 

 15.86 

seconds 

 2. Low Pressure Coolant 

Injection (LPCI) System 

 

 a. Reactor Vessel 

Water Level - Low 

Low 

1, 2, 3 4 B SR 3.3.5.1.1 

SR 3.3.5.1.2 

SR 3.3.5.1.3 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 -48 inches 

 b. Drywell Pressure - 

High 

1, 2, 3 4 B SR 3.3.5.1.2 

SR 3.3.5.1.4 

SR 3.3.5.1.8 

 2 psig 

 c. Reactor Steam 

Dome Pressure - 

Low (Injection 

Permissive) 

1, 2, 3 2 C SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 397 psig and 

 440 psig 

 d. Reactor Steam 

Dome Pressure 

Permissive - Low 

(Pump Permissive) 

1, 2, 3 2 C SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 397 psig 

 

(b) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 

as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before 

returning the channel to service. 

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the nominal trip 

setpoint; otherwise, the channel shall be declared inoperable. The nominal trip setpoint and the methodology 

used to determine the as-found tolerance and the as-left tolerance are specified in the TRM. 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-11 Amendment No. 206 

Table 3.3.5.1-1 (page 3 of 6) 

Emergency Core Cooling System Instrumentation 

FUNCTION 

APPLICABLE 

MODES 

OR OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER 

FUNCTION 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 2. LPCI System 

 e. Reactor Steam 

Dome Pressure 

Permissive - Bypass 

Timer (Pump 

Permissive)

1, 2, 3 2 C SR 3.3.5.1.7 

SR 3.3.5.1.8 

 18 minutes 

 f. Low Pressure 

Coolant Injection 

Pump Start - Time 

Delay Relay 

1, 2, 3 4 per pump B SR 3.3.5.1.7 

SR 3.3.5.1.8 

 Pumps A, B 

 

 5.33 seconds 

 Pumps C, D 

 

 10.59 seconds 

 g. Low Pressure 

Coolant Injection 

Pump Discharge 

Flow - Low (Bypass) 

1, 2, 3 1 per pump E SR 3.3.5.1.2 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 360 gpm and 

 745 gpm 

 h. Reactor Steam 

Dome Pressure - 

Low (Break 

Detection) 

1, 2, 3 4 B SR 3.3.5.1.2 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 873.6 psig 

and 

 923.4 psig 

 i. Recirculation Pump 

Differential Pressure 

- High (Break 

Detection) 

1, 2, 3 4 per pump C SR 3.3.5.1.2 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 63.5 inches 

wc 

 j. Recirculation Riser 

Differential Pressure 

- High (Break 

Detection) 

1, 2, 3 4 C SR 3.3.5.1.2 

SR 3.3.5.1.7(b)(c)

SR 3.3.5.1.8 

 100.0 inches 

wc 

 

(b) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 

as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before 

returning the channel to service. 

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the nominal trip 

setpoint; otherwise, the channel shall be declared inoperable. The nominal trip setpoint and the methodology 

used to determine the as-found tolerance and the as-left tolerance are specified in the TRM. 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-12 Amendment No. 206 

Table 3.3.5.1-1 (page 4 of 6) 

Emergency Core Cooling System Instrumentation 

FUNCTION 

APPLICABLE 

MODES 

OR OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER 

FUNCTION 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 2. LPCI System 

 k. Reactor Steam 

Dome Pressure - 

Time Delay Relay 

(Break Detection) 

1, 2, 3 2 B SR 3.3.5.1.7 

SR 3.3.5.1.8 

SR 3.3.5.1.9 

 2.97 seconds 

 l. Recirculation Pump 

Differential Pressure 

- Time Delay Relay 

(Break Detection) 

1, 2, 3 2 C SR 3.3.5.1.7 

SR 3.3.5.1.8 

SR 3.3.5.1.9 

 0.75 seconds 

 m. Recirculation Riser 

Differential Pressure 

- Time Delay Relay 

(Break Detection) 

1, 2, 3 2 C SR 3.3.5.1.7 

SR 3.3.5.1.8 

SR 3.3.5.1.9 

 0.75 seconds 

 3. High Pressure Coolant 

Injection (HPCI) System 

 a. Reactor Vessel 

Water Level - Low 

Low 

1, 2(d), 3(d) 4 B SR 3.3.5.1.1 

SR 3.3.5.1.2 

SR 3.3.5.1.3 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 -48 inches 

 b. Drywell Pressure - 

High 

1, 2(d), 3(d) 4 B SR 3.3.5.1.2 

SR 3.3.5.1.4 

SR 3.3.5.1.8 

 2 psig 

 c. Reactor Vessel 

Water Level - High 

1, 2(d), 3(d) 2 C SR 3.3.5.1.1 

SR 3.3.5.1.2 

SR 3.3.5.1.3 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 48 inches 

 d. Condensate Storage 

Tank Level - Low 

1, 2(d), 3(d) 2 D SR 3.3.5.1.7 

SR 3.3.5.1.8 

 29.3 inches 

 e. Suppression Pool 

Water Level - High 

1, 2(d), 3(d) 2 D SR 3.3.5.1.5 

SR 3.3.5.1.6 

SR 3.3.5.1.8 

 3.0 inches 

 f. High Pressure 

Coolant Injection 

Pump Discharge 

Flow - Low (Bypass) 

1, 2(d), 3(d) 1 E SR 3.3.5.1.5 

SR 3.3.5.1.6 

SR 3.3.5.1.8 

 362 gpm and 

 849 gpm 

 

(d) With reactor steam dome pressure > 150 psig. 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-13 Amendment No. 206 

Table 3.3.5.1-1 (page 5 of 6) 

Emergency Core Cooling System Instrumentation 

FUNCTION 

APPLICABLE 

MODES 

OR OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER 

FUNCTION 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 4. Automatic 

Depressurization System 

(ADS) Trip System A 

 a. Reactor Vessel 

Water Level - Low 

Low 

1, 2(d), 3(d) 2 F SR 3.3.5.1.1 

SR 3.3.5.1.2 

SR 3.3.5.1.3 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 -48 inches 

 b. Automatic 

Depressurization 

System Initiation 

Timer

1, 2(d), 3(d) 1 G SR 3.3.5.1.7 

SR 3.3.5.1.8 

 120 seconds 

 c. Core Spray Pump 

Discharge Pressure 

- High 

1, 2(d), 3(d) 2 G SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 75 psig and 

 125 psig 

 d. Low Pressure 

Coolant Injection 

Pump Discharge 

Pressure - High 

1, 2(d), 3(d) 4 G SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 75 psig and 

 125 psig 

 5. ADS Trip System B 

 a. Reactor Vessel 

Water Level - Low 

Low 

1, 2(d), 3(d) 2 F SR 3.3.5.1.1 

SR 3.3.5.1.2 

SR 3.3.5.1.3 

SR 3.3.5.1.7 

SR 3.3.5.1.8 

 -48 inches 

 b. Automatic 

Depressurization 

System Initiation 

Timer 

1, 2(d), 3(d) 1 G SR 3.3.5.1.7 

SR 3.3.5.1.8 

 120 seconds 

 

(b) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 

as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before 

returning the channel to service. 

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the nominal trip 

setpoint; otherwise, the channel shall be declared inoperable. The nominal trip setpoint and the methodology 

used to determine the as-found tolerance and the as-left tolerance are specified in the TRM. 

(d) With reactor steam dome pressure > 150 psig. 
ECCS Instrumentation 

3.3.5.1 

Monticello 3.3.5.1-14 Amendment No. 206 

Table 3.3.5.1-1 (page 6 of 6) 

Emergency Core Cooling System Instrumentation 

FUNCTION 

APPLICABLE 

MODES 

OR OTHER 

SPECIFIED 

CONDITIONS 

REQUIRED 

CHANNELS 

PER 

FUNCTION 

CONDITIONS 

REFERENCED 

FROM 

REQUIRED 

ACTION A.1 

SURVEILLANCE 

REQUIREMENTS 

ALLOWABLE 

VALUE 

 5. ADS Trip System B 

 c. Core Spray Pump 

Discharge Pressure 

- High 

1, 2(d), 3(d) 2 G SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 75 psig and 

 125 psig 

 d. Low Pressure 

Coolant Injection 

Pump Discharge 

Pressure - High 

1, 2(d), 3(d) 4 G SR 3.3.5.1.2 

SR 3.3.5.1.4(b)(c)

SR 3.3.5.1.8 

 75 psig and 

 125 psig 

 

(b) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 

as-found tolerance, then the channel shall be evaluated to verify that it is functioning as required before 

returning the channel to service. 

(c) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the nominal trip 

setpoint; otherwise, the channel shall be declared inoperable. The nominal trip setpoint and the methodology 

used to determine the as-found tolerance and the as-left tolerance are specified in the TRM. 

(d) With reactor steam dome pressure > 150 psig. 
RCIC System Instrumentation 

3.3.5.2 

Monticello 3.3.5.2-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation 

LCO 3.3.5.2 The RCIC System instrumentation for each Function in Table 3.3.5.2-1 

shall be OPERABLE. 

APPLICABILITY: MODE 1, 

MODES 2 and 3 with reactor steam dome pressure > 150 psig. 

ACTIONS 

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

Separate Condition entry is allowed for each channel. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more channels 

inoperable. 

A.1 Enter the Condition 

referenced in 

Table 3.3.5.2-1 for the 

channel. 

Immediately 

B. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1. 

B.1 Declare RCIC System 

inoperable. 

AND 

B.2 Place channel in trip. 

1 hour from discovery 

of loss of RCIC 

initiation capability 

24 hours 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 
RCIC System Instrumentation 

3.3.5.2 

Monticello 3.3.5.2-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

C. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1. 

C.1 Restore channel to 

OPERABLE status. 

24 hours 

D. As required by Required 

Action A.1 and 

referenced in 

Table 3.3.5.2-1. 

D.1 ---------------NOTE------------- 

 Only applicable if RCIC 

pump suction is not aligned 

to the suppression pool. 

 ------------------------------------ 

 Declare RCIC System 

inoperable. 

AND 

D.2.1 Place channel in trip. 

 OR 

D.2.2 Align RCIC pump suction 

to the suppression pool. 

1 hour from discovery 

of loss of RCIC 

initiation capability 

24 hours 

OR 

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

Not applicable when 

a loss of function 

occurs. 

---------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 

24 hours 

E. Required Action and 

associated Completion 

Time of Condition B, C, 

or D not met. 

E.1 Declare RCIC System 

inoperable. 

Immediately 
RCIC System Instrumentation

3.3.5.2

Monticello 3.3.5.2-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.5.2-1 to determine which SRs apply for each RCIC Function.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed as 

follows: (a) for up to 6 hours for Function 2; and (b) for up to 6 hours for Functions 1 and 3 

provided the associated Function maintains RCIC initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.5.2.3 Calibrate the trip units. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
RCIC System Instrumentation

3.3.5.2

Table 3.3.5.2-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrumentation

CONDITIONS

REQUIRED REFERENCED

CHANNELS FROM

PER REQUIRED SURVEILLANCE ALLOWABLE

FUNCTION FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water Level - Low 4 8 SR 3.3.5.2.1 > -48 inches

Low SR 3.3.5.2.2

SR 3.3.5.2.3

SR 3.3.5.2.4

SR 3.3.5.2.5

2. Reactor Vessel Water Level - High 2 C SR 3.3.5.2.1 < 48 inches

SR 3.3.5.2.2

SR 3.3.5.2.3

SR 3.3.5.2.4

SIR 3.3.5.2.5

3. Condensate Storage Tank Level - 2 D SR 3.3.5.2.4 _ 29.3 inches

Low SR 3.3.5.2.5

Monticello 3.3.5.2-4 Amendment No. 146
RPV Water Inventory Control Instrumentation

3.3.5.3

Monticello 3.3.5.3-1 Amendment No. 205

3.3 INSTRUMENTATION

3.3.5.3 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation 

LCO 3.3.5.3 The RPV Water Inventory Control instrumentation for each Function in 

Table 3.3.5.3-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.3-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more channels 

inoperable.

A.1 Initiate action to place 

channel in trip.

OR

A.2.1 Declare associated 

penetration flow path(s) 

incapable of automatic 

isolation.

AND

 

A.2.2 Initiate action to calculate

DRAIN TIME.

Immediately

Immediately

Immediately
RPV Water Inventory Control Instrumentation

3.3.5.3

Monticello 3.3.5.3-2 Amendment No. 205 

SURVEILLANCE REQUIREMENTS

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

These SRs apply to each Function in Table 3.3.5.3-1. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.5.3.1 Perform CHANNEL CHECK. In accordance 

with the 

Surveillance 

Frequency 

Control Program

SR 3.3.5.3.2 Perform CHANNEL FUNCTIONAL TEST. In accordance 

with the 

Surveillance 

Frequency 

Control Program
RPV Water Inventory Control Instrumentation

3.3.5.3

Monticello 3.3.5.3-3 Amendment No. 205

Table 3.3.5.3-1 (page 1 of 1) 

RPV Water Inventory Control Instrumentation 

FUNCTION

APPLICABLE

MODES

OR OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS

PER

FUNCTION

ALLOWABLE

VALUE

1. Shutdown Cooling 

System Isolation

 a. Reactor Vessel 

Water Level - Low 

(b) 2 in one trip 

system

≥ 7 inches

2. Reactor Water Cleanup 

(RWCU) System 

Isolation

 a. Reactor Vessel 

Water Level - Low 

Low

(b) 2 in one trip 

system

≥ -48 inches

(a) (Deleted) 

(b) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME. 
Primary Containment Isolation Instrumentation 

3.3.6.1 

Monticello 3.3.6.1-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.6.1 Primary Containment Isolation Instrumentation 

LCO 3.3.6.1 The primary containment isolation instrumentation for each Function in 

Table 3.3.6.1-1 shall be OPERABLE. 

APPLICABILITY: According to Table 3.3.6.1-1. 

ACTIONS 

-----------------------------------------------------------NOTES---------------------------------------------------------- 

1. Penetration flow paths may be unisolated intermittently under administrative controls. 

2. Separate Condition entry is allowed for each channel. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more required 

channels inoperable. 

A.1 Place channel in trip. 12 hours or in 

accordance with 

the Risk Informed 

Completion Time 

Program for 

Functions 2.a, 2.b, 

5.c, 6.b, 7.a, and 7.b 

AND 

24 hours or in 

accordance with 

the Risk Informed 

Completion Time 

Program for 

Functions other than 

Functions 2.a, 2.b, 

5.c, 6.b, 7.a, and 7.b 

B. One or more Functions 

with primary 

containment isolation 

capability not 

maintained. 

B.1 Restore primary 

containment isolation 

capability. 

1 hour 
Primary Containment Isolation Instrumentation 

3.3.6.1 

Monticello 3.3.6.1-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

C. Required Action and 

associated Completion 

Time of Condition A 

or B not met. 

C.1 Enter the Condition 

referenced in 

Table 3.3.6.1-1 for the 

channel. 

Immediately 

D. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1. 

D.1 Isolate associated main 

steam line (MSL). 

OR 

D.2.1 Be in MODE 3. 

 AND 

D.2.2 Be in MODE 4. 

12 hours 

12 hours 

36 hours 

E. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1. 

E.1 Be in MODE 2. 6 hours 

F. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1. 

F.1 Isolate the affected 

penetration flow path(s). 

1 hour 

G. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1. 

G.1 Isolate the affected 

penetration flow path(s). 

24 hours 

H. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1. 

H.1 Declare associated 

standby liquid control 

(SLC) subsystem 

inoperable. 

OR 

H.2 Isolate the Reactor Water 

Cleanup System. 

1 hour 

1 hour 
Primary Containment Isolation Instrumentation

3.3.6.1

Monticello 3.3.6.1-3 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

I. As required by Required 

Action C.1 and 

referenced in 

Table 3.3.6.1-1.

I.1 Initiate action to restore 

channel to OPERABLE 

status.

Immediately

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.6.1-1 to determine which SRs apply for each Primary Containment 

Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for 

up to 6 hours provided the associated Function maintains primary containment isolation 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.1.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.1.3 Calibrate the trip unit. In accordance with 

the Surveillance 

Frequency Control 

Program
Primary Containment Isolation Instrumentation

3.3.6.1

Monticello 3.3.6.1-4 Amendment No. 200 

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
Primary Containment Isolation Instrumentation 

3.3.6.1 

Table 3.3.6.1-1 (page 1 of 3) 

Primary Containment Isolation Instrumentation 

APPLICABLE CONDITIONS 

MODES OR REQUIRED REFERENCED 

OTHER CHANNELS FROM 

SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE 

FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 

1. Main Steam Line 

Isolation 

a. Reactor Vessel 1, 2, 3 2 D SR 3.3.6.1.1 ~ -48 inches 

Water Level - Low SR 3.3.6.1.2 

Low SR 3.3.6.1.3 

SR 3.3.6.1.5 

SR 3.3.6.1.6 

b. Main Steam Line 2 E SR 3.3.6.1.2 ~ 815 psig 

Pressure - Low SR 3.3.6.1.4 

SR 3.3.6.1.6 

c. Main Steam Line 1, 2, 3 2 per D SR 3.3.6.1.1 ~ 116.9% rated 

Flow- High MSL SR 3.3.6.1.2 steam flow 

SR 3.3.6.1.4 

SR 3.3.6.1.6 

d. Main Steam Line 1, 2, 3 2 per trip D SR 3.3.6.1.5 ~ 209°F 

Tunnel string SR 3.3.6.1.6 

Temperature- High 

2. Primary Containment 

Isolation 

a. Reactor Vessel "1, 2, 3 2 F SR 3.3.6.1.1 ~ 7 inches 

Water Level - Low SR 3.3.6.1.2 

SR 3.3.6.1.3 

SR 3.3.6.1.5 

SR 3.3.6.1.6 

b. Drywell Pressure - 1, 2, 3 2 F SR 3.3.6.1.2 ~ 2.0 psig 

High SR 3.3.6.1.4 

SR 3.3.6.1.6 

3. High Pressure Coolant 

Injection (HPCI) System 

Isolation 

a. HPCI Steam Line 1, 2, 3 2 F SR 3.3.6.1.2 ~ 300,000 

Flow- High SR 3.3.6.1.4 lb/hour with 

SR 3.3.6.1.6 ~ 5.58 second 

time delay 

Monticello 3.3.6.1-5 Amendment No. 449, 176 
Primary Containment Isolation Instrumentation

3.3.6.1

Table 3.3.6.1-1 (page 2 of 3)

Primary Containment Isolation Instrumentation

APPLICABLE CONDITIONS

MODES OR REQUIRED REFERENCED

OTHER CHANNELS FROM

SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE

FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

3. HPCI System Isolation

b. HPCI Steam Supply

Line Pressure - Low

c. HPCI Steam Line

Area Temperature -

High

4. Reactor Core Isolation

Cooling (RCIC) System

Isolation

a. RCIC Steam Line

Flow - High

b. RCIC Steam Supply

Line Pressure - Low

c. RCIC Steam Line

Area Temperature -

High

5. Reactor Water Cleanup

(RWCU) System

Isolation

a. RWCU Flow - High

1,2,3

1,2,3

4

16

F SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

95.5 psig

F SR 3.3.6.1.2 _< 196°F

SR 3.3.6.1.4

SR 3.3.6.1.6

1,2,3

1,2,3

1,2,3

2

4

16

F

F

F

SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

SR 3.3.6.1.2

SR 3.3.6.1.4

SR 3.3.6.1.6

_< 45,903 lb/hour

with

< 7.16 second

time delay

> 54 psig

< 196oF

1,2,3 2 F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.3

SR 3.3.6.1.5

SR 3.3.6.1.6

F SR 3.3.6.1.1

SR 3.3.6.1.2

SR 3.3.6.1.3

SR 3.3.6.1.5

SR 3.3.6.1.6

5 500 gpm with

< 11.4 second

time delay

b. RWCU Room

Temperature - High

c. Drywell Pressure -

High

1,2,3

1,2,3

2

2

_< 188 0F

F SR 3.3.6.1.2 :5 2.0 psig

SR 3.3.6.1.4

SR 3.3.6.1.6

Monticello 3.3.6.1-6 Amendment No. 146
Primary Containment Isolation Instrumentation 

3.3.6.1 

Table 3.3.6.1-1 (page 3 of 3) 

Primary Containment Isolation Instrumentation 

APPLICABLE CONDITIONS 

MODES OR REQUIRED REFERENCED 

OTHER CHANNELS FROM 

SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE 

FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE 

5. RWCU System Isolation 

d. SLC System 1,2,3 1 H SR 3.3.6.1.6 NA 

Initiation 

e. Reactor Vessel 1, 2, 3 2 F SR 3.3.6.1.1 ~ -48 inches 

Water Level - Low SR 3.3.6.1.2 

Low SR 3.3.6.1.3 

SR 3.3.6.1.5 

SR 3.3.6.1.6 

6. Shutdown Cooling 

System Isolation 

a. Reactor Steam 1, 2, 3 2 F SR 3.3.6.1.2 ~ 81.8 psig 

Dome Pressure - SR 3.3.6.1.4 

High SR 3.3.6.1.6 

b. Reactor Vessel 3 2 SR 3.3.6.1.1 ~ 7 inches 

Water Level - Low SR 3.3.6.1.2 

SR 3.3.6.1.3 

SR 3.3.6.1.5 

SR 3.3.6.1.6 

7. Traversing lncore Probe 

System Isolation 

a. Reactor Vessel 1, 2, 3 2 G SR 3.3.6.1.1 ~ 7 inches 

Water Level - Low SR 3.3.6.1.2 

SR 3.3.6.1.3 

SR 3.3.6.1.5 

SR 3.3.6.1.6 

b. Drywell Pressure - 1, 2, 3 2 G SR 3.3.6.1.2 ~ 2.0 psig 

High SR 3.3.6.1.4 

SR 3.3.6.1.6 

Monticello 3.3.6.1-7 Amendment No. 146, 164, 198 I 
Secondary Containment Isolation Instrumentation

3.3.6.2

3.3 INSTRUMENTATION

3.3.6.2 Secondary Containment Isolation Instrumentation

LCO 3.3.6.2

APPLICABILITY:

The secondary containment isolation instrumentation for each Function in

Table 3.3.6.2-1 shall be OPERABLE.

According to Table 3.3.6.2-1.

ACTIONS

------------------------------------------------------------ N( r ------------------------------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more channels A.1 Place channel in trip. 12 hours for

inoperable. Functions 1 and 2

AND

24 hours for

Functions other than

Functions 1 and 2

B. One or more Functions B.1 Restore secondary 1 hour

with. secondary. containment isolation

containment isolation capability.

capability not

maintained.

C. Required Action and C.1.1 Isolate the associated 1 hour

associated Completion penetration flow path(s).

Time not met.

OR

C.1.2 Declare associated 1 hour

secondary containment

isolation valves inoperable.

AND

Monticello 3.3.6.2-1 Amendment No. 146
Secondary Containment Isolation Instrumentation

3.3.6.2

Monticello 3.3.6.2-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2.1 Place the associated 

standby gas treatment 

(SGT) subsystem in 

operation.

 OR

C.2.2 Declare associated SGT 

subsystem inoperable.

1 hour

1 hour

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.6.2-1 to determine which SRs apply for each Secondary Containment 

Isolation Function.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for 

up to 6 hours provided the associated Function maintains secondary containment isolation 

capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.2.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.2.3 Calibrate the trip unit. In accordance with 

the Surveillance 

Frequency Control 

Program
Secondary Containment Isolation Instrumentation

3.3.6.2

Monticello 3.3.6.2-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.2.5 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.2.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
Secondary Containment Isolation Instrumentation

3.3.6.2

Monticello 3.3.6.2-4 Amendment No. 200

Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation

FUNCTION

APPLICABLE

MODES OR 

OTHER 

SPECIFIED 

CONDITIONS

REQUIRED 

CHANNELS

PER

TRIP 

SYSTEM

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Reactor Vessel Water Level - Low 

Low

1, 2, 3 2 SR 3.3.6.2.1

SR 3.3.6.2.2

SR 3.3.6.2.3

SR 3.3.6.2.5

SR 3.3.6.2.6

≥ -48 inches

2. Drywell Pressure - High 1, 2, 3 2 SR 3.3.6.2.2

SR 3.3.6.2.4

SR 3.3.6.2.6

≤ 2 psig

3. Reactor Building Ventilation Exhaust 

Radiation - High

1, 2, 3, (a) 2 SR 3.3.6.2.1

SR 3.3.6.2.2

SR 3.3.6.2.4

SR 3.3.6.2.6

≤ 100 mR/hr

4. Refueling Floor Radiation - High 1, 2, 3, (a) 2 SR 3.3.6.2.1

SR 3.3.6.2.2

SR 3.3.6.2.4

SR 3.3.6.2.6

≤ 100 mR/hr

(a) During movement of recently irradiated fuel assemblies in secondary containment.
LLS Instrumentation

3.3.6.3

3.3 INSTRUMENTATION

3.3.6.3 Low-Low Set (LLS) Instrumentation

LCO 3.3.6.3

APPLICABILITY:

The LLS valve instrumentation for each Function in Table 3.3.6.3-1 shall

be OPERABLE.

MODES 1, 2, and 3.

ACTIONS

S ----------------------- NO r- -- ý - - -- - ----------------------------- ---------

Separate Condition entry is allowed for each LLS valve.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more LLS valves A.1 Declare associated LLS 1 hour from discovery

with one or more valve inoperable, of loss of LLS valve

channels inoperable, initiation capability in

both trip systems

AND

A.2 Restore channel(s) to 72 hours

OPERABLE status.

B. Required Action and B.1 Declare the associated LLS Immediately

associated Completion valve(s) inoperable.

Time not met.

Monticello 3. 3y.6. 3- 1 Amendment No. 146
LLS Instrumentation

3.3.6.3

Monticello 3.3.6.3-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.6.3-1 to determine which SRs apply for each Function.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for 

up to 6 hours provided the associated Function maintains LLS initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.6.3.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.3.2 --------------------------------NOTE-------------------------------

For Function 1, only required to be performed prior 

to entering MODE 2 or 3 from MODE 4.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.3.3 Calibrate the trip unit. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.3.4 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.6.3.5 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program
LLS Instrumentation

3.3.6.3

Monticello 3.3.6.3-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.6.3.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
LLS Instrumentation

3.3.6.3

Monticello 3.3.6.3-4 Amendment No. 200

Table 3.3.6.3-1 (page 1 of 1)

Low-Low Set Instrumentation

FUNCTION

REQUIRED

CHANNELS PER 

FUNCTION

SURVEILLANCE

REQUIREMENTS

ALLOWABLE

VALUE

1. Reactor Scram Detection 4 per LLS valve SR 3.3.6.3.2

SR 3.3.6.3.6

NA

2. Low-Low Set Pressure Setpoints 4 per LLS valve SR 3.3.6.3.1

SR 3.3.6.3.2

SR 3.3.6.3.3

SR 3.3.6.3.5

SR 3.3.6.3.6

Low:

 Open ≤ 1066 psig

 Close ≤ 986 psig

Medium:

 Open ≤ 1076 psig

 Close ≤ 996 psig

High:

 Open ≤ 1086 psig

 Close ≤ 1006 psig

3. Tailpipe Pressure Switch 4 per LLS valve SR 3.3.6.3.1

SR 3.3.6.3.2

SR 3.3.6.3.5

SR 3.3.6.3.6

≥ 27 psid and 

≤ 33 psid

4. Inhibit Timers 4 per LLS valve SR 3.3.6.3.2

SR 3.3.6.3.4

SR 3.3.6.3.6

≥ 8 seconds and 

≤ 12 seconds
CREF System Instrumentation

3.3.7.1

3.3 INSTRUMENTATION

3.3.7.1 Control Room Emergency Filtration (CREF) System Instrumentation

LCO 3.3.7.1

APPLICABILITY:

The CREF System instrumentation for each Function in Table 3.3.7.1-1

shall be OPERABLE.

According to Table 3.3.7.1-1

ACTIONS

------- ---------- - ---- ---- ---------- ----------- Ik i t'•Vrl"! - ----------- - --- -------- -----

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more channels A.1 Declare associated CREF 1 hour from discovery

inoperable, subsystem inoperable, of loss of CREF

initiation capability in

AND both trip systems

A.2 Place channel in trip. 12 hours

B. Required Action and B.1 Place the associated CREF 1 hour

associated Completion subsystem in the

Time not met. pressurization mode of

operation.

OR

B.2 Declare associated CREF 1 hour

subsystem inoperable.

Monticello 3.3.7.1-1 Amendment No. 446, 148
CREF System Instrumentation

3.3.7.1

Monticello 3.3.7.1-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREF System Function.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for up 

to 6 hours provided the associated Function maintains CREF System initiation capability.

-----------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.7.1.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.7.1.3 Calibrate the trip unit. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.7.1.5 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.7.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
Table 3.3.7.1-1 (Page 1 of 1) 

CREF System Instrumentation 

3.3.7.1 

Control Room Emergency Filtration System Instrumentation 

APPLICABLE REQUIRED 

MODES OR CHANNELS 

OTHER PER 

SPECIFIED TRIP SURVEILLANCE ALLOWABLE 

FUNCTION CONDITIONS SYSTEM REQUIREMENTS VALUE 

1. Reactor Vessel Water 1,2,3 2 SR 3.3.7.1.1 ;;,; -48 inches 

Level - Low Low SR 3.3.7.1.2 

SR 3.3.7.1.3 

SR 3.3.7.1.5 

SR 3.3.7.1.6 

2. Drywell Pressure - 1, 2, 3 2 SR 3.3.7.1.2 s 2 psig 

High SR 3.3.7.1.4 

SR 3.3.7.1.6 

3. Reactor Building 1, 2, 3, (a) 2 SR 3.3.7.1.1 s 100 mR/hr 

Ventilation Exhaust SR 3.3.7.1.2 

Radiation - High SR 3.3.7.1.4 

SR 3.3.7.1.6 

4. Refueling Floor 1, 2, 3, (a) 2 SR 3.3.7.1.1 s 100 mR/hr 

Radiation - High SR 3.3.7.1.2 

SR 3.3.7.1.4 

SR 3.3.7.1.6 

(a) During movement of recently irradiated fuel assemblies in the secondary containment. 

Monticello 3.3.7.1-3 Amendment No. 14e 148, 198 I 
Mechanical Vacuum Pump Isolation Instrumentation 

3.3.7.2 

Monticello 3.3.7.2-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.7.2 Mechanical Vacuum Pump Isolation Instrumentation 

LCO 3.3.7.2 Four channels of the Main Steam Line Tunnel Radiation – High Function 

for the mechanical vacuum pump isolation shall be OPERABLE. 

APPLICABILITY: MODES 1 and 2 with the mechanical vacuum pump in service and any 

main steam line not isolated. 

ACTIONS 

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

Separate Condition entry is allowed for each channel. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more channels

inoperable.

A.1 Restore channel to 

OPERABLE status. 

OR 

A.2 --------------NOTE--------------- 

Not applicable if inoperable 

channel is the result of an 

inoperable mechanical 

vacuum pump breaker or 

isolation valve. 

------------------------------------- 

Place channel in trip.

12 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

12 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
Mechanical Vacuum Pump Isolation Instrumentation 

3.3.7.2 

Monticello 3.3.7.2-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B. Mechanical vacuum 

pump isolation capability 

not maintained. 

B.1 Restore mechanical vacuum 

pump isolation capability 

1 hour 

C. Required Action and 

associated Completion 

Time not met. 

C.1 Isolate the mechanical 

vacuum pump. 

OR 

C.2 Isolate the main steam lines. 

OR 

C.3 Be in MODE 3. 

12 hours 

12 hours 

12 hours 

SURVEILLANCE REQUIREMENTS 

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

When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 

6 hours provided the associated Function maintains mechanical vacuum pump isolation 

capability. 

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY 

SR 3.3.7.2.1 Perform CHANNEL CHECK. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.7.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program 
Mechanical Vacuum Pump Isolation Instrumentation 

3.3.7.2 

Monticello 3.3.7.2-3 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.3.7.2.3 Perform CHANNEL CALIBRATION. The Allowable 

Value Shall be ≤ 6.9 R/hour. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.3.7.2.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, 

including mechanical vacuum pump breaker and 

isolation valves actuation. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
LOP Instrumentation 

3.3.8.1 

Monticello 3.3.8.1-1 Amendment No. 206 

3.3 INSTRUMENTATION 

3.3.8.1 Loss of Power (LOP) Instrumentation 

LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be 

OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3 

 

ACTIONS 

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

Separate Condition entry is allowed for each channel. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more channels 

inoperable. 

A.1 Place channel in trip. 1 hour 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Required Action and 

associated Completion 

Time not met. 

B.1 Declare associated EDG 

inoperable. 

Immediately 
LOP Instrumentation

3.3.8.1

Monticello 3.3.8.1-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

-----------------------------------------------------------NOTES----------------------------------------------------------

1. Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Instrumentation 

Function.

2. When a channel is placed in an inoperable status solely for performance of required 

Surveillances, entry into associated Conditions and Required Actions may be delayed for 

up to 2 hours provided the associated Function maintains EDG initiation capability.

-------------------------------------------------------------------------------------------------------------------------------

SURVEILLANCE FREQUENCY

SR 3.3.8.1.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.8.1.2 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
LOP Instrumentation

3.3.8.1

Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation

FUNCTION

1. 4.16 kV Essential Bus Loss of Voltage

2. 4.16 kV Essential Bus Degraded

Voltage

a. Bus Undervoltage

b. Time Delay

REQUIRED

CHANNELS

PER BUS

4

SURVEILLANCE

REQUIREMENTS

SR 3.3.8.1.1

SR 3.3.8.1.3

SR 3.3.8.1.4

ALLOWABLE

VALUE

>2345 V and• 2905 V

_>3913 V and• 3927 V

Žt 8.8 seconds and

•5 9.2 seconds

3

3

SR 3.3.8.1.1

SR 3.3.8.1.2

SR 3.3.8.1.4

SR 3.3.8.1.1

SR 3.3.8.1.2

SR 3.3.8.1.4

Monticello 3.3.8.1-3 Amendment No. 446,147
RPS Electric Power Monitoring 

3.3.8.2 

3.3 INSTRUMENTATION 

3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring 

LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for 

each inservice RPS motor generator set or alternate power supply. 

APPLICABILITY: MODES 1, 2, and 3, 

MODES 4 and 5 with residual heat removal (RHR) shutdown cooling 

supply isolation valves open, 

MODE 5 with any control rod withdrawn from a core cell containing one or 

more fuel assemblies, 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or both inservice A.1 Remove associated 72 hours 

power supplies with one inservice power supply(s) 

electric power from service. 

monitoring assembly 

inoperable. 

B. One or both inservice B.1 Remove associated 1 hour 

power supplies with both inservice power supply(s) 

electric power from service. 

monitoring assemblies 

inoperable. 

C. Required Action and C. 1 Be in MODE 3. 12 hours 

associated Completion 

Time of Condition A or B AND 

not met in MODE 1, 2, 

or 3. C.2 Be in MODE 4. 36 hours 

Monticello 3.3.8.2-1 Amendment No. 44&,- 198 I 
ACTIONS (continued) 

CONDITION 

D. Required Action and D.1 

associated Completion 

Time of Condition A or B 

not met in MODE 4 or 5 

with RHR shutdown 

cooling supply isolation 

valves open. 

OR 

D.2 

E. Required Action and E.1 

associated Completion 

Time of Condition A or B 

not met in MODE 5 with 

any control rod 

withdrawn from a core 

cell containing one or 

more fuel assemblies. 

F. Required Action and F.1.1 

associated Completion 

Time of Condition A or B 

not met during 

movement of recently OR 

irradiated fuel 

assemblies in the F.1.2 

secondary containment. 

AND 

F.2.1 

OR 

Monticello 

RPS Electric Power Monitoring 

3.3.8.2 

REQUIRED ACTION COMPLETION TIME 

Initiate action to restore one Immediately 

electric power monitoring 

assembly to OPERABLE 

status for inservice power 

supply(s) supplying 

required instrumentation. 

Initiate action to isolate the Immediately 

RHR Shutdown Cooling 

System. 

Initiate action to fully insert Immediately 

all insertable control rods in 

core cells containing one or 

more fuel assemblies. 

Isolate the associated Immediately 

secondary containment 

penetration flow path(s). 

Declare the associated Immediately 

secondary containment 

isolation valve(s) 

inoperable. 

Place the associated Immediately 

standby gas treatment 

(SGT) subsystem(s) in 

operation. 

3.3.8.2-2 Amendment No. 449, 198 I 
RPS Electric Power Monitoring

3.3.8.2

Monticello 3.3.8.2-3 Amendment No. 200 

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F.2.2 Declare associated SGT 

subsystem(s) inoperable.

AND

F.3.1 Place the associated 

control room emergency 

filtration (CREF) 

subsystem(s) in operation.

 OR

F.3.2 Declare associated CREF 

subsystem(s) inoperable.

Immediately

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.3.8.2.1 Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable 

Values shall be:

a. Overvoltage ≤ 128 V;

b. Undervoltage ≥ 104 V; and

c. Underfrequency ≥ 57 Hz.

In accordance with 

the Surveillance 

Frequency Control 

Program
RPS Electric Power Monitoring

3.3.8.2

Monticello 3.3.8.2-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.3.8.2.3 Perform CHANNEL CALIBRATION of each 

Overvoltage, Undervoltage, and Underfrequency 

time delay relay. The Allowable Value shall be 

≤ 4 seconds.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.3.8.2.4 Perform a system functional test. In accordance with 

the Surveillance 

Frequency Control 

Program
Recirculation Loops Operating 

3.4.1 

3.4 REACTOR COOLANT SYSTEM (RCS) 

3.4.1 Recirculation Loops Operating 

LCO 3.4.1 Two recirculation loops with matched flows shall be in operation. 

One recirculation loop may be in operation provided the plant is not 

operating in the Extended Flow Window domain defined in the COLR and 

provided the following limits are applied when the associated LCO is 

applicable: 

a. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION 

RATE (APLHGR)," single loop operation limits specified in the 

COLR; 

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," single 

loop operation limits specified in the COLR; and 

c. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation," 

Function 2.b (Average Power Range Monitor Simulated Thermal 

Power - High), Allowable Value of Table 3.3.1.1-1 is reset for single 

loop operation. 

APPLICABILITY: MODES 1 and 2. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. Requirements of the A.1 Satisfy the requirements of 24 hours 

LCO not met. the LCO. 

B. Required Action and B.1 Be in MODE 3. 12 hours 

associated Completion 

Time of Condition A not 

met. 

OR 

No recirculation loops in 

operation. 

Monticello 3.4.1-1 Amendment No. 146, 159, 180, 191 
Recirculation Loops Operating

3.4.1

Monticello 3.4.1-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.1.1 --------------------------------NOTE-------------------------------

Not required to be performed until 24 hours after 

both recirculation loops are in operation.

-----------------------------------------------------------------------

Verify jet pump loop flow mismatch with both 

recirculation loops in operation is:

a. ≤ 10% of rated core flow when operating at 

< 70% of rated core flow; and

b. ≤ 5% of rated core flow when operating at 

≥ 70% of rated core flow.

In accordance with 

the Surveillance 

Frequency Control 

Program
Jet Pumps

3.4.2

Monticello 3.4.2-1 Amendment No. 200

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.2 Jet Pumps

LCO 3.4.2 All jet pumps shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more jet pumps 

inoperable.

A.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.2.1 -------------------------------NOTES------------------------------

1. Not required to be performed until 4 hours after 

associated recirculation loop is in operation.

2. Not required to be performed until 24 hours 

after > 25% RTP.

-----------------------------------------------------------------------

Verify at least one of the following criteria (a or b) is 

satisfied for each operating recirculation loop:

a. Recirculation pump flow to speed ratio differs by 

≤ 5% from established patterns, and jet pump 

loop flow to recirculation pump speed ratio 

differs by ≤ 5% from established patterns; or

b. Each jet pump diffuser to lower plenum 

differential pressure differs by ≤ 20% from 

established patterns.

In accordance with 

the Surveillance 

Frequency Control 

Program
S/RVs 

3.4.3 

Monticello 3.4.3-1 Amendment No. 206 

3.4 REACTOR COOLANT SYSTEM (RCS) 

3.4.3 Safety/Relief Valves (S/RVs) 

LCO 3.4.3 The safety function of seven S/RVs shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or two required 

S/RVs inoperable. 

A.1 Restore the required S/RVs 

to OPERABLE status. 

14 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Required Action and 

associated Completion 

Time of Condition A not 

met. 

OR 

Three or more required 

S/RVs inoperable. 

B.1 Be in MODE 3. 

AND 

B.2 Be in MODE 4. 

12 hours 

36 hours 
SURVEILLANCE REQUIREMENTS 

SR 3.4.3.1 

SR 3.4.3.2 

SURVEILLANCE 

Verify the safety function lift setpoints of the required 

S/RVs are 1109 ±. 33.2 psig. Following testing, lift 

settings shall be 1109 ±. 11.0 psig. 

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

Not required to be performed until 12 hours after 

reactor steam flow is adequate to perform the test. 

Verify each required S/RV is capable of being 

opened. 

S/RVs 

3.4.3 

FREQUENCY 

In accordance 

with the 

INSERVICE 

TESTING 

PROGRAM 

In accordance 

with the 

INSERVICE 

TESTING 

PROGRAM 

Monticello 3.4.3-2 Amendment No. 146, 168, 194 I 
RCS Operational LEAKAGE

3.4.4

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.4 RCS Operational LEAKAGE

LCO 3.4.4 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. _< 5gpm unidentified LEAKAGE;

c. < 25 gpm total LEAKAGE averaged over the previous 24 hour

period; and

d. 5 2 gpm increase in unidentified LEAKAGE within the previous

24 hour perind in .AMDE !.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Unidentified LEAKAGE A.1 Reduce LEAKAGE to within 4 hours

not within limit, limits.

OR

Total LEAKAGE not

within limit.

B. Unidentified LEAKAGE BA1 Reduce LEAKAGE to within 4 hours

increase not within limit, limits.

OR

B.2 Verify source of unidentified 4 hours

LEAKAGE increase is not

service sensitive type 304

or type 316 austenitic

stainless steel.

Monticello 3.4.4-1 Amendment No. 146
RCS Operational LEAKAGE

3.4.4

Monticello 3.4.4-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met.

OR

Pressure boundary 

LEAKAGE exists.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.4.1 Verify RCS unidentified and total LEAKAGE and 

unidentified LEAKAGE increases are within limits.

In accordance with 

the Surveillance 

Frequency Control 

Program
RCS Leakage Detection Instrumentation

3.4.5

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.5

LCO 3.4.5

RCS Leakage Detection Instrumentation

The following RCS leakage detection instrumentation shall be

OPERABLE:

a. Either the drywell floor drain sump monitoring system or the drywell

equipment drain sump monitoring system with the drywell floor drain

sump overflowing to the drywell equipment drain sump; and

b. Drywell particulate radioactivity monitoring system.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. LCO 3.4.5.a not met. A.1 -- -- NOTE-----

LCO 3.0.4.c is applicable.

Satisfy the requirements of 30 days

LCO 3.4.5.a.

B. Drywell particulate B.1 Analyze grab samples of Once per 12 hours

radioactivity monitoring primary containment

system inoperable, atmosphere.

C. All required leakage C.1 Satisfy the requirements of 1 hour

detection systems LCO 3.4.5.a.

inoperable.

OR

C.2 Restore drywell particulate 1 hour

radioactivity monitoring

system to OPERABLE

status.

Monticello 3.4.5-1 Amendment No. 146
RCS Leakage Detection Instrumentation

3.4.5

Monticello 3.4.5-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time not met.

D.1 Be in MODE 3.

AND

D.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.5.1 Perform a CHANNEL CHECK of required leakage 

detection instrumentation.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.4.5.2 Perform a CHANNEL FUNCTIONAL TEST of the 

drywell particulate radioactivity monitoring system 

and the flow instrumentation of the required drywell 

drain sump monitoring system.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.4.5.3 Perform a CHANNEL CALIBRATION of required 

leakage detection instrumentation.

In accordance with 

the Surveillance 

Frequency Control 

Program
RCS Specific Activity

3.4.6

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.6 RCS Specific Activity

LCO 3.4.6

APPLICABILITY:

The specific activity of the reactor coolant shall be limited to DOSE

EQUIVALENT 1-131 specific activity _< 0.2 ACi/gm.

MODE 1,

MODES 2 and 3 with any main steam line not isolated.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Reactor coolant specific ----.-.-.--------- NOTE -..--------

activity > 0.2 itCi/gm and LCO 3.0.4.c is applicable.

< 2.0 pCi/gm DOSE

EQUIVALENT 1-131.

A.1 Determine DOSE Once per 4 hours

EQUIVALENT 1-131.

AND

A.2 Restore DOSE 48 hours

EQUIVALENT 1-131 to

within limits.

B. Required Action and B.1 Determine DOSE Once per 4 hours

associated Completion EQUIVALENT 1-131.

Time of Condition A not

met. AND

OR B.2.1 Isolate all main steam lines. 12 hours

Reactor Coolant specific OR

activity > 2.0 p.Ci/gm

DOSE EQUIVALENT B.2.2.1 Be in MODE 3. 12 hours

1-131.

AND

B.2.2.2 Be in MODE 4. 36 hours

I

Monticello 3.4.6-1 Amendment No. 446, 148
RCS Specific Activity

3.4.6

Monticello 3.4.6-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.6.1 --------------------------------NOTE-------------------------------

Only required to be performed in MODE 1.

-----------------------------------------------------------------------

Verify reactor coolant DOSE EQUIVALENT I-131 

specific activity is ≤ 0.2 μCi/gm.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHR Shutdown Cooling System - Hot Shutdown

3.4.7

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.7 Residual Heat Removal (RHR) Shutdown Cooling System - Hot Shutdown

Two RHR shutdown cooling subsystems shall be OPERABLE, and, with

no recirculation pump in operation, at least one RHR shutdown cooling

subsystem shall be in operation.

LCO 3.4.7

-NOTES1. Both RHR shutdown cooling subsystems and recirculation pumps

may be removed from operation for up to 2 hours per 8 hour period.

2. One RHR shutdown cooling subsystem may be inoperable for up to

2 hours for the performance of Surveillances.

APPLICABILITY: MODE 3 with reactor steam dome pressure less than the RHR shutdown

cooling supply isolation interlock.

ACTIONS

-------------------- NOTE -------------------- Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or two RHR A.1 Initiate action to restore Immediately

shutdown cooling RHR shutdown cooling

subsystems inoperable, subsystem(s) to

OPERABLE status.

AND

A.2 Verify an alternate method 1 hour

of decay heat removal is

available for each

inoperable RHR shutdown

cooling subsystem.

AND

A.3 Be in MODE 4. 24 hours

Monticello 3.4.7-1 Amendment No. 146
RHR Shutdown Cooling System - Hot Shutdown

3.4.7

Monticello 3.4.7-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B. No RHR shutdown 

cooling subsystem in 

operation.

AND

No recirculation pump in 

operation.

B.1 Initiate action to restore one 

RHR shutdown cooling 

subsystem or one 

recirculation pump to 

operation.

AND

B.2 Verify reactor coolant 

circulation by an alternate 

method.

AND

B.3 Monitor reactor coolant 

temperature and pressure.

Immediately

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per 12 hours 

thereafter

Once per hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.7.1 --------------------------------NOTE-------------------------------

Not required to be met until 2 hours after reactor 

steam dome pressure is less than the RHR 

shutdown cooling supply isolation interlock.

-----------------------------------------------------------------------

Verify one RHR shutdown cooling subsystem or 

recirculation pump is operating.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHR Shutdown Cooling System - Hot Shutdown

3.4.7

Monticello 3.4.7-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.4.7.2 --------------------------------NOTE-------------------------------

Not required to be performed until 12 hours after 

reactor steam dome pressure is less than the RHR 

shutdown cooling supply isolation interlock.

-----------------------------------------------------------------------

Verify RHR shutdown cooling subsystem locations 

susceptible to gas accumulation are sufficiently filled 

with water.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHR Shutdown Cooling System - Cold Shutdown

. 3.4.8

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.8 Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown

LCO 3.4.8 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with

no recirculation pump in operation, at least one RHR shutdown cooling

subsystem shall be in operation.

| J I L-.. ,- -I - - --

1. Both RHR shutdown cooling subsystems and recirculation pumps

may be removed from operation for up to 2 hours per 8 hour period.

2. One RHR shutdown cooling subsystem may be inoperable for up to

2 hours for the performance of Surveillances.

APPLICABILITY: MODEý 4.

ACTIONS

-- NOTE .....-------------

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or two RHR A.1 Verify an alternate method 1 hour

shutdown cooling of decay heat removal is

subsystems inoperable, available for each AND

inoperable RHR shutdown

cooling subsystem. Once per 24 hours

thereafter

B. No RHR shutdown B.1 Verify reactor coolant 1 hour from discovery

cooling subsystem in circulating by an alternate of no reactor coolant

operation. method. circulation

AND AND

No recirculation pump in Once per 12 hours

operation. thereafter

AND

Monticello 3.4.8-1 Amendment No. 146
RHR Shutdown Cooling System - Cold Shutdown

3.4.8

Monticello 3.4.8-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2 Monitor reactor coolant 

temperature and pressure.

Once per hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.8.1 Verify one RHR shutdown cooling subsystem or 

recirculation pump is operating.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.4.8.2 Verify RHR shutdown cooling subsystem locations 

susceptible to gas accumulation are sufficiently filled 

with water.

In accordance with 

the Surveillance 

Frequency Control 

Program
RCS PIT Limits 

3.4.9 

3.4 REACTOR COOLANT SYSTEM (RCS) 

3.4.9 RCS Pressure and Temperature (PIT) Limits 

LCO 3.4.9 	 RCS pressure, RCS temperature, RCS heatup and cooldown rates, and 

the recirculation pump starting temperature requirements shall be 

maintained within the limits specified in the PTLR. 

APPLICABILITY: 	 At all times. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. ------------NOTE------------

Required Action A.2 

shall be completed if this 

Condition is entered. 

-_.........------------------_.._-------

A.1 

AND 

Restore parameter(s) to 

within limits. 

30 minutes 

Requirements of the 

LCO not met in 

MODE 1, 2, or 3. 

A.2 Determine RCS is 

acceptable for continued 

operation. 

72 hours 

B. Required Action and 

associated Completion 

Time of Condition A not 

met. 

8.1 

AND 

Be in MODE 3. 12 hours 

B.2 Be in MODE 4. 36 hours 

C. ------------NOTE------------

Required Action C.2 

shall be completed if this 

Condition is entered. ... _... __........... _----------------------

Requirements of the 

LCO not met in other 

than MODES 1, 2, 

and 3. 

C.1 

AND 

C.2 

Initiate action to restore 

parameter(s) to within 

limits. 

Determine RCS is 

acceptable for operation. 

Immediately 

Prior to entering 

MODE 2 or 3 

Monticello 	 3.4.9-1 Amendment No. 446, 172 
RCS P/T Limits

3.4.9

Monticello 3.4.9-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.9.1 ------------------------------NOTE--------------------------------

Only required to be performed during RCS 

heatup and cooldown operations and RCS 

inservice leak and hydrostatic testing.

------------------------------------------------------------------------

Verify:

a. RCS pressure and RCS temperature are within 

the applicable limits specified in the PTLR; and

b. RCS heatup and cooldown rates are within the 

the limits specified in the PTLR.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.4.9.2 Verify RCS pressure and RCS temperature are 

within the criticality limits specified in the PTLR.

Once within 

15 minutes prior 

to control rod 

withdrawal for the 

purpose of 

achieving 

criticality

SR 3.4.9.3 --------------------------------NOTE-------------------------------

Only required to be met in MODES 1, 2, 3, and 4 

during recirculation pump startup.

------------------------------------------------------------------------

Verify the difference between the reactor coolant 

temperature in the recirculation loop to be started 

and the RPV coolant temperature is within the limits 

specified in the PTLR.

Once within 

15 minutes prior 

to each startup of 

a recirculation 

pump

SR 3.4.9.4 --------------------------------NOTE-------------------------------

Only required to be performed when tensioning the 

reactor vessel head bolting studs.

------------------------------------------------------------------------

Verify reactor vessel flange and head flange 

temperature are within the limits specified in the 

PTLR.

In accordance with 

the Surveillance 

Frequency Control 

Program
RCS P/T Limits

3.4.9

Monticello 3.4.9-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.4.9.5 --------------------------------NOTE-------------------------------

Not required to be performed until 30 minutes after 

RCS temperature ≤ 80°F in MODE 4.

-----------------------------------------------------------------------

Verify reactor vessel flange and head flange 

temperatures are within the limits specified in the 

PTLR.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.4.9.6 --------------------------------NOTE-------------------------------

Not required to be performed until 12 hours after 

RCS temperature ≤ 100°F in MODE 4.

-----------------------------------------------------------------------

Verify reactor vessel flange and head flange 

temperatures are within the limits specified in the 

PTLR.

In accordance with 

the Surveillance 

Frequency Control 

Program
Reactor Steam Dome Pressure

3.4.10

Monticello 3.4.10-1 Amendment No. 200

3.4 REACTOR COOLANT SYSTEM (RCS)

3.4.10 Reactor Steam Dome Pressure

LCO 3.4.10 The reactor steam dome pressure shall be ≤ 1025.3 psig.

APPLICABILITY: MODES 1 and 2.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Reactor steam dome 

pressure not within limit.

A.1 Restore reactor steam 

dome pressure to within 

limit.

15 minutes

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3. 12 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.4.10.1 Verify reactor steam dome pressure is 

≤ 1025.3 psig. 

In accordance with 

the Surveillance 

Frequency Control 

Program
ECCS - Operating 

3.5.1 

Monticello 3.5.1-1 Amendment No. 206 

3.5 EMERGENCY CORE COOLING SYSTEM (ECCS), RPV WATER INVENTORY 

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 

3.5.1 ECCS - Operating 

LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic 

Depressurization System (ADS) function of three safety/relief valves shall 

be OPERABLE. 

APPLICABILITY: MODE 1, 

MODES 2 and 3, except high pressure coolant injection (HPCI) and ADS 

valves are not required to be OPERABLE with reactor steam dome 

pressure  150 psig. 

ACTIONS 

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

LCO 3.0.4.b is not applicable to HPCI. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One LPCI pump 

inoperable. 

A.1 Restore LPCI pump to 

OPERABLE status. 

30 days 

B. One LPCI subsystem 

inoperable for reasons 

other than Condition A. 

 OR 

 One Core Spray 

subsystem inoperable. 

B.1 Restore low pressure 

ECCS injection/spray 

subsystem to OPERABLE 

status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

C. One LPCI pump in both 

LPCI subsystems 

inoperable. 

C.1 Restore one LPCI pump to 

OPERABLE status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

D. Two LPCI subsystems 

inoperable for reasons 

other than Condition C 

or G. 

D.1 Restore one LPCI 

subsystem to OPERABLE 

status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

E. One Core Spray 

subsystem inoperable. 

 AND 

 One LPCI subsystem 

inoperable. 

OR 

 One or two LPCI 

pump(s) inoperable. 

E.1 Restore Core Spray 

subsystem to OPERABLE 

status. 

OR 

E.2 Restore LPCI subsystem to 

OPERABLE status. 

OR 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-3 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

E.3 Restore LPCI pump(s) to 

OPERABLE status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

F. Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, or E not met. 

F.1 Be in MODE 3. 

AND 

F.2 Be in MODE 4. 

12 hours 

36 hours 

G. Two LPCI subsystems 

inoperable due to open 

RHR intertie return line 

isolation valve(s). 

G.1 Isolate the RHR intertie 

line. 

18 hours 

H. Required Action and 

associated Completion 

Time of Condition G not 

met. 

H.1 Be in MODE 2. 6 hours 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-4 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

I. HPCI System 

inoperable. 

I.1 Verify by administrative 

means RCIC System is 

OPERABLE. 

AND 

I.2 Restore HPCI System to 

OPERABLE status. 

Immediately 

14 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

J. HPCI System 

inoperable. 

 AND 

 Condition A, B, or C 

entered. 

J.1 Restore HPCI System to 

OPERABLE status. 

OR 

J.2 Restore low pressure 

ECCS injection/spray 

subsystem(s) to 

OPERABLE status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

K. One ADS valve 

inoperable. 

K.1 Restore ADS valve to 

OPERABLE status. 

14 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-5 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

L. Required Action and 

associated Completion 

Time of Condition I, J, 

or K not met. 

 OR 

 One ADS valve 

inoperable and 

Condition A, B, C, D, or 

G entered. 

 OR 

 Two or more ADS valves 

inoperable. 

 OR 

 HPCI System inoperable 

and Condition D, E, or G 

entered. 

L.1 Be in MODE 3. 

AND 

L.2 Reduce reactor steam 

dome pressure to 

 150 psig. 

12 hours 

36 hours 

M. Two or more low 

pressure ECCS 

injection/spray 

subsystems inoperable 

for reasons other than 

Condition C, D, E, or G. 

 OR 

 HPCI System and one or 

more ADS valves 

inoperable. 

M.1 Enter LCO 3.0.3. Immediately 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-6 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, 

locations susceptible to gas accumulation are 

sufficiently filled with water. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.2 --------------------------------NOTE------------------------------- 

Not required to be met for system vent flow paths 

opened under administrative control. 

------------------------------------------------------------------------ 

Verify each ECCS injection/spray subsystem 

manual, power operated, and automatic valves in the 

flow path, that is not locked, sealed, or otherwise 

secured in position, is in the correct position. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.3 Verify ADS pneumatic pressure is as follows for 

each required ADS pneumatic supply: 

a. S/RV Accumulator Bank header pressure 

≥ 88.3 psig; and 

b. Alternate Nitrogen System pressure is 

≥ 1060 psig. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.4 --------------------------------NOTE------------------------------- 

Only required to be met in MODE 1. 

------------------------------------------------------------------------ 

Verify the RHR System intertie return line isolation 

valves are closed. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.5 Verify correct breaker alignment to the LPCI swing 

bus. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-7 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.5.1.6 Verify each recirculation pump discharge valve 

cycles through one complete cycle of full travel or is 

de-energized in the closed position. 

In accordance with 

the INSERVICE 

TESTING 

PROGRAM 

SR 3.5.1.7 Verify the following ECCS pumps develop the 

specified flow rate against a system head 

corresponding to the specified reactor to 

containment pressure. 

System Flow Rate 

No. of 

Pumps 

System Head 

Corresponding 

to a Reactor to 

Containment 

Pressure of

Core 

Spray ≥ 2835 gpm 1 ≥ 130 psi 

LPCI ≥ 3870 gpm 1 ≥ 20 psi 

In accordance with 

the INSERVICE 

TESTING 

PROGRAM 

SR 3.5.1.8 --------------------------------NOTE------------------------------- 

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test. 

------------------------------------------------------------------------ 

Verify, with reactor steam dome pressure 

≤ 1025.3 psig and ≥ 950 psig, the HPCI pump can 

develop a flow rate ≥ 2700 gpm against a system 

head corresponding to reactor pressure. 

In accordance with 

the INSERVICE 

TESTING 

PROGRAM 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-8 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.5.1.9 --------------------------------NOTE------------------------------- 

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test. 

------------------------------------------------------------------------ 

Verify, with reactor pressure ≤ 165 psig, the HPCI 

pump can develop a flow rate ≥ 2700 gpm against a 

system head corresponding to reactor pressure. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.10 --------------------------------NOTE------------------------------- 

Vessel injection/spray may be excluded. 

------------------------------------------------------------------------ 

Verify each ECCS injection/spray subsystem 

actuates on an actual or simulated automatic 

initiation signal. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.11 --------------------------------NOTE------------------------------- 

Valve actuation may be excluded. 

------------------------------------------------------------------------ 

Verify the ADS actuates on an actual or simulated 

automatic initiation signal. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.5.1.12 --------------------------------NOTE------------------------------- 

Not required to be performed until 12 hours after 

reactor steam flow is adequate to perform the test. 

------------------------------------------------------------------------ 

Verify each ADS valve is capable of being opened. In accordance with 

the INSERVICE 

TESTING 

PROGRAM 
ECCS - Operating 

3.5.1 

Monticello 3.5.1-9 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.5.1.13 Verify automatic transfer capability of the LPCI 

swing bus power supply from the normal source to 

the backup source. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
RPV Water Inventory Control 

3.5.2 

3.5 EMERGENCY CORE COOLING SYSTEM (ECCS), RPV WATER INVENTORY 

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 

3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control 

LCO 3.5.2 DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall 

be ~ 36 hours. 

One low pressure ECCS injection/spray subsystem shall be OPERABLE. 

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

A Low Pressure Coolant Injection (LPCI) subsystem may be considered 

OPERABLE during alignment and operation for decay heat removal if 

capable of being manually realigned and not otherwise inoperable. 

APPLICABILITY: MODES 4 and 5 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. Required ECCS A.1 Restore required ECCS 4 hours 

injection/spray injection/spray subsystem 

subsystem inoperable. to OPERABLE status. 

B. Required Action and B.1 Initiate action to establish a Immediately 

associated Completion method of water injection 

Time of Condition A not capable of operating 

met. without offsite electrical 

power. 

C. DRAIN TIME< 36 hours C.1 Verify secondary 4 hours 

and ~ 8 hours. containment boundary is 

capable of being 

established in less than the 

DRAIN TIME. 

AND 

Monticello 3.5.2-1 Amendment No. 446, 198 I 
RPV Water Inventory Control

3.5.2

Monticello 3.5.2-2 Amendment No. 205

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C.2 Verify each secondary 

containment penetration 

flow path is capable of 

being isolated in less than 

the DRAIN TIME.

AND

C.3 Verify one standby gas 

treatment (SGT) 

subsystem is capable of 

being placed in operation

in less than the DRAIN 

TIME.

4 hours

4 hours 

D. DRAIN TIME < 8 hours. D.1 ----------- NOTE ---------------

 Required ECCS 

injection/spray subsystem 

or additional method of 

water injection shall be 

capable of operating 

without offsite electrical 

power.

 ------------------------------------

 Initiate action to establish 

an additional method of 

water injection with water 

sources capable of 

maintaining RPV water 

level > TAF for ≥ 36 hours.

AND

D.2 Initiate action to restore 

secondary containment 

boundary.

AND

Immediately

Immediately
RPV Water Inventory Control

3.5.2

Monticello 3.5.2-3 Amendment No. 205 

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D.3 Initiate action to isolate 

each secondary 

containment penetration 

flow path or verify it can be 

manually isolated from the 

control room. 

AND

D.4 Initiate action to verify one 

SGT subsystem is capable 

of being placed in 

operation.

Immediately

Immediately

E. Required Action and 

associated Completion 

Time of Condition C or 

D not met.

OR

DRAIN TIME < 1 hour.

E.1 Initiate action to restore 

DRAIN TIME to ≥ 36 hours. 

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.5.2.1 Verify, for the required ECCS injection/spray 

subsystem, the:

a. Suppression pool water level is ≥ -3 ft; or

b. Condensate storage tank(s) water level is 

≥ 7 ft for one tank operation and ≥ 4 ft for two 

tank operation.

In accordance 

with the 

Surveillance 

Frequency 

Control Program
RPV Water Inventory Control

3.5.2

Monticello 3.5.2-4 Amendment No. 205

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.2.2 Verify, for the required ECCS injection/spray 

subsystem, locations susceptible to gas 

accumulation are sufficiently filled with water. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program

SR 3.5.2.3 (Not Used)

SR 3.5.2.4 ------------------------------NOTES-----------------------------

1. Operation may be through the test return line. 

2. Credit may be taken for normal system 

operation to satisfy this SR.

---------------------------------------------------------------------

Operate the required ECCS injection/spray 

subsystem for ≥ 10 minutes.

In accordance 

with the 

Surveillance 

Frequency 

Control Program

SR 3.5.2.5 -------------------------------NOTE------------------------------

Vessel injection/spray may be excluded.

---------------------------------------------------------------------

Verify the required ECCS injection/spray subsystem 

can be manually operated. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program

SR 3.5.2.6 Verify each valve credited for automatically isolating 

a penetration flow path actuates to the isolation 

position on an actual or simulated isolation signal.

In accordance 

with the 

Surveillance 

Frequency 

Control Program
RPV Water Inventory Control

3.5.2

Monticello 3.5.2-5 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.2.7 Verify DRAIN TIME ≥ 36 hours. In accordance 

with the 

Surveillance 

Frequency 

Control Program
RCIC System 

 3.5.3 

Monticello 3.5.3-1 Amendment No. 206 

3.5 EMERGENCY CORE COOLING SYSTEM (ECCS), RPV WATER INVENTORY 

CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 

3.5.3 RCIC System 

LCO 3.5.3 The RCIC System shall be OPERABLE. 

APPLICABILITY: MODE 1, 

MODES 2 and 3 with reactor steam dome pressure > 150 psig. 

ACTIONS 

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

LCO 3.0.4.b is not applicable to the RCIC System. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. RCIC System 

inoperable. 

A.1 Verify by administrative 

means High Pressure 

Coolant Injection System is 

OPERABLE. 

AND 

A.2 Restore RCIC System to 

OPERABLE status. 

Immediately 

14 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Required Action and 

associated Completion 

Time not met. 

B.1 Be in MODE 3. 

AND 

B.2 Reduce reactor steam 

dome pressure to 

 150 psig. 

12 hours 

36 hours 
RCIC System

3.5.3

Monticello 3.5.3-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.5.3.1 --------------------------------NOTE-------------------------------

Not required to be met for system vent flow paths 

opened under administrative control.

------------------------------------------------------------------------

Verify each RCIC System manual, power operated, 

and automatic valve in the flow path, that is not 

locked, sealed, or otherwise secured in position, is 

in the correct position.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.5.3.2 --------------------------------NOTE-------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

------------------------------------------------------------------------

Verify, with reactor pressure ≤ 1025.3 psig and 

≥ 950 psig, the RCIC pump can develop a flow rate 

≥ 400 gpm against a system head corresponding to 

reactor pressure. 

In accordance with 

the INSERVICE 

TESTING 

PROGRAM

SR 3.5.3.3 --------------------------------NOTE-------------------------------

Not required to be performed until 12 hours after 

reactor steam pressure and flow are adequate to 

perform the test.

------------------------------------------------------------------------

Verify, with reactor pressure ≤ 165 psig, the RCIC 

pump can develop a flow rate ≥ 400 gpm against a 

system head corresponding to reactor pressure. 

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.5.3.4 --------------------------------NOTE-------------------------------

Vessel injection may be excluded.

------------------------------------------------------------------------

Verify the RCIC System actuates on an actual or 

simulated automatic initiation signal. 

In accordance with 

the Surveillance 

Frequency Control 

Program
RCIC System

3.5.3

Monticello 3.5.3-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.5.3.5 Verify the RCIC System locations susceptible to gas 

accumulation are sufficiently filled with water. 

In accordance with 

the Surveillance 

Frequency Control 

Program
Primary Containment

3.6.1.1

3.6 CONTAINMENT SYSTEMS

3.6.1.1 Primary Containment

LCO 3.6.1-.1

APPLICABILITY:

Primary containment shall be OPERABLE.

MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Primary containment A.1 Restore primary 1 hour

inoperable, containment to OPERABLE

status.

B. Required Action and B.1 Be in MODE 3. 12 hours

associated Completion

Time not met. AND

B.2 Be in MODE 4. 36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.1.1 Perform required visual examinations and leakage In accordance

rate testing except for primary containment air lock with the Primary

testing, in accordance with the Primary Containment Containment

Leakage Rate Testing Program. Leakage Rate

Testing Program

Monticello 3.6.1..1-1 Amendment No. 146
Primary Containment

3.6.1.1

Monticello 3.6.1.1-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.1.2 Verify drywell to suppression chamber bypass 

leakage is less than that equivalent to a one inch 

diameter orifice.

In accordance with 

the Surveillance 

Frequency Control 

Program

AND

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

Only required 

after two 

consecutive tests 

fail and continues 

until two 

consecutive tests 

pass

-------------------------

12 months
Primary Containment Air Lock

3.6.1.2

3.6 CONTAINMENT SYSTEMS

3.6.1.2 Primary Containment Air Lock

LCO 3.6.1.2

APPLICABILITY:

The primary containment air lock shall be OPERABLE.

MODES 1, 2, and 3.

ACTIONS h•.i ,•T*I-- C'• ----------------------------------------------------- -- ,M I In -----------------------------------------------------------

1. Entry and exit is permissible to perform repairs of the air lock components.

2. Enter applicable Conditions qnd Requ1itired Artinns of L_(CO1 ' R * 1 "Primann Containment,"

when air lock leakage results in exceeding overall primary containment leakage rate

acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One primary -- - -NOTES ---------

containment air lock 1. Required Actions A.1, A.2,

door inoperable, and A.3 are not applicable if both

doors in the air lock are

inoperable and Condition C is

entered.

2. Entry and exit is permissible for

7 days under administrative

controls.

A.1 Verify the OPERABLE door 1 hour

is closed.

AND

A.2 Lock the OPERABLE door 24 hours

closed.

AND

Monticello 3.6.1.2-1 Amendment No. 146
Primary Containment Air Lock

316.1.2

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.3 ---------- NOTE ---------- •

Air lock doors in high

radiation areas or areas

with limited access due to

inerting may be verified

locked closed by

administrative means.

Verify the OPERABLE door Once per 31 days

is locked closed.

B. Primary containment air ------------- NOTES----------

lock interlock 1. Required Actions B.1, B.2,

mechanism inoperable, and B.3 are not applicable if both

doors in the air lock are

inoperable and Condition C is

entered.

2. Entry into and exit from

containment is permissible under

the control of a dedicated

individual.

B.1 Verify an OPERABLE door 1 hour

is closed.

AND

B.2 Lock an OPERABLE door 24 hours

closed.

AND

Monticello 3.6.1.2-2 Amendment No. 146
Primary Containment Air Lock 

3.6.1.2 

Monticello 3.6.1.2-3 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B.3 ---------------NOTE-------------- 

 Air lock doors in high 

radiation areas or areas 

with limited access due to 

inerting may be verified 

locked closed by 

administrative means. 

 ------------------------------------- 

 Verify an OPERABLE door 

is locked closed. 

Once per 31 days 

C. Primary containment air 

lock inoperable for 

reasons other than 

Condition A or B. 

C.1 Initiate action to evaluate 

primary containment overall 

leakage rate per 

LCO 3.6.1.1, using current 

air lock test results. 

AND 

C.2 Verify a door is closed. 

AND 

C.3 Restore air lock to 

OPERABLE status. 

Immediately 

1 hour 

24 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

D. Required Action and 

associated Completion 

Time not met. 

D.1 Be in MODE 3. 

AND 

D.2 Be in MODE 4. 

12 hours 

36 hours 
Primary Containment Air Lock

3.6.1.2

Monticello 3.6.1.2-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.2.1 -------------------------------NOTES------------------------------

1. An inoperable air lock door does not invalidate 

the previous successful performance of the 

overall air lock leakage test.

2. Results shall be evaluated against acceptance 

criteria applicable to SR 3.6.1.1.1.

------------------------------------------------------------------------

Perform required primary containment air lock 

leakage rate testing in accordance with the Primary 

Containment Leakage Rate Testing Program.

In accordance 

with the Primary 

Containment 

Leakage Rate 

Testing Program

SR 3.6.1.2.2 Verify only one door in the primary containment air 

lock can be opened at a time.

In accordance with 

the Surveillance 

Frequency Control 

Program
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-1 Amendment No. 206 

3.6 CONTAINMENT SYSTEMS 

3.6.1.3 Primary Containment Isolation Valves (PCIVs) 

LCO 3.6.1.3 Each PCIV, except reactor building-to-suppression chamber vacuum 

breakers, shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3 

 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-2 Amendment No. 206 

ACTIONS 

-----------------------------------------------------------NOTES---------------------------------------------------------- 

1. Penetration flow paths may be unisolated intermittently under administrative controls. 

2. Separate Condition entry is allowed for each penetration flow path. 

3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs. 

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment," 

when PCIV leakage results in exceeding overall containment leakage rate acceptance 

criteria. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. ------------NOTE------------ 

 Only applicable to 

penetration flow paths 

with two PCIVs. 

 -------------------------------- 

 One or more penetration 

flow paths with one 

PCIV inoperable for 

reasons other than 

Condition D or E. 

A.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

blind flange, or check valve 

with flow through the valve 

secured. 

AND 

4 hours except for 

main steam line 

 OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

AND 

8 hours for main 

steam line 

 OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-3 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

A.2 --------------NOTES------------ 

 1. Isolation devices in 

high radiation areas 

may be verified by use 

of administrative 

means. 

 2. Isolation devices that 

are locked, sealed, or 

otherwise secured may 

be verified by use of 

administrative means. 

 ------------------------------------ 

 Verify the affected 

penetration flow path is 

isolated. 

Once per 31 days 

following isolation for 

isolation devices 

outside primary 

containment 

AND 

Prior to entering 

MODE 2 or 3 from 

MODE 4 if primary 

containment was deinerted while in 

MODE 4, if not 

performed within the 

previous 92 days, for 

isolation devices 

inside primary 

containment 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-4 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B. ------------NOTE------------ 

 Only applicable to 

penetration flow paths 

with two PCIVs. 

 -------------------------------- 

 One or more 

penetration flow paths 

with two PCIVs 

inoperable for reasons 

other than Condition D 

or E. 

B.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual 

valve, or blind flange. 

1 hour 

C. ------------NOTE------------ 

 Only applicable to 

penetration flow paths 

with only one PCIV. 

 -------------------------------- 

 One or more 

penetration flow paths 

with one PCIV 

inoperable. 

C.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual 

valve, or blind flange. 

AND 

4 hours except for 

excess flow check 

valves (EFCVs) and 

penetrations with a 

closed system 

AND 

72 hours for EFCVs 

and penetrations with 

a closed system 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-5 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

C.2 --------------NOTES------------ 

 1. Isolation devices in 

high radiation areas 

may be verified by use 

of administrative 

means. 

 2. Isolation devices that 

are locked, sealed, or 

otherwise secured may 

be verified by use of 

administrative means. 

 ------------------------------------ 

 Verify the affected 

penetration flow path is 

isolated. 

Once per 31 days 

following isolation for 

isolation devices 

outside primary 

containment 

AND 

Prior to entering 

MODE 2 or 3 from 

MODE 4 if primary 

containment was 

de-inerted while in 

MODE 4, if not 

performed within the 

previous 92 days, for 

isolation devices 

inside primary 

containment 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-6 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

D. One or more penetration 

flow paths with one or 

more 18 inch primary 

containment purge and 

vent valves not within 

purge and vent valve 

leakage limits. 

D.1 Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange. 

AND 

D.2 --------------NOTES------------ 

 1. Isolation devices in high 

radiation areas may be 

verified by use of 

administrative means. 

 2. Isolation devices that 

are locked, sealed, or 

otherwise secured may 

be verified by use of 

administrative means. 

 ------------------------------------ 

 Verify the affected 

penetration flow path is 

isolated. 

24 hours 

OR 

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

Not applicable when 

a loss of function 

occurs. 

----------------------------- 

In accordance with 

the Risk Informed 

Completion Time 

Program 

Once per 31 days 

following isolation for 

isolation devices 

outside containment 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-7 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

E. One or more MSIVs 

with leakage rate not 

within limits. 

E.1 Restore leakage rate to 

within limits. 

8 hours 

F. Required Action and 

associated Completion 

Time of Condition A, B, 

C, or D not met. 

F.1 Be in MODE 3. 

AND 

F.2 Be in MODE 4. 

12 hours 

36 hours 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-8 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.6.1.3.1 --------------------------------NOTE------------------------------- 

Not required to be met when the 18 inch primary 

containment purge and vent valves are open for 

inerting, de-inerting, pressure control, ALARA or air 

quality considerations for personnel entry, or 

Surveillances that require the valves to be open. 

----------------------------------------------------------------------- 

Verify each 18 inch primary containment purge and 

vent valve is closed. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.2 -------------------------------NOTES------------------------------ 

1. Valves and blind flanges in high radiation areas 

may be verified by use of administrative means. 

2. Not required to be met for PCIVs that are open 

under administrative controls. 

----------------------------------------------------------------------- 

Verify each primary containment isolation manual 

valve and blind flange that is located outside primary 

containment and not locked, sealed, or otherwise 

secured and is required to be closed during accident 

conditions is closed. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-9 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.6.1.3.3 -------------------------------NOTES------------------------------ 

1. Valves and blind flanges in high radiation areas 

may be verified by use of administrative means. 

2. Not required to be met for PCIVs that are open 

under administrative controls. 

----------------------------------------------------------------------- 

Verify each primary containment manual isolation 

valve and blind flange that is located inside primary 

containment and not locked, sealed, or otherwise 

secured and is required to be closed during accident 

conditions is closed. 

Prior to entering 

MODE 2 or 3 from 

MODE 4 if 

primary 

containment was 

de-inerted while in 

MODE 4, if not 

performed within 

the previous 

92 days 

SR 3.6.1.3.4 Verify continuity of the traversing incore probe (TIP) 

shear isolation valve explosive charge. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.5 Verify the isolation time of each power operated 

automatic PCIV, except for MSIVs, is within limits. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.6 Verify the isolation time of each MSIV is 

≥ 3 seconds and ≤ 9.9 seconds. 

 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.7 Verify each automatic PCIV actuates to the isolation 

position on an actual or simulated isolation signal. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
PCIVs 

3.6.1.3 

Monticello 3.6.1.3-10 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.6.1.3.8 Verify each reactor instrumentation line EFCV 

actuates on a simulated instrument line break to 

restrict flow to ≤ 2 gpm. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.9 Verify each 18 inch primary containment purge and 

vent valve is blocked to restrict the valve from 

opening > 40°. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.10 Remove and test the explosive squib from each 

shear isolation valve of the TIP System. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.3.11 Perform leakage rate testing for each 18 inch primary 

containment purge and vent valve with resilient seals. 

In accordance with 

the Primary 

Containment 

Leakage Rate 

Testing Program 

SR 3.6.1.3.12 Verify leakage rate through each MSIV is: 

(a) ≤ 100 scfh when tested at ≥ 44.1 psig (Pa); or 

(b) ≤ 75.3 scfh when tested at ≥ 25 psig. 

In accordance with 

the Primary 

Containment 

Leakage Rate 

Testing Program 

SR 3.6.1.3.13 Verify leakage rate through the main steam pathway 

is: 

(a) ≤ 200 scfh when tested at ≥ 44.1 psig (Pa); or 

(b) ≤ 150.6 scfh when tested at ≥ 25 psig. 

In accordance with 

the Primary 

Containment 

Leakage Rate 

Testing Program 
Drywell Air Temperature

3.6.1.4

Monticello 3.6.1.4-1 Amendment No. 200

3.6 CONTAINMENT SYSTEMS

3.6.1.4 Drywell Air Temperature

LCO 3.6.1.4 Drywell average air temperature shall be ≤ 135°F.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Drywell average air 

temperature not within 

limit.

A.1 Restore drywell average air 

temperature to within limit.

8 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.4.1 Verify drywell average air temperature is within limit. In accordance with 

the Surveillance 

Frequency Control 

Program
LLS Valves

3.6.1.5

3.6 CONTAINMENT SYSTEMS

3.6.1.5 Low-Low Set (LLS) Valves

LCO 3.6.1.5 The LLS function of three safety/relief valves shall be OPERABLE.

APPLICABILITY:

ACTIONS

MODES 1, 2, and 3.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One LLS valve A.1 Restore LLS valve to 14 days

inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours

associated Completion

Time of Condition A not AND

met.

B.2 Be in MODE 4. 36 hours

OR

Two or more LLS valves

inoperable.

Monticello 3.6.1.5-1 Amendment No. 146
LLS Valves

3.6.1.5

Monticello 3.6.1.5-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.5.1 --------------------------------NOTE-------------------------------

Not required to be performed until 12 hours after 

reactor steam flow is adequate to perform the test.

-----------------------------------------------------------------------

Verify each LLS valve is capable of being opened. In accordance with 

the INSERVICE 

TESTING 

PROGRAM

SR 3.6.1.5.2 --------------------------------NOTE-------------------------------

Valve actuation may be excluded.

-----------------------------------------------------------------------

Verify the LLS System actuates on an actual or 

simulated automatic initiation signal.

In accordance with 

the Surveillance 

Frequency Control 

Program
Reactor Building-to-Suppression Chamber Vacuum Breakers 

3.6.1.6 

Monticello 3.6.1.6-1 Amendment No. 206 

3.6 CONTAINMENT SYSTEMS 

3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers 

LCO 3.6.1.6 Each reactor building-to-suppression chamber vacuum breaker shall be 

OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

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

Separate Condition entry is allowed for each line. 

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more lines with 

one reactor building-tosuppression chamber 

vacuum breaker not 

closed. 

A.1 Close the open vacuum 

breaker. 

72 hours 

B. One or more lines with 

two reactor building-tosuppression chamber 

vacuum breakers not 

closed. 

B.1 Close one open vacuum 

breaker. 

1 hour 

C. One line with one or 

more reactor buildingto-suppression chamber 

vacuum breakers 

inoperable for opening. 

C.1 Restore the vacuum 

breaker(s) to OPERABLE 

status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
Reactor Building-to-Suppression Chamber Vacuum Breakers 

3.6.1.6 

Monticello 3.6.1.6-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

D. Two lines with one or 

more reactor buildingto-suppression chamber 

vacuum breakers 

inoperable for opening. 

D.1 Restore all vacuum 

breakers in one line to 

OPERABLE status. 

1 Hour 

E. Required Action and 

Associated Completion 

Time not met. 

E.1 Be in MODE 3. 

AND 

E.2 Be in MODE 4. 

12 hours 

36 hours 
Reactor Building-to-Suppression Chamber Vacuum Breakers 

3.6.1.6 

Monticello 3.6.1.6-3 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.6.1.6.1 -------------------------------NOTES------------------------------ 

1. Not required to be met for vacuum breakers that 

are open during Surveillances. 

2. Not required to be met for vacuum breakers 

open when performing their intended function. 

----------------------------------------------------------------------- 

Verify each vacuum breaker is closed. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.6.2 Perform a functional test of each vacuum breaker. In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.6.3 Verify the opening setpoint of each vacuum breaker 

is ≤ 0.5 psid. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
Suppression Chamber-to-Drywell Vacuum Breakers 

3.6.1.7 

Monticello 3.6.1.7-1 Amendment No. 206 

3.6 CONTAINMENT SYSTEMS 

3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers 

LCO 3.6.1.7 Seven suppression chamber-to-drywell vacuum breakers shall be 

OPERABLE for opening. 

 AND 

 Eight suppression chamber-to-drywell vacuum breakers shall be closed. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One required 

suppression chamber-todrywell vacuum breaker 

inoperable for opening. 

A.1 Restore one vacuum 

breaker to OPERABLE 

status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. One suppression 

chamber-to-drywell 

vacuum breaker not 

closed. 

B.1 Close the open vacuum 

breaker. 

12 hours 

C. Required Action and 

associated Completion 

Time not met. 

C.1 Be in MODE 3. 

AND 

C.2 Be in MODE 4. 

12 hours 

36 hours 
Suppression Chamber-to-Drywell Vacuum Breakers

3.6.1.7

Monticello 3.6.1.7-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.1.7.1 -------------------------------NOTES------------------------------

1. Not required to be met for vacuum breakers that 

are open during Surveillances. 

2. Not required to be met for vacuum breakers 

performing their intended function.

3. Not required to be met for vacuum breakers 

being cycled, one at a time, during primary 

containment inerting and de-inerting operations.

------------------------------------------------------------------------

Verify each vacuum breaker is closed. In accordance with 

the Surveillance 

Frequency Control 

Program

AND

Within 12 hours 

after any 

operation that 

causes the 

drywell-tosuppression 

chamber 

differential 

pressure to be 

reduced by 

≥ 0.5 psid if any 

vacuum breaker 

position indicator 

does not indicate 

closed

SR 3.6.1.7.2 Perform a functional test of each required vacuum 

breaker.

In accordance with 

the Surveillance 

Frequency Control 

Program
Suppression Chamber-to-Drywell Vacuum Breakers

3.6.1.7

Monticello 3.6.1.7-3 Amendment No. 200 

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.1.7.3 Verify the opening setpoint of each required vacuum 

breaker is ≤ 0.5 psid.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHR Drywell Spray 

3.6.1.8 

Monticello 3.6.1.8-1 Amendment No. 206 

3.6 CONTAINMENT SYSTEMS 

3.6.1.8 Residual Heat Removal (RHR) Drywell Spray 

LCO 3.6.1.8 Two RHR drywell spray subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One RHR drywell spray 

subsystem inoperable. 

A.1 Restore RHR drywell spray 

subsystem to OPERABLE 

status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Two RHR drywell spray 

subsystems inoperable. 

B.1 Restore one RHR drywell 

spray subsystem to 

OPERABLE status. 

8 hours 

C. Required Action and 

associated Completion 

Time not met. 

C.1 Be in MODE 3. 

AND 

C.2 Be in MODE 4. 

12 hours 

36 hours 
RHR Drywell Spray 

3.6.1.8 

Monticello 3.6.1.8-2 Amendment No. 208 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.6.1.8.1 Verify each RHR drywell spray subsystem manual 

and power operated valve in the flow path that is not 

locked, sealed, or otherwise secured in position is in 

the correct position or can be aligned to the correct 

position. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.1.8.2 Verify each drywell spray header and nozzle is 

unobstructed. 

Following 

maintenance that 

could result in 

nozzle blockage 

SR 3.6.1.8.3 Verify RHR drywell spray subsystem locations 

susceptible to gas accumulation are sufficiently filled 

with water. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
Suppression Pool Average Temperature

3.6.2.1

3.6 CONTAINMENT SYSTEMS

3.6.2.1 Suppression Pool Average Temperature

LCO 3.6.2.1 Suppression pool average temperature shall be:

a. __ 90 ° F with THERMAL POWER > 1 % RTP and no testing that adds

heat to the suppression pool is being performed;

b. <_ 1000 F with THERMAL POWER > 1% RTP and testing that adds

heat to the suppression pool is being performed; and

c. < 11 0°F with THERMAL POWER < 1% RTP.

APPLICABILITY-:- -MODESj1-,2,-and-3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Suppression pool A.1 Verify suppression pool Once per hour

average temperature average temperature

> 90 °F but.< 110°F. -110 0 F.

AND AND

THERMAL POWER A.2 Restore suppression pool 24 hours

> 1% RTP. average temperature to

_900 F.

AND

Not performing testing

that adds heat to the

suppression pool.

B. Required Action and B.1 Reduce THERMAL 12 hours

associated Completion POWER to • 1% RTP.

Time of Condition A not

met.

Monticello 3-6-2-1-1 Amendment No. 146
Suppression Pool Average Temperature

3.6.2.1

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Suppression pool C.1 Suspend all testing that Immediately

average temperature adds heat to the

> 1000F. suppression pool.

AND

THERMAL POWER

> 1% RTP.

AND

Performing testing that

adds heat to the suippression pool_ .. . .. .. . . . . . . . . .... .. . . .. . . .. ...

D. Suppression pool D.1 Place the reactor mode Immediately

average temperature switch in the shutdown

> 110 0F. position.

AND

D.2 Determine suppression Once per 30 minutes

pool average temperature.

AND

D.3 Be in MODE 4. 36 hours

E. Suppression pool E.1 Depressurize the reactor 12 hours

average temperature vessel to < 200 psig.

> 1200 F.

Monticello 3.6.2.1-2 Amendment No. 146
Suppression Pool Average Temperature

3.6.2.1

Monticello 3.6.2.1-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.2.1.1 Verify suppression pool average temperature is 

within the acceptable limits.

In accordance with 

the Surveillance 

Frequency Control 

Program

AND

5 minutes when 

performing testing 

that adds heat to 

the suppression 

pool
Suppression Pool Water Level

3.6.2.2

Monticello 3.6.2.2-1 Amendment No. 200

3.6 CONTAINMENT SYSTEMS

3.6.2.2 Suppression Pool Water Level

LCO 3.6.2.2 Suppression pool water level shall be ≥ - 4.0 inches and ≤ + 3.0 inches.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Suppression pool water 

level not within limits.

A.1 Restore suppression pool 

water level to within limits.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Be in MODE 3.

AND

B.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.2.2.1 Verify suppression pool water level is within limits. In accordance with 

the Surveillance 

Frequency Control 

Program
RHR Suppression Pool Cooling 

3.6.2.3 

Monticello 3.6.2.3-1 Amendment No. 206 

3.6 CONTAINMENT SYSTEMS 

3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling 

LCO 3.6.2.3 Two RHR suppression pooling cooling subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One RHR suppression 

pool cooling subsystem 

inoperable. 

A.1 Restore RHR suppression 

pool cooling subsystem to 

OPERABLE status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. Two RHR suppression 

pool cooling subsystems 

inoperable. 

B.1 Restore one RHR 

suppression pool cooling 

subsystem to OPERABLE 

status. 

8 hours 

C. Required Action and 

associated Completion 

Time not met. 

C.1 Be in MODE 3. 

AND 

C.2 Be in MODE 4. 

12 hours 

36 hours 

 
RHR Suppression Pool Cooling 

3.6.2.3 

Monticello 3.6.2.3-2 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.6.2.3.1 Verify each RHR suppression pool cooling 

subsystem manual and power operated valve in the 

flow path that is not locked, sealed, or otherwise 

secured in position is in the correct position or can be 

aligned to the correct position. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.6.2.3.2 Verify each required RHR pump develops a flow 

rate ≥ 3870 gpm through the associated heat 

exchanger while operating in the suppression pool 

cooling mode. 

In accordance with 

the INSERVICE 

TESTING 

PROGRAM 

SR 3.6.2.3.3 Verify RHR suppression pool cooling subsystem 

locations susceptible to gas accumulation are 

sufficiently filled with water. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
Primary Containment Oxygen Concentration

3.6.3.1

Monticello 3.6.3.1-1 Amendment No. 200

3.6 CONTAINMENT SYSTEMS

3.6.3.1 Primary Containment Oxygen Concentration

LCO 3.6.3.1 The primary containment oxygen concentration shall be < 4.0 volume 

percent.

APPLICABILITY: MODE 1 during the time period:

a. From 24 hours after THERMAL POWER is > 15% RTP following 

startup, to

b. 24 hours prior to reducing THERMAL POWER to < 15% RTP prior to 

the next scheduled reactor shutdown.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Primary containment 

oxygen concentration 

not within limit.

A.1 Restore oxygen 

concentration to within limit.

24 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to ≤ 15% RTP.

8 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.3.1.1 Verify primary containment oxygen concentration is 

within limits.

In accordance with 

the Surveillance 

Frequency Control 

Program
Secondary Containment

3.6.4.1

Monticello 3.6.4.1-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.4.1.1 ------------------------------NOTE--------------------------------

Not required to be met for 4 hours if analysis 

demonstrates one standby gas treatment (SGT) 

subsystem is capable of establishing the required 

secondary containment vacuum. 

-----------------------------------------------------------------------

Verify secondary containment vacuum is ≥ 0.25 inch 

of vacuum water gauge.

In accordance with 

the Surveillance 

Frequency Control

Program

SR 3.6.4.1.2 Verify all secondary containment equipment hatches 

are closed and sealed.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.6.4.1.3 Verify one secondary containment access door in 

each access opening is closed, except when the 

access opening is being used for entry and exit. 

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.6.4.1.4 Verify the secondary containment can be 

maintained ≥ 0.25 inch of vacuum water gauge for 

1 hour using one SGT subsystem at a flow rate 

≤ 4000 cfm.

In accordance with 

the Surveillance 

Frequency Control 

Program
3.6 CONTAINMENT SYSTEMS 

3.6.4.2 Secondary Containment Isolation Valves (SCIVs) 

LCO 3.6.4.2 Each SCIV shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3, 

SCIVs 

3.6.4.2 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

-----------------------------------------------------------NOTES----------------------------------------------------------

1 . Penetration flow paths may be unisolated intermittently under administrative controls. 

2. Separate Condition entry is allowed for each penetration flow path. 

3. Enter applicable Conditions and Required Actions for systems made inoperable by SCIVs. 

CONDITION 

A. One or more penetration A.1 

flow paths with one 

SCIV inoperable. 

Monticello 

REQUIRED ACTION 

Isolate the affected 

penetration flow path by 

use of at least one closed 

and de-activated automatic 

valve, closed manual valve, 

or blind flange. 

3.6.4.2-1 

COMPLETION TIME 

8 hours 

Amendment No. 44e, 198 I 
SCIVs

3.6.4.2

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2 -- .NOTES-------

1. Isolation devices in high

radiation areas may be

verified by use of

administrative means.

2. Isolation devices that

are locked, sealed, or

otherwise secured may

be verified by use of

administrative means.

Verify the affected Once per 31 days

penetration flow path is

isolated.

B. ------- NOTE --------- B.1 Isolate the affected 4 hours

Only applicable to penetration flow path by

penetration flow paths use of at least one closed

with two isolation valves, and de-activated automatic

valve, closed manual valve,

or blind flange.

One or more penetration

flow paths with two

SCIVs inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours

associated Completion

Time of Condition A or B AND

not met in MODE 1,2,

or 3. C.2 Be in MODE 4. 36 hours

Monticello 3.6.4.2-2 Amendment No. 146
SCIVs

3.6.4.2

Monticello 3.6.4.2-3 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Required Action and 

associated Completion 

Time of Condition A or B 

not met during 

movement of recently 

irradiated fuel 

assemblies in the 

secondary containment.

D.1 ---------------NOTE--------------

 LCO 3.0.3 is not applicable.

 -------------------------------------

 Suspend movement of 

recently irradiated fuel 

assemblies in the 

secondary containment.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.4.2.1 ------------------------------NOTES-----------------------------

1. Valves and blind flanges in high radiation areas 

may be verified by use of administrative means.

2. Not required to be met for SCIVs that are open 

under administrative controls.

---------------------------------------------------------------------

Verify each secondary containment isolation manual 

valve and blind flange that is not locked, sealed, or 

otherwise secured and is required to be closed 

during accident conditions is closed.

In accordance 

with the 

Surveillance 

Frequency 

Control Program

SR 3.6.4.2.2 Verify the isolation time of each power operated,

automatic SCIV is within limits.

In accordance 

with the 

Surveillance 

Frequency 

Control Program
SCIVs

3.6.4.2

Monticello 3.6.4.2-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.6.4.2.3 Verify each automatic SCIV actuates to the isolation 

position on an actual or simulated actuation signal.

In accordance 

with the 

Surveillance 

Frequency 

Control Program
3.6 CONTAINMENT SYSTEMS 

3.6.4.3 Standby Gas Treatment (SGT) System 

LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3, 

SGT System 

3.6.4.3 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One SGT subsystem A.1 Restore SGT subsystem to 7 days 

inoperable. OPERABLE status. 

B. Required Action and B.1 Be in MODE 3. 12 hours 

associated Completion 

Time of Condition A not AND 

met in MODE 1, 2, or 3. 

B.2 Be in MODE 4. 36 hours 

C. Required Action and --------------------NOTE-------------------

associated Completion LCO 3.0.3 is not applicable. 

Time of Condition A not ------------------------------------------------

met during movement of 

recently irradiated fuel C. 1 Place OPERABLE SGT Immediately 

assemblies in the subsystem in operation. 

secondary containment. 

OR 

C.2 Suspend movement of Immediately 

recently irradiated fuel 

assemblies in secondary 

containment. 

Monticello 3.6.4.3-1 Amendment No. 448, 198 I 
SGT System

3.6.4.3

Monticello 3.6.4.3-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D. Two SGT subsystems 

inoperable in MODE 1, 

2, or 3.

D.1 Enter LCO 3.0.3. Immediately

E. Two SGT subsystems 

inoperable during 

movement of recently 

irradiated fuel 

assemblies in the 

secondary containment.

E.1 ---------------NOTE--------------

 LCO 3.0.3 is not applicable.

 -------------------------------------

 Suspend movement of 

recently irradiated fuel 

assemblies in secondary 

containment.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.6.4.3.1 Operate each SGT subsystem for ≥ 15 continuous 

minutes.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.6.4.3.2 Perform required SGT filter testing in accordance 

with the Ventilation Filter Testing Program (VFTP).

In accordance with 

the VFTP

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual 

or simulated initiation signal.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHRSW System 

3.7.1 

Monticello 3.7.1-1 Amendment No. 206 

3.7 PLANT SYSTEMS 

3.7.1 Residual Heat Removal Service Water (RHRSW) System 

LCO 3.7.1 Two RHRSW subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One RHRSW subsystem 

inoperable. 

A.1 ---------------NOTE-------------- 

 Enter applicable Conditions 

and Required Actions of 

LCO 3.4.7, "Residual Heat 

Removal (RHR) Shutdown 

Cooling System - Hot 

Shutdown," for RHR 

shutdown cooling made 

inoperable by RHRSW 

System. 

 ------------------------------------- 

 Restore RHRSW 

subsystem to OPERABLE 

status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
RHRSW System 

3.7.1 

Monticello 3.7.1-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B. Both RHRSW 

subsystems inoperable. 

B.1 ---------------NOTE-------------- 

 Enter applicable Conditions 

and Required Actions of 

LCO 3.4.7 for RHR 

shutdown cooling made 

inoperable by RHRSW 

System. 

 ------------------------------------- 

 Restore one RHRSW 

subsystem to OPERABLE 

status. 

8 hours 

C. Required Action and 

associated Completion 

Time not met. 

C.1 Be in MODE 3. 

AND 

C.2 Be in MODE 4. 

12 hours 

36 hours 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.7.1.1 Verify each RHRSW manual, power operated, and 

automatic valve in the flow path, that is not locked, 

sealed, or otherwise secured in position, is in the 

correct position or can be aligned to the correct 

position. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
ESW System and UHS 

3.7.2 

Monticello 3.7.2-1 Amendment No. 206 

3.7 PLANT SYSTEMS 

3.7.2 Emergency Service Water (ESW) System and Ultimate Heat Sink (UHS) 

LCO 3.7.2 Two ESW subsystems and UHS shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One ESW subsystem 

inoperable. 

A.1 --------------NOTE-------------- 

 Enter applicable Conditions 

and Required Actions of 

LCO 3.4.7, "Residual Heat 

Removal (RHR) Shutdown 

Cooling System - Hot 

Shutdown," for RHR 

shutdown cooling made 

inoperable by ESW. 

 ------------------------------------- 

 Restore the ESW 

subsystem to OPERABLE 

status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
ESW System and UHS 

3.7.2 

Monticello 3.7.2-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B. Required Action and 

associated Completion 

Time of Condition A not 

met. 

 OR 

 Both ESW subsystems 

inoperable. 

 OR 

 UHS inoperable. 

B.1 Be in MODE 3. 

AND 

B.2 Be in MODE 4. 

12 hours 

36 hours 
ESW System and UHS 

3.7.2 

Monticello 3.7.2-3 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.7.2.1 Verify the water level in the intake structure is 

≥ 899 ft mean sea level. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.7.2.2 Verify the average water temperature of UHS is 

≤ 90°F. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.7.2.3 --------------------------------NOTE------------------------------- 

Isolation of flow to individual components does not 

render ESW System inoperable. 

----------------------------------------------------------------------- 

Verify each ESW subsystem manual and automatic 

valve in the flow paths servicing safety related 

systems or components, that is not locked, sealed, 

or otherwise secured in position, is in the correct 

position. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.7.2.4 Verify each ESW subsystem actuates on an actual 

or simulated initiation signal. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
EDG-ESW System

3.7.3

Monticello 3.7.3-1 Amendment No. 200

3.7 PLANT SYSTEMS

3.7.3 Emergency Diesel Generator-Emergency Service Water (EDG-ESW) System

LCO 3.7.3 Two EDG-ESW subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS

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

Separate Condition entry is allowed for each EDG-ESW subsystem.

-------------------------------------------------------------------------------------------------------------------------------

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more EDG-ESW 

subsystems inoperable.

A.1 Declare associated EDG 

inoperable.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.3.1 Verify each EDG-ESW subsystem manual valve in 

the flow path, that is not locked, sealed, or otherwise 

secured in position, is in the correct position.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.7.3.2 Verify each EDG-ESW subsystem pump starts 

automatically when the associated EDG starts and 

energizes the respective bus.

In accordance with 

the Surveillance 

Frequency Control 

Program
3. 7 PLANT SYSTEMS 

3.7.4 Control Room Emergency Filtration (CREF) System 

LCO 3.7.4 Two CREF subsystems shall be OPERABLE. 

CREF System 

3.7.4 

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

The control room envelope (CRE) boundary may be opened intermittently 

under administrative control. 

APPLICABILITY: MODES 1, 2, and 3, 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One CREF subsystem A.1 Restore CREF subsystem 7 days 

inoperable for reasons to OPERABLE status. 

other than Condition B. 

B. One or more CREF 8.1 Initiate action to implement Immediately 

subsystems inoperable mitigating actions. 

due to inoperable CRE 

boundary in MODE 1, 2, AND 

or 3. 

8.2 Verify mitigating actions 24 hours 

ensure CRE occupant 

exposures to radiological, 

chemical and smoke 

hazards will not exceed 

limits. 

AND 

8.3 Restore CRE boundary to 90 days 

OPERABLE status. 

Monticello 3.7.4-1 Amendment No. 146, 160, 175, 198 I 
ACTIONS (continued) 

CONDITION 

C. Required Action and 

associated Completion 

Time of Condition A or B 

not met in MODE 1, 2, 

or 3. 

D. Required Action and 

associated Completion 

Time of Condition A not 

met during movement of 

recently irradiated fuel 

assemblies in the 

secondary containment. 

E. Two CREF subsystems 

inoperable in MODE 1, 

2, or 3 for reasons other 

than Condition B. 

Monticello 

REQUIRED ACTION 

C.1 Be in MODE 3. 

AND 

C.2 Be in MODE4. 

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

LCO 3.0.3 is not applicable. 

------------------------------------------------

D.1 Place OPERABLE CREF 

subsystem in pressurization 

mode. 

OR 

D.2 Suspend movement of 

recently irradiated fuel 

assemblies in the 

secondary containment. 

E.1 Enter LCO 3.0.3. 

CREF · System 

3.7.4 

COMPLETION TIME 

12 hours 

36 hours 

Immediately 

Immediately 

Immediately 

3.7.4-2 Amendment No. 146, 160, 198 I 
CREF System

3.7.4

Monticello 3.7.4-3 Amendment No. 200 

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F. Two CREF subsystems 

inoperable during 

movement of recently 

irradiated fuel 

assemblies in the 

secondary containment.

OR

One or more CREF 

subsystems inoperable 

due to an inoperable 

CRE boundary during 

movement of recently 

irradiated fuel 

assemblies in the 

secondary containment.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

F.1 Suspend movement of 

recently irradiated fuel 

assemblies in the 

secondary containment.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.4.1 Operate each CREF subsystem for ≥ 15 continuous 

minutes. 

In accordance 

with the 

Surveillance 

Frequency 

Control Program

SR 3.7.4.2 Perform required CREF filter testing in accordance 

with the Ventilation Filter Testing Program (VFTP).

In accordance 

with the VFTP

SR 3.7.4.3 Verify each CREF subsystem actuates on an actual 

or simulated initiation signal.

In accordance 

with the 

Surveillance 

Frequency 

Control Program
CREF System

3.7.4

Monticello 3.7.4-4 Amendment No. 200 

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.7.4.4 Perform required CRE unfiltered air in-leakage 

testing in accordance with the Control Room 

Envelope Habitability Program.

In accordance 

with the Control 

Room Envelope 

Habitability 

Program
3.7 PLANT SYSTEMS 

Control Room Ventilation System 

3.7.5 

3.7.5 Control Room Ventilation System 

LCO 3.7.5 Two control room ventilation subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3, 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One control room A.1 Restore control room 30 days 

ventilation subsystem ventilation subsystem to 

inoperable. OPERABLE status. 

B. Two control room B.1 Verify control room area Once per 4 hours 

ventilation subsystems temperature< 90°F. 

inoperable. 

AND 

B.2 Restore one control room 72 hours 

ventilation subsystem to 

OPERABLE status. 

C. Required Action and C.1 Be in MODE 3. 12 hours 

associated Completion 

Time of Condition A or B AND 

not met in MODE 1, 2, 

or 3. C.2 Be in MODE4. 36 hours 

D. Required Action and --------------------NOTE-------------------

associated Completion LCO 3.0.3 is not applicable. 

Time of Condition A not ------------------------------------------------ met during movement of 

recently irradiated fuel D.1 Place OPERABLE control Immediately 

assemblies in the room ventilation subsystem 

secondary containment. in operation. 

OR 

Monticello 3.7.5-1 Amendment No. 146, 148, 154, 198 I 
Control Room Ventilation System

3.7.5

Monticello 3.7.5-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

D.2 Suspend movement of 

recently irradiated fuel 

assemblies in the 

secondary containment.

Immediately

E. Required Action and 

associated Completion 

Time of Condition B not 

met during movement of 

recently irradiated fuel 

assemblies in the 

secondary containment.

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

LCO 3.0.3 is not applicable.

------------------------------------------------

E.1 Suspend movement of 

recently irradiated fuel 

assemblies in the 

secondary containment.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.5.1 Verify each control room ventilation subsystem has 

the capability to remove the assumed heat load.

In accordance 

with the 

Surveillance 

Frequency 

Control Program
Main Condenser Offgas

3.7.6

3.7 PLANT SYSTEMS

3.7.6 Main Condenser Offgas

LCO 3.7.6 The gross gamma activity rate of the noble gases measured at the main

condenser offgas system pretreatment monitor station shall be

< 260 mCi/second after decay of 30 minutes.

APPLICABILITY: MODE 1,

MODES 2 and 3 with any main steam line not isolated and steam jet air

ejector (SJAE) in operation.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Gross gamma activity A.1 Restore gross gamma 72 hours

rate of the noble gases activity rate of the noble

not within limit. gases to within limit.

B. Required Action and B.1 Isolate all main steam lines. 12 hours

associated Completion

Time not met. OR

B.2 Isolate SJAE. 12 hours

OR

B.3.1 Be in MODE 3. 12 hours

AND

B.3.2 Be in MODE 4. 36 hours

Monticello 3.7.6-1 Amendment No. 146
Main Condenser Offgas

3.7.6

Monticello 3.7.6-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.6.1 --------------------------------NOTE-------------------------------

Not required to be performed until 31 days after any 

main steam line not isolated and SJAE in operation.

------------------------------------------------------------------------

Verify the gross gamma activity rate of the noble 

gases is ≤ 260 mCi/second after decay of 

30 minutes.

In accordance with 

the Surveillance 

Frequency Control 

Program

AND

Once within 

4 hours after a 

≥ 50% increase in 

the nominal 

steady state 

fission gas 

release after 

factoring out 

increases due to 

changes in 

THERMAL 

POWER level
Main Turbine Bypass System

3.7.7

Monticello 3.7.7-1 Amendment No. 200

3.7 PLANT SYSTEMS

3.7.7 Main Turbine Bypass System

LCO 3.7.7 The Main Turbine Bypass System shall be OPERABLE.

APPLICABILITY: THERMAL POWER ≥ 25% RTP.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Main Turbine Bypass 

System inoperable. 

A.1 Restore Main Turbine 

Bypass System to 

OPERABLE status.

2 hours

B. Required Action and 

associated Completion 

Time not met.

B.1 Reduce THERMAL 

POWER to < 25% RTP.

4 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.7.1 Verify one complete cycle of each main turbine 

bypass valve.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.7.7.2 Perform a system functional test. In accordance with 

the Surveillance 

Frequency Control 

Program
Main Turbine Bypass System

3.7.7

Monticello 3.7.7-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.7.7.3 Verify the TURBINE BYPASS SYSTEM 

RESPONSE TIME is within limits.

In accordance with 

the Surveillance 

Frequency Control 

Program
Spent Fuel Storage Pool Water Level

3.7.8

Monticello 3.7.8-1 Amendment No. 200

3.7 PLANT SYSTEMS

3.7.8 Spent Fuel Storage Pool Water Level

LCO 3.7.8 The spent fuel storage pool water level shall be ≥ 37 ft above the bottom 

of the spent fuel storage pool.

APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel storage 

pool.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Spent fuel storage pool 

water level not within 

limit.

A.1 ---------------NOTE--------------

 LCO 3.0.3 is not applicable.

 -------------------------------------

 Suspend movement of 

irradiated fuel assemblies in 

the spent fuel storage pool.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.7.8.1 Verify the spent fuel storage pool water level is 

≥ 37 ft above the bottom of the spent fuel storage 

pool.

In accordance with 

the Surveillance 

Frequency Control 

Program
AC Sources - Operating

3.8.1

3.8 ELECTRICAL POWER SYSTEMS

3.8.1 AC Sources - Operating

LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmrssion network and

the onsite Class 1 E AC Electrical Power Distribution System; and

b. Two emergency diesel generators (EDGs).

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

-NOTE.

LCO 3.0.4.b is not applicable to EDGs.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One required offsite A.1 Perform SR 3.8.1.1 for 1 hour

circuit inoperable. OPERABLE required offsite

circuit. AND

Once per 8 hours

thereafter

AND

A.2 Declare required feature(s) 24 hours from

with no offsite power discovery of no offsite

available inoperable when power to one division

the redundant required concurrent with

feature(s) are inoperable. inoperability of

redundant required

feature(s)

AND

Monticello 3.8.1-1 Amendment No. 146
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

A.3 Restore required offsite 

circuit to OPERABLE 

status. 

72 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. One EDG inoperable. B.1 Perform SR 3.8.1.1 for 

OPERABLE required offsite 

circuit(s). 

AND 

B.2 Declare required feature(s), 

supported by the inoperable 

EDG, inoperable when the 

redundant required 

feature(s) are inoperable. 

AND 

B.3.1 Determine OPERABLE 

EDG is not inoperable due 

to common cause failure. 

 OR 

B.3.2 Perform SR 3.8.1.2 for 

OPERABLE EDG. 

AND 

1 hour 

AND 

Once per 8 hours 

thereafter 

4 hours from 

discovery of 

Condition B 

concurrent with 

inoperability of 

redundant required 

feature(s) 

24 hours 

24 hours 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-3 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

B.4 Restore EDG to 

OPERABLE status. 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

C. Two required offsite 

circuits inoperable. 

C.1 Declare required feature(s) 

inoperable when the 

redundant required 

feature(s) are inoperable. 

AND 

C.2 Restore one required offsite 

circuit to OPERABLE 

status. 

12 hours from 

discovery of 

Condition C 

concurrent with 

inoperability of 

redundant required 

feature(s) 

24 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-4 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

D. One required offsite 

circuit inoperable. 

 AND 

 One EDG inoperable. 

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

Enter applicable Conditions and 

Required Actions of LCO 3.8.7, 

"Distribution Systems - Operating," 

when Condition D is entered with no 

AC power source to any division. 

------------------------------------------------ 

D.1 Restore required offsite 

circuit to OPERABLE 

status. 

OR 

D.2 Restore EDG to 

OPERABLE status. 

12 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

12 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

E. Two EDGs inoperable. E.1 Restore one EDG to 

OPERABLE status. 

2 hours 

F. Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, or E not met. 

F.1 Be in MODE 3. 

AND 

F.2 Be in MODE 4. 

12 hours 

36 hours 

G. Three or more required 

AC sources inoperable. 

G.1 Enter LCO 3.0.3. Immediately 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-5 Amendment No. 206 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.8.1.1 Verify correct breaker alignment and indicated 

power availability for each required offsite circuit. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.1.2 ------------------------------NOTES------------------------------- 

1. All EDG starts may be preceded by an engine 

prelube period and followed by a warmup 

period prior to loading. 

2. A modified EDG start involving idling and 

gradual acceleration to synchronous speed may 

be used for this SR as recommended by the 

manufacturer. 

----------------------------------------------------------------------- 

Verify each EDG starts from standby conditions and 

achieves steady state voltage ≥ 3975 V and 

≤ 4400 V and frequency ≥ 58.8 Hz and ≤ 61.2 Hz. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-6 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.8.1.3 -------------------------------NOTES------------------------------ 

1. EDG 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 EDG at a time. 

4. This SR shall be preceded by and immediately 

follow, without shutdown, a successful 

performance of SR 3.8.1.2. 

----------------------------------------------------------------------- 

Verify each EDG is synchronized and loaded and 

operates for ≥ 60 minutes at a load ≥ 2250 kW and 

≤ 2500 kW. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.1.4 Check for and remove accumulated water from each 

day tank and base tank. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.1.5 Verify the fuel oil transfer system operates to 

transfer fuel oil from the storage tank to the day 

tanks and from each day tank to the associated 

base tank. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-7 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.8.1.6 --------------------------------NOTE------------------------------- 

This Surveillance shall not normally be performed in 

MODE 1 or 2. However, this Surveillance may be 

performed to reestablish OPERABILITY provided an 

assessment determines the safety of the plant is 

maintained or enhanced. Credit may be taken for 

unplanned events that satisfy this SR. 

-----------------------------------------------------------------------

- 

Verify automatic and manual transfer of unit power 

supply from the normal offsite circuit to the alternate 

offsite circuit. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.1.7 -------------------------------NOTES------------------------------ 

1. This Surveillance shall not normally be 

performed in MODE 1 or 2. However, this 

Surveillance may be performed to reestablish 

OPERABILITY provided an assessment 

determines the safety of the plant is maintained 

or enhanced. Credit may be taken for 

unplanned events that satisfy this SR. 

2. If performed with EDG synchronized with offsite 

power, it shall be performed within the power 

factor limit. However, if grid conditions do not 

permit, the power factor limit is not required to 

be met. Under this condition the power factor 

shall be maintained as close to the limit as 

practicable. 

----------------------------------------------------------------------- 

Verify each EDG rejects a load greater than or equal 

to its associated single largest post-accident load, 

and following load rejection, the frequency is 

≤ 67.5 Hz. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-8 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.8.1.8 --------------------------------NOTE------------------------------- 

This Surveillance shall not normally be performed in 

MODE 1 or 2. However, portions of the Surveillance 

may be performed to reestablish OPERABILITY 

provided an assessment determines the safety of 

the plant is maintained or enhanced. Credit may be 

taken for unplanned events that satisfy this SR. 

----------------------------------------------------------------------- 

Verify on an actual or simulated Emergency Core 

Cooling System (ECCS) initiation signal, 

permanently connected loads remain energized 

from the offsite power system and emergency loads 

are auto-connected through the time delay relays 

from the offsite power system. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.1.9 -------------------------------NOTES------------------------------ 

1. Momentary transients outside the load and 

power factor ranges do not invalidate this test. 

2. This Surveillance shall not normally be 

performed in MODE 1 or 2. However, this 

Surveillance may be performed to reestablish 

OPERABILITY provided an assessment 

determines the safety of the plant is maintained 

or enhanced. Credit may be taken for 

unplanned events that satisfy this SR. 

3. If part b is performed with EDG synchronized 

with offsite power, it shall be performed within 

the power factor limit. However, if grid 

conditions do not permit, the power factor limit 

is not required to be met. Under this condition 

the power factor shall be maintained as close to 

the limit as practicable. 

----------------------------------------------------------------------- 

Verify each EDG operates for ≥ 8 hours: 

a. For ≥ 2 hours loaded ≥ 2625 kW and 

≤ 2750 kW; and 

b. For the remaining hours of the test loaded 

≥ 2250 kW and ≤ 2500 kW. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-9 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.8.1.10 -------------------------------NOTES------------------------------ 

1. This Surveillance shall be performed within 

5 minutes of shutting down the EDG after the 

EDG has operated ≥ 2 hours loaded ≥ 2250 kW 

and ≤ 2500 kW. 

Momentary transients outside of load range do 

not invalidate this test. 

2. All EDG starts may be preceded by an engine 

prelube period. 

----------------------------------------------------------------------- 

Verify each EDG starts and achieves: 

a. In ≤ 10 seconds, voltage ≥ 3975 V and 

frequency ≥ 58.8 Hz; and 

b. Steady state voltage ≥ 3975 V and ≤ 4400 V 

and frequency ≥ 58.8 Hz and ≤ 61.2 Hz. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.1.11 --------------------------------NOTE------------------------------- 

This Surveillance shall not normally be performed in 

MODE 1, 2, or 3. However, this Surveillance may 

be performed to reestablish OPERABILITY provided 

an assessment determines the safety of the plant is 

maintained or enhanced. Credit may be taken for 

unplanned events that satisfy this SR. 

----------------------------------------------------------------------- 

Verify each EDG: 

a. Synchronizes with offsite power source while 

loaded with emergency loads upon a simulated 

restoration of offsite power; 

b. Transfers loads to offsite power source; and 

c. Returns to ready-to-load operation. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-10 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.8.1.12 -------------------------------NOTES------------------------------ 

1. All EDG starts may be preceded by an engine 

prelube period. 

2. This Surveillance shall not normally be 

performed in MODE 1, 2, or 3. However, 

portions of the Surveillance may be performed 

to reestablish OPERABILITY provided an 

assessment determines the safety of the plant 

is maintained or enhanced. Credit may be 

taken for unplanned events that satisfy this SR. 

----------------------------------------------------------------------- 

Verify, on an actual or simulated loss of offsite 

power signal in conjunction with an actual or 

simulated ECCS initiation signal: 

a. De-energization of emergency buses; 

b. Load shedding from emergency buses; and 

c. EDG auto-starts from standby condition and: 

1. Energizes permanently connected loads 

in ≤ 10 seconds; 

2. Energizes auto-connected emergency 

loads through time delay relays; 

3. Achieves steady state voltage ≥ 3975 V 

and ≤ 4400 V; 

4. Achieves steady state frequency 

≥ 58.8 Hz and ≤ 61.2 Hz; and 

5. Supplies permanently connected and 

auto-connected emergency loads for 

≥ 5 minutes. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Operating 

3.8.1 

Monticello 3.8.1-11 Amendment No. 206 

SURVEILLANCE REQUIREMENTS (continued) 

SURVEILLANCE FREQUENCY 

SR 3.8.1.13 --------------------------------NOTE------------------------------- 

This Surveillance shall not normally be performed in 

MODE 1, 2, or 3. However, this Surveillance may 

be performed to reestablish OPERABILITY provided 

an assessment determines the safety of the plant is 

maintained or enhanced. Credit may be taken for 

unplanned events that satisfy this SR. 

----------------------------------------------------------------------- 

Verify interval between each sequenced load block 

is greater than or equal to the minimum design load 

interval. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
AC Sources - Shutdown

3.8.2

3.8 ELECTRICAL POWER SYSTEMS

3.8.2 AC Sources - Shutdown

LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and

the onsite Class 1 E AC electrical power distribution subsystem(s)

required by LCO 3.8.8, "Distribution Systems - Shutdown;" and

b. One emergency diesel generator (EDG) capable of supplying one

division of the onsite Class 1 E AC electrical power distribution

subsystem(s) required by LCO 3.8.8.

APPLICABILITY: MODES 4 and 5,

During movement of recently irradiated fuel assemblies in the secondary

containment. I

ACTIONS

,NOTE----

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One required offsite ----------- NOTE ------ circuit inoperable. Enter applicable Condition and

Required Actions of LCO 3.8.8, with

one required division de-energized

as a result of Condition A.

A.1 Declare affected required Immediately

feature(s), with no offsite

power available,

inoperable.

OR

Monticello 3.8.2-1 Amendment No. 446, 148
ACTIONS (continued) 

CONDITION 

B. One required EOG 

inoperable. 

Monticello 

REQUIRED ACTION 

A.2.1 Suspend CORE 

AL TE RATIONS. 

AND 

A.2.2 Suspend movement of 

recently irradiated fuel 

assemblies in the 

· secondary containment. 

AND 

A.2.3 Initiate action to restore 

required offsite power 

circuit to OPERABLE 

status. 

8.1 Suspend CORE 

AL TERA TIONS. 

AND 

8.2 Suspend movement of 

recently irradiated fuel 

assemblies in the 

secondary containment. 

AND 

8.3 Initiate action to restore 

required EOG to 

OPERABLE status. 

3.8.2-2 

AC Sources - Shutdown 

3.8.2 

COMPLETION TIME 

Immediately 

Immediately 

Immediately 

Immediately 

Immediately 

Immediately 

Amendment No. 146, 148, 198 I 
AC Sources - Shutdown 

3.8.2 

Monticello 3.8.2-3 Amendment No. 209 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.8.2.1 ------------------------------NOTE----------------------------- 

1. The following SRs are not required to be 

performed: SR 3.8.1.3, SR 3.8.1.7, SR 3.8.1.9, 

and SR 3.8.1.11. 

2. SR 3.8.1.5 is not applicable during the fuel oil 

storage tank inspection during the 2023 

Refueling Outage. This note expires upon 

completion of that inspection. 

-------------------------------------------------------------------- 

The following SRs are applicable for AC sources 

required to be OPERABLE: 

SR 3.8.1.1 SR 3.8.1.5

SR 3.8.1.2 SR 3.8.1.7 

SR 3.8.1.3 SR 3.8.1.9

SR 3.8.1.4 SR 3.8.1.11 

In accordance 

with applicable 

SRs 
Diesel Fuel Oil, Lube Oil, and Starting Air 

3.8.3 

Monticello 3.8.3-1 Amendment No. 209 

3.8 ELECTRICAL POWER SYSTEMS 

3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air 

LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystems shall be 

within limits for each required emergency diesel generator (EDG). 

APPLICABILITY: When associated EDG is required to be OPERABLE. 

ACTIONS 

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

1. Separate Condition entry is allowed for each EDG. 

2. a. During the 2023 Refueling Outage the fuel oil storage tank (FOST) may be made 

inoperable and drained, to support cleaning, inspection, testing, and associated repair 

activities without entering Conditions A or G, provided Notes 2.b through 2.d are 

satisfied. 

If the FOST is not restored within 14 days, or Notes 2.b through 2.d are not satisfied, 

enter Condition G. 

b. Verify once per 24 hours that the Alternate Fuel Oil Supply System (AFOSS) contains at 

least a 7-day supply of fuel oil. 

c. While in standby, verify once per 24 hours that the required EDG day/base tanks, in 

combination, provides an 8-hour supply of fuel oil. 

d. The compensatory measures specified within Attachment 1 to letter L-MT-21-072 are 

applicable to performance of the FOST inspection evolution. 

e. SR 3.8.1.5 and SR 3.8.3.1 are not required to be met during the FOST inspection 

evolution. 

f. Note 2 expires upon completion of the FOST inspection evolution during the 2023 

Refueling Outage. 

-------------------------------------------------------------------------------------------------------------------------- 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. Fuel oil level < 7-day 

supply and > 6-day 

supply in storage tank. 

A.1 Restore fuel oil level to 

within limits. 

48 hours 
Diesel Fuel Oil, Lube Oil, and Starting Air 

3.8.3 

Monticello 3.8.3-2 Amendment No. 209 

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 

B. One or more EDGs with 

lube oil inventory 

< 7-day supply and 

> 6-day supply. 

B.1 Restore lube oil inventory to 

within limits. 

48 hours 

C. Stored fuel oil total 

particulates not within 

limit. 

C.1 Restore fuel oil total 

particulates to within limit. 

7 days 

D. New fuel oil properties 

not within limits. 

D.1 Restore stored fuel oil 

properties to within limits. 

30 days 

E. One or more EDGs with 

starting air receiver 

pressure in one starting 

air subsystem 

< 165 psig. 

E.1 Restore starting air receiver 

pressure to  165 psig. 

7 days 

F. One or more EDGs with 

starting air receiver 

pressure in both starting 

air subsystems 

< 165 psig and 

 125 psig. 

F.1 Restore starting air receiver 

pressure in one starting air 

subsystem to  165 psig. 

48 hours 

G. Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, E, or F not met. 

 OR 

 One or more EDGs with 

diesel fuel oil, lube oil, or 

starting air subsystem(s) 

not within limits for 

reasons other than 

Condition A, B, C, D, E, 

or F. 

G.1 Declare associated EDG 

inoperable. 

Immediately 
Diesel Fuel Oil, Lube Oil, and Starting Air 

3.8.3 

Monticello 3.8.3-3 Amendment No. 209 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.8.3.1 Verify the fuel oil storage tank contains ≥ a 7-day 

supply of fuel. 

 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.3.2 Verify, for each EDG, lube oil inventory is ≥ a 7-day 

supply. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil 

are tested in accordance with, and maintained within 

the limits of, the Diesel Fuel Oil Testing Program. 

In accordance 

with the Diesel 

Fuel Oil Testing 

Program 

SR 3.8.3.4 Verify each EDG air start receiver pressure is 

≥ 165 psig. 

In accordance with 

the Surveillance 

Frequency Control 

Program 

SR 3.8.3.5 Check for and remove accumulated water from the 

fuel oil storage tank. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
DC Sources - Operating 

3.8.4 

Monticello 3.8.4-1 Amendment No. 206 

3.8 ELECTRICAL POWER SYSTEMS 

3.8.4 DC Sources - Operating 

LCO 3.8.4 The Division 1 and Division 2 125 VDC and 250 VDC electrical power 

subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more required 

battery chargers on 

Division 1 or Division 2 

inoperable. 

A.1 Restore battery terminal 

voltage to greater than or 

equal to the minimum 

established float voltage. 

AND 

A.2 Verify battery float current 

 2 amps for 250 VDC 

batteries and  1 amp for 

125 VDC batteries. 

AND 

A.3 Restore required Division 1 

or Division 2 battery 

charger(s) to OPERABLE 

status. 

2 hours 

Once per 12 hours 

7 days 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. One Division 1 or 

Division 2 DC electrical 

power subsystem 

inoperable for reasons 

other than Condition A. 

B.1 Restore Division 1 or 

Division 2 DC electrical 

power subsystem to 

OPERABLE status. 

2 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
DC Sources - Operating

3.8.4

Monticello 3.8.4-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

C. Required Action and 

associated Completion 

Time not met.

C.1 Be in MODE 3.

AND

C.2 Be in MODE 4.

12 hours

36 hours

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.4.1 Verify battery terminal voltage is greater than or 

equal to the minimum established float voltage.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.8.4.2 Verify each required battery charger supplies the 

following:

• ≥ 150 amps for 250 VDC Div 1

• ≥ 110 amps for 250 VDC Div 2

• ≥ 75 amps for 125 VDC subsystems,

at greater than or equal to the minimum established 

float voltage for ≥ 4 hours.

In accordance with 

the Surveillance 

Frequency Control 

Program
DC Sources - Operating

3.8.4

Monticello 3.8.4-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.4.3 -------------------------------NOTES------------------------------

1. The modified performance discharge test in 

SR 3.8.6.6 may be performed in lieu of 

SR 3.8.4.3.

2. This Surveillance shall not normally be 

performed in MODE 1, 2, or 3. However, 

portions of the Surveillance may be performed 

to reestablish OPERABILITY provided an 

assessment determines the safety of the plant 

is maintained or enhanced. Credit may be 

taken for unplanned events that satisfy this SR.

------------------------------------------------------------------------

Verify battery capacity is adequate to supply, and 

maintain in OPERABLE status, the required 

emergency loads for the design duty cycle when 

subjected to a battery service test.

In accordance with 

the Surveillance 

Frequency Control 

Program
3.8 ELECTRICAL POWER SYSTEMS 

3.8.5 DC Sources - Shutdown 

DC Sources - Shutdown 

3.8.5 

LCO 3.8.5 Division 1 or Division 2 125 VDC electrical power subsystem shall be 

OPERABLE to support one division of the DC Electrical Power 

Distribution System required by LCO 3.8.8, "Distribution Systems -

Shutdown." 

APPLICABILITY: MODES 4 and 5, 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

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

LCO 3.0.3 is not applicable. 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. Required DC electrical A.1 Suspend CORE Immediately 

power subsystem AL TE RATIONS. 

inoperable. 

AND 

A.2 Suspend movement of Immediately 

recently irradiated fuel 

assemblies in the 

secondary containment. 

AND 

A.3 Initiate action to restore Immediately 

required DC electrical 

power subsystem to 

OPERABLE status. 

Monticello 3.8.5-1 Amendment No. 14e, 148, 198 I 
DC Sources - Shutdown

3.8.5

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.5.1 NOTE.-------------N----------------

The following SR is not required to be performed:

SR 3.8.4.3.

For DC sources required to be OPERABLE, the In accordance

following SRs are applicable: with applicable

SRs

SR 3.8.4.1, SR 3.8.4.2, and SR 3.8.4.3.

Monticello 3.8.5-2 Amendment No. 146
Battery Parameters

3.8.6

3.8 ELECTRICAL POWER SYSTEMS

3.8.6 Battery Parameters

LCO 3.8.6

APPLICABILITY:

Battery parameters for the Division 1 and Division 2 125 VDC and

250 VDC batteries shall be within limits.

When associated DC electrical power subsystems are required to be

OPERABLE.

ACTIONS k I ~X.Y.I. - --------------------------- - ZL JI -- --- ------- - - ------------------------

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more batteries A.1 Perform SR 3.8.4.1. 2 hours

with one or more battery

cells float voltage AND

< 2.07 V.

A.2 Perform SR 3.8.6.1. 2 hours

AND

A.3 Restore affected cell 24 hours

yoltage >_ 2.07 V.

B. One or more batteries B.1 Perform SR 3.8.4.1. 2 hours

with float current

> 2 amps for 250 VDC AND

batteries or > 1 amp for

125 VDC batteries. B.2 Restore battery float current 12 hours

to < 2 amps for 250 VDC

batteries or < 1 amp for

125 VDC batteries.

Monticello 3.8.6-1 Amendment No. 146
Battery Parameters

3.8.6

ACTIONS (continued)__

CONDITION REQUIRED ACTION COMPLETION TIME

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

Required Action C.2 shall be Required Actions C.1 and C.2 are

completed if electrolyte level only applicable if electrolyte level

was below the top of plates. was below the top of plates.

C. One or more batteries C.1 Restore electrolyte level to 8 hours

with one or more cells above top of plates.

electrolyte level less

than minimum AND

established design

limits. C.2 Verify no evidence of 12 hours

leakage.

AND

C-3 Restore electrolyte level to 31 days

greater than or equal to

minimum established

design limits.

D. One or more batteries D-1 Restore battery pilot cell 12 hours

with pilot cell electrolyte temperature to greater than

temperature less than or equal to minimum

minimum established established design limits.

.design limits.

E. Batteries in redundant E.1 Restore battery parameters 2 hours

divisions with battery for batteries in one division

parameters not within to within limits.

limits.

Monticello 3.8.6-2 Amendment No. 146
Battery Parameters

3.8.6

Monticello 3.8.6-3 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

F. Required Action and 

associated Completion 

Time of Condition A, B, 

C, D, or E not met.

OR

One or more batteries 

with one or more battery 

cells float voltage 

< 2.07 V and float 

current > 2 amps for 

250 VDC batteries or 

> 1 amp for 125 VDC 

batteries.

OR

SR 3.8.6.6 not met.

F.1 Declare associated battery 

inoperable.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.6.1 --------------------------------NOTE-------------------------------

Not required to be met when battery terminal 

voltage is less than the minimum established float 

voltage of SR 3.8.4.1.

------------------------------------------------------------------------

Verify each battery float current is ≤ 2 amps for 

250 VDC batteries and ≤ 1 amp for 125 VDC 

batteries.

In accordance with 

the Surveillance 

Frequency Control 

Program
Battery Parameters

3.8.6

Monticello 3.8.6-4 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.6.2 Verify each battery pilot cell voltage is ≥ 2.07 V. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.8.6.3 Verify each battery connected cell electrolyte level is 

greater than or equal to minimum established 

design limits.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.8.6.4 Verify each battery pilot cell temperature is greater 

than or equal to minimum established design limits.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.8.6.5 Verify each battery connected cell voltage is 

≥ 2.07 V. 

In accordance with 

the Surveillance 

Frequency Control 

Program
Battery Parameters

3.8.6

Monticello 3.8.6-5 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.8.6.6 --------------------------------NOTE-------------------------------

This Surveillance shall not normally be performed in 

MODE 1, 2, or 3. However, portions of the 

Surveillance may be performed to reestablish 

OPERABILITY provided an assessment determines 

the safety of the plant is maintained or enhanced. 

Credit may be taken for unplanned events that 

satisfy this SR.

------------------------------------------------------------------------

Verify battery capacity is ≥ 90% of the 

manufacturer’s rating when subjected to a 

performance discharge test or a modified 

performance discharge test.

In accordance with 

the Surveillance 

Frequency Control 

Program

AND

12 months when 

battery shows 

degradation, or 

has reached 85% 

of the expected 

life with capacity 

< 100% of 

manufacturer’s 

rating

AND

24 months when 

battery has 

reached 85% of 

the expected life 

with capacity 

≥ 100% of 

manufacturer’s 

rating
Distribution Systems - Operating 

3.8.7 

Monticello 3.8.7-1 Amendment No. 206 

3.8 ELECTRICAL POWER SYSTEMS 

3.8.7 Distribution Systems - Operating 

LCO 3.8.7 Division 1 and Division 2 AC and DC electrical power distribution 

subsystems shall be OPERABLE. 

APPLICABILITY: MODES 1, 2, and 3. 

ACTIONS 

CONDITION REQUIRED ACTION COMPLETION TIME 

A. One or more AC 

electrical power 

distribution subsystems 

inoperable. 

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

Enter applicable Conditions and 

Required Actions of LCO 3.8.4, "DC 

Sources - Operating," for DC 

divisions made inoperable by 

inoperable power distribution 

subsystems. 

----------------------------------------------- 

A.1 Restore AC electrical power 

distribution subsystem(s) to 

OPERABLE status. 

8 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 

B. One or more DC 

electrical power 

distribution subsystems 

inoperable. 

B.1 Restore DC electrical 

power distribution 

subsystem(s) to 

OPERABLE status. 

2 hours 

OR 

In accordance with 

the Risk Informed 

Completion Time 

Program 
Distribution Systems - Operating 

3.8.7 

Monticello 3.8.7-2 Amendment No. 206 

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME 

C. Required Action and 

associated Completion 

Time of Condition A 

or B not met. 

C.1 Be in MODE 3. 

AND 

C.2 Be in MODE 4. 

12 hours 

36 hours 

D. Two or more electrical 

power distribution 

subsystems inoperable 

that result in a loss of 

function. 

D.1 Enter LCO 3.0.3. Immediately 

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY 

SR 3.8.7.1 Verify correct breaker alignments and voltage to 

required AC and DC electrical power distribution 

subsystems. 

In accordance with 

the Surveillance 

Frequency Control 

Program 
Distribution Systems - Shutdown 

3.8.8 

3.8 ELECTRICAL POWER SYSTEMS 

3.8.8 Distribution Systems - Shutdown 

LCO 3.8.8 The necessary portions of the AC and DC electrical power distribution 

subsystems shall be OPERABLE to support equipment required to be 

OPERABLE. 

APPLICABILITY: MODES 4 and 5, 

During movement of recently irradiated fuel assemblies in the secondary 

containment. 

ACTIONS 

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

LCO 3.0.3 is not applicable. 

CONDITION 

A. One or more required 

AC or DC electrical 

power distribution 

subsystems inoperable. 

Monticello 

A.1 

REQUIRED ACTION 

Declare associated 

supported required 

feature(s) inoperable. 

A.2.1 Suspend CORE 

ALTERATIONS. 

A.2.2 Suspend handling of 

recently irradiated fuel 

assemblies in the 

secondary containment. 

3.8.8-1 

COMPLETION TIME 

Immediately 

Immediately 

Immediately 

Amendment No. 14e, 148, 198 I 
Distribution Systems - Shutdown

3.8.8

Monticello 3.8.8-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2.3 Initiate actions to restore 

required AC and DC 

electrical power distribution 

subsystems to OPERABLE 

status.

 AND

A.2.4 Declare associated 

required shutdown cooling 

subsystem(s) inoperable 

and not in operation.

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.8.8.1 Verify correct breaker alignments and voltage to 

required AC and DC electrical power distribution 

subsystems.

In accordance with 

the Surveillance 

Frequency Control 

Program
Refueling Equipment Interlocks

3.9.1

3.9 REFUELING OPERATIONS

3.9.1 Refueling Equipment Interlocks

The refueling equipment interlocks associated with the reactor mode

switch refuel position shall be OPERABLE.

LCO 3.9.1

.APPLICABILITY: During in-vessel fuel movement with equipment associated with the

interlocks when the reactor mode switch is in the refuel position.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more required A.1 Suspend in-vessel fuel Immediately

refueling equipment movement with equipment

interlocks inoperable, associated with the

inoperable interlock(s).

OR

A.2.1 Insert a control rod Immediately

withdrawal block.

AND

A.2.2 Verify all control rods are Immediately

fully inserted.

Monticello 3.9.1-1 Amendment No. 146
Refueling Equipment Interlocks

3.9.1

Monticello 3.9.1-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of 

the following required refueling equipment interlock 

inputs:

a. All-rods-in;

b. Refuel platform position;

c. Refuel platform fuel grapple, fuel loaded;

d. Refuel platform fuel grapple fully retracted 

position;

e. Refuel platform frame mounted hoist, fuel 

loaded;

f. Refuel platform monorail mounted hoist, fuel 

loaded; and

g. Service platform hoist, fuel loaded.

In accordance with 

the Surveillance 

Frequency Control 

Program
Refuel Position One-Rod-Out Interlock

3.9.2

Monticello 3.9.2-1 Amendment No. 200

3.9 REFUELING OPERATIONS

3.9.2 Refuel Position One-Rod-Out Interlock

LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.

APPLICABILITY: MODE 5 with the reactor mode switch in the refuel position and any 

control rod withdrawn.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Refuel position one-rodout interlock inoperable.A.1 Suspend control rod 

withdrawal.

AND

A.2 Initiate action to fully insert 

all insertable control rods in 

core cells containing one or 

more fuel assemblies.

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.2.1 Verify reactor mode switch locked in refuel position. In accordance with 

the Surveillance 

Frequency Control 

Program
Refuel Position One-Rod-Out Interlock

3.9.2

Monticello 3.9.2-2 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.9.2.2 --------------------------------NOTE-------------------------------

Not required to be performed until 1 hour after any 

control rod is withdrawn.

------------------------------------------------------------------------

Perform CHANNEL FUNCTIONAL TEST. In accordance with 

the Surveillance 

Frequency Control 

Program
Control Rod Position

3.9.3

Monticello 3.9.3-1 Amendment No. 200

3.9 REFUELING OPERATIONS

3.9.3 Control Rod Position

LCO 3.9.3 All control rods shall be fully inserted.

APPLICABILITY: When loading fuel assemblies into the core.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more control 

rods not fully inserted.

A.1 Suspend loading fuel 

assemblies into the core.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.3.1 Verify all control rods are fully inserted. In accordance with 

the Surveillance 

Frequency control 

Program
Control Rod Position Indication

3.9.4

3.9 REFUELING OPERATIONS

3.9.4 Control Rod Position Indication

LCO 3.9.4

APPLICABILITY:

The control rod "full-in" position indication channel for each control rod

shall be OPERABLE.

MODE 5.

ACTIONS

------------ --------------- NOTESeparate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more control rod A.1.1 Suspend in vessel fuel Immediately

position indication movement.

channels inoperable.

AND

A.1.2 Suspend control rod Immediately

withdrawal.

AND

A.1.3 Initiate action to fully insert Immediately

all insertable control rods in

core cells containing one or

more fuel assemblies.

OR

A.2.1 Initiate action to fully insert Immediately

the control rod associated

with the inoperable position

indicator.

AND

Monticello 3.9.4-1 Amendment No. 146
Control Rod Position Indication

3.9.4

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.2.2 Initiate action to disarm the Immediately

control rod drive associated

with the fully inserted

control rod.

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.4.1 Verify the channel has no "full-in" indication on each Each time the

control rod that is not "full-in." control rod is

withdrawn from

the "full-in"

position

Monticello 3.9.4-2 Amendment No. 146
Control Rod OPERABILITY - Refueling

3.9.5

Monticello 3.9.5-1 Amendment No. 200

3.9 REFUELING OPERATIONS

3.9.5 Control Rod OPERABILITY - Refueling

LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more withdrawn 

control rods inoperable.

A.1 Initiate action to fully insert 

inoperable withdrawn 

control rods.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.5.1 --------------------------------NOTE-------------------------------

Not required to be performed until 7 days after the 

control rod is withdrawn.

------------------------------------------------------------------------

Insert each withdrawn control rod at least one notch. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.9.5.2 Verify each withdrawn control rod scram 

accumulator pressure is ≥ 940 psig.

 

In accordance with 

the Surveillance 

Frequency Control 

Program
RPV Water Level

3.9.6

Monticello 3.9.6-1 Amendment No. 200 

3.9 REFUELING OPERATIONS

3.9.6 Reactor Pressure Vessel (RPV) Water Level

LCO 3.9.6 RPV water level shall be ≥ 21 ft 11 inches above the top of the RPV 

flange.

APPLICABILITY: During movement of irradiated fuel assemblies within the RPV,

During movement of new fuel assemblies or handling of control rods 

within the RPV, when irradiated fuel assemblies are seated within the 

RPV.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. RPV water level not 

within limit.

A.1 Suspend movement of fuel 

assemblies and handling of 

control rods within the RPV.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.6.1 Verify RPV water level is ≥ 21 ft 11 inches above the 

top of the RPV flange.

In accordance with 

the Surveillance 

Frequency Control 

Program 
RHR - High Water Level

3.9.7

3.9 REFUELING OPERATIONS

3.9.7 Residual Heat Removal (RHR) - High Water Level

LCO 3.9.7 One RHR shutdown cooling subsystem shall be OPERABLE and in

operation.

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

The required RHR shutdown cooling subsystem may be removed from

operation for up to 2 hours per 8 hour period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the

water level > 21 ft 11 inches above the top of the RPV flange.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A, Required RHR shutdown A.1 Verify an alternate method 1 hour

cooling subsystem of decay heat removal is

inoperable. available. AND

Once per 24 hours

thereafter

B. Required Action and B.1 Suspend loading irradiated Immediately

associated Completion fuel assemblies into the

Time of Condition A not RPV.

met.

AND

B.2 Initiate action to restore Immediately

secondary containment to

OPERABLE status.

AND

Monticello 3.9.7-1 Amendment No. 146
RHR - High Water Level

3.9.7

Monticello 3.9.7-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.3 Initiate action to restore one 

standby gas treatment 

subsystem to OPERABLE 

status.

AND

B.4 Initiate action to restore 

isolation capability in each 

required secondary 

containment penetration 

flow path not isolated.

Immediately

Immediately

C. No RHR shutdown 

cooling subsystem in 

operation.

C.1 Verify reactor coolant 

circulation by an alternate 

method.

AND

C.2 Monitor reactor coolant 

temperature.

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per 12 hours 

thereafter

Once per hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is 

operating.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHR - High Water Level

3.9.7

Monticello 3.9.7-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.9.7.2 Verify required RHR shutdown cooling subsystem 

locations susceptible to gas accumulation are 

sufficiently filled with water.

In accordance with 

the Surveillance 

Frequency Control 

Program
RHR - Low Water Level

3.9.8

3.9 REFUELING OPERATIONS

3.9.8 Residual Heat Removal (RHR) - Low Water Level

LCO 3.9.8 Two RHR shutdown cooling subsystems shall be OPERABLE, and one

RHR shutdown cooling subsystem shall be in operation.

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

The required operating shutdown cooling subsystem may be removed

from operation for up to 2 hours per 8 hour period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the

water level < 21 ft 11 inches above the top of the RPV flange.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. ------- NOTE ------.. ----- A.1 Verify an alternate method 1 hour

Separate Condition entry of decay heat removal is

is allowed for each available for the inoperable AND

required RHR shutdown required RHR shutdown

cooling subsystem. cooling subsystem. Once per 24 hours

thereafter

One or two required

RHR shutdown cooling

subsystems inoperable.

B. Required Action and B.1 Initiate action to restore Immediately

associated Completion secondary containment to

Time of Condition A not OPERABLE status.

met.

AND

B.2 Initiate action to restore one Immediately

standby gas treatment

subsystem to OPERABLE

status.

AND

Monticello 3.9.8-1 Amendment No. 146
RHR - Low Water Level

3.9.8

Monticello 3.9.8-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.3 Initiate action to restore 

isolation capability in each 

required secondary 

containment penetration 

flow path not isolated.

Immediately

C. No RHR shutdown 

cooling subsystem in 

operation.

C.1 Verify reactor coolant 

circulation by an alternate 

method.

AND

C.2 Monitor reactor coolant 

temperature.

1 hour from discovery 

of no reactor coolant 

circulation

AND

Once per 12 hours 

thereafter

Once per hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 

operating.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.9.8.2 Verify RHR shutdown cooling subsystem locations

susceptible to gas accumulation are sufficiently filled 

with water.

In accordance with 

the Surveillance 

Frequency Control 

Program
Inservice Leak and Hydrostatic Testing Operation 

3.10.1 

3.10 	 SPECIAL OPERATIONS 

3.10.1 Inservice Leak and Hydrostatic Testing Operation 

LCO 3.10.1 

APPLICABI LlTY: 

The average reactor coolant temperature specified in Table 1.1-1 for 

MODE 4 may be changed to "NA," and operation considered not to be in 

MODE 3; and the requirements of LCO 3.4.8, "Residual Heat Removal 

(RHR) Shutdown Cooling System - Cold Shutdown," may be suspended, 

to allow reactor coolant temperature> 212°F provided the specific activity 

of the reactor coolant is ::;; 0.02 J!Ci/gm DOSE -EQUIVALENT 1-131: 

• 	 For performance of an inservice leak or hydrostatic test, 

• 	 As a consequence of maintaining adequate pressure for an 

inservice leak or hydrostatic test, or 

• 	 As a consequence of maintaining adequate pressure for control 

rod scram time testing initiated in conjunction with an inservice leak 

or hydrostatic test, 

provided the following MODE 3 LCOs are met: 

a. 	 LCO 3.3.6.2, "Secondary Containment Isolation Instrumentation," 

Functions 1, 3, and 4 of Table 3.3.6.2-1; 

b. 	 LCO 3.6.4.1, "Secondary Containment"; 

c. 	 LCO 3.6.4.2, 'iSecondary Containment Isolation Valves (SCIVs)"; 

and 

d. 	 LCO 3.6.4.3, "Standby Gas Treatment (SGT) System." 

MODE 4 with average reactor coolant temperature> 212°F. 

Monticello 	 3.10.1-1 Amendment No. 446,174 
Inservice Leak and Hydrostatic Testing Operation

3.10.1

ACTIONS

-------------------.----- NOTE -----------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the LCO A1 ----- NOTE --------------

requirements not met. Required Actions to be in

MODE 4 include reducing

average reactor coolant

temperature to < 212 0F.

Enter the applicable Immediately

Condition of the affected

LCO.

OR

A.2.1 Suspend activities that Immediately

could increase the average

reactor coolant temperature

or pressure.

AND

A.2.2 Reduce average reactor 24 hours

coolant temperature to

< 212 0F.

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.1.1 Perform the applicable SRs for the required According to the

MODE 3 LCOs. applicable SRs

Monticello 3.10.1-2 Amendment No. 146
Inservice Leak and Hydrostatic Testing Operation

3.10.1

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.1.2 Verify reactor coolant DOSE EQUIVALENT 1-131 Once within

specific activity is _< 0.02 pCi/gm. 24 hours prior to

increasing

average reactor

coolant

temperature

> 212oF

Monticello 3.10.1-3 Amendment No. 146
Reactor Mode Switch Interlock Testing

3.10.2

3.10 SPECIAL OPERATIONS

3.10.2 Reactor Mode Switch Interlock Testing

LCO 3.10.2 The reactor mode switch position specified in Table 1.1-1 for MODES 3,

4, and 5 may be changed to include the run, startup/hot standby, and

refuel position, and operation considered not to be in MODE 1 or 2, to

allow testing of instrumentation associated with the reactor mode switch

interlock functions, provided:

a. All control rods remain fully inserted in core cells containing one or

more fuel assemblies; and

b. No CORE ALTERATIONS are in progress.

MODES 3 and 4 with the reactor mode switch in the run, startup/hot

standby, or refuel position,

MODE 5 with the reactor mode switch in the run or startup/hot standby

position.

APPLICABILITY:

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the A.1 Suspend CORE Immediately

LCO not met. ALTERATIONS except for

control rod insertion.

AND

A.2 Fully insert all insertable 1 hour

control rods in core cells

containing one or more fuel

assemblies.

AND

A-3.1 Place the reactor mode 1 hour

switch in the shutdown

position.

OR

Monticello 3.10.2-1 Amendment No. 146
Reactor Mode Switch Interlock Testing 

3.10.2 

Monticello 3.10.2-2 Amendment No. 200

ACTIONS (continued) 

CONDITION REQUIRED ACTION COMPLETION TIME

A.3.2 ---------------NOTE--------------

Only applicable in MODE 5.

-------------------------------------

Place the reactor mode 

switch in the refuel position.

1 hour

SURVEILLANCE REQUIREMENTS 

SURVEILLANCE FREQUENCY

SR 3.10.2.1 Verify all control rods are fully inserted in core cells 

containing one or more fuel assemblies.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. In accordance with 

the Surveillance 

Frequency Control 

Program
Single Control Rod Withdrawal - Hot Shutdown

3.10.3

3.10 SPECIAL OPERATIONS

3.10.3 Single Control Rod Withdrawal - Hot Shutdown

LCO 3.10.3 The reactor mode switch position specified in Table 1.1-1 for MODE 3

may be changed to include the refuel position, and operation considered

not to be in MODE 2, to allow withdrawal of a single control rod, provided

the following requirements are met:

a. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock";

b. LCO 3.9.4, "Control Rod Position Indication";

c. All other control rods are fully inserted; and

d.1. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation,"

MODE 5 requirements for Functions 1.a, 1,b, 7.a, 7.b, 10, and 11 of

Table 3.3.1.1-1 and LCO 3.9.5, "Control Rod OPERABILITY -

Refueling,"

OR

2. All other control rods in a five by five array centered on the control

rod being withdrawn are disarmed; at which time LCO 3.1.1,

"SHUTDOWN MARGIN (SDM)," MODE 3 requirements may be

changed to allow the single control rod withdrawn to be assumed to

be the highest worth control rod.

APPLICABILITY: MODE 3 with the reactor mode switch in the refuel position.

Monticello 3.10.3-1 Amendment No. 146
Single Control Rod Withdrawal - Hot Shutdown

3.10.3

ACTIONS

----------------- ...-.-..--.-.-.-....------ --------- .- NC- ) r ------------------------------------------------------------

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the LCO

requirements not met.

A.1 ---- ----------- NOTES-------

1. Required Actions to fully

insert all insertable

control rods include

placing the reactor

mode switch in the

shutdown position.

2. Only applicable if the

requirement not met is a

required LCO.

Enter the applicable

Condition of the affected

LCO.

OR

A.2.1 Initiate action to fully insert

all insertable control rods.

AND

A.2.2 Place the reactor mode

switch in the shutdown

position.

Immediately

Immediately

1 hour

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.3.1 Perform the applicable SRs for the required LCOs. According to the

applicable SRs

Monticello 3.10.3-2 Amendment No. 146
Single Control Rod Withdrawal - Hot Shutdown

3.10.3

Monticello 3.10.3-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.3.2 --------------------------------NOTE-------------------------------

Not required to be met if SR 3.10.3.1 is satisfied for 

LCO 3.10.3.d.1 requirements.

------------------------------------------------------------------------

Verify all control rods, other than the control rod 

being withdrawn, in a five by five array centered on 

the control rod being withdrawn, are disarmed.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.3.3 Verify all control rods, other than the control rod 

being withdrawn, are fully inserted.

In accordance with 

the Surveillance 

Frequency Control 

Program
Single Control Rod Withdrawal - Cold Shutdown

3.10.4

3.10 SPECIAL OPERATIONS

3.10.4 Single Control Rod Withdrawal - Cold Shutdown

LCO 3.10.4 The reactor mode switch position specified in Table 1.1-1 for MODE 4

may be changed to include the refuel position, and operation considered

not to be in MODE 2, to allow withdrawal of a single control rod, and

subsequent removal of the associated control rod drive (CRD) if desired,

provided the following requirements are met:

a. All other control rods are fully inserted;

b.1. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock," and LCO 3.9.4,

"Control Rod Position Indication,"

OR

2. A control rod withdrawal block is inserted; and

c.1. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation,"

MODE 5 requirements for Functions 1.a, 1.b, 7.a, 7.b, 10, and 11 of

Table 3.3.1.1-1, LCO 3.3.8.2, "Reactor Protection System (RPS)

Electric Power Monitoring," MODE 5 requirements, and LCO 3.9.5,

"Control Rod OPERABILITY - Refueling,"

OR

2. All other control rods in a five by five array centered on the control

rod being withdrawn are disarmed; at which time LCO 3.1.1,

"SHUTDOWN MARGIN (SDM)," MODE 4 requirements may be

changed to allow the single control rod withdrawn to be assumed to

be the highest worth control rod.

APPLICABILITY: MODE 4 with the reactor mode switch in the refuel position.

Monticello 3.10.4-1 Amendment No. 146
Single Control Rod Withdrawal - Cold Shutdown

3.10.4

ACTIONS

------------------------------------------------------------ NO r -- - ----- - - - --------------------------------- - -----

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME

A. One or more of the LCO

requirements not met

with the affected control

rod insertable.

A.1 ----------- NOTES-----

1. Required Actions to fully

insert all insertable

control rods include

placing the reactor

mode switch in the

shutdown position.

2. Only applicable if the

requirement not met is a

required LCO.

* Enter the applicable

Condition of the affected

LCO.

OR

A.2.1 Initiate action to fully insert

all insertable control rods.

AND

A.2.2 Place the reactor mode

switch in the shutdown

position.

Immediately

Immediately

1 hour

B. One or more of the LCO B.1 Suspend withdrawal of the Immediately

requirements not met control rod and removal of

with the affected control associated CRD.

rod not insertable.

AND

B.2.1 Initiate action to fully insert Immediately

all control rods.

OR

Monticello 3.10.4-2 Amendment No. 146
Single Control Rod Withdrawal - Cold Shutdown

3.10.4

Monticello 3.10.4-3 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

B.2.2 Initiate action to satisfy the 

requirements of this LCO.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.4.1 Perform the applicable SRs for the required LCOs. According to the 

applicable SRs

SR 3.10.4.2 --------------------------------NOTE-------------------------------

Not required to be met if SR 3.10.4.1 is satisfied for 

LCO 3.10.4.c.1 requirements.

-----------------------------------------------------------------------

Verify all control rods, other than the control rod 

being withdrawn, in a five by five array centered on 

the control rod being withdrawn, are disarmed.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.4.3 Verify all control rods, other than the control rod 

being withdrawn, are fully inserted.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.4.4 --------------------------------NOTE-------------------------------

Not required to be met if SR 3.10.4.1 is satisfied for 

LCO 3.10.4.b.1 requirements.

-----------------------------------------------------------------------

Verify a control rod withdrawal block is inserted. In accordance with 

the Surveillance 

Frequency Control 

Program
Single CRD Removal - Refueling

3.10.5

3.10 SPECIAL OPERATIONS

3.10.5 Single Control Rod Drive (CRD) Removal - Refueling

LCO 3.10.5 The requirements of:

LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation";

LCO 3.3.8.2, "Reactor Protection System (RPS) Electric Power

Monitoring";

LCO 3.9.1, "Refueling Equipment Interlocks";

LCO 3.9.2, "Refuel Position One-Rod-Out Interlock";

LCO 3.9.4, "Control Rod Position Indication"; and

LCO 3.9.5, "Control Rod OPERABILITY - Refueling";

may be suspended in MODE 5 to allow the removal of a single CRD

associated with a control rod withdrawn from a core cell containing one or

more fuel assemblies, provided the following requirements are met:

a. All other control rods are fully inserted;

b. All other control rods in a five by five array centered on the

withdrawn control rod are disarmed;

c. A control rod withdrawal block is inserted and LCO 3.1.1,

"SHUTDOWN MARGIN (SDM)," MODE 5 requirements may be

changed to allow the single control rod withdrawn to be assumed to

be the highest worth control rod; and

d. No other CORE ALTERATIONS are in progress.

APPLICABILITY: MODE 5 with LCO 3.9.5 not met.

Monticello 3.10.5-1 Amendment No. 146
Single CRD Removal - Refueling

3.10.5

Monticello 3.10.5-2 Amendment No. 200

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the 

LCO not met.

A.1 Suspend removal of the 

CRD mechanism.

AND

A.2.1 Initiate action to fully insert 

all control rods.

 OR

A.2.2 Initiate action to satisfy the 

requirements of this LCO.

Immediately

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.5.1 Verify all control rods, other than the control rod 

withdrawn for the removal of the associated CRD, 

are fully inserted.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.5.2 Verify all control rods, other than the control rod 

withdrawn for the removal of the associated CRD, in 

a five by five array centered on the control rod 

withdrawn for the removal of the associated CRD, 

are disarmed.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.5.3 Verify a control rod withdrawal block is inserted. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.5.4 Perform SR 3.1.1.1. According to 

SR 3.1.1.1
Single CRD Removal - Refueling

3.10.5

Monticello 3.10.5-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.5.5 Verify no other CORE ALTERATIONS are in 

progress.

In accordance with 

the Surveillance 

Frequency Control 

Program
Multiple Control Rod Withdrawal - Refueling

3.10.6

3.10 SPECIAL OPERATIONS

3.10.6 Multiple Control Rod Withdrawal - Refueling

LCO 3.10.6 The requirements of:

LCO 3.9.3, "Control Rod Position";

LCO 3.9.4, "Control Rod Position Indication"; and

LCO 3.9.5, "Control Rod OPERABILITY - Refueling";

may be suspended, and the "full-in" position indicators may be bypassed

for any number of control rods in MODE 5, to allow withdrawal of these

control rods, removal of associated control rod drives (CRDs), or both,

provided the following requirements are met:

a. The four fuel assemblies are removed from the core cells

associated with each control rod or CRD to be removed;

b. All other control rods in core cells containing one or more fuel

assemblies are fully inserted; and

c. Fuel assemblies shall only be loaded in compliance with an

approved reload sequence.

APPLICABILITY: MODE 5 with LCO 3.9.3, LCO 3.9.4, or LCO 3.9.5 not met.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the A.1 Suspend withdrawal of Immediately

LCO not met. control rods and removal of

associated CRDs.

AND

A.2 Suspend loading fuel Immediately

assemblies.

AND

Monticello 3.10.6-1 Amendment No. 146
Multiple Control Rod Withdrawal - Refueling

3.10.6

Monticello 3.10.6-2 Amendment No. 200

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

A.3.1 Initiate action to fully insert 

all control rods in core cells 

containing one or more fuel 

assemblies.

 OR

A.3.2 Initiate action to satisfy the 

requirements of this LCO.

Immediately

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.6.1 Verify the four fuel assemblies are removed from 

core cells associated with each control rod or CRD 

removed.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.6.2 Verify all other control rods in core cells containing 

one or more fuel assemblies are fully inserted.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.6.3 --------------------------------NOTE-------------------------------

Only required to be met during fuel loading.

------------------------------------------------------------------------

Verify fuel assemblies being loaded are in 

compliance with an approved reload sequence.

In accordance with 

the Surveillance 

Frequency Control 

Program
Control Rod Testing - Operating

3.10.7

3.10 SPECIAL OPERATIONS

3.10.7 Control Rod Testing - Operating

LCO 3.10.7 The requirements of LCO 3.1.6, "Rod Pattern Control," may be

suspended to allow performance of SDM demonstrations, control rod

scram time testing, and control rod friction testing, provided:

a. The banked position withdrawal sequence requirements of

SR 3.3.2.1.8 are changed to require the control rod sequence to

conform to the specified test sequence;

OR

b. The RWM is bypassed; the requirements of LCO 3.3.2.1, "Control

Rod Block Instrumentation," Function 2 are suspended; and

conformance to the approved control rod sequence for the specified

test is verified by a second licensed operator or other qualified

member of the technical staff.

APPLICABILITY: MODES 1 and 2 with LCO 3.1.6 not met.

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. Requirements of the A.1 Suspend performance of Immediately

LCO not met. the test and exception to

LCO 3.1.6.

Monticello 3.10.7-1 Amendment No. 146
Control Rod Testing - Operating

3.10.7

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.7.1 ----------------------- NOTE----------------

Not required to be met if SR 3.10.7.2 satisfied.

Verify movement of control rods is in compliance During control rod

with the approved control rod sequence for the movement

specified test by a second licensed operator or other

qualified member of the technical staff.

SR 3.10.7.2 ---------------------- NOTE ----------------

Not required to be met if SR 3.10.7.1 satisfied.

Verify control rod sequence input to the RWM is in Prior to control

conformance with the approved control rod rod movement

sequence for the specified test.

Monticello 3.10.7-2 Amendment No. 146
SDM Test - Refueling

3.10.8

3.10 SPECIAL OPERATIONS

3.10.8 SHUTDOWN MARGIN (SDM) Test - Refueling

LCO 3.10.8 The reactor mode switch position specified in Table 1.1-1 for MODE 5

may be changed to include the startup/hot standby position, and

operation considered not to be in MODE 2, to allow SDM testing,

provided the following requirements are met:

a. All Reactor Protection System (RPS) shorting links are removed;

b.1. LCO 3.3.2.1, "Control Rod Block Instrumentation," MODE 2

requirements for Function 2 of Table 3.3.2.1-1, with the banked

position withdrawal sequence requirements of SR 3.3.2.1.8 changed

to require the control rod sequence to conform to the SDM test

sequence,

OR

2. Conformance to the approved control rod sequence for the SDM

test is verified by a second licensed operator or other qualified

member of the technical staff;

c.. Each withdrawn control rod shall be coupled to the associated CRD;

d. All control rod withdrawals during out of sequence control rod

moves shall be made in the single notch withdrawal mode;

e. No other CORE ALTERATIONS are in progress; and

f. CRD charging water header pressure __ 940 psig.

APPLICABILITY: MODE 5 with the reactor mode switch in startup/hot standby position.

Monticello 3.10.8-1 Amendment No. 146
SDM Test - Refueling

3.10.8

Monticello 3.10.8-2 Amendment No. 200

ACTIONS

CONDITION REQUIRED ACTION COMPLETION TIME

A. ------------NOTE------------

Separate Condition entry 

is allowed for each 

control rod.

---------------------------------

One or more control 

rods not coupled to its 

associated CRD.

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

Rod worth minimizer may be 

bypassed as allowed by 

LCO 3.3.2.1, "Control Rod Block 

Instrumentation," if required, to 

allow insertion of inoperable control 

rod and continued operation.

------------------------------------------------

A.1 Fully insert inoperable 

control rod.

AND

A.2 Disarm the associated 

CRD.

3 hours

4 hours

B. Requirements of the 

LCO not met for reasons 

other than Condition A.

B.1 Place the reactor mode 

switch in the shutdown or 

refuel position.

Immediately

SURVEILLANCE REQUIREMENTS

SURVEILLANCE FREQUENCY

SR 3.10.8.1 Verify all RPS shorting links are removed. In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.8.2 --------------------------------NOTE-------------------------------

Not required to be met if SR 3.10.8.3 satisfied.

-----------------------------------------------------------------------

Perform the MODE 2 applicable SRs for 

LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1 

According to the 

applicable SRs
SDM Test - Refueling

3.10.8

Monticello 3.10.8-3 Amendment No. 200

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

SR 3.10.8.3 --------------------------------NOTE-------------------------------

Not required to be met if SR 3.10.8.2 satisfied.

------------------------------------------------------------------------

Verify movement of control rods is in compliance 

with the approved control rod sequence for the SDM 

test by a second licensed operator or other qualified 

member of the technical staff.

During control rod 

movement

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 

progress.

In accordance with 

the Surveillance 

Frequency Control 

Program

SR 3.10.8.5 Verify each withdrawn control rod does not go to the 

withdrawn overtravel position.

Each time the 

control rod is 

withdrawn to “full 

out” position

AND

Prior to satisfying 

LCO 3.10.8.c 

requirement after 

work on control 

rod or CRD 

System that could 

affect coupling

SR 3.10.8.6 Verify CRD charging water header pressure 

≥ 940 psig.

In accordance with 

the Surveillance 

Frequency Control 

Program
Design Features 

4.0 

4.0 DESIGN FEATURES 

4.1 Site Location 

4.1.1 Site and Exclusion Area Boundaries 

The site area and exclusion area boundaries are as shown in Chapter 15, 

Figure ND-95208 of the USAR. 

4.1.2 Low Population Zone 

The low population zone is all the land within a 1 mile radius circle as shown in 

Chapter 15, Figure ND-95208 of the USAR. 

4.2 Reactor Core 

4.2.1 Fuel Assemblies 

The reactor shall contain 484 fuel assemblies. Each assembly shall consist of a 

matrix of Zircalloy fuel rods with an initial composition of natural or slightly 

enriched uranium dioxide (U02) as fuel material and water rods. Some fuel rods 

may consist of a Zircalloy base and a zirconium inner liner. Fuel assemblies 

shall be limited to those fuel designs that have been analyzed with NRC staff 

approved codes and methods and have been shown by tests or analyses to 

comply with all safety design bases. A limited number of lead test assemblies 

that have not completed representative testing may be placed in nonlimiting core 

regions. 

4.2.2 Control Rod Assemblies 

The reactor core shall contain 121 cruciform shaped control rod assemblies. The 

control material shall be boron carbide or hafnium metal as approved by the 

NRC. 

4.3 Fuel Storage 

4.3.1 Criticality 

Monticello 

4.3.1.1 The spent fuel storage racks are designed and shall be maintained 

with: 

a. Fuel assemblies having a maximum k-infinity of 0.8825 in the 

normal spent fuel pool storage rack configuration; 

b. kett :s: 0.95 for high density fuel racks and low density fuel racks if 

fully flooded with unborated water, which includes an allowance 

for uncertainties as described in Section 10.2.1 of the USAR; 

4.0-1 Amendment No. 446, 182 
Design Features 

4.0 

4.0 DESIGN FEATURES 

4.3 Fuel Storage (continued) 

c. A nominal 6.563 inch center to center distance between fuel 

assemblies placed in the 13 x 13 high density storage racks, a 

nominal 6.625 inch center to center distance between fuel 

assemblies placed in the original storage rack, and a 12-inch gap 

between the high density racks and the original rack. 

4.3.1.2 The new fuel vault shall not be used for fuel storage. The new fuel 

shall be stored in the spent fuel storage racks. 

4.3.2 Drainage 

The spent fuel storage pool is designed and shall be maintained to prevent 

inadvertent draining of the pool below elevation 1003 ft 7.25 inches. 

4.3.3 Capacity 

Monticello 

The spent fuel storage pool is designed and shall be maintained with a storage 

capacity limited to no more than 2217 fuel assemblies. 

4.0-2 Amendment No. 146, 150, 182 
Responsibility 

5.1 

5.0 ADMINISTRATIVE CONTROLS 

5.1 Responsibility 

5.1.1 The plant manager shall be responsible for overall unit operation and shall 

delegate in writing the succession to this responsibility during his absence. 

The plant manager or his designee shall approve, prior to implementation, each 

proposed test, experiment, or modification to systems or equipment that affects 

nuclear safety. 

5.1.2 The shift supervisor shall be responsible for the control room command function. 

Monticello 

During any absence of the shift supervisor from the control room complex while 

the unit is in MODE 1, 2, or 3, an individual with an active senior reactor operator 

(SRO) license shall be designated to assume the control room command 

function. During any absence of the shift supervisor from the control room 

complex while the unit is in MODE 4 or 5, an individual with an active SRO 

license or reactor operator (RO) license shall be designated to assume the 

control room command function. 

5.1-1 Amendment No. 44&, 195 I 
Organization

5.2

5.0 ADMINISTRATIVE CONTROLS

5.2 Organization

5.2.1 Onsite and Offsite Organizations

Onsite and offsite organizations shall be established for unit operation and

corporate management, respectively. The onsite and offsite organizations shall

include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and

established throughout highest management levels, intermediate levels,

and all operating organization positions. These relationships shall be

documented and updated, as appropriate, in organization charts, functional

descriptions of departmental responsibilities and relationships, and job

descriptions for key personnel positions, or in equivalent forms of

documentation. These requirements including the plant-specific titles of

those personnel fulfilling the responsibilities of the positions delineated in

these Technical Specifications shall be documented in the USAR or Quality

Assurance Topical Report.

b. The plant manager shall be responsible for overall safe operation of the

plant and shall have control over those onsite activities necessary for safe

operation and maintenance of the plant.

c. A specified corporate officer shall have corporate responsibility for overall

plant nuclear safety and shall take any measures needed to ensure

acceptable performance of the staff in operating, maintaining, and providing

technical support to the plant to ensure nuclear safety.

d. The individuals who train the operating staff, carry out health physics, or

perform quality assurance functions may report to the appropriate onsite

manager; however, these individuals shall have sufficient organizational

freedom to ensure their independence from operating pressures.

5.2.2 Unit Staff

The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned to each reactor containing fuel

and an additional non-licensed operator shall be assigned for each control

room from which a reactor is operating in MODES 1, 2, or 3.

b. Shift crew composition may be less than the minimum requirement of

10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.f for a period of time not to

exceed 2 hours in order to accommodate unexpected absence of on-*duty

shift crew members provided immediate action is taken to restore the shift

crew composition to within the minimum requirements.

Monticello 5.2-1 Amendment No. 146

Monticello 5.2-1 Amendment No. 146
Organization 

5.2 

5.2 Organization 

5.2.2 Unit Staff (continued) 

Monticello 

c. A radiation protection technician shall be on site when fuel is in the reactor. 

The position may be vacant for not more than 2 hours, in order to provide 

for unexpected absence, provided immediate action is taken to fill the 

required position. 

d. Not Used. 

e. The operations manager shall hold an SRO license or shall formerly have 

held an SRO license. If the operations manager does not hold an SRO 

license, another member of plant management shall hold an SRO license 

and shall be assigned to the plant operations group on a long term basis 

(approximately 2 years). This individual shall not be assigned to a rotating 

shift. 

f. An individual shall provide advisory technical support to the unit operations 

shift crew in the areas of thermal hydraulics, reactor engineering, and plant 

analysis with regard to the safe operation of the unit. This individual shall 

meet the qualifications specified by the Commission Policy Statement on 

Engineering Expertise on Shift. 

5.2-2 Amendment No. 146, 163, 195 I 
Unit Staff Qualifications 

5.3 

5.0 ADMINISTRATIVE CONTROLS 

5.3 Unit Staff Qualifications 

5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of 

ANSI N 18.1-1971 for comparable positions, except for the following: 

• The radiation protection manager shall meet or exceed the qualifications of 

Regulatory Guide 1.8, Revision 1, September 1975. 

• In addition, the operations manager shall be qualified as required by 

Specification 5.2.2.e. 

• The licensed operators shall comply only with the requirements of 

10 CFR 55. 

5.3.2 For the purpose of 10 CFR 55.4, a licensed SRO and a licensed RO are those 

individuals who, in addition to meeting the requirements of Specification 5.3.1, 

perform the functions described in 10 CFR 50.54(m). 

Monticello 5.3-1 Amendment No. 44e, 195 I 
Procedures

5.4

5.0 ADMINISTRATIVE CONTROLS

5.4 Procedures

5.4.1 Written procedures shall be established, implemented, and maintained covering

the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33,

Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the

requirements of NUREG-0737 and NUREG-0737, Supplement 1, as stated

in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

Monticello 5.4-1 Amendment No. 146
Programs and Manuals 

5.5 

Monticello 5.5-1 Amendment No. 146 

5.0 ADMINISTRATIVE CONTROLS 

5.5 Programs and Manuals 

The following programs shall be established, implemented, and maintained. 

5.5.1 Offsite Dose Calculation Manual (ODCM)

 a. The ODCM shall contain the methodology and parameters used in the 

calculation of offsite doses resulting from radioactive gaseous and liquid 

effluents, in the calculation of gaseous and liquid effluent monitoring alarm 

and trip setpoints, and in the conduct of the radiological environmental 

monitoring program; and 

 b. The ODCM shall also contain the radioactive effluent controls and 

radiological environmental monitoring activities, and descriptions of the 

information that should be included in the Annual Radiological 

Environmental Operating, and Radioactive Effluent Release Reports 

required by Specification 5.6.1 and Specification 5.6.2. 

 c. Licensee initiated changes to the ODCM: 

 1. Shall be documented and records of reviews performed shall be 

retained. This documentation shall contain: 

 a) Sufficient information to support the change(s) together with the 

appropriate analyses or evaluations justifying the change(s); 

and 

 b) A determination that the change(s) maintain the levels of 

radioactive effluent control required by 10 CFR 20.1302, 

40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and 

not adversely impact the accuracy or reliability of effluent, dose, 

or setpoint calculations; 

 2. Shall become effective after the approval of the plant manager; and 

 3. Shall be submitted to the NRC in the form of a complete, legible copy 

of the entire ODCM as a part of or concurrent with the Radioactive 

Effluent Release Report for the period of the report in which any 

change in the ODCM was made. Each change shall be identified by 

markings in the margin of the affected pages, clearly indicating the 

area of the page that was changed, and shall indicate the date 

(i.e., month and year) the change was implemented. 
Programs and Manuals

5.5

5.5 Programs and Manuals

5.5.2 Primary Coolant Sources Outside Containment

This program provides controls to minimize leakage from those portions of

systems outside containment that could contain highly radioactive fluids during a

serious transient or accident to levels as low as practicable. The systems include

Core Spray, High Pressure Coolant Injection, Residual Heat Removal, Reactor

Core Isolation Cooling, process sampling, and Standby Gas Treatment. The

program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at least once per

24 months.

The provisions of SR 3.0.2 are applicable.

5.5.3 Radioactive Effluent Controls Program

This program conforms to 10 CFR 50.36a for the control of radioactive effluents

and for maintaining the doses to members of the public from radioactive effluents

as low as reasonably achievable. The program shall be contained in the ODCM,

shall be implemented by procedures, and shall include remedial actions to be

taken whenever the program limits are exceeded. The program shall include the

following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous

monitoring instrumentation including surveillance tests and setpoint

determination in accordance with the methodology in the ODCM;

b. Limitations on the concentrations of radioactive material released in liquid

effluents to unrestricted areas, conforming to ten times the concentration

values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001-20.2402;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous

effluents in accordance with 10 CFR 20.1302 and with the methodology

and parameters in the ODCM;

d. Limitations on the annual and quarterly doses or dose commitment to a

member of the public from radioactive materials in liquid effluents released

from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative dose contributions from radioactive effluents

for the current calendar quarter and current calendar year in accordance

with the methodology and parameters in the ODCM at least every 31 days.

Determination of projected dose contributions from radioactive effluents in

accordance with the methodology in the ODCM at least every .31 days;

Monticello 5.5-2 Amendment No. 146
Programs and Manuals

5.5

5.5 Programs and Manuals

5.5.3 Radioactive Effluent Controls Program (continued)

f. Limitations on the functional capability and use of the liquid and gaseous

effluent treatment systems to ensure that appropriate portions of these

systems are used to reduce releases of radioactivity when the projected

doses in a period of 31 days would exceed 2% of the guidelines for the

annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

g. Limitations on the dose rate resulting from radioactive material released in

gaseous effluents from the site to areas at or beyond the site boundary

shall be in accordance with the following:

1. For noble gases: a dose rate _ 500 mrem/yr to the whole body and a

dose rate _< 3000 mrem/yr to the skin; and

2. For iodine-131, iodine-1 33, tritium, and all radionuclides in particulate

form with half-lives greater than 8 days: a dose rate _• 1500 mrem/yr

to any organ;

h. Limitations on the annual and quarterly air doses resulting from noble

gases released in gaseous effluents from each unit to areas beyond the

site boundary, conforming to 10 CFR 50, Appendix I;

i. Limitations on the annual and quarterly doses to a member of the public

from iodine-131, iodine-133, tritium, and all radionuclides in particulate form

with half lives > 8 days in gaseous effluents released from each unit to

areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;

j. Limitations on the annual dose or dose commitment to any member of the

public, beyond the site boundary, due to releases of radioactivity and to

radiation from uranium fuel cycle sources, conforming to 40 CFR 190; and

k. Limitations on venting and purging of the primary containment through the

Standby Gas Treatment System to maintain releases as low as reasonably

achievable.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive

Effluent Controls Program surveillance frequency.

5.5.4 Component Cyclic or Transient Limit

This program provides controls to track the USAR Table 4.2-1, cyclic and

transient occurrences to ensure that components are maintained within the

design limits.

Monticello 5.5-3 Amendment No. 146

Monticello 5.5-3 Amendment No. 146
Programs and Manuals 

5.5 

5.5 Programs and Manuals 

5.5.5 (Deleted) 

5.5.6 Ventilation Filter Testing Program (VFTP) 

Monticello 

A program shall establish the required testing of Engineered Safety Feature 

(ESF) filter ventilation systems. Tests described in Specifications 5.5.6.a and 

5.5.6.b shall be performed once per 24 months and following painting, fire, or 

chemical release in any ventilation zone communicating with the subsystem 

while it is in operation that could adversely affect the high efficiency particulate 

air (HEPA) filters or charcoal adsorber capability. 

5.5-4 Amendment No. -Me, 194 I 
Programs and Manuals 

5.5 

5.5 Programs and Manuals 

5.5.6 Ventilation Filter Testing Program (VFTP) (continued) 

Monticello 

The test described in Specification 5.5.6.a shall be performed after any 

maintenance or testing that could affect the leak tight integrity of the HEPA filters. 

The test described in Specification 5.5.6.b shall be performed after any 

maintenance or testing that could affectthe leak tight integrity of the charcoal 

adsorber banks. 

Tests described in Specification 5.5.6.c shall be performed once per 24 months; 

at least once per 720 hours of system operation; following painting, fire, or 

chemical release in any ventilation zone communicating with the subsystem 

while it is in operation that could adversely affect the ch~rcoal adsorber 

capability. · 

The tests described in Specification 5.5.6.d shall be performed once per 92 days 

· for the Standby Gas Treatment (SGT) System and once per 24 months for the 

Control Room Emergency Filtration (CREF) System. 

(Deleted) 

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test 

frequencies. · 

a. Demonstrate for each of the ESF systems that an in place test of the HEPA 

. filters shows a penetration. and system bypass specified below when tested 

in accordance with Regulatory Guide 1.52, Revision 2, and 

ANSI N510-1989 at the system flowrate specified below. 

ESF Ventilation 

System 

SGT System 

CREF Sy~em 

Penetration {%) 

~ 1.0 

.s; 1.0 for each individual 

. HEPA fi1ter and 5 0.05 for 

each pair of HEPA filters 

Flowrate ( cfm) 

~ 3, 150 and ~ 3,850 

:.:: 900 and ~ 1,100 

·5.5-5 Amendment No. 449, 181 

I 
Programs and Manuals 

5.5 

5.5 Programs and Manuals 

· 5.5.6 Ventilation Filter Testing Program NFTP) (continued) 

Monticello 

b. Demonstrate for each of the ESF systems that an inplace test of the 

charcoal adsotber shows a penetration and system bypass specified below 

· when tested in accordance with Regulatory Guide 1.52, Revision 2, and 

ANSI N510-1989 at the system flowrate specified below. 

ESF Ventilation 

System Penetration(%) 

SGT System ~ 1.0 

CREF System ~ 1.Q for each individual 

charcoal adsorber section 

and s; 0.05 for each pair of 

charcoal adsorber sections 

Flowrate ( cfm) 

~ 3, 150 and ~ 3,850 

~ 900 and~ 1,100 

c. Demonstrate for each of the ESF systems that a laboratciry test of a sample 

of the charcoal adsorber, when obtained as described in Regulatory 

Position C.6.b of Regulatory Guide 1.52, Revision 2, shows the methyl 

iodide penetration specified below when tested in accordance with 

ASTM 03803~1989 at a temperature of 30°C (86°F) a~d the relative 

humidity specified below. · 

ESF Ventilation 

System 

SGT System 

CREF System 

Penetration (%) 

::; 5.0 

~0'.5 

RH(%) 

95 

95 

d. Demonstrate for each of the ESF systems that the pressure drop across 

the combined filters is as specified below when tested in· accordance with 

Regulatory Guide 1.52, Revision 2, and ANSI N510~1989 at the system 

flowrate specified below. · 

ESF Ventilation 

System 

SGT System 

CREF System 

e. (Deleted) 

Delta P (inches water· 

gauge) 

~6 

::;8 

5.5-6 

Flowrate (cfm) 

~ 3,150 and ~ 3,850 

~ 900 ands 1,100 

Amendment No.~. 181 
Programs and Manuals 

5.5 

5.5' Programs and Manuals 

5.5.7 

Monticello 

Explosive Gas and Storage Tank Radioactivity Monitoring Program 

This program provides controls for potentially explosive gas mixtures contained 

in the Offgas Treatment System, the quantity of radioactivity contained in gas 

storage tanks or fed into the Offgas Treatment System, and the quantity of 

radioactivity contained in unprotected outdoor liquid storage tanks. The quantity 

of radioactivity aft.er 12 hours holdup contained in each gas storage tank shall be 

~ 22,000 Ci of noble gases (considered as dose equivalent Xe-133). The 

quantity of liquid radioactive waste contained in each unprotected outdoor liquid 

storage tank shall be~ 10 Ci, excluding tritium and dissolved or entrained noble 

gases. 

The program shall include: 

a. The limits for concentrations of hydrogen and oxygen in the Offgas 

Treatmerit System and a Surveillance program to ensure the limits are 

maintained. Such limits shall be appropriate to the system's design cr1teria 

(i.e., whether or not the system is designed to withstand a hydrogen 

explosion}; 

b. A Surveillance program to ensure that the quantity of radioactivity 

contained in each gas storage tank and fed into the Offgas Treatment 

System is less than the amount that would result in a whole body exposure 

of~ 0.5 rem to any individual in an unrestricted area, in the event of an 

uncontrolled release of the tanks' contents; and 

c. A Surveillance program to ensure that the quantity of radioactivity 

contained in all oμtdoor liquid radwaste tanks that are not surrounded by 

liners, dikes, or walls, capable of holding the tanks' contents and that do not 

have tank overflows and surrounding area drains connected to the Liquid 

Radwaste Treatment System is less than the amount that would result in 

concentrations less than the limits of 1 O CFR 20, Appendix B, Table 2, 

Column 2, at the nearest potable water supply and the nearest surface 

water supply in an unrestricted area, in the event of an uncontrolled release 

of the tanks' contents. 

5.5-7 Amendment No. 44-e, 181 
Programs and Manuals

5.5

5.5 Programs and Manuals

5.5.7 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued)

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and

Storage Tank Radioactivity Monitoring Program Surveillance Frequencies.

5.5.8 Diesel Fuel Oil Testing Program

A diesel fuel oil testing program to implement required testing of both new fuel oil

and stored fuel oil shall be established. The program shall include sampling and

testing requirements, and acceptance criteria, all in accordance with applicable

ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to the storage tank by

determining that the fuel oil has:

1. An API gravity within limit;

2. A flash point and saybolt viscosity within limits; and

3. A water and sediment content within limits;

b. Within 31 days following addition of the new fuel oil to the storage tank,

verify that the properties of the new fuel oil, other than those addressed in

Specification 5.5.8.a above, are within limits; and

c. Total particulate concentration of the fuel oil is < 10 mg/l when tested every

31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil

Testing Program test Frequencies.

5.5.9 Technical Specifications (TS) Bases Control Program

This program provides a means for processing changes to the Bases of these

Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate

administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval

provided the changes do not require either of the following:

1. A change in the TS incorporated in the license; or

2. A change to the USAR or Bases that requires NRC approval pursuant

to 10 CFR 50.59.

Monticello 5.5-8 Amendment No. 146

Monticello 5.5-8 Amendment No. 146
Programs and Manuals

5.5

5.5 Programs and Manuals

5.5.9 Technical Specifications (TS) Bases Control Program (continued)

c. The TS Bases Control Program shall contain provisions to ensure that the

Bases are maintained consistent with the USAR.

d. Proposed changes that meet the criteria of Specification 5.5.9.b above shall

be reviewed and approved by the NRC prior to implementation. Changes

to the Bases implemented without prior NRC approval shall be provided to

the NRC on a frequency consistent with 10 CFR 50.71(e).

5.5.10 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions

taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if

loss of safety function exists. Additionally, other appropriate actions may be

taken as a result of the support system inoperability and corresponding exception

to entering supported system Condition and Required Actions. This program

implements the requirements of LCO 3.0.6.

a. The SFDP shall contain the following:

•1. Provisions for cross train checks to ensure a loss of the capability to

perform the safety function assumed in the accident analysis does not

go undetected;

2. Provisions for ensuring the plant is maintained in a safe condition if a

loss of function condition exists;

3. Provisions to ensure that an inoperable supported system's

Completion Time is not inappropriately extended as a result of

multiple support system inoperabilities; and

4. Other appropriate limitations and remedial or compensatory actions.

b. A loss of safety function exists when, assuming no concurrent single failure,

no concurrent loss of offsite power, or no concurrent loss of onsite

emergency'diesel generator(s), a safety function assumed in the accident

analysis cannot be performed. For the purpose of this program, a loss of

safety function may exist when a support system is inoperable, and:

1. A required system redundant to the system(s) supported by the

inoperable support system is also inoperable;

2. A required system redundant to the system(s) in turn supported by the

inoperable supported system is also inoperable; or

Monticello 5.5-9 Amendment No. 146.Monticello 5.5-9 Amendment No. 146
Programs and Manuals 

5.5 

5.5 Programs and Manuals 

5.5.10 

5.5.11 

Monticello 

Safety Function Determination Program (SFDP) (continued) 

3. A required system redundant to the support system(s) for the 

supported systems described in Specifications 5.5.1 O.b.1 and 

5.5.1 O.b.2 above is also inoperable. 

c. The SFDP identifies where a loss of safety function exists. 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 loss of safety function is 

caused by the inoperability of a single Technical Specification support 

system, the appropriate Conditions and Required Actions to enter are those 

of the support system. 

Primary Containment Leakage Rate Testing Program 

a. A program shall establish the leakage rate testing of the containment as 

required by 1 O CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as 

modified by approved exemptions. This program shall be in accordance 

with the guidelines contained in NEI 94-01, "Industry Guideline for 

Implementing Performance-Based Option of 10 CFR 50, Appendix J," 

Revision 2-A, dated October 2008, as modified by the following exceptions: 

1. The main steam line pathway leakage contribution is excluded from 

the sum of the leakage rates from Type B and C tests specified in 

Section 111.B of 10 CFR 50, Appendix J, Option B, Section 6.4.4 of 

ANSI/ANS 56.8-2002, and Section 10.2 of NEI 94-01, Revision 2-A; 

and 

2. The main steam line pathway leakage contribution is excluded from 

the overall integrated leakage rate from Type A tests specified in 

Section Ill.A of 10 CFR 50, Appendix J, Option B, Section 3.2 of 

ANSI/ANS 56.8-2002, and Section 8.0 and 9.0 of NEI 94-01, 

Revision 2-A. 

b. The calculated peak containment internal pressure for the design basis loss 

of coolant accident, Pa, is 44.1 psig. The containment design pressure is 

56 psig. 

c. The maximum allowable containment leakage rate, La. at Pa, shall be 1.2% 

of containment air weight per day. 

5.5-10 Amendment No. 146 148, 175, 176, 193 
Programs and Manuals 

5.5 

5.5 Programs and Manuals 

5.5.11 Primary Containment Leakage Rate Testing Program (continued) 

5.5.12 

Monticello 

d. Leakage rate acceptance criteria are: 

1. Containment leakage rate acceptance criterion is ~ 1.0 La. During the 

first unit startup following testing in accordance with this program, the 

leakage rate acceptance criteria are < 0.60 La for the Type B and C 

tests and~ 0.75 La for Type A tests. 

2. Air lock testing acceptance criterion is an overall air lock leakage rate 

of~ 0.05 La when tested at~ Pa. 

e. The resilient seals of each 18 inch primary containment purge and vent 

valve shall be replaced at least once every 9 years. The provisions of 

SR 3.0.2 are applicable to this requirement. If a common mode failure 

attributable to the resilient seals is identified based on the results of 

SR 3.6.1.3.11, the resilient seals of all 18 inch primary containment purge 

and vent valves shall be replaced. 

f. The provisions of SR 3.0.3 are applicable to the Primary Containment 

Leakage Rate Testing Program. 

Battery Monitoring and Maintenance Program 

This Program provides for battery restoration and maintenance, based on the 

recommendations of IEEE Standard 450-1995, "IEEE Recommended Practice 

for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for 

Stationary Applications," or of the battery manufacturer of the following: 

a. Actions to restore battery cells with float voltage< 2.13 V; and 

b. Actions to equalize and test battery cells that had been discovered with 

electrolyte level below the minimum established design limit. 

5.5-11 Amendment No. 146, 148, 160, 187 
Programs and Manuals 

5.5 

5.5 Programs and Manuals 

5.5.13 

Monticello 

Control Room Envelope Habitability Program 

A Control Room Envelope (CRE) Habitability Program shall be established 

and implemented to ensure that CRE habitability is maintained such that, 

with an OPERABLE Control Room Emergency Filtration (CREF) System, 

CRE occupants can control the reactor safely under normal conditions and 

maintain it in a safe condition following a radiological event, hazardous 

chemical release, or a smoke challenge. The program shall ensure that 

adequate radiation protection is provided to permit access and occupancy of 

the CRE under design basis accident (OBA) conditions without personnel 

receiving radiation exposures in excess of 5 rem total effective dose 

equivalent (TEDE) for the duration of the accident. The program shall include 

the following elements: 

a. The definition of the CRE and the CRE boundary. 

b. Requirements for maintaining the CRE boundary in its design condition 

including configuration control and preventative maintenance. 

c. Requirements for (i) determining the unfiltered air in-leakage past the 

CRE boundary into the CRE in accordance with the testing methods 

and at the Frequencies specified in Sections C.1 and C.2 of 

Regulatory Guide 1.197, "Demonstrating Control Room Envelope 

Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) 

assessing CRE habitability at the Frequencies specified in Sections 

C.1 and C.2 of Regulatory Guide 1.197, Revision 0. 

d. Measurement, at designated locations, of the CRE pressure relative to 

all external areas adjacent to the CRE boundary during the 

pressurization mode of operation by one subsystem of the CREF 

System, operating at the flow rate required by the VFTP, at a 

Frequency of 24 months on a STAGGERED TEST BASIS. The results 

shall be trended and used as part of the 24 month assessment of the 

CRE boundary. 

e. The quantitative limits on unfiltered air in-leakage into the CRE. These 

limits shall be stated in a manner to allow direct comparison to the 

unfiltered air in-leakage measured by the testing described in 

paragraph c. The unfiltered air in-leakage limit for radiological 

challenges is the in-leakage flow rate assumed in the licensing basis 

analyses of OBA consequences. Unfiltered air in-leakage limits for 

hazardous chemicals must ensure that exposure of CRE occupants to 

these hazards will be within the assumptions in the licensing basis. 

f. The provisions of SR 3.0.2 are applicable to the Frequencies for 

assessing CRE habitability, determining CRE unfiltered in-leakage, 

and measuring CRE pressure and assessing the CRE boundary as 

required by paragraphs c and d, respectively. 

5.5-12 Amendment No. +60, 182 
Programs and Manuals 

5.5 

Monticello 5.5-13 Amendment No. 206 

5.5 Programs and Manuals 

5.5.14 Spent Fuel Pool Boral Monitoring Program 

 The program provides routine monitoring and actions to ensure that the condition 

of Boral in the spent fuel pool racks is appropriately monitored to ensure that the 

Boral neutron attenuation capability described in the criticality safety analysis of 

USAR Section 10.2.1 is maintained. The program shall include the following: 

 a. Periodic physical examination of representative Boral coupons or in situ 

storage racks at a frequency defined by observed trends or calculated 

projections of Boral degradation. The measurement will be performed to 

ensure that average thickness of the coupon (or average thickness of a 

representative area of the in situ storage rack) does not exceed the nominal 

design thickness of the coupon (or storage rack) plus the 0.055-inch 

dimension assumed for the analyzed blister. 

 b. Neutron attenuation testing of a representative Boral coupon or in situ 

storage rack shall be performed prior to December 31, 2015, and thereafter 

at a frequency of not more than 10 years, or more frequently based on 

observed trends or calculated projections of Boral degradation. The 

acceptance criterion for minimum boron areal density will be that value 

assumed in the criticality safety analysis (0.013 gm/cm2). 

 c. Description of appropriate corrective actions for discovery of nonconforming 

Boral. 

5.5.15 Surveillance Frequency Control Program 

This program provides controls for Surveillance Frequencies. The program shall 

ensure that Surveillance Requirements specified in the Technical Specifications 

are performed at intervals sufficient to assure the associated Limiting Conditions 

for Operation are met. 

a. The Surveillance Frequency Control Program shall contain a list of 

Frequencies of those Surveillance Requirements for which the Frequency is 

controlled by the program. 

 

b. Changes to the Frequencies listed in the Surveillance Frequency Control 

Program shall be made in accordance with NEI 04-10, “Risk-Informed 

Method for Control of Surveillance Frequencies,” Revision 1. 

c. The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable 

to the Frequencies established in the Surveillance Frequency Control 

Program. 
Programs and Manuals 

5.5 

Monticello 5.5-14 Amendment No. 206 

5.5 Programs and Manuals 

5.5.16 Risk Informed Completion Time Program 

This program provides controls to calculate a Risk Informed Completion Time 

(RICT) and must be implemented in accordance with NEI 06-09-A, Revision 0, 

"Risk-Managed Technical Specifications (RMTS) Guidelines." The program shall 

include the following: 

 a. The RICT may not exceed 30 days; 

 b. A RICT may only be utilized in MODE 1, 2; 

 c. When a RICT is being used, any change to the plant configuration, as 

defined in NEI 06-09-A, Appendix A, must be considered for the effect on 

the RICT. 

 1. For planned changes, the revised RICT must be determined prior to 

implementation of the change in configuration. 

 2. For emergent conditions, the revised RICT must be determined within 

the time limits of the Required Action Completion Time (i.e., not the 

RICT) or 12 hours after the plant configuration change, whichever is 

less. 

 3. Revising the RICT is not required if the plant configuration change 

would lower plant risk and would result in a longer RICT. 

 d. For emergent conditions, if the extent of condition evaluation for inoperable 

structures, systems, or components (SSCs) is not complete prior to 

exceeding the Completion Time, the RICT shall account for the increased 

possibility of common cause failure (CCF) by either: 

 1. Numerically accounting for the increased possibility of CCF in the 

RICT calculation; or 

 2. Risk Management Actions (RMAs) not already credited in the RICT 

calculation shall be implemented that support redundant or diverse 

SSCs that perform the function(s) of the inoperable SSCs, and, if 

practicable, reduce the frequency of initiating events that challenge 

the function(s) performed by the inoperable SSCs. 

 e. The risk assessment approaches and methods shall be acceptable to the 

NRC. The plant PRA shall be based on the as-built, as-operated, and 

maintained plant; and reflect the operating experience at the plant, as 

specified in Regulatory Guide 1.200, Revision 2. Methods to assess the risk 

from extending the Completion Times must be PRA methods used to 

support this license amendment, or other methods approved by the NRC 

for generic use; and any change in the PRA methods to assess risk that are 

outside these approval boundaries require prior NRC approval. 
Reporting Requirements

5.6

Monticello 5.6-1 Amendment No. 207

5.0 ADMINISTRATIVE CONTROLS

5.6 Reporting Requirements

The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Annual Radiological Environmental Operating Report

 The Annual Radiological Environmental Operating Report covering the operation 

of the unit during the previous calendar year shall be submitted by May 15 of 

each year. The report shall include summaries, interpretations, and analyses of 

trends of the results of the Radiological Environmental Monitoring Program for 

the reporting period. The material provided shall be consistent with the 

objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 

10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

 The Annual Radiological Environmental Operating Report shall include the 

results of analyses of all radiological environmental samples and of all 

environmental radiation measurements taken during the period pursuant to the 

locations specified in the table and figures in the ODCM, as well as summarized 

and tabulated results of these analyses and measurements in the format of the 

table in the Radiological Assessment Branch Technical Position, Revision 1, 

November 1979. In the event that some individual results are not available for 

inclusion with the report, the report shall be submitted noting and explaining the 

reasons for the missing results. The missing data shall be submitted in a 

supplementary report as soon as possible.

5.6.2 Radiological Effluent Release Report

 The Radioactive Effluent Release Report covering the operation of the unit 

during the previous year shall be submitted prior to May 15 of each year in 

accordance with 10 CFR 50.36a. The report shall include a summary of the 

quantities of radioactive liquid and gaseous effluents and solid waste released 

from the unit. The material provided shall be consistent with the objectives 

outlined in the ODCM and Process Control Program and in conformance with 

10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.

5.6.3 CORE OPERATING LIMITS REPORT (COLR)

 a. Core operating limits shall be established prior to each reload cycle, or prior 

to any remaining portion of a reload cycle, and shall be documented in the 

COLR for the following:

 1. The APLHGR for Specification 3.2.1;

 2. The MCPR and MCPR99.9% for Specification 3.2.2;

 3. The LHGR for Specification 3.2.3;
Reporting Requirements 

5.6 

Monticello 5.6-2 Amendment No. 210 

5.6 Reporting Requirements 

5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued) 

 4. Control Rod Block Instrumentation Allowable Value for the 

Table 3.3.2.1-1 Rod Block Monitor Functions 1.a, 1.b, and 1.c and 

associated Applicability RTP levels; 

 5. Reactor Protection System Instrumentation Delta W value for Table 

3.3.1.1-1, Function 2.b, APRM Simulated Thermal Power – High, 

Note b; and 

 6. The Manual Backup Stability Protection (BSP) Scram Region 

(Region I), the Manual BSP Controlled Entry Region (Region II), the 

Reactor Protection System Instrumentation Period Based Detection 

Algorithm OPRM Upscale trip setpoints associated with Table 

3.3.1.1-1 Function 2.f. 

 b. The analytical methods used to determine the core operating limits shall be 

those previously reviewed and approved by the NRC, specifically those 

described in the following documents: 

 1. NEDE-24011-P-A, "General Electric Standard Application for Reactor 

Fuel" 

 2. NEDO-31960-A, "BWR Owners’ Group Long-Term Stability Solutions 

Licensing Methodology”, with Supplement 1, dated November 1995 

 3. NEDO-32465-A, "Reactor Stability Detect and Suppress Solutions 

Licensing Basis Methodology and Reload Applications,” August 1996 

 4. (Deleted) 

 5. XN-NF-81-58(P)(A) Revision 2 and Supplements 1 and 2, “RODEX2 

Fuel Rod Thermal-Mechanical Response Evaluation Model,” March 

1984 

 6. EMF-85-74(P) Revision 0 Supplement 1(P)(A) and Supplement 

2(P)(A), “RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation 

Model,” February 1998 

 7. ANF-89-98(P)(A) Revision 1 and Supplement 1, “Generic Mechanical 

Design Criteria for BWR Fuel Designs,” May 1995 
Reporting Requirements 

5.6 

Monticello 5.6-3 Amendment No. 210 

5.6 Reporting Requirements 

5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued) 

8. XN-NF-80-19(P)(A) Volume 1 and Supplements 1 and 2, “Exxon 

Nuclear Methodology for Boiling Water Reactors - Neutronic Methods 

for Design and Analysis,” March 1983 

 9. XN-NF-80-19(P)(A) Volume 4 Revision 1, “Exxon Nuclear 

Methodology for Boiling Water Reactors: Application of the ENC 

Methodology to BWR Reloads,” June 1986 

 10. EMF-2158(P)(A) Revision 0, “Siemens Power Corporation 

Methodology for Boiling Water Reactors: Evaluation and Validation of 

CASMO-4/MICROBURN-B2,” October 1999 

. 

 11. XN-NF-80-19(P)(A) Volume 3 Revision 2, “Exxon Nuclear 

Methodology for Boiling Water Reactors, THERMEX: Thermal Limits 

Methodology Summary Description,” January 1987 

 12. ANP-10333P-A, Revision 0, AURORA-B: An Evaluation Model for 

Boiling Water Reactors; Application to Control Rod Drop Accident 

(CRDA), Framatome Inc., March 2018 

 13. ANP-10300P-A, Revision 1, AURORA-B: An Evaluation Model for 

Boiling Water Reactors; Application to Transient and Accident 

Scenarios, Framatome Inc., January 2018 

 14. EMF-2209(P)(A) Revision 3, “SPCB Critical Power Correlation,” 

September 2009 

 15. EMF-2245(P)(A) Revision 0, “Application of Siemens Power Corporation's 

Critical Power Correlations to Co-Resident Fuel,” August 2000 

 16. EMF-2361(P)(A) Revision 0, “EXEM BWR-2000 ECCS Evaluation 

Model,” May 2001 

 17. EMF-2292(P)(A) Revision 0, “ATRIUMTM-10: Appendix K Spray Heat 

Transfer Coefficients,” September 2000 

 18. EMF-CC-074(P)(A) Volume 4 Revision 0, “BWR Stability Analysis: 

Assessment of STAIF with Input from MICROBURN-B2,” August 2000 

 19. BAW-10247P-A Revision 0, “Realistic Thermal-Mechanical Fuel Rod 

Methodology for Boiling Water Reactors,” February 2008 

 20. ANP-10298P-A Revision 1, “ACE/ATRIUM 10XM Critical Power 

Correlation,” March 2014 
Reporting Requirements 

5.6 

Monticello 5.6-4 Amendment No. 210 

5.6 Reporting Requirements 

5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued) 

 21. ANP-10307P-A Revision 0, “AREVA MCPR Safety Limit Methodology 

for Boiling Water Reactors,” AREVA NP, Inc., June 2011 

 22. BAW-10255(P)(A) Revision 2, “Cycle-Specific DIVOM Methodology 

Using the RAMONA5-FA Code,” AREVA NP Inc., May 2008 

 23. ANP-10344P-A, Revision 0, “Framatome Best-estimate Enhanced 

Option III Methodology,” Framatome Inc., March 2021 

 24. ANP-3857P Revision 2, “Design Limits for Framatome Critical Power 

Correlations,” Framatome, Inc., July 2020 

 25. BAW-10247P-A, Supplement 2P-A, Revision 0, “Realistic ThermalMechanical Fuel Rod Methodology for Boiling Water Reactors 

Supplement 2: Mechanical Methods,” Framatome Inc., August 2018 

 26. ANP-10340P-A, Revision 0, “Incorporation of Chromia-Doped Fuel 

Properties in AREVA Approved Methods,” Framatome Inc., May 2018 

 27. ANP-10335P-A, Revision 0, “ACE/ATRIUM 11 Critical Power 

Correlation,” Framatome Inc., May 2018 

 28. ANP-10332P-A, Revision 0, “AURORA-B: An Evaluation Model for 

Boiling Water Reactors; Application to Loss of Coolant Accident 

Scenarios,” Framatome Inc., June 2019 

The COLR will contain the complete identification for each of the Technical 

Specification referenced topical reports used to prepare the COLR (i.e., 

report number, title, revision, date, and any supplements). 

 c. The core operating limits shall be determined such that all applicable limits 

(e.g., fuel thermal mechanical limits, core thermal hydraulic limits, 

Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as 

SDM, transient analysis limits, and accident analysis limits) of the safety 

analysis are met. 

 d. The COLR, including any midcycle revisions or supplements, shall be 

provided upon issuance for each reload cycle to the NRC. 
Reporting Requirements 

5.6 

5.6 Reporting Requirements 

5.6.4 Post Accident Monitoring Report 

When a report is required by Condition B or F of LCO 3.3.3.1, "Post Accident 

Monitoring (PAM) Instrumentation," a report shall be submitted within the 

following 14 days. The report shall outline the preplanned alternate method of 

monitoring, the cause of the inoperability, and the plans and schedule for 

restoring the instrumentation channels of the Function to OPERABLE status. 

5.6.5 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS 

REPORT (PTLR) 

Monticello 

a. RCS pressure and temperature limits for heatup, cooldown, low 

temperature operation, criticality, and hydrostatic testing as well as heatup 

and cooldown rates shall be established and documented in the PTLR for 

the following: 

1. Limiting Conditions for Operation Section 3.4.9, "RCS Pressure and 

Temperature (PIT) Limits" 

2. Surveillance Requirements Section 3.4.9, "RCS Pressure and 

Temperature (PIT) Limits" 

b. The analytical methods used to determine the RCS pressure and 

temperature limits shall be those previously reviewed and approved by the 

NRC, specifically those described in the following documents: 

1. SIR-05-044-A, "Pressure-Temperature Limits Report Methodology for 

Boiling Water Reactors," Revision 0, dated April 2007. 

c. The PTLR shall be provided to the NRC upon issuance for each reactor 

vessel fluence period and for any revision or supplements thereto. 

5.6-5 Amendment No. 146, 159, 172, 180, 191 
High Radiation Area

5.7

5.0 ADMINISTRATIVE CONTROLS

5.7 High Radiation Area

As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied

to high radiation areas in place of the controls required by paragraph 20.1601 (a) and (b) of

10 CFR Part 20:

5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at

30 Centimeters from the Radiation Source or from any Surface Penetrated by the

Radiation

a. Each entryway to such an area shall be barricaded and conspicuously

posted as a high radiation area. Such barricades may be opened as

necessary to permit entry or exit of personnel or equipment.

b. Access to, and activities in, each such area shall be controlled by means of

Radiation Work Permit (RWP) or equivalent that includes specification of

radiation dose rates in the immediate work area(s) and other appropriate

radiationprotection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel

continuously escorted by such individuals may be exempted from the

requirement for an RWP or equivalent while performing their assigned

duties provided that they are otherwise following plant radiation protection

procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess one of the

following:

1. A radiation monitoring device that continuously displays radiation

dose rates in the area;

2. A radiation monitoring device that continuously integrates the

radiation dose rates in the area and alarms when the device's dose

alarm setpoint is reached, with an appropriate alarm setpoint;

3. A radiation monitoring device that continuously transmits dose rate

and cumulative dose information to a remote receiver monitored by

radiation protection personnel responsible for controlling personnel

radiation exposure within the area; or

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic

dosimeter) and,

Monticello 5.7-1 Amendment No. 146
High Radiation Area

5.7

5.7 High Radiation Area

5.7.1 High Radiation Areas with Dose Rates Not Exceeding 1.0 rem/hour at

30 Centimeters from the Radiation Source or from any Surface Penetrated by the

Radiation (continued)

(i) Be under the surveillance, as specified in the RWP or

equivalent, while in the area, of an individual qualified in

radiation protection procedures, equipped with a radiation

monitoring device that continuously displays radiation dose

rates in the area; who is responsible for controlling personnel

exposure within the area, or

(ii) Be under the surveillance, as specified in the RWP or

equivalent, while in the area, by means of closed circuit

television, of personnel qualified in radiation protection

procedures, responsible for controlling personnel radiation

exposure in the area, and with the means to communicate with

individuals in the area who are covered by such surveillance.

e. Except for individuals qualified in radiation protection procedures, or

personnel continuously escorted by such individuals, entry into such areas

shall be made only after dose rates in the area have been determined and

entry personnel are knowledgeable of them. These continuously escorted

personnel will receive a pre-job briefing prior to entry into such areas. This

dose rate determination, knowledge, and pre-job briefing does not require

documentation prior to initial entry.

5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at

30 Centimeters from the Radiation Source or from any Surface Penetrated by the

Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or

from any Surface Penetrated by the Radiation

a. Each entryway to such an area shall be conspicuously posted as a high

radiation area and shall be provided with a locked or continuously guarded

door or gate that prevents unauthorized entry, and, in addition:.

1. All such door and gate keys shall be maintained under the

administrative control of the shift supervisor, radiation protection

manager, or his or her designee; and

2. Doors and gates shall remain locked except during periods of

personnel or equipment entry or exit.

b. Access to, and activities in, each such area shall be controlled by means of

an RWP or equivalent that includes specification of radiation does rates in

the immediate work area(s) and other appropriate radiation protection

equipment and measures.

Monticello 5.7-2 Amendment No. 146
High Radiation Area

5.7

5.7 High Radiation Area

5.7.2 Hiqh Radiation Areas with Dose Rates Greater than 1.0 rem/hour at

30 Centimeters from the Radiation Source or from any Surface Penetrated by the

Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or

from any Surface Penetrated by the Radiation (continued)

c. Individuals qualified in radiation protection procedures may be exempted

from the requirement for an RWP or equivalent while performing radiation

surveys in such areas provided that they are otherwise following plant

radiation protection procedures for entry to, exit from, and work in such

areas.

d. Each individual or group entering such an area shall possess one of the

following:

1. A radiation monitoring device that continuously integrates the

radiation dose rates in the area and alarms when the device's dose

alarm setpoint is reached, with an appropriate alarm setpoint;

2. A radiation monitoring device that continuously transmits dose rate

and cumulative dose information to a remote receiver monitored by

radiation protection personnel responsible for controlling personnel

radiation exposure within the area with the means to communicate

with and control every individual in the area;

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic

dosimeter) and,

(i) Be under the surveillance, as specified in the RWP or

equivalent, while in the area, of an individual qualified in

radiation protection procedures, equipped with a radiation

monitoring device that continuously displays radiation dose

rates in the area; who is responsible for controlling personnel

exposure within the area, or

(ii) Be under the surveillance, as specified in the RWP or

equivalent, while in the area, by means of closed circuit

television, of personnel qualified in radiation protection

procedures, responsible for controlling personnel radiation

exposure in the area, and with the means to communicate with

and control every individual in the area; or

4. In those cases where Specifications 5.7.2.d.2 and 5.7.2.d.3, above,

are impractical or determined to be inconsistent with the "As Low As

is Reasonably Achievable" principle, a radiation monitoring device

that continuously displays radiation dose rates in the area.

Monticello 5.7-3 Amendment No. 146

Monticello 5.7-3 Amendment No. 146
High Radiation Area

5.7

5.7 High Radiation Area

5.7.2 High Radiation Areas with Dose Rates Greater than 1.0 rem/hour at

30 Centimeters from the Radiation Source or from any Surface Penetrated by the

Radiation, but less than 500 rads/hour at 1 Meter from the Radiation Source or

from any Surface Penetrated by the Radiation (continued)

e. Except for individuals qualified in radiation protection procedures, or

personnel continuously escorted by such individuals, entry into such areas

shall be made only after dose rates in the area have been determined and

entry personnel are knowledgeable of them. These continuously escorted

personnel will receive a pre-job briefing prior to entry into such areas. This

dose rate determination, knowledge, and pre-job briefing does not require

documentation prior to initial entry.

f. Such individual areas that are within a larger area where no enclosure

exists for the purpose of locking and where no enclosure can reasonably be

constructed around the individual area need not be controlled by a locked

door or gate, nor continuously guarded, but shall be barricaded,

conspicuously posted, and a clearly visible flashing light shall be activated

at the area as a warning device.

Monticello 5.7-4 Amendment No. 146
LICE1NSE AUTHoRITY RILE G-OP~tj

00 ~

APPENDIX B

TO

FACILITY OPERATING LICENSE DPR-22

MONTICELLO NUCLEAR GENERATING PLANT UNIT 1

NORTHERN STATES POWER COMPANY

DOCKET NO. 50-263

~L

L

.~ ~.f'j~

•_-'k•' ..

I tDate:
APPENDIX C 

ADDITIONAL CONDITIONS 

RENEWED FACILITY OPERATING LICENSE NO. DPR-22 

Northern States Power Company shall comply with the following conditions on the schedules 

noted below: 

Amendment 

Number Additional Condition 

98 The emergency operating procedures (EOPs) shall 

be changed to require manual isolation of torus and 

drywell sprays prior to the point where primary 

containment pressure would not provide adeq.uate 

net positive suction head (NPSH) for the emergency 

core cooling system (ECCS) pumps, change the 

caution statement regarding NPSH in the Primary 

Containment Pressure EOP to include cores spray 

pumps, and add a caution statement regarding NPSH 

considerations for pressure control while venting to 

control primary containment pressure. 

98 Finalize the additional containment analysis and 

associated NPSH evaluation which extends the 

existing long-term cause evaluation to a time when 

the required containment overpressure returns to 

atmospheric ~onditions. Changes to the requested 

long-term containment overpressure, if any, shall be 

promptly reported to the NRC prior to starting up the 

unit from the current maintenance. outage. 

98 Submit the results of the additional containment 

analysis and associate NPSH evaluation discussed 

above. 

Implementation 

Date 

Prior to starting 

up from the 

current 

maintenance 

outage, or 

August 1, 1997, 

whichever is 

later. 

Prior to starting 

up from the 

current 

maintenance 

. outage or 

August 1, 1997, 

whichever is 

later.. 

Within 90 days 

from the date of 

the plant startup 

from the cu rrent 

maintenance 

outage or 

November 1, 

1997, whichever is 

later. 

C-1 Amendment No. 98, 110, 175 
APPENDIX C---continued

Amendment

Number

98

98

101

101

102

102

Additional Condition

Update Section 5.2 of the Updated Safety

Analysis Report by incorporating Figure E.2

of the NSP submittal dated July 16, 1997.

Process a 10 CFR 50.59 evaluation to

change the EOP definition of adequate

core cooling to 2/3 core height. The

corresponding EOP changes and the

required operator training shall also be

completed. Final implementations shall be

completed when all the 10 CFR 50.59

evaluation requirements are satisfied.

Conduct an independent evaluation of the

testing methodology and the testing

configuration of the EFT [emergency

filtration testing] system by HEPA and

charcoal filter testing experts. This

evaluation shall include review of the

exceptions to the ASME N510-1989 testing

standard listed in Exhibit F of NSP's

June 19, 1998, letter. The evaluation

results shall be reported to the NRC.

Initiate appropriate modifications to the

EFT system to comply with the ASME

N510-1989 testing standard or obtain NRC

approval for continued use of the

exceptions.

All affected environmental qualification'

files, including service life and maintenance

intervals if necessary, shall be revised to

reflect the new environmental profile

changes associated with power uprate.

All affected process computer and SPDS

data points shall be changed to reflect

uprate operating conditions.

Implementation

Date

Within 90 days from the

date of plant startup

from the current

maintenance outage, or

November 1, 1997,

whichever is later.

Within 180 days from the

date of plant startup

from the current

maintenance outage, or

February 1, 1998,

whichever is later.

Within 9 months of the

date of issuance of

Amendment No. 1.01.

Within 24 months of the

date of issuance of

Amendment No. 101.

Prior to implementation

of Amendment No. 102

(prior to exceeding 1670

MWt).

Prior to implementation

of Amendment No. 102

(prior to exceeding 1670

MWt).

.C-2 Amendment No. 102
APPENDIX C - continued 

Amendment 

Number Additional Condition 

102 All affected process computer and SPDS data 

points shall be changed to reflect uprate 

operating conditions. 

102 	 Control room simulator changes shall be 

completed in accordance with ANSIIANS 

3.5-1985 Section 5.4.1. Simulator Performance 

Testing. and Monticello simulator configuration 

control procedures. 

102 	 Classroom and simulator training on new 

knowledge and abilities associated with the 

power uprate shall be provided in accordance 

with Monticello Training Center procedures. 

102 	 NSPM shall monitor plant operational parameters 

for uprate impacts on the PRA models. 

102 	 Control room simulator changes shall be verified 

against actual plant startup data. 

102 	 The applicable training programs and the 

simulator. shall be modified. or appropriate 

compensatory actions shall be taken, in 

accordance with the Monticello Training 

Center procedures toi reflect issues and 

discrepancies identified during startup testing. 

102 The MNGP USAR shall be updated to reflect 

the changes associated with power uprate 

operation. 	This update shall not include credit for 

suppression pool scrubbing in the MSIV leakage 

pathway in the revised LOCA analysis. . 

Implementation 

Date 

Prior to implementation 

of Amendment No.1 02 

(prior to exceeding 1670 

MWt). 

Prior to implementation 

of Amendment No. 102 

(prior to exceeding 1670 

MWt). 

Prior to implementation 

of Amendment No. 102 

(prior to exceeding 1670 

MWt). 

During and after the 

power uprate ascension 

test program. 

Within 3 months of 

completion of the power 

uprate ascension test 

program. 

Within 6 months of 

completion of the power 

uprate ascension test 

program. 

Within 9 months of 

completion of the power 

uprate ascension test 

program. 

C-3 	 Amendment No. 102, 110 , 175 
APPENDIX C - continued

Amendment

Number

Implementation Date Additional Condition

102

102

NSP* shall evaluate whether MO-2034 and

MO-4229 are capable of allowing a subsequent

operation after the required isolation safety

functions are completed. This evaluation may

include an examination of assumptions and

methodologies, additional administrative controls,

and modifications. The evaluation shall be

completed in order to institute the corrective

actions, if any, by the end of the next scheduled

refueling outage.

NSP* shall evaluate the capacity margins of

MO-2398 and MO-2034. This evaluation may

include an examination of assumptions and

methodologies, additional administrative controls,

and modifications. The evaluation shall be

completed in order to institute the corrective actions.

By the end of the next

scheduled refueling

outage from the date of

Amendment No. 102.

By the end of the next

scheduled refueling

outage from the date of

Amendment No. 102.

I

I

* Reference to NSP is maintained for historical purposes. I

It

C-4 Amendment No. 4-.02, 110