Text

Response to Request for Additional Information Regarding License Amendment to Implement Prnm/Arts/Mellla
	ML13141A581
Person / Time
Site:	Columbia
Issue date:	05/09/2013
From:	Sawatzke B; Energy Northwest
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	GO2-13-075, TAC ME7905
	Download: ML13141A581 (118)
	v • d • e

Bradley J. Sawatzke ENERGY Columbia Generating Station P.O. Box 968, PE08 NORTHWEST Richland, WA 99352-0968 Ph. 509.377.4300 1F. 509.377.4150 bjsawatzke@energy-northwest.com Proprietary - Withhold under 10 CFR 2.390. Enclosure I contains PROPRIETARY information.

May 9, 2013 G02-13-075 10 CFR 50.90 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

Subject:

COLUMBIA GENERATING STATION, DOCKET NO. 50-397 RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNMIARTS/MELLLA

References:

1) Letter, G02-12-017, dated January 31, 2012, BJ Sawatzke (Energy Northwest) to NRC, "License Amendment Request to Change Technical Specifications in Support of PRNM / ARTS / MELLLA Implementation" (ADAMS Accession No. ML12040A072)

2) Letter dated April 10, 2013, NRC to ME Reddemann (Energy Northwest),

"Columbia Generating Station - Request for Additional Information Regarding License Amendment Request to Implement PRNM/ARTS/MELLLA (TAC NO. ME7905)" (ADAMS Accession No. ML13098A778)

Dear Sir or Madam:

By Reference 1, Energy Northwest requested approval of a license amendment request to revise the Columbia Generating Station Technical Specifications to reflect improvements in the Average Power Range Monitor / Rod Block Monitor Technical Specifications (ARTS) and expand the facility operating domain to reflect operations using the Maximum Extended Load Line Limit Analysis (MELLLA). These improvements coincide with the installation of the digital General Electric-Hitachi (GEH)

Nuclear Measurement Analysis and Control (NUMAC) Power Range Neutron Monitoring (PRNM) System.

Via Reference 2, the Nuclear Regulatory Commission (NRC) requested additional information related to the Energy Northwest submittal. Transmitted herewith in is the response to the request for additional information (RAI). Additionally, GEH notified Energy Northwest of an error discovered in an input document used in a previous RAI response. This error and its impact are also discussed in Enclosure 1.

When Enclosure I is removed from this letter, the letter and remaining Enclosures are NON-PROPRIETARY.

AýOUI

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 2 contains proprietary information as defined by 10 CFR 2.390. GEH, as the owner of the proprietary information, has executed the affidavit, included in Enclosure 3, which identifies that the enclosed proprietary information has been handled and classified as proprietary, is customarily held in confidence, and has been withheld from public disclosure. The proprietary information was provided to Energy Northwest in a GEH transmittal that is referenced by the affidavit. The proprietary information has been faithfully reproduced in the Enclosure such that the affidavit remains applicable.

GEH hereby requests that the enclosed proprietary information be withheld from public disclosure in accordance with the provisions of 10 CFR 2.390 and 9.17. Information that is not considered proprietary is provided in Enclosure 2. of Reference 1 contained proposed changes to the Columbia Generating Station Technical Specifications to reflect the installation of the PRNM/ARTS/MELLLA modification. The installation of this modification is currently scheduled for Refueling Outage 22 (R22) in spring 2015. In order to accommodate this installation schedule, the proposed Technical Specifications are being revised as indicated in Enclosures 4-6.

There are no new regulatory commitments identified with this response. Should you have any questions or require additional information regarding this matter, please contact Ms.

LL Williams, Licensing Supervisor, at (509) 377-8148.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the date of this letter.

Respectfully, BJ aak Vice President, Nuclear Generation & Chief Nuclear Officer - Response to Request for Additional Information (Proprietary) - Response to Request for Additional Information (Non Proprietary) - Affidavit for Enclosure 1 - Revision to Description of Proposed Technical Specification Changes - Technical Specification Mark-ups - Retyped Technical Specification Pages cc: NRC Region IVAdministrator NRC NRR Project Manager NRC Senior Resident Inspector/988C AJ Rapacz - BPA/1 399 (w/o Enclosure 1)

WA Horin - Winston & Strawn (w/o Enclosure 1)

JO Luce - EFSEC (w/o Enclosure 1)

RR Cowley - WDOH (w/o Enclosure 1)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 1 of 12 Response to Request for Additional Information - Non-Proprietary NRC Request:

1. Please explain whether EN is planning to use filtered or unfiltered set points for establishing the low/intermediate or high power trip set point (

Reference:

Attachment A to NEDC-33507P, "APRM/RBM/Technical Specifications / Maximum Extended Load Line Limit Analysis (ARTS/MELLLA)"). Please document how the use of filtered or unfiltered values will be determined and explicitly state how these limits will be conservatively applied for implementation of PRNM/ARTS/MELLLA at CGS.

Response

Energy Northwest is planning to use the unfiltered set point values for the Rod Block Monitor (RBM) low, intermediate and high power trip set points. The use of these setpoints has been analyzed to ensure that the analytical limits that supports the control rod withdrawal error (RWE) event is met as detailed in section 4.3 of NEDC-33507P.

The PRNM system has the capability to provide filtering of the RBM signal to reduce signal noise levels. The filter time constant is adjustable up to a maximum of 0.5 +/- 0.05 seconds.

When the filter is utilized, the filtered signal lags the unfiltered signal. This has the net result of reducing the allowed setpoints to remain within the analytical limits of the RWE. IfRBM noise levels are such that any level of filtering is required (up to the maximum allowed filtering of 0.55 seconds), plant procedures will ensure that the filtered setpoints are incorporated into the PRNM system, thus ensuring that the analytical limits specified in NEDC-33507P are met.

NRC Request:

2. The following clarification was provided to RAI 17 (RAI regarding use of 3-Sigma errors), dated March 12, 2013: Not all of the 3-Sigma errors were explained in the information provided by the licensee; specifically, please explain the use of 3-Sigma for the rod block monitor tracking Process Measurement Accuracy (PMA) trip set points.

Response

This clarification to RAI 17 was addressed in the response provided via letter G02-13-059 dated April 11, 2013, BJ Sawatzke (Energy Northwest) to NRC, "Response to Request for Additional Information Regarding License Amendment Request to Implement PRNM/ARTS/MELLLA.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 2 of 12 NRC Request:

3. What are the bases for the Oscillation Power Range Monitor set points? This question was subsequently resolved by information located in NEDC-33685P, "Digitall&C-ISG-06 Compliance for Columbia GeneratingStation, NUMAC PowerRange Neutron Monitoring Retrofit Plus Option /1/ Stability Trip Function."

Response

No further response is necessary.

NRC Request:

4. Please clarify how as-found tolerance and as-left tolerance values are defined by EN for CGS. Define the error terms used in determining their values. TSTF-493 Technical Specifications Task Force (TSTF) Change Traveler TSTF-493, "Clarify Application of Setpoint Methodology for LSSS [Limiting Safety System Setting]

Functions," provides guidance, but does not specify the error terms, for calculating these numbers.

Response

The as-found tolerance (AFT) and as-left tolerance (ALT) values for the PRNM system have been determined for the analog inputs for the local power range monitors (LPRMs) and recirculation flow utilizing the Columbia Generating Station (Columbia) Setpoint Methodology procedure EES-4. This procedure utilizes the approach specified in ANSI/ISA-67.04.01-200, "Setpoints for Nuclear Safety Related Instrumentation," and ISA RP67.04.02-2000, "Methodologies for the Determination of Setpoints for Nuclear Safety Related Instrumentation." EES-4 has also been updated to incorporate the TSTF-493 Revision 4 methodology for calculating the AFT and ALT.

The AFT and ALT for the analog inputs to the PRNM system for the LPRM's and recirculation flow are determined as follows:

2 1 2 AFT+ =k*[(_TCAL

2 A2+ +(Z'DRR) I / +

+)+ (RA*) + JDR B AFT = k*[(ZCAL) + (RA) +(9DRR) ]1/2 + ZDRB ALT+ = k*[(ZCAL+)2 + (RA)]

ALT = k*[('CAL) + (RA') ]1/2 Where; k=1 for a normal distribution and 0.839 for a Single Sided Distribution DRR is a Random Drift Term DRB is a Bias Drift Term

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 3 of 12 CAL includes MT&E accuracy and Setting Accuracy RA is the Reference Accuracy The Columbia procedure EES-4 defines the terms described above as follows:

Drift is the undesired change in a device's input/output relationship over a period of time.

Reference Accuracy is defined as closeness of a device's input/output relationship to the ideal, or desired, input/output relationship and includes the effects of hysteresis, linearity and repeatability.

The Measuring and Test Equipment (M&TE) effect is the square root of the sum of the squares of the independent loop device M&TE values.

Setting Accuracy is the inaccuracy introduced into the calibration process by the physical limitations of the technician during calibration.

The process described above is consistent with the approach specified in TSTF-493 for determining an AFT and ALT.

The TSTF-493 notes that have been applied in the markup of the Technical Specifications to calibration of the PRNM performed at the interval specified in the Technical Specifications (e.g., 24 months for the recirculation flow transmitters), whereas the APRM setpoints are calculated based on the overall APRM system calibration to a heat balance value performed by a required weekly surveillance test.

The APRM fixed setpoints are calculated based on all errors applicable to the weekly calibration of the APRM system (including appropriate PRNM-LPRM instrumentation errors) against the thermal heat balance according to weekly surveillance test SR 3.3.1.1.2. The APRM flow biased setpoints are also based on recirculation flow transmitters being calibrated according to SR 3.3.1.1.10 every 24 months. This full APRM system calibration is performed every week according to CGS SR 3.3.1.1.2 and overrides the calibration and drift errors incurred since the last PRNM calibration required by SR 3.3.1.1.10, which is one a frequency of every 24 months.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 4 of 12 NRC Request:

5. Please explain how the 95/95 probability/confidence criteria are being implemented in the GEH set point methodology for the set points under review.

Response

5.1 GENERAL GEH setpoint calculations are based on the GEH setpoint methodology contained in NEDC 31336P-A (Reference 1) which has been approved and licensed by the NRC. Conceptually, the GEH method is based on Instrumentation Society of America (ISA) Method 2, but leads to more conservative setpoints and is referred to as "Method 2 plus." During the original licensing of the GEH setpoint methodology the NRC Safety Evaluation Report (SER) concluded that the GEH setpoint methodology used acceptable methods for calculating setpoints that provide 95% probability at high confidence (95%) of getting channel trip before the process variable reaches the Analytical Limit.

The GEH setpoint calculation process for Technical Specification setpoints starts with the Analytical Limit (AL) when there is an analytical basis in the safety analysis for the setpoint function. These are the setpoints for which the 95/95 requirements of Regulatory Guide (RG) 1.105 apply. For Technical Specification setpoint functions where there is no analytical basis for an AL (because the setpoint function is not credited in any safety analysis) the setpoint calculation procedure starts with the Allowable Value (AV), and for these setpoints the 95/95 requirements of RG 1.105 do not apply.

For the general case where there is an AL, an overview of the methodology used by GEH to calculate the Allowable Value (AV), Limiting Trip Setpoint (LTSP), called the first NTSP in GEH methodology (NTSP1), and the final adjusted NTSPF, is described below:

A pictorial representation of the methodology is shown in Figure RAI 5-1.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 5 of 12 Figure RAI 5-1: GEH Setpoint Methodology I]

The GEH setpoint calculation methodology determines an AV that has margin to the AL based on all errors for an instrument channel during operating conditions, except drift. ((

)) Conservative values for each of the error components are used to assure, with high confidence (95%) that ((

)) The GEH methodology then calculates an initial value for the Nominal

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 6 of 12 Trip Setpoint (NTSP1), which has margin to the AL, based on all errors (i.e., all errors used in the AV calculation and also including conservative values for drift of all devices in the channel), as illustrated in Figure RAI 5-1. NTSP1 is calculated using all errors (including drift) and is referred to as the Limiting Trip Setpoint (LTSP) because it meets the RG 1.105 Rev. 3 (henceforth referred to as RG 1.105 in this document) requirement of providing 95%

probability of not exceeding the AL with high confidence (95%).

Although NTSP1 has the required margin to the AL to meet RG 1.105, GEH methodology also requires the final setpoint to have an adequate margin to the AV, which is referred to as the LER (Licensee Event Report) avoidance margin. The LER margin is prescribed by GEH methodology. Therefore, in the GEH setpoint calculation process, the setpoint is adjusted conservatively from NTSP1 to the final value (NTSPF) to assure with high confidence (95%)

)), as defined by the AL/AV margin provided in GEH methodology. NTSPF is always equal to or more conservative (further from the AL) than NTSPI. Thus generally, and specifically for Power Range Neutron Monitor (PRNM) setpoints, the final setpoint (NTSPF) is more conservative than NTSP1 and has margin to the AL that is significantly larger than the AL/NTSP1 margin required to meet RG 1.105. Therefore generally, and specifically for PRNM, the final setpoint (NTSPF) implemented in the instrument conservatively exceeds the 95% RG 1.105 probability requirement for not exceeding the AL.

Note that meeting the RG 1.105 requirement of 95% probability of not exceeding the AL at 95% confidence is assured by the following two basic steps:

Using values for the random instrument errors, measured in terms of standard deviation (i.e., sigma) of the normal error distribution function that has high confidence, and statistically combining the standard deviation of pertinent random errors for each device connected in series or parallel in the channel. The high confidence component random errors are combined using the Square Root of the Sum of the Squares (SRSS) technique to give the channel error standard deviation (StndDev) that has high confidence (95%). Also adding all the non-conservative bias errors algebraically gives the channel bias error (B) that is incorporated in the setpoint margin calculation.

Calculating the setpoint margins by multiplying StndDev by 1.645 for setpoints where the variables approach the setpoints in one direction as described in Reference 1, and algebraically adding the channel bias error B. It can be shown from statistical first principles that when StndDev is known to 95% confidence, a setpoint margin of B + 1.645

StndDev meets the RG 1.105 setpoint margin 95/95 requirement (i.e., it provides 95% probability at 95% confidence) of not exceeding the AL for setpoints approached from one direction. Use of the single-sided 1.645

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTSIMELLLA Page 7 of 12 statistical factor for setpoint margin calculations where the variable approaches the setpoint from one direction, has been endorsed by the NRC staff for GEH setpoint methodology (Reference 1) and also by ISA Standard ISA-RP67.04, Part II, 1994 (and later revision ISA-RP67.04.02-2000).

During licensing of the GEH setpoint methodology, GEH presented field data that demonstrated, and the NRC agreed (Reference 1), that the margins calculated by GEH setpoint methodology bounded 95% of the data with high confidence (95% confidence limits).

Note that the final safety setpoint margin is the NTSPF margin to the AL (i.e., the AINTSPF margin). This is the margin that needs to be large enough to meet or exceed the 95/95 requirements specified in RG 1.105. Thus, since the AL/NTSP1 meets the 95/95 margin requirement and NTSPF is generally (and specifically for PRNM setpoints) more conservative than NTSP1, the AL/NTSPF margin is larger and therefore more conservative than that required to meet the 95/95 requirements. Note that the larger the AL/NTSPF margin is, the more conservative the setpoint is with respect to the 95/95 requirement.

A description and basis of the GEH setpoint methodology and its applicability to provide setpoints that meet the RG 1.105 95/95 requirements has been presented to the NRC (References 2 and 3).

5.2 PRNM SETPOINTS The PRNM setpoints include the Average Power Range Monitor (APRM) and Rod Block Monitor (RBM) setpoints. A list of the setpoints is given in References 4 and 5 and includes setpoints which protect safety limits and have ALs (such as APRM high neutron flux and RBM trip setpoints) for which the 95/95 requirements apply, and also those which do not have ALs (such as APRM flow biased scram and rod block setpoints) for which the 95/95 requirements do not apply.

The errors needed for GEH setpoint calculations include the following:

Process Measurement Accuracy

" Primary Element Accuracy

" Accuracy under Trip and Calibration conditions for all devices in the loop

Drift between calibrations for all devices in the loop

Calibration error for all devices in the loop The errors for the APRM and RBM channels are a statistical combination of the pertinent random errors of the pertinent number of devices in the APRM and RBM channels, and algebraic addition of the bias errors.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 8 of 12 5.2.1 PRNM Errors The PRNM uses an analog front end to interface with the Recirculation Loops flow sensors and the Local Power Range Monitor (LPRM) sensors for the APRM trip functions and only the LPRM sensors for the RBM trip functions. Processed data from this analog front end is converted to digital data using 16 bit analog to digital (A/D) conversion. For the electronic signal processing errors used in the setpoint calculations, only the errors (accuracy and drift) of the PRNM analog front end (and associated sample and hold circuit and A/D conversion) are pertinent. There is no error associated with the downstream digital signal processing since that is done by firmware algorithms. The trip function is also performed digitally, so that has no error, and a trip setting in firmware will not drift from one calibration to the next.

Therefore, there is no setting tolerance (such as an As-Left Tolerance) for the PRNM digital trip setting.

The specified errors of the pertinent PRNM components are based on extensive testing that verified that the accuracy of the equipment designed according to the design specifications was within the performance specifications at the specified temperature and humidity extremes. The performance specifications were based on the highest error observed in the testing, and additional error margin was added for conservatism. Each pertinent PRNM component is tested to meet its performance specification before shipment, so there is high confidence (95%) that the specified errors are applicable to all PRNMs in the field.

For the PRNM APRM Neutron Flux High setpoint and APRM setdown setpoint functions, the error from components that can be calibrated are the components within the PRNM APRM electronics. The PRNM RBM Trip setpoints and RBM Power setpoints (at which the RBM Trip setpoints are enabled) use the same components as the APRM setpoints, so the error sources are the same. These PRNM errors are due to the accuracy and drift of the analog LPRM processing modules in the front end which process the LPRM detector signals, and their associated A/D conversion. The errors for each LPRM processor are specified conservatively in the PRNM specifications, and these independent random errors are combined statistically to determine the overall APRM electronics error. For these setpoints, the use of the conservative and high confidence (95%) PRNM accuracy specifications together with GEH setpoint methodology provides assurance that RG 1.105 requirements are met.

For the PRNM flow biased APRM Simulated Thermal Power (STP) high setpoints, additional errors are considered, including errors due to accuracy, drift, and calibration of the Recirculation Loop flow transmitters (FTs), and errors due to the accuracy and drift of the analog flow processing modules in the PRNM front end that are used to process the flow signals. The errors specified for the PRNM flow channel electronics in the PRNM

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 9 of 12 specifications are conservative and have high confidence (95%). The specified errors for the FT are conservatively treated and also have high confidence.

The errors used in the calculation of PRNM APRM and RBM setpoints are summarized below:

PMA (includes random errors due to APRM and RBM tracking and neutron noise for the neutron flux loop and flow noise error for the Recirculation Flow loops)

PEA (includes bias and random errors due to non-linearity and drift of the LPRM detectors, and error due to accuracy of the flow elements used in the Recirculation Loop flow measurements)

Accuracy of the PRNM APRM electronics under trip conditions (same as accuracy under calibration conditions)

Drift of PRNM APRM and RBM neutron flux measurement electronics and PRNM APRM flow measurement electronics, for the duration appropriate for the APRM and RBM setpoints.

PRNM calibration errors

" Accuracy of the flow transmitters

Drift of the flow transmitters

Calibration error of the flow transmitters Values for these errors for the Columbia PRNM (APRM and RBM) equipment are shown in the summary APRM and RBM Inputs/Outputs documents (Reference 4 for APRM and Reference 5 for RBM) and were used as inputs in the APRM and RBM setpoint calculations.

These summary APRM and RBM Inputs/Outputs documents have been sent to the NRC for their review of the instrument uncertainty inputs used in the setpoint calculations. The associated setpoint calculation spreadsheets for References 4 and 5 were recently reviewed with the NRC at NRC headquarters on 4/3/2013 for further clarification of RAI 18 response.

5.2.2 PRNM Setpoint Calculations The PRNM setpoints (which include APRM and RBM setpoints) are calculated as described in Section 5.1, using errors specified in the PRNM specifications as described in Section 5.2.1. The specified PRNM errors are conservative and have high confidence (95%). Thus, the PRNM setpoint calculations based on specified PRNM errors and the approved GEH setpoint methodology meet the RG 1.105 95/95 requirements for AL/NTSPF margin.

Specifically since NTSP1 (Limiting Trip Setpoint) has the required margin to the AL to meet RG 1.105 requirements and since NTSPF is equal or more conservative than NTSP1, it also meets RG 1.105 requirements. As an example note that according to GEH methodology, the AL/NTSP1 margin is the algebraic addition of the bias errors plus a random error margin equal to 1.645

Standard Deviation of the total channel random error under trip conditions, whereas the AL/NTSPF margin, for APRM Neutron Flux High setpoint with typical PRNM

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 10 of 12 errors, is much larger and equal to the same bias errors plus a random error margin which is larger than 2.5

Standard Deviation of the total channel random error under trip conditions.

In GEH methodology, the final setpoint (NTSPF) is based on satisfying the following two criteria:

Minimum margin to the AL to satisfy RG 1.105 and assure 95% probability of not exceeding the AL with high confidence (95%). This calculation uses all the errors under trip conditions and includes the process measurement errors and primary element errors that are present during operation, and the accuracy, calibration and drift errors of the measuring equipment. The setpoint with this required minimum margin to the AL is referred to as NTSP1 in GEH methodology and corresponds to the Limiting Trip Setpoint (LTSP). This criterion is only applicable to setpoints with ALs.

)) This calculation uses all the errors under calibration conditions and includes the accuracy, calibration and drift errors of the measuring equipment. For setpoints with ALs, this requirement generally, and specifically for PRNM, results in the final setpoint (NTSPF) being significantly more conservative than NTSP1, and never less conservative than NTSP1. The reasons for this are as follows:

o Generally (and specifically for PRNM setpoints) there is not a significant difference between NTSP1 and AV because by GEH methodology the AL/AV margin is calculated with all the same errors used in the AL/NTSP1 (i.e., AL/LTSP) calculation except drift, and the drift generally (and specifically for PRNM) does not increase the margin significantly.

o Generally (and specifically for PRNM setpoints) the margin between AV and NTSPF is significantly larger than between AV and NTSP1 because this margin includes the same calibration and drift errors used in the AV and NTSP1 calculations, and also includes the accuracy under calibration conditions. Calculation of NTSPF ((

1]

According to the general GEH methodology, for setpoints that protect safety limits and have ALs the Limiting Setpoint (NTSP1) meets the 95/95 requirement in RG 1.105, and since the final setpoint (NTSPF) is more conservative than NTSP1, it more than meets the 95/95 requirement of RG 1.105. For PRNM setpoints in this category the difference between

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 11 of 12 NTSP1 and NTSPF is more significant, so these PRNM setpoints are significantly more conservative than required to meet the 95/95 criterion in RG 1.105.

5.3 REFERENCES

1. NEDC-31336P-A, "General Electric Instrument Setpoint Methodology," GEH Proprietary, September 1996

2. "Discussion of 1-sided statistics for Setpoint Margin Calculations", Presentation to NRC, September 28, 2010 (ADAMS Accession No. ML102980517).

3. "Response to NRC Summary Points on Application of Single-Sided Factor for Setpoint Margin Calculations," Enclosure 1, MFN 10-334, Letter GEH to NRC, October 25, 2010 (ADAMS Accession No. ML102980533).

4. GE Hitachi Nuclear Energy, "Columbia Generating Station, Instrument Limits Calculation, Average Power Range Monitor (NUMAC ARTS-MELLLA)," NEDC-33753P, Revision 0, June 2012 (ADAMS Accession No. ML12219A255).

5. GE Hitachi Nuclear Energy, "Columbia Generating Station, Instrument Limits Calculation, Rod Block Monitor (NUMAC ARTS-MELLLA)," NEDC-33754P, Revision 0, June 2012 (ADAMS Accession No. ML12219A255).

Additional Item In letter G02-12-135 dated October 5, 2012, from BJ Sawatzke (Energy Northwest) to NRC, "Response to Request for Additional Information Regarding Licensing Amendment Request to Implement PRNM/ARTS/MELLLA," Energy Northwest responded to an RAI (RAI #11) related to NEDC-33690P, "Columbia Generating Station Power Range Neutron Monitoring System Response Time Analysis Report" (ML12040A083), which discussed data error rate testing performed on a similar PRNM system installed with another licensee. On April 9, 2013, GEH notified Energy Northwest that an error was discovered in one of the input documents used for this data error rate testing. This error was a conflict in the tolerance limit specified on the transmission rate of the LA6 message and was captured in a GEH Condition Report.

The minimum test duration for the FDDI link data error rate testing increased from 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months to 45 hours5.208333e-4 days 0.0125 hours 7.440476e-5 weeks 1.71225e-5 months , while the actual test ran for 52 hours6.018519e-4 days 0.0144 hours 8.597884e-5 weeks 1.9786e-5 months and 26 minutes. This error was corrected and verified with an update to the following documents:

Columbia PRNM Integration Test Plan

Columbia PRNM Integration Test Report

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 12 of 12 The updated documents were verified to confirm that the statements and conclusions remain valid. In specific, the following key conclusions remain valid:

" The conclusion in the response to Staff Position 1.19 remains valid in that "the theoretical maximum capacity usage is small compared to the available capacity, which precludes the possibility of exceeding the communication link capacity."

" There is no change to the maximum expected impact to response time documented in the response to Staff Position 1.20.

" The conclusion that "the data error rate on the FDDI link from the LPRM instrument to the APRM instrument is less than or equal to lx10-6 data errors per message" remains valid.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Affidavit for Enclosure I

GE-Hitachi Nuclear Energy Americas LLC AFFIDAVIT I, Linda C. Dolan, state as follows:

(1) I am the Manager of Regulatory Compliance, Regulatory Affairs, of GE-Hitachi Nuclear Energy Americas LLC ("GEH"), and have been delegated the function of reviewing the infonrmation described in paragraph (2) which is sought to be withheld, and have been authorized to apply for its withholding.

(2) The information sought to be withheld is contained in Enclosure 1 of GEH letter, GE-MS-CT-106244-SROO1, "GEH Response to ENW-CGS PRNM/ARTS/MELLLA Audit RAI 5," dated May 6, 2013. The GEH proprietary information in Enclosure 1, which is entitled "GEH Response to NRC Audit RAI 5" is identified by a dotted underline inside double square brackets.

((This.sentence is...a.example...1e..L31 )) In each case, the superscript notation 131refers to Paragraph (3) of this affidavit, which provides the basis for the proprietary determination.

(3) In making this application for withholding of proprietary information of which it is the owner or licensee, GEH relies upon the exemption from disclosure set forth in the Freedom ofInformation Act ("FOIA"), 5 U.S.C. Sec. 552(b)(4), and the Trade Secrets Act, 18 U.S.C. Sec. 1905, and NRC regulations 10 CFR 9.17(a)(4), and 2.390(a)(4) for trade secrets (Exemption 4). The material for which exemption from disclosure is here sought also qualifies under the narrower definition of trade secret, within the meanings assigned to those terms for purposes of FOIA Exemption 4 in, respectively, Critical Mass Energy Proiect v. Nuclear Regulatory Comma-ission, 975 F.2d 871 (D.C. Cir. 1992), and Public Citizen Health Research Group v. FDA, 704 F.2d 1280 (D.C. Cir. 1983).

(4) The information sought to be withheld is considered to be proprietary for the reasons set forth in paragraphs (4)a. and (4)b. Some examples of categories of information that fit into the definition of proprietary information are:

a. Information that discloses a process, method, or apparatus, including supporting data and analyses, where prevention of its use by GEH's competitors without license from GEH constitutes a competitive economic advantage over other companies;

b. Information that, if used by a competitor, would reduce their expenditure of resources or improve their competitive position in the design, manufacture, shipment, installation, assurance of quality, or licensing of a similar product;

c. Information that reveals aspects of past, present, or future GEH customer-funded development plans and programs, resulting in potential products to GEH;

d. Information that discloses trade secret or potentially patentable subject matter, or both, for which it may be desirable to obtain patent protection.

(5) To address 10 CFR 2.390(b)(4), the information sought to be withheld is being submitted to NRC in confidence. The information is of a sort customarily held in confidence by GEH, and is

GE-Hitachi Nuclear Energy Americas LLC in fact so held. The information sought to be withheld has, to the best of my knowledge and belief, consistently been held in confidence by GEH, not been disclosed publicly, and not been made available in public sources. All disclosures to third parties, including any required transmittals to the NRC, have been made, or must be made, pursuant to regulatory provisions, or to proprietary or confidentiality agreements that provide for maintaining the information in confidence. The initial designation of this information as proprietary information, and the subsequent steps taken to prevent its unauthorized disclosure, are as set forth in the following paragraphs (6) and (7).

(6) Initial approval of proprietary treatment of a document is made by the manager of the originating component, who is the person most likely to be acquainted with the value and sensitivity of the information in relation to industry knowledge, or who is the person most likely to be subject to the terms under which it was licensed to GEH. Access to such documents within GEH is limited to a "need to know" basis.

(7) The procedure for approval of external release of such a document typically requires review by the staff manager, project manager, principal scientist, or other equivalent authority for technical content, competitive effect, and determination of the accuracy of the proprietary designation.

Disclosures outside GEH are limited to regulatory bodies, customers, and potential customers, and their agents, suppliers, and licensees, and others with a legitimate need for the information, and then only in accordance with appropriate regulatory provisions or proprietary or confidentiality agreements, or both.

(8) The information identified in paragraph (2), above, is classified as proprietary because it contains the detailed setpoint methodology and design information for the instrumentation and control equipment that is used in the design and analysis of the power range neutron monitoring system for the GEH Boiling Water Reactor (BWR). These methods, techniques, and data along with their application to the design, modification, and analyses associated with the power range neutron monitoring system was achieved at a significant cost to GEH.

The development of the evaluation processes along with the interpretation and application of the analytical results is derived from the extensive experience databases that constitute a major GEH asset. Moreover, procedure docunentation is generally held as company proprietary throughout the General Electric Company. The procedure document discussed with reference to the verification process used by GEH is a part of the overall General Electric Company library of procedures that has been developed over the company's long history.

(9) Public disclosure of the information sought to be withheld is likely to cause substantial harm to GEH's competitive position and foreclose or reduce the availability of profit-making opportunities. The information is part of GEH's comprehensive BWR safety and technology base, and its comnmercial value extends beyond the original development cost. The value of the technology base goes beyond the extensive physical database and analytical methodology and includes development of the expertise to determine and apply the appropriate evaluation process.

In addition, the technology base includes the value derived from providing analyses done with NRC-approved methods.

GE-Hitachi Nuclear Energy Americas LLC The research, development, engineering, analytical and NRC review costs comprise a substantial investment of time and money by GEH. The precise value of the expertise to devise an evaluation process and apply the correct analytical methodology is difficult to quantify, but it clearly is substantial. GEH's competitive advantage will be lost if its competitors are able to use the results of the GEH experience to normalize or verify their own process or if they are able to claim an equivalent understanding by demonstrating that they can arrive at the same or sinilar conclusions.

The value of this information to GEH would be lost if the information were disclosed to the public. Making such information available to competitors without their having been required to undertake a similar expenditure of resources would unfairly provide competitors with a windfall, and deprive GEH of the opportunity to exercise its competitive advantage to seek an adequate return on its large investment in developing and obtaining these very valuable analytical tools.

I declare under penalty of perjury that the foregoing affidavit and the matters stated therein are true and correct to the best of my knowledge, information, and belief.

Executed on this 6 th of May 2013.

Linda C. Dolan Manager, Regulatory Compliance Regulatory Affairs GE-Hitachi Nuclear Energy Americas LLC 3901 Castle Hayne Rd.

Wilmington, NC 28401

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 1 of 2 Revision to Description of Proposed Technical Specification Changes to letter G02-12-017 (Reference 1) provided the description of proposed Technical Specification (TS) changes necessary to implement the Power Range Neutron Monitor (PRNM) modification and reflect the expanded operating domain resulting from implementation of Average Power Range Monitor/Rod Block Monitor/Technical Specifications (ARTS) and Maximum Extended Load Line Limit Analysis (MELLLA). The scheduled implementation of PRNM/ART/MELLLA will be Refueling Outage 22 (R22) in the spring of 2015. The following changes to the proposed TS are required to accommodate this implementation schedule:

1. Specifications 3.2.4 and 3.3.1.3 were initially proposed to be deleted. Instead of deleting these Specifications, the Applicability of each will be changed to "... prior to implementation of Power Range Neutron Monitor (PRNM) upgrade." The header of each specification will be updated to include "(Priorto implementation of PRNM Upgrade)."

2. Since the above two Specifications will not be deleted, the Table of Contents will not be changed.

3. The Definition of Maximum Fraction of Limiting Power Density (MFLPD) was initially proposed to be deleted. Since TS 3.2.4 is not being deleted, this Definition will not be deleted,

4. Specifications 3.3.1.1, 3.3.2.1, 3.4.1, and 3.10.8 were initially proposed to be changed to reflect the new analyses and hardware associated with the PRNM and ARTS/MELLLA upgrade. Instead, two versions of each Specification will be created with different Applicability Statements.

Each existing Specification will be retained with the revised Applicability of ".. . prior to implementation of PRNM upgrade." The header of each specification will be updated to include "(Priorto implementation of PRNM Upgrade)."

Each revised version of the Specification will include a change to the Applicability to include "...after implementation of PRNM upgrade." The header of each specification will be updated to include "(After implementation of PRNM Upgrade)."

5. TS 5.6.3.a was initially proposed to be changed to reflect the deletion of TS 3.3.1.3 and the revisions to TS 3.3.1.1 and TS 3.3.2.1. Bullet a.4 of TS 5.6.3 will be revised to refer to "prior to implementation of Power Range Neutron Monitor (PRNM) upgrade. New bullets a.5 and a.6 will be revised to refer to "after the PRNM upgrade."

6. The footer of Specifications 3.10.8 and 5.6 will be revised to add "No." after Amendment to be consistent with the remainder of the TS.

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Page 2 of 2 The revised TS mark-ups are provided in Enclosure 5. The retyped pages are provided in . These enclosures replace Attachments 1 and 2 to Enclosure 1 of Reference 1 in their entirety.

Conforming changes will be made to the TS Bases pages. Since the TS Bases markups in to Enclosure 1 of Reference 1 were provided for information only and since no technical changes are being proposed, revised versions will not be provided.

Once the ARTS/MELLLA/PRNM upgrade is installed in the plant, a TS change will be submitted to delete the obsolete Specifications and portions thereof.

References:

1. Letter, G02-12-017, dated January 31, 2012, BJ Sawatzke (Energy Northwest) to NRC, "License Amendment Request to Change Technical Specifications in Support of PRNM / ARTS / MELLLA Implementation" (ADAMS Accession No. ML12040A072)

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Technical Specification Markups

APRM Gain and Setpoint (Priorto Implementation of PRNM Upgrade) 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Average Power Range Monitor (APRM) Gain and Setpoint LCO 3.2.4 a. MFLPD shall be less than or equal to Fraction of RTP (FRTP); or

b. Each required APRM Flow Biased Simulated Thermal Power - High Function Allowable Value shall be modified by greater than or equal to the ratio of FRTP and the MFLPD; or

c. Each required APRM gain shall be adjusted such that the APRM readings are >_100% times MFLPD.

APPLICABILITY: THERMAL POWER > 25% RTP prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the requirements of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months LCO not met. the LCO.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to < 25% RTP.

Time not met.

Columbia Generating Station 3.2.4-1 Amendment No. 4499 22-5

APRM Gain and Setpoint (Priorto Implementation of PRNM Upgrade) 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 --------------------- NOTE ---------------

Not required to be met if SR 3.2.4.2 is satisfied for LCO 3.2.4.b or LCO 3.2.4.c requirements.

Verify MFLPD is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter

.4-SR 3.2.4.2 --------------------- NOTE--- ----------

Not required to be met if SR 3.2.4.1 is satisfied for LCO 3.2.4.a requirements.

Verify each required: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

a. APRM Flow Biased Simulated Thermal Power -

High Function Allowable Value is modified by greater than or equal to the ratio of FRTP and the MFLPD; or

b. APRM gain is adjusted such that the APRM reading is > 100% times MFLPD.

Columbia Generating Station 3.2.4-2 Amendment No. 46.9 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 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 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS N rý-----------------------------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months channels inoperable.

OR A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

B. One or more Functions B.1 Place channel in one trip 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months with one or more system in trip.

required channels inoperable in both trip OR systems.

B.2 Place one trip system in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trip.

C. One or more Functions C.1 Restore RPS trip capability. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, B, Table 3.3.1.1-1 for the or C not met. channel.

Columbia Generating Station 3.3.1.1-1 Amendment No. 4499 2225

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Action D.1 and POWER to < 30% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by Required G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by Required H.1 Initiate action to fully insert Immediately Action D.1 and all insertable control rods in referenced in core cells containing one or Table 3.3.1.1-1. more fuel assemblies.

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.3.1.1-2 Amendment No. 4-6.9 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.2 - ------------------ NOTE ---------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER Ž_25% RTP.

Verify the absolute difference between the average 7 days power range monitor (APRM) channels and the calculated power < 2% RTP plus any gain adjustment required by LCO 3.2.4, "Average Power Range Monitor (APRM) Gain and Setpoint," while operating at > 25% RTP.

S R 3.3.1.1.3 - ------------------ NOTE ---------------

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels overlap, withdrawing SRMs from the fully inserted position SR 3.3.1.1.6 - ------------------ NOTE ---------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Calibrate the local power range monitors. 1130 MWD/T average core exposure Columbia Generating Station 3.3.1.1-3 Amendment No. 469 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.9 ------------------- NOTES---------------

1. Neutron detectors are excluded.

2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 184 days SR 3.3.1.1.10 ------------------- NOTES---------------

1. Neutron detectors are excluded.

2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 18 months for Functions 1 through 4, 6, 7, and 9 through 11 AND 24 months for Functions 5 and 8 SR 3.3.1.1.11 Verify the APRM Flow Biased Simulated Thermal 18 months Power - High Function time constant is < 7 seconds.

SR 3.3.1.1.12 Verify Turbine Throttle Valve - Closure, and Turbine 18 months Governor Valve Fast Closure Trip Oil Pressure -

Low Functions are not bypassed when THERMAL POWER is > 30% RTP.

SR 3.3.1.1.13 Perform CHANNEL FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.1.1-4 Amendment No. 47-9 2-2-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.14 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.1.15 ------------------- NOTES---------------

1 Neutron detectors are excluded.

2. Channel sensors for Functions 3 and 4 are excluded.

3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

Verify the RPS RESPONSE TIME is within limits. 24 months on a STAGGERED TEST BASIS Columbia Generating Station 3.3.1.1-5 Amendment No. 469 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE 1.Intermediate Range Monitors

a. Neutron Flux - High 2 3 G SR 3.3.1.1.1 < 122/125 SR 3.3.1.1.3 divisions of full SR 3.3.1.1.5 scale SR 3.3.1.1.6 SR 3.3.1.1.10 SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.1 < 122/125 SR 3.3.1.1.4 divisions of full SR 3.3.1.1.10 scale SR 3.3.1.1.14

b. Inop 2 3 G SR 3.3.1.1.3 NA SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.4 NA SR 3.3.1.1.14

2. Average Power Range Monitors

a. Neutron Flux - High, 2 2 G SR 3.3.1.1.1 < 20% RTP Setdown SR 3.3.1.1.3 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.9 SR 3.3.1.1.14

b. Flow Biased Simulated 2 SR 3.3.1.1.1 < 0.58 W + 62% RTP Thermal Power - High SR 3.3.1.1.2 and !5 114.9% RTP SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14

c. Fixed Neutron Flux - 2 F SR 3.3.1.1.1 -<120% RTP High SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15

d. Inop 1,2 2 G SR 3.3.1.1.7 NA SR 3.3.1.1.8 SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-6 Amendment No. 4-69 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

3. Reactor Vessel Steam 1,2 2 G SR 3.3.1.1.8 _1079 psig Dome Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

4. Reactor Vessel Water Level 1,2 2 G SR 3.3.1.1.1 > 9.5 inches

- Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

5. Main Steam Isolation Valve 1 8 F SR 3.3.1.1.8 5 12.5% closed

- Closure SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

6. Primary Containment 1,2 2 G SR 3.3.1.1.8 < 1.88 psig Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14

7. Scram Discharge Volume Water Level - High

a. Transmitter/Trip Unit 1,2 2 G SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5 (a) 2 H SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

b. Float Switch 1,2 2 G SR 3.3.1.1.8

529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 2 H SR 3.3.1.1.8 _<529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

8. Turbine Throttle Valve - _ 30% RTP 4 E SR 3.3.1.1.8 _<7% closed Closure SR 3.3.1.1.10 SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-7 Amendment No. 469 2-25

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

9. Turbine Governor Valve >30% RTP 2 E SR 3.3.1.1.8 _1000 psig Fast Closure, Trip Oil SR 3.3.1.1.10 Pressure - Low SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15

10. Reactor Mode Switch - 1,2 2 G SR 3.3.1.1.13 NA Shutdown Position SR 3.3.1.1.14 5(') 2 H SR 3.3.1.1.13 SR 3.3.1.1.14 NA

11. Manual Scram 1,2 2 G SR 3.3.1.1.4 NA SR 3.3.1.1.14 5a) H SR 3.3.1.1.4 NA SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-8 Amendment No. 4-" 2-2-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 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 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS

NOTE---.

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months channels inoperable.

OR

............. NOTEOTE -------

Not applicable for Functions 2.a, 2.b, 2.c, 2.d, or 2.f.

A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

-NOTE

B.1 Place channel in one trip 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Not applicable for system in trip.

Functions 2.a, 2.b, 2.c, 2.d, or 2.f. OR B.2 Place one trip system in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. One or more Functions trip.

with one or more required channels inoperable in both trip systems.

Columbia Generating Station 3.3.1.1-1 Amendment No. 499 225

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Restore RPS trip capability. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, B, Table 3.3.1.1-1 for the or C not met. channel.

E. As required by Required E.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Action D.1 and POWER to < 30% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by Required G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by Required H.1 Initiate action to fully insert Immediately Action D.1 and all insertable control rods in referenced in core cells containing one or Table 3.3.1.1-1. more fuel assemblies.

Columbia Generating Station 3.3.1.1-2 Amendment No. 46.9 2,15

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME As required by Required 1.1 Initiate alternate method to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and detect and suppress referenced in thermal hydraulic instability Table 3.3.1.1-1. oscillations.

AND

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

LCO 3.0.4 is not applicable.

1.2 Restore required channels 120 days to OPERABLE J. Required Action and J.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to less than the Time of Condition I not value specified in the met. COLR.

SURVEILLANCE REQUIREMENTS k

~mrvrrc' I ----------------------------------------------------------

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.3.1.1-3 Amendment No. 449 2-2-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER > 25% RTP.

Verify the absolute difference between the average 7 days power range monitor (APRM) channels and the calculated power _ 2% RTP plus any ai ..

adjWctmonAt roquirod by LCOQ 3.2.4, "Avorago Powor Range Mo..tor (APRM) Gain and- Setpoeit," while operating at > 25% RTP.

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

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels overlap, withdrawing SRMs from the fully inserted position SR 3.3.1.1.6 -------------------- NOTE ---------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Calibrate the local power range monitors. 1130 MWD/T average core exposure Columbia Generating Station 3.3.1.1-4 Amendment No. 469 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.9 NOTES

1. Noutron detectore aro excluded.

2. For Function 2.a,notrequirod to bo performed whon entering MODE 2 from MODE1uil 12 hourt aft2r hou Dntering MODE 2.

Perform CHANNEL CALIBRATIONDeeted. 184 days SR 3.3. 1.1.10------------------------- NOTES ----------------------

1. Neutron detectors are excluded.

2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

3. For Functions 2.b and 21f, the recirculation flow transmitters that feed the APRMs are included.

Perform CHANNEL CALIBRATION. 18 months for Functions 1, 3, th.~eu.gh4, 6, 7, and 9 through 11 AND 24 months for Functions 2, 5, and 8 SR 3.3.1.1.11 Deleted Verify the APRM Flow Biased Simul'atod !8-onths 7-se~ene~.

SR 3.3.1.1.12 Verify Turbine Throttle Valve - Closure, and Turbine 18 months Governor Valve Fast Closure Trip Oil Pressure -

Low Functions are not bypassed when THERMAL POWER is Ž 30% RTP.

Columbia Generating Station 3.3.1.1-5 Amendment No. 4-7-9 22-6

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SR 3.3.1.1.13 Perform CHANNEL FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.1.1-6 Amendment No. 4-79 2-2-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.14 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.1.15 ------------------- NOTES---------------

1 Neutron detectors are excluded.

2. Channel sensors for Functions 3 and 4 are excluded.

3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

4. For Function 2.e, "n" equals 8 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. Testing of APRM and oscillation power range monitor (OPRM) outputs shall alternate.

24 months on a Verify the RPS RESPONSE TIME is within limits. STAGGERED TEST BASIS SR 3.3.1.1.16 ------------------- NOTES---------------

1 For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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. 184 days SR 3.3.1.1.17 Verify the OPRM is not bypassed when APRM 24 months Simulated Thermal Power is greater than or equal to the value specified in the COLR and recirculation drive flow is less than the value specified in the COLR.

Columbia Generating Station 3.3.1.1-7 Amendment No. 469 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 1 of 34)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

1. Intermediate Range Monitors

a. Neutron Flux - High 2 3 G SR 3.3.1.1.1 _122/125 SR 3.3.1.1.3 divisions of full SR 3.3.1.1.5 scale SR 3.3.1.1.6 SR 3.3.1.1.10 SR 3.3.1.1.14 5(') 3 H SR 3.3.1.1.1 < 122/125 SR 3.3.1.1.4 divisions of full SR 3.3.1.1.10 scale SR 3.3.1.1.14

b. Inop 2 3 G SR 3.3.1.1.3 NA SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.4 NA SR 3.3.1.1.14

2. Average Power Range Monitors

a. Neutron Flux - High- 2 23(b) G SR 3.3.1.1.1 *20% RTP (Setdown) R, 2 .4.*4 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1 g 1 0 (d),(e)

SR 3.3.1.1.4416

b. R-ew- iaeed-Simulated 1 _3(b) F SR 3.3.1.1.1 _0.584+62% RTP Thermal Power - High SR 3.3.1.1.2 *,w - 4. 99A SR 3.3.1.1.7 R; O.63W+64.0%

2R 2. a. 4 4 R RTP and < 114.9%

SR 2.2.4.4.9 RTP(c)

SR 3.3.1.1.4 4.10 (d).(.)

SR 3.3.1.1.4416 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

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

(c) s 0.63W + 60.8% RTP and < 114.9% RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating."

(d) If the as-found channel setpoint is 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.

(e) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm Columbia Generating Station 3.3.1.1-8 Amendment No. 449 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications. I Columbia Generating Station 3.3.1.1-9 Amendment No. 449 2-2.5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 2 of 4)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

2. Average Power Range Monitors

c. Rmad Neutron Flux - 123b) F SR 3.3.1.1.1 <120% RTP High SR 3.3.1.1.2 SR 3.3.1.1.7 RRt 2" 2 41 SR 3 .3.1.1.4 4 10 (d),(.)

SR 3.3.1.1.44516

d. Inop 1,2 2 3 (b) G SR 34.1..7 NA SIR 3.3.!.!.A SR 3.3.1.1.4416

e. 2-Out-of-4 Voter 1,2 2 G SR 3.3.1.1.1 NA SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.16

f. OPRM Upscale (f) 3 (b) I SR 3.3.1.1.1 NA(g)

SR 3.3.1.1.7 SR 3.3.1.1 .10(*o)(e)

SR 3.3.1.1.16 SR 3.3.1.1.17 (b) Each APRM/OPRM channel provides inputs to both trip systems.

(d) Ifthe as-found channel setpoint is 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.

(e) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.

(f) THERMAL POWER greater than or equal to the value specified in the COLR.

(g) The OPRM Upscale does not have an Allowable Value. The Period Based Detection Algorithm (PBDA) trip setpoints are specified in the COLR.

Columbia Generating Station 3.3.1.1-10 Amendment No. 449 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 23 of 34)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

3. Reactor Vessel Steam 1,2 2 G SR 3.3.1.1.8 _ 1079 psig Dome Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

4. Reactor Vessel Water Level 1,2 2 G SR 3.3.1.1.1 > 9.5 inches

- Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

5. Main Steam Isolation Valve 1 8 F SR 3.3.1.1.8 < 12.5% closed

- Closure SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

6. Primary Containment 1,2 2 G SR 3.3.1.1.8 < 1.88 psig Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14

7. Scram Discharge Volume Water Level - High

a. Transmitter/Trip Unit 1,2 2 G SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 2 H SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

b. Float Switch 1,2 2 G SR 3.3.1.1.8

529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5 (a) 2 H SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

8. Turbine Throttle Valve - > 30% RTP 4 E SR 3.3.1.1.8 < 7% closed Closure SR 3.3.1.1.10 SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-11 Amendment No. 46-9 2,25

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 34 of 34)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

9. Turbine Governor Valve >30% RTP 2 E SR 3.3.1.1.8 Ž1000 psig Fast Closure, Trip Oil SR 3.3.1.1.10 Pressure - Low SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15

10. Reactor Mode Switch - 1,2 2 G SR 3.3.1.1.13 NA Shutdown Position SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.13 SR 3.3.1.1.14 NA

11. Manual Scram 1,2 2 G SR 3.3.1.1.4 NA SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.4 NA SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-12 Amendment No.

OPRM Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.3 3.3 INSTRUMENTATION 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation LCO 3.3.1.3 Four channels of the OPRM instrumentation shall be OPERABLE within the limits as specified in the COLR.

APPLICABILITY: THERMAL POWER Ž 25% RTP prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS

Nn r------------------------------------------------------------,

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 30 days channels inoperable.

OR A.2 Place associated RPS trip 30 days system in trip.

OR A.3 Initiate alternate method to 30 days detect and suppress thermal hydraulic instability oscillations.

B. OPRM trip capability not B.1 Initiate alternate method to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months maintained, detect and suppress thermal hydraulic instability oscillations.

C. Required Action and C.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER < 25% RTP.

Time not met.

Columbia Generating Station 3.3.1.3-1 Amendment No. 474 2,75

OPRM Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.3 SURVEILLANCE REQUIREMENTS

Iv r------------------------------------------------------------

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the OPRM System maintains trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Perform CHANNEL FUNCTIONAL TEST. 184 days SR 3.3.1.3.2 Calibrate the local power range monitors. 1130 MWD/T average core exposure SR 3.3.1.3.3 - ------------------ NOTE ---------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 24 months SR 3.3.1.3.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.3.5 Verify OPRM is not bypassed when THERMAL 24 months POWER is > 30% RTP and core flow < 60% rated core flow.

SR 3.3.1.3.6 ------------------- NOTE ----------------

Neutron detectors are excluded.

Verify the RPS RESPONSE TIME is within limits. 24 months on a STAGGERED TEST BASIS Columbia Generating Station 3.3.1.3-2 Amendment No. 496 2-25

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel OPERABLE status.

inoperable.

B. Required Action and B.1 Place one RBM channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 Columbia Generating Station 3.3.2.1-1 Amendment No. 469 225

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable has not been performed in the last calendar year.

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.

Columbia Generating Station 3.3.2.1-2 Amendment No. 46.9 2-2-5

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.2 - ------------------ NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at < 10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 - ------------------ NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is_< 10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.4 -------------------- NOTE ---------------

Neutron detectors are excluded.

Verify the RBM is not bypassed: 92 days

a. When THERMAL POWER is Ž 30% RTP; and

b. When a peripheral control rod is not selected.

Columbia Generating Station 3.3.2.1-3 Amendment No. 469 2-25

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.1.5 -------------------- NOTE--- ------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 92 days SR 3.3.2.1.6 Verify the RWM is not bypassed when THERMAL 24 months POWER is < 10% RTP.

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

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.2.1.8 Verify control rod sequences input to the RWM are Prior to declaring in conformance with BPWS. RWM OPERABLE following loading of sequence into RWM Columbia Generating Station 3.3.2.1-4 Amendment No. 4-7-9 2-25

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Rod Block Monitor

a. Upscale (a) 2 SR 3.3.2.1.1 *0.58W + 51 %

SR 3.3.2.1.4 RTP SR 3.3.2.1.5

b. Inop (a) 2 SR 3.3.2.1.1 NA SR 3.3.2.1.4

c. Downscale (a) 2 SR 3.3.2.1.1 >3% RTP SR 3.3.2.1.4 SR 3.3.2.1.5

2. Rod Worth Minimizer 1 (b) 2 (b) 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8

3. Reactor Mode Switch - Shutdown (c) 2 SR 3.3.2.1.7 NA Position (a) THERMAL POWER > 30% RTP and no peripheral control rod selected.

(b) With THERMAL POWER < 10% RTP.

(c) Reactor mode switch in the shutdown position.

Columbia Generating Station 3.3.2.1-5 Amendment No.'4-6@ 2-29

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) I 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel OPERABLE status.

inoperable.

B. Required Action and B.1 Place one RBM channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 Columbia Generating Station 3.3.2.1-1 Amendment No. 469 22-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable has not been performed in the last calendar year.

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.

Columbia Generating Station 3.3.2.1-2 Amendment No. 4-" 2-2-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS

. r~-rrr' I I ----------------------------------------------------------

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. 82 184 days I SR 3.3.2.1.2 -------------------- NOTE---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at < 10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 -------------------- NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is *10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days Columbia Generating Station 3.3.2.1-3 Amendment No. 4499 22-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

+

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

Neutron detectors are excluded.

Verify the RBM is not bypassed: 2.-days 24

a. Whn THERMAL POWER ic, . 30-0,4 RTDP; and months

a. Low Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is > 28% and < 63% RTP and peripheral control rod is not selected.

b-1.Whon -Rporiphoral conAtrol ro-d i4no seAeeed~

b. Intermediate Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is > 63% and < 83% RTP and peripheral control rod is not selected.

c. High Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is > 83% and peripheral control rod is not selected.

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

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 92 -days 2 4 months SR 3.3.2.1.6 Verify the RWM is not bypassed when THERMAL 24 months POWER is < 10% RTP.

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

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.2.1.8 Verify control rod sequences input to the RWM are Prior to declaring in conformance with BPWS. RWM OPERABLE following loading of sequence into RWM Columbia Generating Station 3.3.2.1-4 Amendment No. 4-7-9 22-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) I 3.3.2.1 Table 3.3.2.1-1 (page 1 of 4-2)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Rod Block Monitor

a. Low Power Range - Upscale (a) 2 SR 3.3.2.1.1 !5-0.58W SR 3.3.2.1.4 64,9A RTW(f)

SR 3.3.2.1.5()'('e)

b. Ilep*intermediated Power (b) 2 SR 3.3.2.1.1 (f)

Range - Upscale SR 3.3.2.1.4 SR 3.3.2.1. 5 (d),(eI

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

SR 3.3.2.1.4 SR 3.3.2.1. 5 (d),(e) bd. Inop (a),(b),(c) 2 SR 3.3.2.1.1 NA

c. Downczalo Ž4%-ARTP SRR 3244 (a) THERMAL POWER Ž:30% RTP and no poripheral cont-Fra! rod- soloctosd.

(a) APRM Simulated Thermal Power is a 28% and < 63% RTP and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.

(b) APRM Simulated Thermal Power is > 63% and < 83% RTP and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.

(c) APRM Simulated Thermal Power is > 83% and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.

(d) If the as-found channel setpoint is 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.

(e) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.

(f) Allowable Value Specified in the COLR.

/I\ IAI4I'. TIUOIIRAI -/lI**4fl01- DrDT (c'I Raniotor modA Ai~itrh in thAi chutdcwnR ;noc4iti Columbia Generating Station 3.3.2.1-5 Amendment No. 4.69 22-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 2 of 2)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

2. Rod Worth Minimizer 1(b), 2(b) 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8

3. Reactor Mode Switch - Shutdown (eh) 2 SR 3.3.2.1.7 NA Position (fg) With THERMAL POWER < 10% RTP.

(Gh) Reactor mode switch in the shutdown position.

Columbia Generating Station 3.3.2.1-6 Amendment No.

Recirculation Loops Operating (Priorto Implementation of PRNM Upgrade) I 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.

OR One recirculation loop shall be in operation provided that 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; and

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," single loop operation limits specified in the COLR.

APPLICABILITY: MODES 1 and 2 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop flow A.1 Declare the recirculation 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months mismatch not within loop with lower flow to be limits. "not in operation."

B. Requirements of the B.1 Satisfy the requirements of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LCO not met for reasons the LCO.

other than Condition A.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met.

OR No recirculation loops in operation.

Columbia Generating Station 3.4.1-1 Amendment No. 2-95 22-5

Recirculation Loops Operating (Priorto Implementation of PRNM Upgrade) 3.4.1 SURVEILLANCE REQUIREMENTS 7

SURVEILLANCE FREQUENCY

+

SR 3.4.1.1 ---------------------------- NOTE ---------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation loop drive flow mismatch with 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months both recirculation loops in operation is:

a. < 10% of rated recirculation loop drive flow when operating at < 70% of rated core flow; and

b. < 5% of rated recirculation loop drive flow when operating at > 70% of rated core flow.

Columbia Generating Station 3.4.1-2 Amendment No. 474 22-5

Recirculation Loops Operating (After Implementation of PRNM Upgrade) 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.

OR One recirculation loop shall be in operation provided that 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; aiid

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," single loop operation limits specified in the COLR7 ; and

c. LCO 3.3.1.1, "Reactor Protection System (RPS) Instrumentation,"

Function 2.b (Average Power Range Monitors, Simulated Thermal Power - High), Allowable Value of Table 3.3.1.1-1 is reset for single loop operation.

APPLICABILITY: MODES 1 and 2 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop flow A.1 Declare the recirculation 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months mismatch not within loop with lower flow to be limits. "not in operation."

B. Requirements of the B. 1 Satisfy the requirements of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LCO not met for reasons the LCO.

other than Condition A.

Columbia Generating Station 3.4.1-1 Amendment No. 205 22-5

Recirculation Loops Operating (After Implementation of PRNM Upgrade) 3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met.

OR No recirculation loops in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 ---------------------- NOTE ---------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation loop drive flow mismatch with 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months both recirculation loops in operation is:

a. < 10% of rated recirculation loop drive flow when operating at < 70% of rated core flow; and

b. < 5% of rated recirculation loop drive flow when operating at > 70% of rated core flow.

Columbia Generating Station 3.4.1-2 Amendment No. 47-4 2229

SDM Test - Refueling (Priorto Implementation of PRNM Upgrade) I 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. LCO 3.3.1.1, "Reactor Protection System Instrumentation," MODE 2 requirements for Functions 2.a and 2.d of Table 3.3.1.1-1;

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 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 control rod drive (CRD);

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out 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 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

Columbia Generating Station 3.10.8-1 Amendment No. 469 22-5

SDM Test - Refueling (Priorto Implementation of PRNM Upgrade) I 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------- NOTE ------------------- NOTE ---------

Separate Condition entry Rod worth minimizer may be is allowed for each bypassed as allowed by control rod. LCO 3.3.2.1, "Control Rod Block

................................. Instrumentation," if required, to allow insertion of inoperable control One or more control rod and continued operation.

rods not coupled to its associated CRD.

A.1 Fully insert inoperable 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

B. One or more of the B.1 Place the reactor mode Immediately above requirements not switch in the shutdown or met for reasons other refuel position.

than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for According to the LCO 3.3.1.1, Functions 2.a and 2.d of applicable SRs Table 3.3.1.1-1.

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 According to the LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. applicable SRs Columbia Generating Station 3.10.8-2 Amendment No. 4-6.9 2-26

SDM Test - Refueling (Priorto Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS 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 During control rod with the approved control rod sequence for the SDM movement test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months progress.

SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. 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 7 days

_>940 psig.

Columbia Generating Station 3.10.8-3 Amendment No. 4-69 2-2-5

SDM Test - Refueling (After Implementation of PRNM Upgrade) I 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. LCO 3.3.1.1, "Reactor Protection System Instrumentation," MODE 2 requirements for Functions 2.a, ad-2.d, and 2.e of Table 3.3.1.1-1;

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 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 control rod drive (CRD);

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out 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 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

Columbia Generating Station 3.10.8-1 Amendment No. 469 2-2-5

SDM Test - Refueling (After Implementation of PRNM Upgrade) 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------- NOTE ------------------- NOTE -------------------

Separate Condition entry Rod worth minimizer may be is allowed for each bypassed as allowed by control rod. LCO 3.3.2.1, "Control Rod Block Instrumentation," if required, to allow insertion of inoperable control One or more control rod and continued operation.

rods not coupled to its associated CRD.

A.1 Fully insert inoperable 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

B. One or more of the B.1 Place the reactor mode Immediately above requirements not switch in the shutdown or met for reasons other refuel position.

than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for According to the LCO 3.3.1.1, Functions 2.a,-aAe2.d, and 2.e of applicable SRs Table 3.3.1.1-1.

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 According to the LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. applicable SRs Columbia Generating Station 3.10.8-2 Amendment No. 449 2-2-5

SDM Test - Refueling (After Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS 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 During control rod with the approved control rod sequence for the SDM movement test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months progress.

SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. 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 7 days

>_940 psig.

Columbia Generating Station 3.10.8-3 Amendment No. 4-99 2-2-5

Reporting Requirements 5.6 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 Radioactive Effluent Release Report The Radioactive Effluent Release Report covering the operation of the unit shall be submitted 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 the Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

5.6-1 Amendment No. 1-9~ 225 Generating Station Columbia Generating Station 5.6-1 Amendment No. 4-90 2-2-5

Reporting Requirements 5.6 5.6 Reporting Requirements 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 for Specification 3.2.2;

3. The LHGR for Specification 3.2.3; aRd

4. LCO 3.3.1.3, "Oscillation Power Range Monitor (OPRM)

Instrumentation" prior to implementation of Power Range Neutron Monitor (PRNM) upgrade;-

5. The Oscillation Power Range Monitor (OPRM) Instrumentation for Specification 3.3.1.1 after implementation of PRNM upgrade; and

6. The Rod Block Monitor Instrumentation for Specification 3.3.2.1 after implementation of PRNM upgrade.

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. XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model," Exxon Nuclear Company

2. XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Nuclear Jet Pump BWR Reload Fuel," Exxon Nuclear Company

3. EMF-85-74(P) Supplement 1(P)(A) and Supplement 2(P)(A),

"RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model,"

Siemens Power Corporation

4. ANF-89-98(P)(A), "Generic Mechanical Design Criteria for BWR Fuel Designs," Advanced Nuclear Fuels Corporation

5. XN-NF-80-19(P)(A) Volume 1, "Exxon Nuclear Methodology for Boiling Water Reactors - Neutronic Methods for Design and Analysis,"

Exxon Nuclear Company

6. XN-NF-80-19(P)(A) Volume 4, "Exxon Nuclear Methodology for Boiling Water Reactors: Application of the ENC Methodology to BWR Reloads," Exxon Nuclear Company 5.6-2 Amendment No. 1-QO 22~

Columbia Generating Station Columbia Generating Station 5.6-2 Amendment No. 4-99 22-5

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued)

7. EMF-2158(P)(A), "Siemens Power Corporation Methodology for Boiling Water Reactors: Evaluation and Validation of CASMO-4/MICROBURN-B2," Siemens Power Corporation

8. XN-NF-80-19(P)(A) Volume 3, "Exxon Nuclear Methodology for Boiling Water Reactors, THERMEX: Thermal Limits Methodology Summary Description," Exxon Nuclear Company

9. XN-NF-84-105(P)(A) Volume 1, "XCOBRA-T: A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis," Exxon Nuclear Company

10. ANF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors," Advanced Nuclear Fuels Corporation

11. ANF-913(P)(A) Volume 1, "COTRANSA2: A Computer Program for Boiling Water Reactor Transient Analysis," Advanced Nuclear Fuels Corporation

12. ANF-1358(P)(A) "The Loss of Feedwater Heating Transient in Boiling Water Reactors," Advanced Nuclear Fuels Corporation

13. EMF-2209(P)(A), "SPCB Critical Power Correlation," Siemens Power Corporation

14. EMF-2245(P)(A), "Application of Siemens Power Corporation's Critical Power Correlations to Co-Resident Fuel," Siemens Power Corporation

15. EMF-2361(P)(A), "EXEM BWR-2000 ECCS Evaluation Model,"

Framatome ANP Richland

16. EMF-2292(P)(A), "ATRIUMTM -10: Appendix K Spray Heat Transfer Coefficients," Siemens Power Corporation

17. EMF-CC-074(P)(A) Volume 4, "BWR Stability Analysis-Assessment of STAIF with Input from MICROBURN-B2," Siemens Power Corporation

18. CENPD-300-P-A, "Reference Safety Report for Boiling Water Reactor Reload Fuel," ABB Combustion Engineering Nuclear Operations

19. NEDO-32465-A, "BWR Owners' Group Reactor Stability Detect and Suppress Solutions Licensing Basis Methodology and Reload Applications"

20. NEDC-33419P, "GEXL97 Correlation Applicable to ATRIUM-10 Fuel,"

Global Nuclear Fuel Columbia Generating Station 5.6-3 Amendment No. 499 22-5

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.3 CORE OPERATING LIMITS REPORT (COLR) (continued)

21. NEDE-24011-P-A and NEDE-24011-P-A-US, "General Electric Standard Application for Reactor Fuel (GESTAR II) and Supplement for United States," Global Nuclear Fuel

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.

5.6.4 Post Accident Monitoring (PAM) Instrumentation 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.

Columbia Generating Station 5.6-4 Amendment No. 490 22-5

RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION REGARDING LICENSE AMENDMENT REQUEST TO IMPLEMENT PRNM/ARTS/MELLLA Retyped Technical Specification Pages

APRM Gain and Setpoint (Priorto Implementation of PRNM Upgrade) I 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Average Power Range Monitor (APRM) Gain and Setpoint LCO 3.2.4 a. MFLPD shall be less than or equal to Fraction of RTP (FRTP); or

b. Each required APRM Flow Biased Simulated Thermal Power - High Function Allowable Value shall be modified by greater than or equal to the ratio of FRTP and the MFLPD; or

c. Each required APRM gain shall be adjusted such that the APRM readings are >_100% times MFLPD.

APPLICABILITY: THERMAL POWER _> 25% RTP prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Satisfy the requirements of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months LCO not met. the LCO.

B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to < 25% RTP.

Time not met.

Columbia Generating Station 3.2.4-1 Amendment No. 469 22-5

APRM Gain and Setpoint (Priorto Implementation of PRNM Upgrade) 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 -NOTE Not required to be met if SR 3.2.4.2 is satisfied for LCO 3.2.4.b or LCO 3.2.4.c requirements.

Verify MFLPD is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

> 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter i

SR 3.2.4.2 ------------------

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

Not required to be met if SR 3.2.4.1 is satisfied for LCO 3.2.4.a requirements.

Verify each required: 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months

a. APRM Flow Biased Simulated Thermal Power -

High Function Allowable Value is modified by greater than or equal to the ratio of FRTP and the MFLPD; or

b. APRM gain is adjusted such that the APRM reading is _>100% times MFLPD.

Columbia Generating Station 3.2.4-2 Amendment No. 46.9 2-2-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 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 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months channels inoperable.

OR A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

B. One or more Functions B.1 Place channel in one trip 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months with one or more system in trip.

required channels inoperable in both trip OR systems.

B.2 Place one trip system in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trip.

C. One or more Functions C.1 Restore RPS trip capability. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, B, Table 3.3.1.1-1 for the or C not met. channel.

Columbia Generating Station 3.3.1.1-1 Amendment No. 4-69 2-2-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. As required by Required E.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Action D.1 and POWER to < 30% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by Required G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by Required H.1 Initiate action to fully insert Immediately Action D.1 and all insertable control rods in referenced in core cells containing one or Table 3.3.1.1-1. more fuel assemblies.

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.3.1.1-2 Amendment No. 4-69 2-2-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.2 --------------- NOTE ------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER Ž>25% RTP.

Verify the absolute difference between the average 7 days power range monitor (APRM) channels and the calculated power < 2% RTP plus any gain adjustment required by LCO 3.2.4, "Average Power Range Monitor (APRM) Gain and Setpoint," while operating at > 25% RTP.

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

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels overlap, withdrawing SRMs from the fully inserted position SR 3.3.1.1.6 -------------------- NOTE---------------

Only required to be met. during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Calibrate the local power range monitors. 1130 MWD/T average core exposure Columbia Generating Station 3.3.1.1 -3 Amendment No. 449 2-2-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.9 -------------------- NOTES---------------

1. Neutron detectors are excluded.

2. For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 184 days SR 3.3.1.1.10 ------------------- NOTES---------------

1. Neutron detectors are excluded.

2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 18 months for Functions 1 through 4, 6, 7, and 9 through 11 AND 24 months for Functions 5 and 8 SR 3.3.1.1.11 Verify the APRM Flow Biased Simulated Thermal 18 months Power - High Function time constant is < 7 seconds.

SR 3.3.1.1.12 Verify Turbine Throttle Valve - Closure, and Turbine 18 months Governor Valve Fast Closure Trip Oil Pressure -

Low Functions are not bypassed when THERMAL POWER is Ž 30% RTP.

SR 3.3.1.1.13 Perform CHANNEL FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.1.1-4 Amendment No. 47-9 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.14 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.1.15 ------------------- NOTES---------------

1 Neutron detectors are excluded.

2. Channel sensors for Functions 3 and 4 are excluded.

3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

Verify the RPS RESPONSE TIME is within limits. 24 months on a STAGGERED TEST BASIS Columbia Generating Station 3.3.1.1-5 Amendment No. 4-69 2-25

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE I. Intermediate Range Monitors

a. Neutron Flux - High 2 3 G SR 3.3.1.1.1 < 122/125 SR 3.3.1.1.3 divisions of full SR 3.3.1.1.5 scale SR 3.3.1.1.6 SR 3.3.1.1.10 SR 3.3.1.1.14 3 H SR 3.3.1.1.1 < 122/125 SR 3.3.1.1.4 divisions of full SR 3.3.1.1.10 scale SR 3.3.1.1.14

b. Inop 2 3 G SR 3.3.1.1.3 NA SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.4 NA SR 3.3.1.1.14

2. Average Power Range Monitors

a. Neutron Flux - High, 2 2 G SR 3.3.1.1.1

20% RTP Setdown SR 3.3.1.1.3 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.9 SR 3.3.1.1.14

b. Flow Biased Simulated I 2 F SR 3.3.1.1.1

0.58 W + 62% RTP Thermal Power - High SR 3.3.1.1.2 and *114.9% RTP SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14

c. Fixed Neutron Flux - 2 F SR 3.3.1.1.1 < 120% RTP High SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.14 SR 3.3.1.1.15

d. Inop 1,2 2 G SR 3.3.1.1.7 NA SR 3.3.1.1.8 SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-6 Amendment No. 469 22-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

3. Reactor Vessel Steam 1,2 2 G SR 3.3.1.1.8 < 1079 psig Dome Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

4. Reactor Vessel Water Level 1,2 2 G SR 3.3.1.1.1 > 9.5 inches

- Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

5. Main Steam Isolation Valve F SR 3.3.1.1.8 < 12.5% closed

- Closure SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

6. Primary Containment 1,2 G SR 3.3.1.1.8 _<1.88 psig Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14

7. Scram Discharge Volume Water Level - High

a. Transmitter/Trip Unit 1,2 2 G SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 2 H SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

b. Float Switch 1,2 G SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5 (a) 2 H SR 3.3.1.1.8 5 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

8. Turbine Throttle Valve - _>30% RTP 4 E SR 3.3.1.1.8 < 7% closed Closure SR 3.3.1.1.10 SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-7 Amendment No. 469 2-2-5

RPS Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

9. Turbine Governor Valve _30% RTP 2 E SR 3.3.1.1.8 >1000 psig Fast Closure, Trip Oil SR 3.3.1.1.10 Pressure - Low SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15

10. Reactor Mode Switch - 1,2 2 G SR 3.3.1.1.13 NA Shutdown Position SR 3.3.1.1.14 5(8) 2 H SR 3.3.1.1.13 SR 3.3.1.1.14 NA

11. Manual Scram 1,2 2 G SR 3.3.1.1.4 NA SR 3.3.1.1.14 5()2 H SR 3.3.1.1.4 NA SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-8 Amendment No. 4-6-9 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 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 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months channels inoperable.

OR NOTE ---------------

Not applicable for Functions 2.a, 2.b, 2.c, 2.d, or 2.f.

A.2 Place associated trip 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months system in trip.

-NOTE

B.1 Place channel in one trip 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Not applicable for system in trip.

Functions 2.a, 2.b, 2.c, 2.d, or 2.f. OR B.2 Place one trip system in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. One or more Functions trip.

with one or more required channels inoperable in both trip systems.

Columbia Generating Station 3.3.1.1-1 Amendment No. 4-69 2-2-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Restore RPS trip capability. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability not maintained.

D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A, B, Table 3.3.1.1-1 for the or C not met. channel.

E. As required by Required E.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Action D.1 and POWER to < 30% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

G. As required by Required G.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by Required H.1 Initiate action to fully insert Immediately Action D.1 and all insertable control rods in referenced in core cells containing one or Table 3.3.1.1-1. more fuel assemblies.

Columbia Generating Station 3.3.1.1-2 Amendment No. 46.9 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME As required by Required 1.1 Initiate alternate method to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action D.1 and detect and suppress referenced in thermal hydraulic instability Table 3.3.1.1-1. oscillations.

AND

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

LCO 3.0.4 is not applicable.

1.2 Restore required channels 120 days to OPERABLE J. Required Action and J.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to less than the Time of Condition I not value specified in the met. COLR.

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Columbia Generating Station 3.3.1.1-3 Amendment No. 469 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.2 -------------------- NOTE ---------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER Ž>25% RTP.

Verify the absolute difference between the average 7 days power range monitor (APRM) channels and the calculated power < 2% RTP while operating at

Ž>25% RTP.

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

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.4 Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.5 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels overlap, withdrawing SRMs from the fully inserted position SR 3.3.1.1.6 -------------------- NOTE ---------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.7 Calibrate the local power range monitors. 1130 MWD/T average core exposure Columbia Generating Station 3.3.1.1-4 Amendment No. 46@ 2-2-9

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY S R 3.3.1.1.8 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.1.1.9 Deleted.

SR 3.3.1.1.10 ------------------- NOTES---------------

1. Neutron detectors are excluded.

2. For Function 1, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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. 18 months for Functions 1, 3, 4, 6, 7, and 9 through 11 AND 24 months for Functions 2, 5, and 8 SR 3.3.1.1.11 Deleted.

SR 3.3.1.1.12 Verify Turbine Throttle Valve - Closure, and Turbine 18 months Governor Valve Fast Closure Trip Oil Pressure -

Low Functions are not bypassed when THERMAL POWER is Ž 30% RTP.

SR 3.3.1.1.13 Perform CHANNEL FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.1.1-5 Amendment No. 4-7-9 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.1.14 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.1.15 ------------------- NOTES---------------

1 Neutron detectors are excluded.

2. Channel sensors for Functions 3 and 4 are excluded.

3. For Function 5, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

4. For Function 2.e, "n" equals 8 channels for the purpose of determining the STAGGERED TEST BASIS Frequency. Testing of APRM and oscillation power range monitor (OPRM) outputs shall alternate.

24 months on a Verify the RPS RESPONSE TIME is within limits. STAGGERED TEST BASIS SR 3.3.1.1.16 ------------------- NOTES---------------

1 For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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. 184 days SR 3.3.1.1.17 Verify the OPRM is not bypassed when APRM 24 months Simulated Thermal Power is greater than or equal to the value specified in the COLR and recirculation drive flow is less than the value specified in the COLR.

Columbia Generating Station 3.3.1.1-6 Amendment No. 46.9 Q4

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 1 of 4)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

1. Intermediate Range Monitors

a. Neutron Flux - High 2 3 G SR 3.3.1.1.1 _122/125 SR 3.3.1.1.3 divisions of full SR 3.3.1.1.5 scale SR 3.3.1.1.6 SR 3.3.1.1.10 SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.1 _122/125 SR 3.3.1.1.4 divisions of full SR 3.3.1.1.10 scale SR 3.3.1.1.14

b. Inop 2 3 G SR 3.3.1.1.3 NA SR 3.3.1.1.14 5(a) 3 H SR 3.3.1.1.4 NA SR 3.3.1.1.14

2. Average Power Range Monitors

a. Neutron Flux - High 2 3(bG SR 3.3.1.1.1 *20% RTP (Setdown) SR 3.3.1.1.6 SR 3.3.1.1.7 SR .3.1.1. 10 (d),(e) 3 SR 3.3.1.1.16

b. Simulated Thermal 1 3 (b) F SR 3.3.1.1.1 _<0.63W + 64.0% RTP Power - High SR 3.3.1.1.2 and *114.9% RTP("

SR 3.3.1.1.7 SR 3 .3.1 1 .10 (d)-(e)

SR 3.3.1.1.16 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

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

(c) < 0.63W + 60.8% RTP and < 114.9% RTP when reset for single loop operation per LCO 3.4.1, "Recirculation Loops Operating."

(d) Ifthe as-found channel setpoint is 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.

(e) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.

Columbia Generating Station 3.3.1.1-7 Amendment No. 449 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) 3.3.1.1 Table 3.3.1.1-1 (page 2 of 4)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

2. Average Power Range Monitors

c. Neutron Flux - High 13(b) F SR 3.3.1.1.1 5 120% RTP SR 3.3.1.1.2 SR 3.3.1.1.7 SR 3.3.1.1. 10(d)'-e)

SR 3.3.1.1.16

d. Inop 1,2 3 (b) G SR 3.3.1.1.16 NA

e. 2-Out-of-4 Voter 1,2 2 G SR 3.3.1.1.1 NA SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.16

f. OPRM Upscale (f) 3 (b) I SR 3.3.1.1.1 NA~g)

SR 3.3.1.1.7 SR .3.1. 1

. 10 (d),Ie) 3 SR 3.3.1.1.16 SR 3.3.1.1.17 (b) Each APRM/OPRM channel provides inputs to both trip systems.

(d) If the as-found channel setpoint is 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.

(e) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.

(f) THERMAL POWER greater than or equal to the value specified in the COLR.

(g) The OPRM Upscale does not have an Allowable Value. The Period Based Detection Algorithm (PBDA) trip setpoints are specified in the COLR.

Columbia Generating Station 3.3.1.1-8 Amendment No. 46.9 2-2-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 3 of 4)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

3. Reactor Vessel Steam 1,2 2 G SR 3.3.1.1.8 < 1079 psig Dome Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

4. Reactor Vessel Water Level 1,2 2 G SR 3.3.1.1.1 > 9.5 inches

- Low, Level 3 SR 3.3.1.1.8 SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

5. Main Steam Isolation Valve 1 8 F SR 3.3.1.1.8 < 12.5% closed

- Closure SR 3.3.1.1.10 SR 3.3.1.1.14 SR 3.3.1.1.15

6. Primary Containment 1,2 2 G SR 3.3.1.1.8 < 1.88 psig Pressure - High SR 3.3.1.1.10 SR 3.3.1.1.14

7. Scram Discharge Volume Water Level - High

a. Transmitter/Trip Unit 1,2 2 G SR 3.3.1.1.8 5 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.8 < 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

b. Float Switch 1,2 2 G SR 3.3.1.1.8 5 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.8 5 529 ft 9 inches SR 3.3.1.1.10 elevation SR 3.3.1.1.14

8. Turbine Throttle Valve - - 30% RTP 4 E SR 3.3.1.1.8 < 7% closed Closure SR 3.3.1.1.10 SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-9 Amendment No. 46.9 22-5

RPS Instrumentation (After Implementation of PRNM Upgrade) I 3.3.1.1 Table 3.3.1.1-1 (page 4 of 4)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

9. Turbine Governor Valve _30% RTP 2 E SR 3.3.1.1.8 Ž1000 psig Fast Closure, Trip Oil SR 3.3.1.1.10 Pressure - Low SR 3.3.1.1.12 SR 3.3.1.1.14 SR 3.3.1.1.15

10. Reactor Mode Switch - 1,2 2 G SR 3.3.1.1.13 NA Shutdown Position SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.13 SR 3.3.1.1.14 NA

11. Manual Scram 1,2 2 G SR 3.3.1.1.4 NA SR 3.3.1.1.14 5(a) 2 H SR 3.3.1.1.4 NA SR 3.3.1.1.14 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

Columbia Generating Station 3.3.1.1-10 Amendment No.

OPRM Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.1.3 3.3 INSTRUMENTATION 3.3.1.3 Oscillation Power Range Monitor (OPRM) Instrumentation LCO 3.3.1.3 Four channels of the OPRM instrumentation shall be OPERABLE within the limits as specified in the COLR.

APPLICABILITY: THERMAL POWER > 25% RTP prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS

-NOTE.

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 30 days channels inoperable.

OR A.2 Place associated RPS trip 30 days system in trip.

OR A.3 Initiate alternate method to 30 days detect and suppress thermal hydraulic instability oscillations.

B. OPRM trip capability not B.1 Initiate alternate method to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months maintained, detect and suppress thermal hydraulic instability oscillations.

C. Required Action and C.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER < 25% RTP.

Time not met.

Columbia Generating Station 3.3.1.3-1 Amendment No. 474 2,24

OPRM Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.1.3 SURVEILLANCE REQUIREMENTS I*I

I------------------------------------------------ IWLj~. rý -----------------------------------------------------------

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the OPRM System maintains trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Perform CHANNEL FUNCTIONAL TEST. 184 days SR 3.3.1.3.2 Calibrate the local power range monitors. 1130 MWD/T average core exposure SR 3.3.1.3.3 -------------------- NOTE ---------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 24 months SR 3.3.1.3.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.3.5 Verify OPRM is not bypassed when THERMAL 24 months POWER is > 30% RTP and core flow _ 60% rated core flow.

SR 3.3.1.3.6 ------------------- NOTE ----------------

Neutron detectors are excluded.

Verify the RPS RESPONSE TIME is within limits. 24 months on a STAGGERED TEST BASIS Columbia Generating Station 3.3.1.3-2 Amendment No. 496 22-5

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) I 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel OPERABLE status.

inoperable.

B. Required Action and B.1 Place one RBM channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 Columbia Generating Station 3.3.2.1-1 Amendment No. 449 2-2-5

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable has not been performed in the last calendar year.

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.

Columbia Generating Station 3.3.2.1-2 Amendment No. 469 2-25

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.2 -------------------- NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at < 10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 -------------------- NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is < 10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.4 -------------------- NOTE ---------------

Neutron detectors are excluded.

Verify the RBM is not bypassed: 92 days

a. When THERMAL POWER is Ž 30% RTP; and

b. When a peripheral control rod is not selected.

Columbia Generating Station 3.3.2.1-3 Amendment No. 4AQ 2-25

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.1.5 -------------------- NOTE ---------------

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 92 days SR 3.3.2.1.6 Verify the RWM is not bypassed when THERMAL 24 months POWER is < 10% RTP.

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

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.2.1.8 Verify control rod sequences input to the RWM are Prior to declaring in conformance with BPWS. RWM OPERABLE following loading of sequence into RWM Columbia Generating Station 3.3.2.1-4 Amendment No. 47-9 2-2-5

Control Rod Block Instrumentation (Priorto Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Rod Block Monitor

a. Upscale (a) 2 SR 3.3.2.1.1 < 0.58W + 51 %

SR 3.3.2.1.4 RTP SR 3.3.2.1.5

b. Inop (a) 2 SR 3.3.2.1.1 NA SR 3.3.2.1.4

c. Downscale (a) 2 SR 3.3.2.1.1 > 3% RTP SR 3.3.2.1.4 SIR 3.3.2.1.5

2. Rod Worth Minimizer 1 (b), 2 (b) 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8

3. Reactor Mode Switch - Shutdown (c) 2 SR 3.3.2.1.7 NA Position (a) THERMAL POWER > 30% RTP and no peripheral control rod selected.

(b) With THERMAL POWER < 10% RTP.

(c) Reactor mode switch in the shutdown position.

Columbia Generating Station 3.3.2.1-5 Amendment No. 4-64 2-25

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) I 3.3.2.1 3.3 INSTRUMENTATION 3.3,2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, One rod block monitor A.1 Restore RBM channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (RBM) channel OPERABLE status.

inoperable.

B, Required Action and B.1 Place one RBM channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 Columbia Generating Station 3.3.2.1-1 Amendment No. 469 2-25

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) I 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable has not been performed in the last calendar year.

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.

Columbia Generating Station 3.3.2.1-2 Amendment No. 499 2-2-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 SURVEILLANCE REQUIREMENTS ki I.%lI II ----------------------------------------------------------

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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 Perform CHANNEL FUNCTIONAL TEST. 184 days SR 3.3.2.1.2 -------------------- NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn at < 10% RTP in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 -------------------- NOTE ---------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL POWER is *10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days Columbia Generating Station 3.3.2.1-3 Amendment No. 469 22-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) I 3.3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.1.4 -------------------- NOTE ---------------

Neutron detectors are excluded.

Verify the RBM is not bypassed: 24 months

a. Low Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is > 28% and < 63% RTP and peripheral control rod is not selected.

b. Intermediate Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is > 63% and < 83% RTP and peripheral control rod is not selected.

c. High Power Range - Upscale Function is not bypassed when APRM Simulated Thermal Power is > 83% and peripheral control rod is not selected.

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

Neutron detectors are excluded.

Perform CHANNEL CALIBRATION. 24 months SR 3.3.2.1.6 Verify the RWM is not bypassed when THERMAL 24 months POWER is < 10% RTP.

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

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.2.1.8 Verify control rod sequences input to the RWM are Prior to declaring in conformance with BPWS. RWM OPERABLE following loading of sequence into RWM Columbia Generating Station 3.3.2.1-4 Amendment No. 4-7-9 22-5

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) I 3.3.2.1 Table 3.3.2.1-1 (page 1 of 2)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Rod Block Monitor

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

SR 3.3.2.1.4 SR 3.3.2.1. 5 (dI,(eI

b. Intermediated Power Range- (b) 2 SR 3.3.2.1.1 (f)

Upscale SR 3.3.2.1.4 SR 3.3.2.1. 5 (dI.(eI

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

SR 3.3.2.1.4 SR 3.3.2.1.5(d).(e)

d. Inop (a),(b),(c) 2 SR 3.3.2.1.1 NA (a) APRM Simulated Thermal Power is 2 28% and < 63% RTP and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.

(b) APRM Simulated Thermal Power is -e63% and < 83% RTP and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.

(c) APRM Simulated Thermal Power is ? 83% and MCPR is less than the limit specified in the COLR and no peripheral control rod selected.

(d) If the as-found channel setpoint is 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.

(e) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance around the Limiting Trip Setpoint (LTSP) at the completion of the surveillance; otherwise, the channel shall be declared inoperable.

Setpoints more conservative than the LTSP are acceptable provided that the as-found and as-left tolerances apply to the actual setpoint implemented in the surveillance procedures (Nominal Trip Setpoint) to confirm channel performance. The LTSP and the methodologies used to determine the as-found and as-left tolerances are specified in the Licensee Controlled Specifications.

(f) Allowable Value Specified in the COLR.

Columbia Generating Station 3.3.2.1-5 Amendment No. 4-&9 2-25

Control Rod Block Instrumentation (After Implementation of PRNM Upgrade) 3.3.2.1 Table 3.3.2.1-1 (page 2 of 2)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

2. Rod Worth Minimizer 1(9), 2(9) 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.6 SR 3.3.2.1.8

3. Reactor Mode Switch - Shutdown (h) 2 SR 3.3.2.1.7 NA Position (g) With THERMAL POWER < 10% RTP.

(h) Reactor mode switch in the shutdown position.

Columbia Generating Station 3.3.2.1-6 Amendment No.

Recirculation Loops Operating (Priorto Implementation of PRNM Upgrade) 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.

OR One recirculation loop shall be in operation provided that 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; and

b. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," single loop operation limits specified in the COLR.

APPLICABILITY: MODES 1 and 2. prior to implementation of Power Range Neutron Monitor (PRNM) upgrade. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop flow A.1 Declare the recirculation 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months mismatch not within loop with lower flow to be limits. "not in operation."

B. Requirements of the B.1 Satisfy the requirements of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LCO not met for reasons the LCO.

other than Condition A.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met.

OR No recirculation loops in operation.

Columbia Generating Station 3.4.1-1 Amendment No. 2-95 2-25

Recirculation Loops Operating (Priorto Implementation of PRNM Upgrade) I 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 ------------------------ NOTE ---------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation loop drive flow mismatch with 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months both recirculation loops in operation is:

a. < 10% of rated recirculation loop drive flow when operating at < 70% of rated core flow; and

b. < 5% of rated recirculation loop drive flow when operating at _>70% of rated core flow.

Columbia Generating Station 3.4.1-2 Amendment No. 4-74 22-5

Recirculation Loops Operating (After Implementation of PRNM Upgrade) 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.

OR One recirculation loop shall be in operation provided that 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 Monitors, Simulated Thermal Power - High), Allowable Value of Table 3.3.1.1-1 is reset for single loop operation.

APPLICABILITY: MODES 1 and 2 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop flow A.1 Declare the recirculation 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months mismatch not within loop with lower flow to be limits. "not in operation."

B. Requirements of the B.1 Satisfy the requirements of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LCO not met for reasons the LCO.

other than Condition A.

Columbia Generating Station 3.4.1-1 Amendment No. 2-05 2-2-5

Recirculation Loops Operating (After Implementation of PRNM Upgrade) 3.4.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A or B not met.

OR No recirculation loops in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 -- ------------------ NOTE ---------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation loop drive flow mismatch with 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months both recirculation loops in operation is:

a. < 10% of rated recirculation loop drive flow when operating at < 70% of rated core flow; and

b. < 5% of rated recirculation loop drive flow when operating at > 70% of rated core flow.

Columbia Generating Station 3.4.1-2 Amendment No. 474 22-5

SDM Test - Refueling (Priorto Implementation of PRNM Upgrade) I 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. LCO 3.3.1.1, "Reactor Protection System Instrumentation," MODE 2 requirements for Functions 2.a and 2.d of Table 3.3.1.1-1;

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 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 control rod drive (CRD);

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out 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 prior to implementation of Power Range Neutron Monitor (PRNM) upgrade.

Columbia Generating Station 3.10.8-1 Amendment No. 46.9 22-5

SDM Test - Refueling (Priorto Implementation of PRNM Upgrade) I 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------- NOTE ------------------- NOTE ---------

Separate Condition entry Rod worth minimizer may be is allowed for each bypassed as allowed by control rod. LCO 3.3.2.1, "Control Rod Block Instrumentation," if required, to allow insertion of inoperable control One or more control rod and continued operation.

rods not coupled to its associated CRD.

A. 1 Fully insert inoperable 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

B. One or more of the B.1 Place the reactor mode Immediately above requirements not switch in the shutdown or met for reasons other refuel position.

than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for According to the LCO 3.3.1.1, Functions 2.a and 2.d of applicable SRs Table 3.3.1.1-1.

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 According to the LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. applicable SRs Columbia Generating Station 3.10.8-2 Amendment No. 46-9 2-2-5

SDM Test - Refueling (Priorto Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS 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 During control rod with the approved control rod sequence for the SDM movement test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months progress.

SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. 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 7 days

>_940 psig.

Columbia Generating Station 3.10.8-3 Amendment No. 464 22-5

SDM Test - Refueling (After Implementation of PRNM Upgrade) 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. LCO 3.3.1.1, "Reactor Protection System Instrumentation," MODE 2 requirements for Functions 2.a, 2.d, and 2.e of Table 3.3.1.1-1;

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 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 control rod drive (CRD);

d. All control rod withdrawals during out of sequence control rod moves shall be made in notch out 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 after implementation of Power Range Neutron Monitor (PRNM) upgrade.

Columbia Generating Station 3.10.8-1 Amendment No. 469 22-5

SDM Test - Refueling (After Implementation of PRNM Upgrade) I 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------- NOTE ------------------- NOTE--- -----

Separate Condition entry Rod worth minimizer may be is allowed for each bypassed as allowed by control rod. LCO 3.3.2.1, "Control Rod Block Instrumentation," if required, to allow insertion of inoperable control One or more control rod and continued operation.

rods not coupled to its associated CRD.

A.1 Fully insert inoperable 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months control rod.

AND A.2 Disarm the associated 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months CRD.

B. One or more of the B.1 Place the reactor mode Immediately above requirements not switch in the shutdown or met for reasons other refuel position.

than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.8.1 Perform the MODE 2 applicable SRs for According to the LCO 3.3.1.1, Functions 2.a, 2.d, and 2.e of applicable SRs Table 3.3.1.1-1.

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 According to the LCO 3.3.2.1, Function 2 of Table 3.3.2.1-1. applicable SRs Columbia Generating Station 3.10.8-2 Amendment No. 4&9 22-5

SDM Test - Refueling (After Implementation of PRNM Upgrade) 3.10.8 SURVEILLANCE REQUIREMENTS 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 During control rod with the approved control rod sequence for the SDM movement test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months progress.

SR 3.10.8.5 Verify each withdrawn control rod does not go to the Each time the withdrawn overtravel position. 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 7 days

_>940 psig.

Columbia Generating Station 3.10.8-3 Amendment No. 449 22-5

Reporting Requirements 5.6 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 Radioloqical 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 Radioactive Effluent Release Report The Radioactive Effluent Release Report covering the operation of the unit shall be submitted 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 the Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

5.6-1 Amendment No. 1-90 22~

Generating Station Columbia Generating Station 5.6-1 Amendment No. 4-99 2-25

Reporting Requirements 5.6 5.6 Reporting Requirements 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 for Specification 3.2.2;

3. The LHGR for Specification 3.2.3;

4. LCO 3.3.1.3, "Oscillation Power Range Monitor (OPRM)

Instrumentation" prior to implementation of Power Range Neutron Monitor (PRNM) upgrade;

5. The Oscillation Power Range Monitor (OPRM) Instrumentation for Specification 3.3.1.1 after implementation of PRNM upgrade; and

6. The Rod Block Monitor Instrumentation for Specification 3.3.2.1 after implementation of PRNM upgrade.

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. XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model," Exxon Nuclear Company

2. XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Nuclear Jet Pump BWR Reload Fuel," Exxon Nuclear Company

3. EMF-85-74(P) Supplement 1(P)(A) and Supplement 2(P)(A),

"RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model,"

Siemens Power Corporation

4. ANF-89-98(P)(A), "Generic Mechanical Design Criteria for BWR Fuel Designs," Advanced Nuclear Fuels Corporation

5. XN-NF-80-19(P)(A) Volume 1, "Exxon Nuclear Methodology for Boiling Water Reactors - Neutronic Methods for Design and Analysis,"

Exxon Nuclear Company

6. XN-NF-80-19(P)(A) Volume 4, "Exxon Nuclear Methodology for Boiling Water Reactors: Application of the ENC Methodology to BWR Reloads," Exxon Nuclear Company Columbia Generating Station 5.6-2 Amendment No. 4@G 22-5