NLS2008097, Startup Test Report for Measurement Uncertainty Recapture Power Uprate

Startup Test Report for Measurement Uncertainty Recapture Power Uprate

ML083030042
Person / Time
Site:	Cooper
Issue date:	10/22/2008
From:	Vanderkamp D Nebraska Public Power District (NPPD)
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NLS2008097
Download: ML083030042 (33)

Text

Nebraska Public Power District "Always there when you need us" NLS2008097 October 22, 2008 U.S. Nuclear Regulatory Commission Attention:Document Control Desk Washington, D.C. 20555-0001

Subject:

Startup Test Report for Measurement Uncertainty Recapture Power Uprate Cooper Nuclear Station, Docket No. 50-298, DPR-46

References:

1.

Letter from Stewart B. Minahan, Nebraska Public Power District, to the U.S. Nuclear Regulatory Commission, dated November 19, 2007, "License Amendment Request to Revise Technical Specifications -

Appendix K Measurement Uncertainty Recapture Power Uprate"

2.

Letter from Carl F. Lyon, U.S. Nuclear Regulatory Commission, to Stewart B. Minahan, Nebraska Public Power District, dated June 30, 2008, "Cooper Nuclear Station - Issuance of Amendment Re: Measurement Uncertainty Recapture Power Uprate (TAC No. MD7385)"

3.

Letter from Stewart B. Minahan, Nebraska Public Power District, to the U.S. Nuclear Regulatory Commission, dated September 22, 2008, "Revision to Commitment Referenced in Amendment 231 Safety Evaluation"

Dear Sir or Madam:

The purpose of this letter is for the Nebraska Public Power District to provide the Cooper Nuclear Station (CNS) Startup Test Report for Measurement Uncertainty Recapture (MUR)

Power Uprate. This report is submitted in accordance with the requirements in the CNS Updated Safety Analysis Report for the MUR Power Uprate and closes Commitment Number NLS2007069-11, as listed in Reference 1, reflected in Reference 2, and revised in Reference 3.

The attachments provide the CNS Startup Test Report, including steam flow values and Nuclear Steam Supply System parameter monitoring results.

COOPER NUCLEAR STATION P.O. Box 98 / Brownville, NE 68321-0098 Telephone: (402) 825-3811 / Fax: (402) 825-5211 A

www,,.nppd.com

NLS2008097 Page 2 of 2 If you have questions concerning this matter, please contact me at (402) 825-2904.

Sincerely, David W. Van Der Kamp Licensing Manager

/dm Attachments cc:

Regional Administrator, w/attachments USNRC - Region IV Cooper Project Manager, w/attachments USNRC - NRR Project Directorate IV-I Senior Resident Inspector, w/attachments USNRC - CNS NPG Distribution, w/o attachments CNS Records, w/attachments

NLS2008097 Attachment 15 Pages Total Cooper Nuclear Station Startup Test Report Measurement Uncertainty Recapture Power Uprate Cooper Nuclear Station, Docket No. 50-298, DPR-46

NLS2008097 Attachment Page 1 of 14 Cooper Nuclear Station Startup Test Report for MUR Power Uprate Introduction This startup report is submitted in accordance with the requirements of the Cooper Nuclear Station (CNS) Updated Safety Analysis Report (USAR) Chapter XIII, Section 5.0 for the Measurement Uncertainty Recapture (MUR) uprate. The startup testing was conducted July 24 through July 25, 2008.

Tests were selected in accordance with the guidelines in NEDC-32938P-A, "Licensing Topical Report - Generic Guidelines and Evaluations for General Electric Boiling Water Reactor Thermal Power Optimization," Revision 2, May 2003 (Section 5.11.9 - Power Uprate Testing).

For each test, the purpose, description, method of data acquisition, conditions, acceptance criteria, and results are described below. Level 1 acceptance criteria are those criteria, if any, important to plant safety. Level 2 acceptance criteria are those criteria, if any, that are associated with design performance.

In addition to the tests selected in accordance with the licensing topical report, Nebraska Public Power District (NPPD) committed to compliance with Regulatory Guide 1.20, "Comprehensive Vibration Assessment Program for Reactor Internals During Preoperational and Initial Startup Testing," Revision 3, March 2007.

To accomplish this, CNS evaluated the components listed in the regulatory guide along with piping deemed potentially susceptible to vibration-induced damage for CNS. This evaluation was done using industry experience for MUR power uprates and CNS operating history for the subject components and piping. The results are contained in the section of the Startup Test Report discussing Commitment Number NLS2007069-08, Main Steam Line Vibration Monitoring.

Test 1A - Chemical and Radiochemical

Purpose:

The purpose of this test is to maintain control of and knowledge about the quality of the reactor coolant chemistry and radiochemistry at Thermal Power Optimization (TPO) conditions.

==

Description:==

Samples are taken and measurements made at TPO test conditions to determine:

1)

The chemical and radiochemical quality of reactor water and reactor feedwater.

2)

Gaseous release.

Test Data Acquisition: Chemical and radiochemical data was obtained from the chemistry department routine sampling and analysis program.

NLS2008097 Attachment Page 2 of 14 Test Conditions: Measure chemical and radiochemical quality of reactor water and reactor feedwater gaseous release at 100% Current License Thermal Power (CLTP) and at TPO power level.

Level 1 Acceptance Criteria:

a)

Chemical factors defined in the Technical Specifications and Fuel Warranty must be maintained within the limits specified.

b)

The activity of gaseous and liquid effluents conforms to license limitations.

c)

Water quality is known at all times and remains within the requirements of the utility chemistry program.

Level 2 Acceptance Criteria: None.

Results: All acceptance criteria were met. The table below standard chemistry parameters at 100% CLTP and TPO.

contains a comparison between Parameter 100% CLTP TPO Reactor Water Conductivity 0.105 uS/cm 0.107 uS/cm Chloride

<0.3 ppb

<0.3 ppb pH N/A (not done for 7.3 conductivity <1 uS/cm)

Dose-equivalent 1-131 1.50E-05 uCi/cc 1.57E-05 uCi/cc Isotopic*

Soluble 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> decay 8.529E-03 8.825E-03 Insoluble 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> decay 7.248E-05 2.165E-04 Soluble 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> decay 1.687E-03 1.645E-03 Insoluble 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> decay 1.440E-05 7.326E-05 Boron 24 ppb 21 ppb Sulfate 0.8 ppb 0.7 ppb Silica 111.3 ppb 30 ppb Feedwater Metals (filterable-insoluble)

Iron 0.42 ppb 0.26 ppb Copper 0 ppb 0 ppb Nickel 0 ppb 0 ppb Cobalt 0.002 ppb 0 ppb Chromium 0 ppb 0 ppb Metals (soluble)

Iron 0.01 ppb 0.02 ppb Copper 0 ppb 0 ppb Nickel 0.04 ppb 0.04 ppb Zinc 0.326 ppb 0.309 ppb Cobalt 0.001 ppb 0 ppb Dissolved Oxygen 60.6 ppb 58.8 ppb

NLS2008097 Attachment Page 3 of 14 Parameter 100% CLTP TPO Conductivity

[0.056 uS/cm 0.056 uS/cm Elevated Release Point Stack Effluents Noble Gas (Augmented Offgas system in service)

Xe-135 3.69E-09 uCi/cc Not found Xe-135m 1.36E-08 uCi/cc 1.04E-08 uCi/cc Xe-138 5.88E-08 uCi/cc 2.41E-08 uCi/cc Noble Gas (Augmented Offgas system out of service)

Kr-85m 5.76E-07 uCi/cc' 5.72E-07 uCi/cc Kr-87 2.45E-06 uCi/cc 2.49E-06 uCi/cc Kr-88 1.93E-06 uCi/cc 1.87E-06 uCi/cc Xe-133 1.18E-07 uCi/cc 1.62E-07 uCi/cc Xe-135 1.77E-06 uCi/cc 2.37E-06 uCi/cc Xe-135m 8.07E-07 uCi/cc 1.24E-06 uCi/cc Xe-138 2.60E-06 uCi/cc 3.39E-06 uCi/cc Particulate/Iodine (Augmented Offgas system in service)

Co-60 6.60E-14 uCi/cc 7.94E-14 uCi/cc Sr-91 3.55E-12 uCi/cc 3.16E-12 uCi/cc Cs-137 2.76E-14 uCi/cc Not found Ba-139 2.03E-10 uCi/cc 1.03 E-10 uCi/cc 1-131 6.50E-13 uCi/cc 5.08E-13 uCi/cc 1-133 1.83 E-12 uCi/cc 1.02E-12 uCi/cc Particulate/Iodine (Augmented Offgas system not in service)

Rb-88 8.47E-09 uCi/cc Not found Te-132 1.09E-12 uCi/cc Not found Cs-138 1.71E-08 uCi/cc 2.32E-10 uCi/cc Ba-139 1.35E-09 uCi/cc 1.76E-10 uCi/cc 1-131 2.36E-12 uCi/cc 1.57E-1I uCi/cc 1-133 2.24E-11 uCi/cc 1.27E-11 uCi/cc 1-134 6.97E-1I uCi/cc Not found 1-135 7.44E-1I uCi/cc Not found Tritium 7.71E-08 uCi/cc 3.81E-08 uCi/cc Gross alpha 2.44E-05 uCi/cc

< Minimum Detectable Sr-89 3.38E-04 uCi/cc 6.98E-14 uCi/cc Sr-90 9.49E-06 uCi/cc

< Minimum Detectable

• Isotopic analysis is reported total gamma activity (all isotopes) in uCi/mL.

NLS2008097 Attachment Page 4 of 14 Test 1B - Steam Dryer/Separator Performance

Purpose:

Evaluate steam dryer/separator performance at TPO conditions by measuring main steam line moisture content.

==

Description:==

Steam dryer/separator performance (i.e., moisture carryover) is determined by utilizing a tracer test similar to that performed in the original startup test program or by other equivalent plant procedure. For this testing, main steam line moisture content is considered equivalent to the steam dryer/separator moisture carryover. Testing at 100%

TPO satisfies this testing recommendation.

Test Data Acquisition: Samples are drawn from the reactor vessel, main condenser hotwell, and other sample points designated by the tracer test or other equivalent plant procedures at selected power/flow operating points and analyzed for main steam line moisture content.

Test Conditions: Measure main steam line moisture content to evaluate steam dryer/separator performance at 100% CLTP and TPO power level.

Level 1 Acceptance Criteria: None.

Level 2 Acceptance Criteria: Main steam line moisture content shall not be in excess of the moisture content performance specification for long-term operations (<0.1 wt%).

Results: All acceptance criteria were met. CNS determines moisture carryover based on the Na-24 concentration in the reactor water and hotwell. The results are below:

100% CLTP TPO Moisture Carryover 0.002%

0.004%

Test Number 2 - Radiation Measurements

Purpose:

Monitor radiation at TPO conditions to assure that personnel exposures are maintained As Low As Reasonably Achievable, that radiation survey maps are accurate, and that radiation zones are properly posted.

==

Description:==

At TPO test conditions, gamma dose rate measurements and, where appropriate, neutron dose rate measurements will be made at specific limiting locations throughout the plant to assess the effect of the uprate on actual plant area dose rates.

USAR radiation zones will be monitored for any required changes.

Test Data Acquisition: Within the TPO power ascension test procedure or the governing test schedule, add steps, at TPO test conditions, to conduct radiation surveys of these areas that are expected to experience an increase in radiation dose rates. Some areas that are expected to experience radiation dose increases (e.g., drywell) will not be accessible.

NLS2008097 Attachment Page 5 of 14 Test Conditions: Measure radiation level at selected locations throughout the plant at 100% CLTP and TPO power level.

Level 1 Acceptance Criteria: The radiation doses of plant origin and the occupancy times of personnel in radiation zones shall be controlled in accordance with 10 CFR 20.

Level 2 Acceptance Criteria: None.

Results: All acceptance criteria were met. Surveys were taken at TPO power level and compared with those done at 100% CLTP. No radiation zones required reposting at the TPO power level. All zones continue to be controlled in accordance with 10 CFR 20.

Test Number 12 - Average Power Range Monitor (APRM) Calibration

Purpose:

Calibrate the APRM system to the TPO power level.

==

Description:==

Each APRM channel reading will be adjusted to be consistent with the core thermal power, referenced to the TPO power level, as determined from the heat balance.

Test Data Acquisition: Within the TPO ascension test procedure or on the power ascension test schedule, add a requirement to calibrate the APRMs to the TPO power level after receipt of a Safety Evaluation (SE) from the Nuclear Regulatory Commission (NRC) authorizing the MUR power increase. Calibrate the APRM trip and alarm setpoints, as necessary, for the MUR power uprate.

Test Conditions: Calibrate APRM system based on heat balance data consistent with Technical Specifications.

Level 1 Acceptance Criteria:

a)

The APRM channels must be calibrated consistent with Technical Specifications.

b)

Technical Specifications and Fuel Warranty limits on APRM scram and rod block setpoints shall not be exceeded.

Level 2 Acceptance Criteria: None.

Results: All acceptance criteria were met. The NRC SE was signed on June 30, 2008.

The APRM trip and alarm setpoints were calibrated on July 22 and 23, 2008. The APRM readings were adjusted to the TPO power level heat balance on July 24, 2008, consistent with the Technical Specifications.

NLS2008097 Attachment Page 6 of 14 Test Number 19 - Core Performance

Purpose:

1)

Evaluate the core thermal power and core flow.

2)

Evaluate whether core performance parameters are within limits to ensure a careful, monitored approach to the TPO power level.

==

Description:==

Routine measurements of reactor and system parameters are taken near 95%

and 100% of CLTP along the constant flow control line that will be used to increase to maximum TPO power. Core thermal power measurements will be performed utilizing the more accurate heat balance methods indicated in the NRC approved MUR submittal.

Core performance parameters are calculated using accepted methods to ensure current licensed and operational practice are maintained. Fuel thermal margin and other core performance parameters will be projected to the TPO power level from the 100% CLTP test conditions. Power increase above CLTP is along a constant rod pattern line in one increment to TPO power level. Measured reactor parameters and calculated core performance parameters at TPO power level are evaluated by comparison to limits specified in Technical Specifications and projected values.

Test Data Acquisition: Once steady-state conditions are established at each test condition, reactor measurements will be taken, and core thermal power and core performance parameters calculated. TPO power level values for fuel thermal margin and other core performance parameters will be projected from 100% CLTP test conditions.

At TPO power level, reactor parameters and core performance parameters will be evaluated against Technical Specification limits and projected values. Use of the more accurate heat balance methods described in the approved MUR submittal is required for TPO power uprate. Use existing core performance parameter calculation methods to maintain continuity with past and current accepted licensed and operational practice.

Test Conditions: Measure reactor and system parameters, calculate core thermal power and core performance parameters, and evaluate TPO power level values at 95% CLTP, 100% CLTP, and TPO power level.

Level 1 Acceptance Criteria:

a)

All core performance parameters shall be within the limits specified in Technical Specifications (or Core Operating Limit Report (COLR) as applicable); e.g.,

Average Planar Linear Heat Generation Rate (APLHGR), Linear Heat Generation Rate (LHGR), Maximum Average Planar Linear Heat Generation Rate (MAPLHGR), Maximum Linear Heat Generation Rate (MLHGR), and Minimum Critical Power Ratio (MCPR).

b)

Steady-state reactor power shall be limited to maximum values of the lesser of either TPO power level or the upper boundary rod line as indicated on the Power-Flow Map.

c)

Core flow shall not exceed its maximum value depicted on the Power-Flow Map.

NLS2008097 Attachment Page 7 of 14 Results: All acceptance criteria were met. Results for core performance parameters are shown in the table below. All power changes were done using a constant rod pattern rod line. CNS core performance parameter limits are in the COLR for MAPLHGR, MLHGR, and MCPR. The steady state reactor power was limited to the TPO power level as the rod line for the test was well below the upper boundary rod line as indicated on the Power-Flow Map. Core flow is limited to 105% as depicted on the Power-Flow Map and did not exceed this limit during testing.

Parameter 95% CLTP 100% CLTP TPO Power Level Maximum Average 0.653 0.670 0.680 Planar Ratio Maximum Fraction 0.815 0.836 0.848 of Limiting Power Density Maximum Fraction 0.829 0.828 0.826 of Limiting Critical Power Ratio Rod Line 103.81%

103.42%

104.02%

Core Flow 85%

92.65%

93.87%

Test Number 22 - Pressure Regulator

Purpose:

Confirm the adequacy of the pressure control settings for TPO operations by inducing transients in the reactor pressure control system using the pressure regulators.

==

Description:==

Turbine Pressure Controller Setpoint - Prior to commencing TPO baseline (at 95% CLTP test condition), the turbine pressure controller setpoint will be adjusted to achieve desired reactor pressure at TPO uprate conditions and then held constant throughout the TPO power ascension. This provides the most meaningful evaluation of turbine steam flow margin at TPO conditions.

Pressure Regulator Testing: In each test condition, testing of the pressure control system response to pressure setpoint step changes is accomplished by first making a down setpoint step change, followed by an up setpoint step change after conditions stabilize, in accordance with the following setpoint change sequence:

1)

-3 psi.

2)

+3 psi.

When testing is completed for one pressure regulator, the other pressure regulator is selected and the pressure setpoint step testing is repeated.

Test Data Acquisition: Analog variables that should be recorded for each pressure step test are:

1)

Narrow range vessel water level.

2)

Vessel dome pressure.

NLS2008097 Attachment Page 8 of 14

3)

Pressure regulator input pressure (controlling regulator).

4)

Pressure regulator output signal (controlling regulator).

5)

Reactor thermal power.

6)

Turbine first stage pressure.

7)

Turbine control valve position "A."

8)

Turbine control valve position "B."

9)

Turbine control valve position "C."

10)

Turbine control valve position "D."

Test Conditions: Pressure Setpoint Steps (each regulator in service) at 95% CLTP, 100%

CLTP, and TPO power level in manual recirculation mode.

Level 1 Acceptance Criteria: The decay ratio must be less than 1.0 for each process variable that exhibits oscillatory response to pressure regulator changes.

Level 2 Acceptance Criteria:

a)

The decay ratio of any oscillatory variable must be <0.25.

b)

Pressure control system deadband, decay, etc., shall be small enough that steady state limit cycle, if any, shall produce turbine steam flow variations no larger than

+/-0.5% of rated steam flow.

Results: All acceptance criteria were met. CNS has a Westinghouse turbine-generator system. The system uses a digital-electro hydraulic control system. The analog parameters taken were adjusted to those applicable to the CNS control system. The data taken is shown in the table below. This data, in combination with steam flow values shown in Attachment 1 to this Startup Test Report, demonstrates the decay ratio of the parameters meets both acceptance criteria specified above. The steam flow variations noted while steam flow was steady state was less than 0.001 Mlbm/hr. Rated steam flow is 9.76 Mlbm/hr. The variations noted are less than the 0.0488 Mlbmlhr.

Parameter 95% CLTP (-3 100% CLTP (-3 TPO (-3 psi/+3 psi) psi/+3 psi) psi/+3 psi)

Narrow Range Vessel Water Level A

36 in./36 in.

35 in./35 in.

36 in./36 in.

B 35 in./35 in.

36 in./35 in.

36 in./36 in.

C 35 in./36 in.

35 in./35 in.

36 in./36 in.

Vessel Dome Pressure A

1000 lbs./1000 lbs.

1000 lbs./1000 lbs.

1000 lbs./1000 lbs.

B 1000 lbs./1000 lbs.

1000 lbs./1000 lbs.

1000 lbs./1000 lbs.

C 1000 lbs./1000 lbs.

1000 lbs./1000 lbs.

1000 lbs./1000 lbs.

Turbine Throttle 951 lbs./953 lbs.

952 lbs./955 lbs.

952 lbs./956 lbs.

Pressure Turbine Display 923 lbs./926 lbs.

923 lbs./926 lbs.

923 lbs./926 lbs.

NLS2008097 Attachment Page 9 of 14 (Demand)

Turbine Impulse 647 lbs./648 lbs.

690 lbs./686 lbs.

702 lbs./698 lbs.

Pressure Governor Valve Position Valve #1 100%/100%

100%/100%

100%/100%

Valve #2 0%/0%

10%/8%

12%/12%

Valve #3 100%/100%

100%/100%

100%/100%

Valve #4 60%/58%

78%/76%

86%/86%

Test Number 23 - Feedwater System

Purpose:

Verify the feedwater control system has been adjusted to provide acceptable reactor water level control for TPO operating conditions.

==

Description:==

This testing may produce core power excursions due to the feedwater addition. The power levels of these operational transients may exceed the steady-state power level of the test condition. These excursions are expected in the TPO power ascension test program.

At each test condition, reactor water level setpoint changes are introduced into the feedwater control system in accordance with the following setpoint change sequence:

1)

+3 inches.

2)

-3 inches.

The normal feedwater control system mode is three-element control, with single-element control only being used for temporary backup situations. The feedwater control system in three-element control mode should be adjusted, not only for stable operational transient level control (i.e., decay ratio), but also for stable, steady-state level control (i.e.,

minimize water level limit cycles). In single-element control mode, the system adjustments must achieve the operational transient level control criteria, but for steady-state level control the temporary backup nature of this mode should be considered.

Test Data Acquisition: Analog variables that should be recorded for each feedwater control system test are:

1)

Narrow range vessel water level.

2)

Vessel dome pressure.

3)

APRM.

4)

Total feedwater flow.

5)

"A" Feedwater pump output.

6)

"B" Feedwater pump output.

7)

"A" Feedwater pump controller output.

8)

"B" Feedwater pump controller output.

NLS2008097 Attachment Page 10 of 14 Test Conditions: Level setpoint changes for both three-element and single-element control at 95% CLTP, 100% CLTP,,and TPO power level.

Level 1 Acceptance Criteria: The decay ratio must be less than 1.0 for each process variable that exhibits oscillatory response to feedwater system changes.

Level 2 Acceptance Criteria: The decay ratio of any oscillatory variable must be 50.25.

Results: The analog values recorded are in the tables below. This data, in combination with steam flow values shown in Attachment 1 to the Startup Test Report, demonstrates-the decay ratio of these values were less than both acceptance criteria specified above.

Three-Element Control Parameter 95% CLTP (+3 in/-

100% CLTP (+3 in/- TPO (+3 in/-3 in) 3 in) 3 in)

Narrow Range Reactor Level A

39 in/36 in 38 in/36 in 38 in/36 in B

39 in/36 in 38 in/36 in 38 in/36 in C

39 in/36 in 38 in/36 in 38 in/36 in Reactor Pressure A

1000 lbs./1000 lbs 1000 lbs/i 000 lbs 1000 lbs/1000 lbs B

1000 lbs./1000 lbs 1000 lbs/i 000 lbs 1000 lbs/1000 lbs C

1000 lbs./1000 lbs 1000 lbs/1000 lbs 1000 lbs/1000 lbs APRM A

95%/96%

99%/100%

100%/100%

B 94%/94%

97%/98%

98%/99%

C 93%/93%

98%/97%

98%/98%

D 95%/94%

99%/98%

100%/99%

E 95%/95%

99%/99%

99%/100%

F 92%/93%

98%/98%

99%99%

Reactor Feedwater 9.03 Mlbm/hr/9.03 9.55 Mlbm/hr/9.55 9.73 Mlbm/hr/9.64 Flow Mlbm/hr Mlbm/hr Mlbm/hr Feedwater Flow Loop A 4.6 Mlbm/hr/4.6 4.8 Mlbm/hr/4.8 5.0 Mlbm/hr/4.9 Mlbm/hr Mlbm/hr Mlbm/hr Loop B 4.6 Mlbm/hr/4.6 4.8 Mlbm/hr/4.8 5.0 Mlbm/hr/4.9 Mlbm/hr Mlbm/hr Mlbm/hr Feedwater Pump Speed Pump A 4417 rpm/4414 rpm 4557 rpm/4566 rpm 4616 rpm/4605 rpm Pump B 4407 rpm/4405 rpm 4523 rpm/4561 rpm 4598 rpm/4592 rpm

NLS2008097 Attachment Page 11 of 14 Single-Element Control Parameter 95% CLTP (+3 in/-

100% CLTP (+3 in/- TPO (+3 in/-3 in) 3 in) 3 in)

Reactor Level A

39 in/35 in 38 in/35 in 38 in/36 in B

39 in/36 in 38 in/35 in 40 in/36 in C

39 in/36 in 38 in/35 in 38 in/36 in Reactor Pressure A

1000 lbs./1000 lbs 1000 lbs/1000 lbs 1000 lbs/1000 lbs B

1000 lbs./1000 lbs 1000 lbs/1000 lbs 1000 lbs/1000 lbs C

1000 lbs./1000 lbs 1000 lbs/1000 lbs 1000 lbs/1000 lbs APRM A

93%/95%

99%/98%

100%/100%

B 93%/94%

98%/98%

100%/99%

C 92%/93%

97%/98%

99%/98%

D 95%/94%

99%/99%

98%/99%

E 96%/96%

99%/98%

98%/100%

F 93%/93%

98%/98%

99%/98%

Reactor Feedwater 9.03 Mlbm/hr/9.00 9.53 Mlbm/hr/9.58 9.72 Mlbm/hr/9.71 Flow Mlbm/hr Mlbm/hr Mlbm/hr Feedwater Flow Loop A 4.6 Mlbm/hr/4.6 4.8 Mlbm/hr/4.8 5.0 Mlbm/hr/5.0 Mlbm/hr Mlbm/hr Mlbm/hr Loop B 4.6 Mlbm/hr/4.6 4.8 Mlbmlhr/4.8 4.9 Mlbm/hr/4.9 Mlbm/hr Mlbm/hr Mlbm/hr Feedwater Pump Speed Pump A 4411 rpm/4422 rpm 4569 rpm/4561 rpm 4616 rpm/4603 rpm Pump B 4397 rpm/4401 rpm 4547 rpm/4545 rpm 4602 rpm/4577 rpm Test Number 101 - Plant Parameter Monitoring and Evaluation

Purpose:

The purpose of this test is to evaluate the power-dependant parameters of systems and equipment, affected by the TPO power uprate, remain within limits to ensure a careful, monitored approach to the TPO level.

==

Description:==

Routine measurements of the power-dependant parameters of systems and equipment (i.e., pressures, temperatures, flows, vibration) affected by the TPO, are taken at 95% and 100% of CLTP on the constant flow dontrol line that will be used to increase to maximum TPO power. Power-dependant parameters that are calculated will be calculated using accepted methods to ensure current licensed and operational practices are maintained. Measured and calculated power-dependant parameters are utilized to project those values at the next power level step prior to increasing to the next TPO test condition. Each test condition's actual values will be evaluated to confirm that they have

NLS2008097 Attachment Page 12 of 14 been satisfactorily predicted by the projected values before advancing to the next step and the final increase to TPO power.

Test Data Acquisition: Once steady-state conditions are established at each test condition, measurements will be taken and calculation performed to determine the changes to power-dependant parameters. All values will be evaluated against projected values and operational limits before increasing power the next step. Use existing parameter calculation methods to maintain continuity with past and current accepted licensed and operational practice.

Test Conditions: Measure reactor and system power-dependant parameters, evaluate data, and project next power step's values at 95% of CLTP, 100% of CLTP, and TPO power level.

Acceptance Criteria: All power-dependant parameters shall be within the limits specified in Technical Specifications (Technical Requirements Manual or COLR as applicable).

Results: All acceptance criteria were met. Data taken is shown in Attachment 2 to the Startup Test Report. The appropriate parameters were trended during the startup testing.

The last trend point at TPO is shown on Attachment 2 to the Startup Test Report. All parameters met Technical Specification, Technical Requirements Manual, or COLR limits where applicable.

Commitment Number NLS2007069 Main Steam Line Vibration Monitoring

Purpose:

Confirm that the small increase in main steam flow from the MUR power uprate does not trigger acoustic resonances in the system, which may result in a significant increase of the baseline vibration levels.

==

Description:==

During refueling outage (RE) 24, CNS installed vibration monitoring equipment on main steam piping in the heater bay area. This equipment will be used to obtain vibration levels on the piping to support Regulatory Guide 1.20 compliance.

It was determined that CNS does not have a history of vibration-induced damage in vessel internal components and that the industry does not have operating experience indicating problems with these components for MUR uprates. CNS does have operating history with resonant vibration issues on the main steam lines. Due to this operating history, CNS installed vibration monitoring equipment on the main steam lines during RE

24. Vibration readings were taken at 2381 Megawatts thermal (MWt) CLTP and 2419 MWt Operating Limit Thermal Power and evaluated by CNS engineers and an outside vendor with expertise in this area.

Test Data Acquisition: Thirty-one channels for measurement were set up. Data was taken at 100% CLTP to establish a baseline for data taken at TPO power level.

NLS2008097 Attachment Page 13 of 14 Test Conditions:

1)

Record a set of 100% CLTP baseline vibration levels the week before implementation. These measurements will consist of 10 steady-state measurements of at least five minutes in length. Each measurement will be averaged over a 200-second time interval.

2)

The range of natural variation in the measured vibration level will be determined based on the 100% CLTP baseline measurements.

3)

Verify at TPO power level that the vibration levels generally fall within the upper range of the baseline data. If vibration of any channel exceeds the upper range of the baseline by more than 10% on a consistent basis, then the power uprate should be suspended in order to determine the cause of the vibration excursion.

4)

Monitoring applies to all operable vibration channels.

5)

If vibration levels of all channels are below 110% of the baseline, power uprate may proceed without further vibration monitoring action.

Acceptance Criteria: All operable vibration channels have vibration levels below 110%

of the baseline vibration levels at the TPO power level.

Results: All acceptance criteria were met. The baseline and TPO vibration levels are in the table below. All operable channels levels at the TPO vibration levels were lower than the 110% maximum 100% CLTP vibration levels.

100% CLTP TPO Channel Average Maximum 110%

110%

Data Data Data Average Maximum Set 1 Set 2 Set 3 1

0.21 0.22 0.23 0.24 0.20 0.21 0.22 2

0.31 0.33 0.34 0.36 0.31 0.32 0.31 3

0.50 0.54 0.55 0.59 0.51 0.53 0.50 4

0.80 0.86 0.88 0.94 0.76 0.86 0.74 5

Channel Inoperable 6

Channel Inoperable 7

Channel Inoperable 8

0.15 0.16 0.17 0.18 0.16 0.16 0.16 9

0.38 0.42 0.42 0.46 0.40 0.40 0.37 10 Channel Inoperable 11 0.46 0.50 0.51 0.55 0.46 0.51 0.46 12 0.41 0.44 0.45 0.48 0.38 0.43 0.38 13 0.26 0.27 0.29 0.30 0.26 0.26 0.26 14 0.52 0.55 0.57 0.60 0.50 0.53 0.51 15 0.66 0.70 0.73 0.77 0.67 0.61 0.72 16 0.58 0.92 0.64 1.01 0.67 0.87 0.71 17 0.18 0.20 0.20 0.22 0.19 0.19 0.19 18 0.59 0.65 0.65 0.72 0.62 0.58 0.66 19 Channel Inoperable

NLS2008097 Attachment Page 14 of 14 100% CLTP TPO Channel Average Maximum 110%

110%

Data Data Data Average Maximum Set 1 Set 2 Set 3 20 0.34 0.36 0.37 0.40 0.33 0.36 0.35 21 0.48 0.51 0.53 0.56 0.48 0.48 0.47 22 0.33 0.36 0.36 0.39 0.33 0.33 0.36 23 0.10 0.10 0.11 0.12 0.10 0.10 0.10 24 0.56 0.65 0.62 0.72 0.51 0.55 0.53 25 0.99 1.05 1.09 1.15 0.92 0.97 0.95 26 0.59 0.64 0.65 0.70 0.58 0.61 0.59 27 0.41 0.45 0.45 0.50 0.40 0.40 0.39 28 0.41 0.43 0.45 0.47 0.38 0.43 0.40 29 0.48 0.82 0.53 0.90 0.28 0.28 0.28 30 0.14 0.16 0.16 0.18 0.13 0.13 0.13 31 0.31 0.34 0.34 0.37 0.29 0.31 0.30

NLS2008097 2 Pages Total to Cooper Nuclear Station Startup Test Report Steam Flow Measurement Uncertainty Recapture Power Uprate Cooper Nuclear Station, Docket No. 50-298, DPR-46

0 00 Attachment I 10 9.8 9.6 9.4 E 9.2 9

E 8.8 8.6 8.4 8.2 8

W 0 M V

r-0

• 0

)

0) 00 Co

ý6 e

(N NN N

N M

oo9 9 9 9 9 9 9° N

(N1)

)0 M

I I

In 7

r-2

-o

-o 9

9 9

9 9

9 V

0 a M0 0

(N 0 M-q r-0 M

M 0

LO M

0

(ý N 7~ lp In 0

p (N

ý

"~

at U) 0i (N

C')

kn In0~

(

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0 0

0D 0

0 0

0D 0

0 0D 0

0 0

0 0

0 0

0 0

40 0 0

00 M =3 :3D to U) to U) eO to Ui )

O U) V) W) V) LO Ul) Uo LA Uo 6 L6 L6 6 N

NI (N

(N (N

(N CV (N

(N 0N (N

(N N

(N (N

(N (N

(N (N

N(

DaterTime

NLS2008097 13 Pages Total to Cooper Nuclear Station Startup Test Report Nuclear Steam Supply System (NSSS) Parameter Testing Measurement Uncertainty Recapture Power Uprate Cooper Nuclear Station, Docket No. 50-298, DPR-46 NSSS Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MWth 2381 MWth 2419 MWtt Start Time 7124108 23:25 7/25108 1:08 7/25/08 3:21

_ Finish Time 7/24108 23:30 7/25/08 1:13!

7/25/08 3:21 NSS620 CORE THERMAL POWER

• MWT 2261.05 2378.67 24116.41 NSS640 I5MIN CORE THERMAL POWER MWT 2243.12 2374.98 2415.0' NSS637

'PERCENT LOADLINE

_103.97 103.37, 103.9:

BOO0 APRM A FLUX LEVEL

% PWR 94.40 99.42 100.9, BOO1 APRM.B FLUX LEVEL

.% PWR 93.18:

98.13 99.6 B002 APRM C FLUX LEVEL

% PWR 92.20 96.94 98.5, 8003 APRM D FLUX LEVEL

'%PWR 94.18, 99.14 100.7I B004 APRM E FLUX LEVEL

%,PVR 94.71, 99.61 101.11 BOO5

.APRM FFLUX LEVEL T% PVVR 92.55 97.47 99.11 B012 REACTOR TOTAL CORE FLOW M.LBH 62.43 6.8.02 69.3 B013 REACTOR CORE PRESS DIFF iPSIo 15.20 18.11 18.89 B014 CRD SYSTEM FLOW MLBH 0.02 0.02 0.0:

8015 REACTOR FW LOOP A FLOW MLBH 4.55 4.82 4.91 B016 REACTOR FW LOOP B FLOW 1MLBHi 4.49 4.74 4.8&

017 CLEAN-*UP SYSTEM A FLOW MLBH 0.05 0.05 0u_

B01.8 CLEAN-UP SYSTEM B FLOW MLBH 0.05 0.05 00 B019 RECtRC PUMP MTR A POWER MW 2.11 2.71.

2.85 B020.RECIRC PUMP MTR B POWER MW 2.09 2.79 2.92 B021 REACTOR WATER LEVEL A INCH 35.11 34.75 35.A 8022 TOTAL STEAM FLO MLBH 8.85 9.39 9.51

-~(D 00 B023 CLEANUP SYSTEM INUT TEMP DEGF 512.09 513.89 B024 CLEANUP SYSTEM OULT TEMP DEGF 431.56 433.20,

8025 REACTOR PRESSURE PSI 983.88 988.20 ;

B026 RECORC LOOP Al DRV FLOW MLBH 14.82 16.11 8027 RECIRC LOOP A2 DRV FLOW MLBH 14.87 16.15 B028 RECIRC LOOP BI DRV FLOW MLBH 14.77 16.26 8029 RECLRC LOOP B2 DRV FLOW MLBH 14.81 16.28_

B030 REACTOR FW CHNL B1 TEMP DEGF 359.83 363.65,

8031 REACTOR FW CHFNL Al TEMP DEGF 359.79.

363.62.

8,032 REACTOR FW CHINL B2 TEMP DEGF 359.63 363.47 IB033 REACTOR FW CHNL A2 TEMP DEGF 359.91 363.81 B034 TRECURC LOOP Al LNLT TEMP DEGF 521.151 523.00 i

IB035 RECIRC LOOP A2 INLT TEMP DEGF 521.25 523.11,1 1B036 RECMRC LOOP B1 INLT TEMP

DEGF 521.391 523.20 Page 1 of 12 NSSS Parameter Monitoring

• PMIS DESCRIPTION UNITS 2262 MWth 2381 MVfth 2419 Start Time 7/24108 23:25 7/25/08 1:08 7121.

Finish Time 7/24/08 23:30 7/25/08 1:13j 7/21, NSS620 CORE THERMAL POWER

_MWT 2261.05 2378.67' C~00 B037 RECIRC LOOP B2 tNLT TEMP DEGF 521.59 523.38j 1-1*

B038 CLEANUP SYSTEM A FLOW GPM 100.77 100.84 B039 CLEANUP SYSTEM.B FLOW GPM

%99.39 100.10 100.(

iLEFM,104 ILEFM-A TEMPERATURE DEGF 359.56 363.50, 364.,

LEFM204 iLEFM-B TEMPERATURE DEGF 359.54 363.47 364.1 iEFM102 LEFM-A MASS FLOW MLBH 4.44 4.711 4.1 LEFM202 jLEFM-B MASS FLOW LMLBH 4.50:

4.75 4.1 Page 2 of 12 CONTAINMENT Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MWth 2381 MWth 2419 MWth Start Time 7/24/08 23:25 7/25/08 1:08 7/25/08 3:2' Finish Time 7/24/08 23:30 7/25/08 1:13 7/25/08 3:2 NSS620 CORE THERMAL POWER MWT 2261.05 2378.67 2416.4 NSS640 15 MIN CORE THERMAL POWER MWT 2243.12 2374.98 2415.0 F084 DRYWELL PRESSURE PT512A PSIG 0.59 0.59 0.6' F085 DRYWELL PRESSURE PT512B PSIG 0.44 0.44 0.4 N343 TORUS WIDE RANGE PRESSURE PSIG 0.38 0.37 0.3 N344 TORUS WIDE RANGE PRESSURE PSIG 0.19 0.19 0.2 N357 DRYWELL ZONE 2C TEMP PC-TE DEG F 169.48 170.12 171.5 N358 DRYWELL ZONE 2C TEMP PC-TE DEG F 149.78 149.68 150.1 N359 DRYWELL ZONE 2C TEMP PC-TE DEG F 160.34 160.22 160.1 N360 DRYWELL ZONE 2C TEMP PC-TE DEG F 162.78 162.74 162.4 N361 DRYWELL ZONE 2C TEMP PC-TE DEG F 170.13 169.81 170.3 N401 DW FAN INLET TEMP PC-TE-50 DEG F 147.34 148.00 148.5 N402 DW FAN INLET TEMP PC-TE-50 DEG F 126.97 127.85 128.7' N403 DW FAN OUTLET TEMP PC-TE-5 DEG F 100.27 100.28 100.2 N404 DW FAN OUTLET TEMP PC-TE-5 DEG F 97.74 97.69 97.5 N405 DW FAN OU.TLET TEMP PC-TE-5 DEG F 98.38 67.84 62.1 N406 DW ZONE 1 TEMP A PC-TE-502 DEG F 132.24 133.68 135.8 N407 DWZONE 1 TEMP B PC-TE-502 DEG F 134.98 136.19 138.7 N271 RECIRC PUMP AREA DRYWELL T DEGF 131.37 132.45 134.2 N272 RECIRC PUMP. AREA DRYWELL T DEGF 136.80 137.96 140.6 N273 DRYWELL ZONE 2A INLET AIR DEGF 184.94 185:21 185.21 N274 DRYWELL ZONE 2A INLET AIR DEGF 195.97 196.15 195.7, N275 DRYWELL ZONE 2A INLET AIR DEGF 156.10 156.06 156.3 N276 DRYWELL ZONE 2B TEMPERATUR DEGF 145.79 145.79 145.0 N277 DRYWELL ZONE 2B TEMPERATUR DEGF 144.44 144.47 144.7 N278 DRYWELL RETURN RING HDR TE DEGF 187.67 187.78 188.1 N279 DRYWELL RETURN RING HDR TE DEGF 188.30 188.59 188.1' N280 DRYWELL RETURN RING HDR TE DEGF 190.50 190.67 190.9 N281 REACTOR HEAD FLANGE AREAT DEGF 161.84 162.16 162.5 N282 REACTOR HEAD FLANGE AREA T DEGF 161.50 161.42 161.5 N283 REACTOR HEAD FLANGE AREA TDEGF 162.83 162.85 162.8 N284 DRYWELL FAN FC-R-IC INLET DEGF 135.39 135.73 136.2 N285 DRYWELL FAN FC-R-1D INLET DEGF 137.66 138.48 139.8 N286 DRYWELL ZONE 2C HOR TEMP DEGF 180.53 179.97 180.1 CD 00 Page 3 of 12 CONTAINMENT Parameter Monitoring N287 DRYWELL ZONE 3 AREA TEMP DEGF 11,0.67 110.73 110.89["

.*110.775 N288 DRYWELL ZONE 3 AREA TEMP 1DEGF 111.39 111.40 111.641 1*,

.4!

N289 lDRYWELL ZONE 3 AREA TEMP DEGF 111.69 111.67 111.87 ]

11.67

->o CD*

o

)

0-t CD 0

• IF A A.

Page 4 of 12 SECONDARY PLANT Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MWth 2381 MWth 2419 MWth Start Time 7/24/08 23:25 7/25/08 1:08 7/25/08 3:20

_ Finish Time 7/24108 23:30 7125/08 1:13 7/25108 3:25 NSS620 CORE THERMAL POWER MWT 2261.05 2378.67 2416.48 NSS640 15 MIN CORE THERMAL POWER MWT 2243.12 2374.98 2415.07 FOOO MAIN CONDENSATE FLOW GPM 18239.22 1,9471.57 19844.95 F002 REACTOR FD PUMP IA DISCH PSIG 1052.91-1063.19 1065.50 F003 REACTOR FD PUMIP 1B DISCH PSIG 1066.30 1077.04 108.0.53 F004 REACTOR FD PUMP 1A SUCT PSIG 448.43 426.69 420.64

-F006 REACTOR FD PUMP liB SUCT PSIG 48.83 428.39 420.85 F007 iCOND BSTR PUMP DISCH HDR PSIG 506.93, 491.65 486.74 F008

-COND PUMP DISCH HiDR PSIG 127.51 124.35 123.54 F009 GLND STMCOND DIFF PRESS PSID 7.15 7.17 7.ft F010 CONDENSR HOTWEL 1A LEVEL FT 6.82 6.81 6.80" Fol1 CQHDENSR HOTWEL 1.8 LEVEL FT 6.91 6.89 6.80 F012 RFP TURB 1A LP STU iNLET PSIG 142.15 150.69 153.58 F013 RFP TURB IB LP STM INLET PSIG 142.50 151.16 154.00 F020 FW HTR 1-Al SH.ELL PRESS PSIA 5.21 5.53 5.64, F021 FW HTR 1-A2 SHELL PRESS iPSIA 9.96.

10.46 10.96 F022 FW HTR 1-A3 SHELL PRESS PSIA 30.57 32.06 32.60 F023 FW:HTR 1-A4 SHELL PRESS IPSIA 66.77 70.33 72.18 F024 FWIHTR 1-A5 SHELL PRESS PSIA 152.21 160.81 163.55 1F025 FWHTR 1-81 SHELL PRESS PSIA 5.05 5.36 5.46 F026

.W HTR 1-B2 SHELL PRESS iPSIA 9.36, 9.70 10.06

,F027 FWrHTR 1-B3 SHELL PRESS PSIA 28.621 30.08 30.28 F028 FW HTR 1-64 SHELL PRESS IPSIA 69.72 73.17 74.42

,F029,

WHTR I-B5 SHELL PRESS PSIA 152.08, 160.32 163.06 F034 REACTOR FEED PUMPS DISCH DEGF 367.96 371.75 373.03, F035 REACTOR FEED PUMPS SUCTN LDEGF 365.49 369.28 370.52 F036 CONDPUMP DISCH HDR DEGF 116.43 1,17.97 118.40 F037 COND BOOST PMP DISCH HDR DEGF 119.33 121.07 121.48 iF038 GLND STM CONDSR COND OUT DEGF 120.12 121.5S 121.99 F039 GLND STM CONDSR COND IN DEGF 118.10 119.50, 119.91 iF043

• HTR #1-Al FDWR OUTLET DEGF 163.25 165.36 1,66.02 F044 HTR #1-A2 FDVVTR OUTLET DEGF 190.51r 192.42 193.04 F045 HTR #1-A3 FDWTR OUTLET DEGF 249.09 251.46 252.12 F046 HTR #1-A4 FDWTR OUTLET IDEGF 304.74 307.82 308.69 0.,

L'Q z

Ci~)

00 Page 5 of 12 SECONDARY PLANT Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MWth 2381 MWth 2419 MWth Start Time 7/24108 23:25 7125108 1:08ý 7/25/08 3:20,

_ CFinish Time 7/24/08 23:30 7/25/08 1:13 7/2508 3:25 NSS620 CORE THERMAL POWER MWT 2261.05, 2378.67 2416.4a NSS64O 15 MN CORE THERMAL POWER JMA 2243.12 2374.98 2415.07

,F047

'HTR #1-A5 FDWTR OUTLET jDEGF 367.341 371.15i 372.41.

F048 IHTR #1-B1 FDWTR OUTLET DEGF 160.81 1,62.94 163.65 F049 IITR #1-B2 FDWTR :OUTLET

'DEGF 190.65 192.75 193.53 F050 HTR #1-83 FDWTR OUTLET DEGF 248.01 250.03 2,50.79 iF051

ý,HTR #1-B4 FDWTR OUTLET DEGW 303,05, 305.11, 306.02 F052 WTR #1-85 FDWTR OUTLET IDEGF 364.75 368.42 369.62 F053 FW HTR 1-Al DRAIN TEMP DEGF 123.33 125.14 125.68 P054 FW HTR 1-A2 DRAIN.TEMP iDEGF 169.201 171.30 171.97 iF055 fW HTR I-A3 DRAIN TEMP DEGF 201.66 204.05, 204.74 Pf056 FW HTR 1-A4 DRAIN TEMP DEGF 256.34 259.01, 260.12 PF057 FW HTR 1-A5 DRAIN TEMP IDEGF 310.23 313.44, 314.51 F058 FWHTR 1-B1 DRAIN TEMP DEGF 124.00 125.8I 126.29 F059 FW HTR 1-B2 DRAWN TEMP DEGF 164.13 166.29 166.98 F060 FW HTR 1-B3 DRAIN TEMP DEGF 201.66 203.69 204.59 F061 FW HTR 1-B4 DRAIN TEMP DEGF 254.71' 256.75 257.48 F062 FW HTR 1-B5.DRAIN TEMP IDEGF 311,70 314.47 315.38 F063 RFP 1A TURB STEAM INLET iDEGF 360.25 364.50 365.89 7F064!

REP 1 B TURB STEAM INLET

!DEGF 360.47 364.71 366.08 F065 MOIST SEP # 1-A DRAIN DEGF 360.31 364.82 366.19 fF066 MOIST SEP # 1-C DRAIN

ýDEGF 359.10 363.04 364.31.

F067 OIST SEP # 1-B DRAIN DEGF 360.61.

364.63 366.04 JF068 MOIST SEP # 1-D DRAIN DEGF 363.57 367.47 368.75 C

0 0

0z Page 6 of 12 GEN & EXCITER Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MWth 2381 MWth 2419 MWth sT

_ Start Time 7/24/08 23:25 7/25108 1:08 7/25/08 3:20,E t0

Finish Time 7/24/08 23

30 7/24/08 23:30 7/25/08 3:25..-

NSS620 CORE THERMAL POWER MWT 2261.05 2378.67 241648 4B

• ,*-,i.0Q NSS640 15 MIN CORE THERMAL POWER MWT 2243.12 2374.98 2415.07 **2 C009 REACTOR THERMAL POWER MWT 2242.74 2387.24 2438.76

• E002 MAIN GEN GROSS WATT'S MW 750.71 792.56 804.97 : ý G007 MAIN TG STATOR COIL #14 DEGF 146.47 151.42 152.86

• t5' G008 __MAIN TG STATOR COIL #7 DEGF 148.05 153.32, 155.02 I*1*_

W009 MAIN TG STATOR COIL #42 DEGF 150.63 155.96 157.65 1,5 1 G010 _

MAlIN TG STATOR COIL #10 DEGF 147.31:

152.36 153.90 14 G0011 MAIN TG STAT OR COIL #3 DEGF 149.25 154.53 156.12....

G012 MINTG STATOR COIL #38 DEGF 152.81 158.34 160.15 G013 H2 COOLER 1A HOT GAS DEGF 133.44:

134.43 134.82 i

0G014 H2 COOLER 1B HOT GAS DEGF 130.41 131.30i 131.

-n 0015 H2 COOLER 1iC HOT GAS DEGF 131.77 132.79 133.16 13'31 IG016

H2 COOLER 1iD.HOT GAS.

DE 129.1,9; 130.08 130 39 G017 H2 COOLER IA COLD GAS DEGF 101.07 100.23 9993 r

E 3

G018

ýH2 COOLER lB COLD GAS

_DEGF 101.36, 100.59 100.29 K

G0,19 H2 COOLER 11C COLD GAS DEGF 98.66 98.05 97.ý65 Y 0G020 H2 COOLER I!D COLD GAS

_DEGF 98.53 97.74 97.45, 13025 EXCItER HOT AIR TEMP

_DEGF 128.42.

128.88 129.23

'0026 EXCITER HOT AIR TEMP 122.66 122.52 12 G027 EXCITETR COLD AIR TEMP

_DEGF 110.16 1110.69 a

G028 EXCITER COLD AIR TEMP

___DEGF 1100.80 101.09 10 1'.29i

-t (D

00 zQC tQ Page 7 of 12 BOP Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MWth 2381 MWth 2419 MWth

Start Time 7/24108 23:25 7/25/08 1:08 7W25/08 3:20 Finish Time 7/24108 23:30 7W25/08 1:13 7/25/08 3:25 NSS620 CORE THERMAL POWER MWT 2261.05 2378.67 2416.48 iNSS640 15 MIN.CORE THERMAL POWER MWT 2243.12, 2374.98 2415.07 C009 REACTOR THERMAL POWER MWT 2242.74 2387.24 2438.76 1E002 MAIN GEN GROSS WATTS MW 750.71 792.56 804.97 COOO lGENERATOR REACTIVE POWER MVAR 45.14

77.

78.52 C001 GENERATOR POWER FACTOR PCNT 99.81 99.85 99.52 C002

.MINI-HYDROGEN PRESSURE 1PSIA 30.00 30.00 30.001 iC003 TOTAL FEEDWATER FLOW MLBH 8.87 9.51.

9.74 C004 TOTAL MAN STEAM FLOW MLBH 8.891 9.53 9176 iC006 MAIN STEAM ENTHALPY B/LB 1191.98 1191.75 1191.68, C007 MAIN STEAM MOIST CONTENT FRAC 0.00 0.00 0.00; C008 iFEEDWATER ENTHALPY AVG B/LB 332.01 337.13 339.13 3CO09 iREACTOR THERMAL POWER MWT 2242.74 2387.24 2438.76 C010 HYDROGEN PRESSURE DIFF PSID 20.92 20.93 20.93 C011 REJECTED FLOW MLBH 0.04.

0.01i 0.02 C012 TOTAL CLEAN-UP FLOW MLBH 0.101 0.10 0.10 C013 DEM:N MAKE-UP FLOW MLBH 0.00i 0.00 0.00.1 C014 CLEANUP ENTHALPY INLET B/LB 500.95,

.. 503.97 504.841 C015 CLEANrUP ENTHALPY OUTLET

BILB 408.94 411.36 412.04.

C016 CLEANUP HEAT EXCHANGE MB/H 9.58&

9.68 9.71 0017 NSSS HEAT ADDED

MBIH 7650.45 8148.26 8325.33 C018 NSSS HEAT LOSSES MB/H 15.67 15.83 15.97-C019 HOTWELL MAKE-UP FLOW

'MLBH 0.02

-0.02 0.00 C020 RECIRC PUMP HEAT ADDED MB/H 12.22' 17.02 18.42 C021

NSSS EFFICIENCY iPCNT 99.80 99.81 99.81 C022 1NET STATION HEATRATE

!B/KW 10692.54, 10665.84 10694.27 C023 GROSS TURBINE HEAT RATE B/KW 10422.28, 10404.09 10434.6 C024

'HEAT RETURNED TO REACTOR 1MB/H 2946.08 3206.54 3303.78, C025

• CORR TURB THROTTLE FLOW

MLBH 8.68 9.24 9.45 C026 PCNT CHAUGE IN HEAT RATE PCNT

-0.72

-1.40

-0.94 C027

!CORR TURB GROSS HEAT RATE B/KW 10497.23 10549.52 10532.29 C028 TOTAL HEAT ADDED BY PUMP PMW 19.58 20.17 20.40 0029 CALC RFW TURBINE FLOW IA MLBH 0.05 0.05 0.06 C03 iCALC RFW TURBINE FLOW lB MLBH 0.051 0.06 0.06 00 O0 CD z

r j3 Cn t00 CD OD 00 Page 8 of 12 BOP Parameter Monitoring Start Time 7/24/08 23:25 7/25/08 1:08 7/25/08 3:20 Finish Time 7/24/08 23:30 7/25/08 1:13 7/25/08 3:25 NSS620 CORE THERMAL POWER MWT 2261.05 2378.67 2416.48 NSS640 15 MIN CORE THERMAL POWER MWT 2243.12 2374.98 241.5.07 C031 HEAT REJECTED TO CONDNSR MB/H 5125.86 5430.90 5582.70 C032 AVE CW TEMP OUT COND 1A iDEGF 99.34 100.41 100.75 C033 AVE CW TEMP OUT COND 1B DEGF 99.54 100.62:

100.97 C034 CW TEMP RISE COND IA iDEGF 15.31 116.42 16.91 C035 CW TEMP RISE COND 1B LDEGF 9.21 10.35 10.82 C036 AVE CONDNSR CW TEMP RISE DEGF 12.26 13.39 13.87 C037 AVE CONDNSR CW IN TEMP iDEGF 87.18 87.13 86.99 C038 SAT TEMP AT COND PRES 1A DEGF 113.01 114.60 115.13 C039 SAT TEMP AT COND PRES 1B DEGF 114.63 116.04 116.586 C040 CW INITIAL TEMP DIFF-WATER iDEGF 28.97 30.62 31.29 C0041 CW INITIAL TEMP DWFF-WATER DEGF 24.30 25.77 26.44' C042 AVE COND CW INITIAL TEMP D 1DEGF 26.63 28.19 28.88 C043 TERMINAL TEMP DP-WATERBOX DEGF 13.67 14.20 14.38, C045 TERMINAL TEMP DP-WATERBOX DEGF 15.08 115.42 15.62 C0046 AVE CONDSR TERMINAL TEMP D DEGF 14.37 14.81 15.00 C047

!CONDENSER LOG MEAN TEMP DI DEGF 19.88 20.79

21. 18, C047 CONDNSR HEAT TRAN COEF BHF2 554.27 564.55 566.57 C0048 IHEI HEAT TRAN COEF BHF2 704.93 700.74 691.40i C049

ýCONDNSR TUBE METL CONST FRAC 1.06 1-06 1.06 CO50 CW SPECIFIC VOLUME FT/#

0.02 0.02 0.02 C051 CONDNSR TUBE VELOCITY FT/S 10.118 1"0.06 9;80.

0052 LHEATER 1A TERM TEMP DIFF DEGF 0.90 1.25 13 C053 HEATER 2A TERM TEMP D0FF DEGF 3.07 3.06 4.32 C054 HEATER 3A TERM TEMP D0FF DEGF 2.05 2.61 2.75 C055 HEATER 4A TERM TEMP D0FF DEGF

-4.37

-4.32

-4.31 0056 HEATER 5A TERM TEMP DtFF iDEGF

-7.60

-7.09,

-6.96 C057

HEATER 1 B TERM TEMP D0FF LDEGF 1.83 2.34 2.39 C058

'HEATER 2B TERM TEMP DIFF DEGF 0.03

-0.81

-0.26 0059 HEATER 3B TERM TEMP DIFF

DEGF

-0.95 0.24

-0.06 0060 HEATER 4B TERM TEMP DIFF DEGF

-0.86 0.47 1.04 C061 HEATER 5B TERM TEMP DIFF DEGF

-5.03

-4.54

-4.39 1062 COND CLEAN FACTOR UNIT 0.79 0.81 0.82 C063 RFW HTR IA DRN CLR APPROAC DEGF 4.14 4.07 4.20, ci z

00 00 Page 9 of 12 BOP Parameter Monitoring Start Time 7/24108 23:25 7/25108 1:08 7/25108 3:20 Finish Time 7/24108 23:30 7/25/08 1:13 7/25/08 3:25 NSS620 CORE THERMAL POWER MVWT 2261.05 2378.67 2416.48 NSS640 15 MIN CORE THERMAL POWER MWT 2243.12 2374.98 2415.07 C064 iRFW HTR 2A ORN CLR APPROAC DEGF 5.93' 5.90 5.92, C065 IRFW:HTR 3A DRN CLR APPROAC DEGF 10.98 11.53 11.73; C066

!RFWVH.TR 4A DRN CLR APPROAC DEGF 6.80 7.42 7.90 C067 iRFW HTR 5A DRN CLR APPROAC IDEGF 5.26:

5.55 5.75

.C068 RFW HTR l.B DRN CLR APPROAC

'DEGF 4.21.

4.74 4.79.

C069 RFWlHTR 2B DRN CLR APPROAC iDEGF 3.31 3.31 3.35Q C070 RFW HTR 3B DRN CLR APPROAC

'DEGF 11.03 11.00 11.00, C071 IRFW HTR 4B DRN CLR APPROAC DEGF 6.55 6.73 6.70 0C072 RFWHTR 5B DRN CLR APPROAC DEGF 8.32 9.18 9.4*

0073

!MOIST,SEP A DIFF PRESS PSID

-8.53

-9.07

-9.08 C074 MOIST SEP B DIFF PRESS

'PSID

-11.27

-11.74

-11.74 C075 MOIST SEP C DIFF PRESS PSID

-9.77

-9.18

-8.85 C076 MOIST SEP D DIFF PRESS PSiD

-2.32

-2.17

-2.01 0081

'GEN AVE COLD GAS TEMP DEGF 99.27 98.76 98.52 C082 GEN AVE HOT GAS TEMP DEGF 133.57 134.67 135.11, C083 AVE APRM READING.

% PWR 93.87 98.27 100.96 C084 RECIRC LOOP INLET AVE DEGF 521.35 523.18 523.50 C085 AVE RFP TURB STM IN TEMP IDEGF 360.44 364.58 365.99 0086 REACTOR FW ENTHALPY B B&LB 332.10 337.23

'-m,.:_339.23, 0

-087 RFW LOOP A TEMP JDEGF 358.05 362.93 364.86; C088 3lRFW LOOP B TEMP DEGF 358.21 363.13 365.05 C1090 TOTAL REACTOR RECIRC FLOW M.BH 28.85 32.13 32.97 C091 HEAT SUPP BY COND PUMPS MB/H 5.49 5.57 5.61' 0092 4HEAT SUPP BY C.B. PUMPS MB/H 14.09' 14.59 14.80, 0093 PC REC OUTLET ENTHALPY JBILB 59.15 59.13 59.00 C094 PC REC INLET ENTHALPY iBILB 52.97 52.88 52.66, C097 DRYVELL TORUS DELTA PRESS PSI 0.00 0.00 0.00 C098 IFEEDWATER FLOW WAV(1)

MLBH 4.55 4.82 4.91 C099 FEEDWTER FLOW WAV(2)

!MLBH 4.49 4.75 4.83 C100 IEGBERATOR STATOR MAX O1FF DEGF 9.07 10.09 10.60 01,01 CONDENSER IA ABSOLUTE PRES INHG 2.72 2.84 2.85 01,02 ICONDENSER TB ABSOLUTE PRES I.NHG 2.79 2.91:

2.92 C250.

MAIN GENERATOR POWER iMMW 735.93 785.15 799.81:1 a

0 k)

C z

00 C/)

Page 10 of 12 BOP Parameter Monitoring Start Time 7/24108 23:25 7/25/08 1:08 7125/08 3:20 Finish Time 7/24/08 23:301 7/25/08 1:13, 7/25/08 3:25 NSS620 CORE THERMAL POWER MWI" 2261.05 2378.67 241,6.48 NSS640 15 MWN CORE THERMAL POWER 2243.12 2374.98, 2415.07 C251 AUXILIARY STATION MW 18.33 19.09 19.29 C253 STATION SERVICE PWR REOR MW 20.11 21.27 21.58 C254 STATION NET POWERW 715.82 763.88 778.26 C255 GENERATOR APPARENT POWER MW 737.31 786.32 803.66 C256 GENERATOR DYNAMIC LOSSES MW 4.78 5.21 5.46 C257 TOTAL GENERATOR LOSSES MW 7.97 8.40 8.65 C258 TOTAL RECIRC PUMP POWER MW 3.85 5.36 5.801 E003 iMAIN GEN GROSS WATTS

[MW 750.71 792.56 804.971 z

Cl) 00 Page 11 of 12 TURBINE VIBRATION Parameter Monitoring PMIS DESCRIPTION UNITS 2262 MVih 2381 MWth 2419 M Start Time 7/24/08 23:25 7/25/08 1:08 7/25101 Finish Time 7/24/08 23:30 7/25/08 1:13 7/25/01 NSS620 CORE THERMAL POWER MWT 2261.05 2378.67 24 TOOO MAIN TG CASING EXP (GOV)

INCH 0.40 0.40_

T"001 MAItN TG D0FF EXP NO.2 INCH 0.15 0.15i T002 MAIN TG RTR EXCENTRICITY MILS 0.01 0.01 T003 IN TG VIBRATION BRG 1 MILS 3.85 3.88Z T004 MAIN TG VIBRATION BRG 2 OMILS 2.19 2.22, 0-,. 03 z

07 00 I00 T0G5 MAIKN TG VIBRATION BHG 3 MILS 1.17 1.1104 T006 MAIN TG VIBRATION BRG 4 MILS 1.12 0.98.

0.9:

T007 MAIN TG VIBRATION BRG 5 MILS 1.83 1.78 1.71 T008 MA*INTG VIBRATION BRG 6 MILS 0.79 0.85' 0.8:

G003 MANTG D0FF EXP NO. 1 INCH 0.07 0.07 0.0 G004 MAIN TG VIBRATION BRG 7 MtLS 1.28 1.25 1.2'

'GO05 MAIN TG VIBRATION BRG 8 MILS 2.16 2.09 2.0' G006

[MAIN TG V1IB EXCITER BRG 7M1LS 7.11 7.00&

6.9 Page 12 of 12

ATTACHMENT 3 LIST OF REGULATORY COMMITMENTS@

ATTACHMENT 3 LIST OF REGULATORY COMMITMENTS© Correspondence Number: NLS2008097 The following table identifies those actions committed to by Nebraska Public Power District (NPPD) in this document. Any other actions discussed in the submittal represent intended or planned actions by NPPD. They are described for information only and are not regulatory commitments. Please notify the Licensing Manager at Cooper Nuclear Station of any questions regarding this document or any associated regulatory commitments.

COMMITMENT COMMITTED DATE COMMITMENT NUMBER OR OUTAGE None N/A N/A 1-