RS-23-081, Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation

Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation

ML23233A168
Person / Time
Site:	Clinton
Issue date:	08/21/2023
From:	Lueshen K Constellation Energy Generation
To:	Office of Nuclear Reactor Regulation, Document Control Desk
References
RS-23-081
Download: ML23233A168 (1)

Text

4300 Winfield Road Warrenville, IL 60555 630 657 2000 Office RS-23-081 10 CFR 50.90 August 21, 2023 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 NRC Docket No. 50-461

Subject:

Request for License Amendment to Revise Technical Specifications Related to Reactor Water Cleanup Isolation Instrumentation In accordance with 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," Constellation Energy Generation, LLC (CEG) requests an amendment to Facility Operating License No. NPF-62 for Clinton Power Station (CPS), Unit 1. The proposed change revises the Reactor Water Cleanup (RWCU) system isolation functions that are listed in Technical Specifications (TS) 3.3.6.1, "Primary Containment and Drywell Isolation Instrumentation," Table 3.3.6.1-1, "Primary Containment and Drywell Isolation Instrumentation."

Specifically, the proposed change increases the allowable value for Function 4.b, "Differential Flow-Timer," and renames Function 4.b as "Differential Flow Timer - High." In addition, new functions are added for a Differential Flow - High-High trip and an associated Differential Flow High-High Timer.

This request is subdivided as follows.

• Attachment 1 provides a description and evaluation of the proposed change.

• Attachment 2 provides a markup of the affected TS page.

• Attachment 3 provides a markup of the affected TS Bases pages. The TS Bases pages are provided for information only and do not require NRC approval.

• Attachment 4 provides design analysis IP-C-0132, "RWCU Differential Flow Setpoint Analysis for Detecting Large Leaks," Revision 0.

• Attachment 5 provides design analysis IP-C-0096, "Setpoint Calculation Reactor Water Cleanup (RWCU) System Isolation-Differential Flow Timers, 1E31R615A(B), and 1E31R616A(B)," Revision 0B.

The proposed change has been reviewed by the Plant Operations Review Committee in accordance with the requirements of the CEG Quality Assurance Program.

August 21, 2023 U.S. Nuclear Regulatory Commission Page 2 CEG requests approval of the proposed change by August 21, 2024. Once approved, the amendment will be implemented prior to startup from the fall 2025 refueling outage. This implementation period will provide adequate time for the affected station documents to be revised using the appropriate change control mechanisms.

In accordance with 10 CFR 50.91, "Notice for public comment; State consultation,"

paragraph (b), CEG is notifying the State of Illinois of this application for license amendment by transmitting a copy of this letter and its attachments to the designated State Official.

There are no regulatory commitments contained in this letter. Should you have any questions concerning this letter, please contact Mr. Kenneth M. Nicely at (779) 231-6119.

I declare under penalty of perjury that the foregoing is true and correct. Executed on the 21st day of August 2023.

Respectfully, Digitally signed by Lueshen, Lueshen, Kevin Kevin Date: 2023.08.21 13:27:23

-05'00' Kevin Lueshen Sr. Manager Licensing Constellation Energy Generation, LLC Attachments:

1. Evaluation of Proposed Change

2. Markup of Technical Specifications Page

3. Markup of Technical Specifications Bases Pages (For Information Only)

4. Design Analysis IP-C-0132, "RWCU Differential Flow Setpoint Analysis for Detecting Large Leaks," Revision 0

5. Design Analysis IP-C-0096, "Setpoint Calculation Reactor Water Cleanup (RWCU)

System Isolation-Differential Flow Timers, 1E31R615A(B), and 1E31R616A(B),"

Revision 0B cc: NRC Regional Administrator, Region III NRC Senior Resident Inspector - Clinton Power Station Illinois Emergency Management Agency - Division of Nuclear Safety

ATTACHMENT 1 Evaluation of Proposed Change 1.0

SUMMARY

DESCRIPTION 2.0 DETAILED DESCRIPTION

3.0 TECHNICAL EVALUATION

3.1 System Description 3.2 History of RWCU Spurious Isolations 3.3 Modification Summary 3.4 Summary of Analyses Performed

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements/Criteria 4.2 No Significant Hazards Consideration 4.3 Conclusions

6.0 REFERENCES

Page 1

ATTACHMENT 1 Evaluation of Proposed Change 1.0

SUMMARY

DESCRIPTION In accordance with 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," Constellation Energy Generation, LLC (CEG) requests an amendment to Facility Operating License No. NPF-62 for Clinton Power Station (CPS), Unit 1. The proposed change revises the Reactor Water Cleanup (RWCU) system isolation functions that are listed in Technical Specifications (TS) 3.3.6.1, "Primary Containment and Drywell Isolation Instrumentation," Table 3.3.6.1 1, "Primary Containment and Drywell Isolation Instrumentation."

Specifically, the proposed change increases the allowable value for Function 4.b, "Differential Flow-Timer," and renames Function 4.b as "Differential Flow Timer - High." In addition, new functions are added for a Differential Flow - High-High trip and an associated Differential Flow High-High Timer.

2.0 DETAILED DESCRIPTION The proposed change extends the allowable value for the Function 4.b RWCU differential flow timer length from 47 seconds to 863 seconds. This time delay works in conjunction with Function 4.a, "Differential Flow-High," to prevent spurious trips during most RWCU operational transients. Due to this relationship between Functions 4.a and 4.b, the proposed change also renames Function 4.b as "Differential Flow Timer - High."

In addition, the proposed change adds the following new RWCU system isolation functions.

APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION F.1 REQUIREMENTS VALUE

i. Differential 1,2,3 2 I SR 3.3.6.1.1 < 182.4 gpm Flow - SR 3.3.6.1.2 High-High SR 3.3.6.1.6 SR 3.3.6.1.8

j. Differential 1,2,3 2 I SR 3.3.6.1.2 < 47 seconds Flow SR 3.3.6.1.4 Timer - SR 3.3.6.1.6 High-High A markup of the proposed change is provided in Attachment 2. Attachment 3 provides a markup of the affected TS Bases pages. The TS Bases pages are provided for information only and do not require NRC approval.

Page 2

ATTACHMENT 1 Evaluation of Proposed Change

3.0 TECHNICAL EVALUATION

3.1 System Description 3.1.1 RWCU System The RWCU system is described in Section 5.4.8, "Reactor Water Cleanup System," of the CPS Updated Safety Analysis Report (USAR). The RWCU system continuously removes solid and dissolved impurities from the reactor water through filter demineralizers to maintain the purity within specified limits. Although the RWCU system is of importance to startup and long-term operation, the reactor may operate while the RWCU system is out of service.

The system takes its suction from the inlet of each reactor main recirculation pump and from the reactor pressure vessel bottom head. The process fluid is circulated with the cleanup pumps through a regenerative and nonregenerative heat exchanger for cooling, through the filter demineralizers for cleanup and back through the regenerative heat exchanger for reheating .

The processed water is returned to the reactor pressure vessel and/or the main condenser or radwaste. A simplified schematic is shown in Figure 1.

D302 FD 41 Restricting Bypass Valve Orifice

, - - - - - M~ I--........... l--'-----4~ 1--+-__,..__--I l--,..l- l~ l--- - - ' - - - 1 1 f----+ To Condense, F0JJ F028 F034 F046 O3l0 Control 0001 CT tsol CT lsol N011 Flow lsol Vatve Restricting Vilve Restricting OtlrJCa Orifice Orifice .___ _ _ _ _ _ _ _ _...,_ __ _ ToRadwaste F035 lsol Vatve F107 RHX Byp,i;!SS F032 F/0 lsol cc F304A&B F040 F039 CTl>0I CT l,ol RHXlsol Non--Regsn Hx'sA&B

~1~*i-.1 R"9;;BHx"s 1--- ---l~k'l----...i....f"::,1,Cl---l-l~'." I--I I~ To~RI F042A&B RHX lsol N040 Flow F044 Component Orifice F/0 Bypass Cooling (CC)

Fit1er-Oemins F303A&B NRHX lsol N035 Flow Venturi RWCU Pumps CT Wall A. B, & C CT Wall DWWal Figure 1: Simplified RWCU System Schematic Page 3

ATTACHMENT 1 Evaluation of Proposed Change The primary RWCU system functions are power generation (i.e., non-safety related) functions.

Specifically, the RWCU system:

1. Removes solid and dissolved impurities from reactor coolant and measures the reactor water conductivity in accordance with Regulatory Guide 1.56 (i.e., Reference 1).

2. Discharges excess reactor water during startup, shutdown, and hot standby conditions to the main condenser or radwaste.

3. Minimizes temperature gradients in the main recirculation piping and reactor pressure vessel during periods when the main recirculation pumps are unavailable. The operation of the RWCU system with the heat exchangers bypassed and the reactor coolant temperature above 435°F is prohibited since the feedwater piping is not analyzed for temperatures above 435°F.

4. Minimizes the RWCU heat loss.

5. Enables the major portion of the RWCU to be serviced during reactor operation.

6. Prevents the standby liquid reactivity control material from being removed from the reactor water by the cleanup system when required for shutdown.

Portions of the RWCU system form a part of the reactor coolant pressure boundary (RCPB),

and therefore, perform a safety function. The RCPB portion of the RWCU system meets the requirements of Regulatory Guides 1.26 and 1.29 (i.e., References 2 and 3, respectively) to:

1. Prevent excessive loss of reactor coolant,

2. Prevent the release of radioactive material from the reactor, and

3. Isolate the major portion of the RWCU system from the RCPB.

The proposed change does not affect the non-safety related power generation functions nor the safety related RCPB functions described above.

3.1.2 Leak Detection System Since the RWCU system penetrates the containment boundary, General Design Criterion (GDC) 54 requires that the system be provided with leak detection, having redundancy, reliability, and performance capabilities which reflect the importance to safety of isolating the piping system. The leak detection system for CPS is described in USAR Section 5.2.5, "Reactor Coolant Pressure Boundary and ECCS System Leakage Detection System," and its associated instrumentation and controls are described in USAR Chapter 7, "Instrumentation and Control Systems." The primary safety function of the leak detection system is to ensure that abnormal leakage from select systems within the primary containment and within selected areas of the plant outside the primary containment is detected, indicated, alarmed, and in certain cases isolated. RWCU is one of the systems monitored by the leak detection system. As shown in USAR Table 5.2-9b, "Summary of Isolation/Alarm of System Monitored and the Leak Page 4

ATTACHMENT 1 Evaluation of Proposed Change Detection Methods Used," and TS Table 3.3.6.1-1, the RWCU system can be isolated by the following signals:

1. Reactor Vessel Water Level Low Low, Level 2;

2. Main Steam Tunnel Ambient Temperature High;

3. RWCU Differential Flow High;

4. RWCU Equipment Areas (Heat Exchanger Equipment Room or Pump Rooms) Ambient Temperature High;

5. Standby Liquid Control System Initiation; and

6. Manual Initiation.

Only the RWCU Differential Flow High function is affected by the proposed change. As described in TS Bases Section 3.3.6.1, the high differential flow signal is provided to detect leaks in the RWCU system when area or differential temperature would not provide detection (i.e., a cold leg break). Should the reactor coolant continue to flow out of the break, offsite dose limits may be exceeded. Therefore, isolation of the RWCU system is initiated when high differential flow is sensed to prevent exceeding offsite doses. A time delay is provided to prevent spurious trips during most RWCU operational transients, though this has proven ineffective as discussed below in Section 3.2. This function is not assumed in any USAR transient or accident analysis for pipe breaks outside containment, since bounding analyses are performed for large breaks such as main steam line breaks (MSLBs).

The RWCU differential flow isolation is assumed to mitigate breaks in the RWCU piping inside containment to preclude subcompartment pressurization which could lead to containment failure. The containment subcompartments that credit the RWCU differential flow isolation are:

1. Containment pipe tunnel,

2. RWCU heat exchanger rooms,

3. RWCU valve rooms,

4. RWCU crossover pipe tunnel,

5. RWCU filter-demineralizer holding pump room,

6. RWCU filter-demineralizer rooms, and

7. RWCU filter-demineralizer valve room.

As listed in TS Table 3.3.6.1-1, the current TS allowable values are < 66.1 gpm for differential flow high (i.e., Function 4.a) and < 47 seconds for the time delay (i.e., Function 4.b). The actual/nominal trip setpoints are 59 gpm for differential flow high and 45 seconds for the timer.

These values are consistent with the General Electric (GE) Design Specification and Design Spec Data Sheet (DSDS) for the Leak Detection System, as discussed below.

The GE leak detection system Design Specification states that "The cleanup system shall have a means of flow comparison between the system inlet and the outlets. The alarm and isolation setpoints shall be established at a differential between inlet flow and outlet flow which equals 20% of system rated flow. A bypass timer shall be provided to override the isolation during system pump and valve surge conditions." The GE leak detection system DSDS states that "The RWCU system does have a portion of its piping that contains cold reactor coolant and therefore temperature monitoring for leakage would not be responsive. For this reason, a flow Page 5

ATTACHMENT 1 Evaluation of Proposed Change comparison between inlet and outlet flow is monitored for this piping." The DSDS also identified that the timer setpoint should be 45 seconds.

The current RWCU differential flow nominal trip setpoint of 59 gpm is approximately 20%

percent of the CPS RWCU rated system flow (i.e., 294 gpm), and the 45 second timer nominal setpoint is used to override the isolation during system pump and valve surge conditions. There is no discussion in the documents discussed above regarding why the specific 45 second value was chosen for CPS, versus a lower or higher value. Based on the similarity of the CPS and Perry Nuclear Power Plant (PNPP) RWCU system designs (i.e., GE BWR/6 designs) and differential flow/timer setpoints, the setpoint values were likely chosen by GE for the same reason. As discussed in Reference 4, the PNPP differential flow and timer setpoints were conservatively chosen by GE based on engineering judgement, with the intent of ensuring, without the need for any plant-specific dose calculations, that any offsite dose effects associated with this leakage would be acceptable. In addition, based on discussions with GE, the CPS differential flow analytical value is arbitrary but conservative for the purpose of pipe break detection. The same logic can be applied to the timer analytical value.

3.1.3 RWCU Differential Flow System Design The RWCU differential flow system schematic is shown in Figure 2. Six differential pressure instruments (i.e., flow transmitters) monitor RWCU system flow. Two monitor RWCU pump-suction flow from the recirculation lines with the 1G33N035 flow element, two monitor the flow to the Feedwater system with the 1G33N040 flow element, and two monitor the flow to the main condenser with the 1G33N011 flow element. One of each of the redundant sets of flow transmitters is associated with one instrument channel. The second set of flow monitoring instruments is associated with the other instrument channel.

The signals from the flow transmitters are sent to square root converters to convert the differential pressure signal to flow in the 1H13P632 and 1H13P642, Division 1 and Division 2 Leak Detection Panels, respectively, located in the main control room (MCR). The inlet and outlet flow signals are then subtracted in a summer card, one per channel. The output of the summer card is read by an alarm card, which is set at a 59 gpm nominal trip setpoint for differential flow. If the summer card signal exceeds the 59 gpm setpoint on either channel, signals are sent to the 5000-2F MCR annunciator and to start the 45 second timer. If the differential flow signal exceeds 59 gpm for more than 45 seconds, the timer signals the 5000-1F MCR annunciator and the associated channel for the Containment and Reactor Vessel Isolation Control System (CRVICS) trip logic.

As discussed in USAR Section 7.3.1.1.2.4.1.9, two instrumentation trip channels are provided to assure protective action. The output trip signal of each instrumentation channel initiates one logic channel trip. The Division 1 logic signal closes the outboard RWCU isolation valve, and the Division 2 logic signal closes the inboard RWCU isolation valve. Each differential flow monitor is supplied from the appropriate logic channel power source. Each channel is redundant and divisional such that failure of either channel will not prevent the differential flow isolation from occurring.

Page 6

ATTACHMENT 1 Evaluation of Proposed Change 5000-2F RWCU HI DIFF FLOW TIMER INITIATED FT SQRT 1E31N076A/B 1E31K602A/B Inlet Flow 5000-lF RWCU DIFF FLOW HI ALARM TIMER FT 1E31N075A/B SQ RT 1E31K605A/B f------i' SUMMER 1E31K604A/B -----. 1E31N609A/B 66.l gpmAV i------------.

1E31R615A/B 47 sec AV Slowdown 59 gpm NTSP 45 sec NTSP FT 1H13P680 SQRT 1E31N077A/B 1E31K603A/B Return Flow CRVICS LOGIC 1H13P661 Local Panels

• Existing 3-F window 1H13P632/642 will be moved to spa re window 5-F Figure 2: RWCU Differential Flow System Schematic 3.2 History of RWCU Spurious Isolations The RWCU differential flow isolation has had historical issues of spurious isolations during plant transients, especially during plant startup and shutdown. This causes delays to outages, issues with reactor water chemistry , undesirable challenges to operators and safety equipment, and loss of RWCU system availability.

Spurious RWCU differential flow isolations are a common issue with boiling water reactor (BWR) RWCU designs. For example, GE has issued several Service Information Letters (SI Ls) to notify plants of these issues (e.g., References 5, 6, and?).

CPS has installed modifications and implemented operational changes to reduce the instances of spurious isolations due to high differential flow. These changes are summarized below.

1. A restricting orifice 1G33D310 was installed in the RWCU letdown line to the condenser downstream of flow element 1G33N011 to provide back pressure on the 1G33N011 flow element. The purpose is to eliminate flashing across the flow element to improve the flow indication.

2. The 1G33F033 pressure control valve in the letdown line to the condenser was modified with trim for better throttling characteristics and a new actuator for better isolation capability .

Page 7

ATTACHMENT 1 Evaluation of Proposed Change

3. Operational changes were implemented to reduce reactor heat-up and cool-down rates, reducing the severity of transients in the RWCU system.

4. Operational changes were implemented to open the 1G33F031 orifice bypass valve during low reactor pressure conditions to reduce the potential for cavitation across orifice 1G33D001.

While these changes may have had some effect in reducing the instances of spurious isolations, high differential flow isolations continue to occur during plant startup and shutdown. To further understand the causes of the spurious isolations and investigate potential solutions to this issue, CEG contracted architect engineer Sargent & Lundy to perform a study. The study involved review of historical operation and design basis documents to determine an approach for reducing or eliminating spurious RWCU system isolations on high differential flow.

Historical operating data was reviewed from several recent high differential flow events along with older data where the isolation was bypassed. The data showed that inlet flow and condenser reject flow remained relatively steady, even during the high differential time period.

Outlet flow data was not available, but it was inferred that this reading is where the flow change occurred. In general, differential flow rapidly increased above the setpoint. Because of this and the temperature/pressure data, it is unlikely that the differential flow reading is due to pressure/temperature calibration or errors introduced by changing temperatures, though this could reduce margin to the setpoint.

There are occasions where the Division 1 and 2 RWCU differential flow readings are mismatched. This typically occurs during reactor startup and/or shutdown conditions. Fill and vent of the instrument lines and calibration of the instruments typically corrects the issue.

Some events occurred when system inlet flow had very low subcooling, which could result in void formations in the regenerative heat exchanger and consequential inlet/outlet flow mismatch during void formation/collapse (i.e., heat exchanger re-fill). This is similar to a cause that was identified at PNPP as discussed in Reference 4. Another potential trip source was identified as flashing when reactor pressure dropped due to shutdown cooling initiation. A third cause hypothesized was void/air pocketing in instrument sensing lines that throw off the differential pressure readings. Since the measured differential pressures are small, it only takes a small disturbance to significantly alter the flow reading.

3.3 Modification Summary Because several potential causes were identified in the Sargent & Lundy study discussed above, a design solution was developed that would prevent spurious differential flow isolations regardless of the cause. The proposed change implements this design solution. Specifically, the differential flow timer allowable value is increased from 47 seconds to 863 seconds. This timer and allowable value are listed in TS Table 3.3.6.1-1 as Function 4.b (as shown in ). Based on review of past events, this time duration should bound the duration of system transients that have caused spurious differential flow isolations.

Increasing the time delay setpoint impacts the analyses for high energy line break (HELB),

internal flooding, and radiological dose because more mass and energy would be released Page 8

ATTACHMENT 1 Evaluation of Proposed Change before isolation of a postulated pipe break. The design basis guillotine break would result in large break flows that, based on reviews of the design basis analyses, would exceed design limits if unisolated for this length of time. Therefore, the design solution uses a hybrid approach to add a new differential flow isolation at a higher flow rate (i.e., 182.4 gpm allowable value) with the existing 47 second time delay. This higher setpoint quickly isolates large breaks to remain within the existing design basis analyses. The proposed change adds these new isolation functions to TS Table 3.3.6.1-1 as Function 4.i (i.e., Differential Flow - High-High) and Function 4.j (i.e., Differential Flow Timer - High-High). As shown in Attachment 2, the TS allowable values are < 182.4 gpm and < 47 seconds for new Functions 4.i and 4.j, respectively.

The modes of applicability for the new functions, as well as the applicable surveillance requirements, are identical to the existing isolation functions (i.e., Functions 4.a and 4.b). The proposed change continues to ensure that leaks in the cold leg portion of RWCU system piping inside containment are detected and mitigated for pipe breaks ranging from 66.1 gpm up to and including a double-ended guillotine break.

With this strategy, intermediate pipe breaks less than 182.4 gpm are allowed to occur for up to 863 seconds prior to RWCU system isolation. Larger leaks, up to and including a double-ended guillotine break, are isolated within 47 seconds in accordance with the existing design basis.

Breaks less than 66.1 gpm are not isolated in accordance with the existing design basis.

A simplified schematic of the proposed modification is shown in Figure 3. The existing components are shown in black, with new components shown in red.

1. Flow transmitters 1E31-N075A/B, 1E31-N076A/B, and 1E31-N077A/B are replaced with a new model that has higher accuracy. These transmitters are installed on instrument racks inside the containment and auxiliary buildings.

2. New summer cards 1E31-K606A/B, alarm cards1E31-N611A/B, and time delay relays 1E31R616A/B are installed in the Leak Detection Cabinets 1H13P632 (Division 1) and 1H13P642 (Division 2) in the MCR. The "A" components are associated with Division 1 and the "B" components are associated with Division 2.

This provides redundancy and divisional separation such that the RWCU isolation occurs despite a failure on either division, in accordance with the CPS design basis.

3. The new summer cards 1E31-K606A/B take signals from the existing square root cards 1E31-R602A/B, 1E31-R603A/B, and 1E31-R605A/B.

4. The existing 1E31N609A/B alarm cards, when the 59 gpm setpoint is exceeded, outputs a signal to the new 1E31R616A/B timers to start the 14-minute time delay setpoint. The new 1E31N611A/B alarm cards, when the 164.2 gpm setpoint is exceeded, outputs a signal to the existing 1E31R615A/B timers to start the 45 second time delay. This configuration allows a moderately sized leak (i.e.,59-164.2 gpm setpoint) to occur for 14 minutes prior to RWCU system isolation.

A leak larger than the 164.2 gpm setpoint, up to and including a double-ended guillotine break, is isolated within 45 seconds, consistent with the existing design for large leaks and breaks.

Page 9

ATTACHMENT 1 Evaluation of Proposed Change

5. Both the existing 1E31R615A/B 45 second timers and the new 1E31R616A/B 14-minute timers are visible from the exterior of panels 1H13P632 and 1H13P642.

These timers have a light to indicate which timer has started and a display of the elapsed time and timer setpoints.

6. Both the existing 1E31R615A/B 45 second timers and the new 1E31R616A/B 14-minute timers output to the divisional CRVICS logic to perform isolation of the RWCU system via a Group 4 containment isolation. The Group 4 isolation valves are listed in Table 1. The RWCU inlet flow signal interlocks the RWCU pumps to stop the pumps when flow is below a predetermined value. The modification does not change the CRVICS isolation logic.

7. The new alarm cards 1E31N611A/B output a signal to new annunciator 5000-3F in the MCR. This gives separate alarms to the operators for exceeding either the existing 59 gpm HI DIFF FLOW setpoint and the new 164.2 gpm HI-HI DIFF FLOW setpoint. Both the existing 1E31R615A/B 45 second timers and the new 1E31R616A/B 14-minute timers output to the same 5000-1F annunciator in the MCR to notify operators that a RWCU system isolation has occurred due to either setpoint.

8. Local differential flow indicators 1E31-R614A/B located on the exterior of panels 1H13P632 and 1H13P642, and Plant Process Computer point 1E31-DA001, are scaled to 0 - 100 gpm differential flow. These are rescaled to show higher differential flow values to give operators indication if the higher differential flow setpoint is exceeded.

9. The new equipment meets the applicable CPS design basis requirements for:

a. Safety-related equipment,

b. Environmental Qualification for normal and accident environmental conditions,

c. Seismic Qualification,

d. Class 1E electrical equipment,

e. Electromagnetic capability,

f. Redundancy, and

g. Divisional separation.

Page 10

ATTACHMENT 1 Evaluation of Proposed Change 5000-2F RWCU HI DIFF FLOW TIMER INITIATED FT SQRT 1E31N076NB 1E31K602A/B Inlet Flow 5000-lF Replace RWCU DIFF FLOW

~~

HI ALARM TIM ER FT SQRT SUMMER 1E31R615A/ B 1E31N609A/B

\I 1E31N075A/B 1E31K605A/B - -+ 1E31K604NB 47 sec AV 66.1 gpm AV 5000-3F*

Blowdown 45 sec NTSP 59 gpm NTSP RWCU Replace HI-HI DIFF FLOW TIMER INITIATED A

FT 1H13P680 SQRT 1E31N077A/B 1E31K603NB Retu rn Flow Replace CRVICS LOG IC

• ALARM TIM ER SUMMER 1Hl3P661 1E31N11A/B 1E31R616A/B Local Pa nels 1E31K606NB f-------+ 863 sec AV 182.4gpmAV

'-----to 164.2 gpm NTSP 840 sec NTSP

• Existing 3-F w indow 1H13P632/642 will be moved to spa re window 5-F Figure 3: Modification Simplified Schematic Table 1: Group 4 Isolation Valves Valve EIN Valve Function Division 1G33-F004 RWCU Suction Outboard Isolation 1G33-F054 RWCU Pump Discharge Outboard Isolation 1

1G33-F039 RWCU Return Flow Outboard Isolation 1G33-F034 RWCU Reject/Condenser Flow Outboard Isolation 1G33-F001 RWCU Suction Inboard Isolation 1G33-F053 RWCU Pump Discharge Inboard Isolation 2

1G33-F040 RWCU Return Flow Inboard Isolation 1G33-F028 RWCU Reject/Condenser Flow Inboard Isolation 3.4 Summary of Analyses Performed As discussed above, increasing the time delay setpoint impacts the analyses for HELB, internal flooding, and radiological dose because more mass and energy would be released before Page 11

ATTACHMENT 1 Evaluation of Proposed Change isolation of a postulated pipe break. Therefore, analyses were performed for a 182.4 gpm leak for 863 seconds (allowable values) to ensure the results are bounded by the existing design basis analyses for a guillotine break isolated within 47 seconds. Impacts to environmental qualification (EQ) and seismic qualification have also been evaluated. In addition, calculations were performed to determine the setpoints and allowable values for the new RWCU differential flow isolation instrumentation. With the exception of the proposed TS changes shown in , the analyses performed to support the planned modification have been evaluated in accordance with 10 CFR 50.59, "Changes, tests and experiments," and determined to not require NRC approval prior to implementation. A summary of the analyses is provided below.

3.4.1 HELB Analysis The existing containment subcompartment responses for a double-ended guillotine break remain applicable because the timer for detecting and isolating large breaks is unchanged.

Intermediate breaks up to 182.4 gpm for 863 seconds (i.e., allowable values) were evaluated to demonstrate that these breaks remain bounded by the existing analysis. Results of analyses for intermediate breaks are discussed below.

Subcompartment response was analyzed for the RWCU Heat Exchanger and Heat Exchanger Valve Rooms, RWCU Crossover Pipe Tunnel, Filter Demineralizer Holding Pump Room, Filter Demineralizer Valve Room, and Filter Demineralizer Rooms. The results show peak temperatures, pressures, and differential pressures for each zone are bounded by the large break result in the base calculation or the structure was evaluated to ensure allowable stresses were not exceeded.

The response to an RWCU line break in the Main Steam Tunnel (MST) inside containment (i.e.,

EQ Zone C.3.4) was analyzed. The peak temperature and pressure in the MST (i.e., 218.4°F, 16.7 psia) are lower than the maximum temperature and pressure in the existing EPU-T1009 analysis (i.e., 218.7°F, 16.8 psia), confirming that the new setpoint is bounded by the previous analysis.

The following zones do not contain high energy RWCU piping, nor is there significant leakage of steam from adjacent zones due to a postulated RWCU HELB. Therefore, there is no detailed HELB analysis for these zones. The changes to the RWCU differential flow timer and setpoints do not alter the RWCU piping or HELB locations. Therefore, these zones are not affected by the changes.

• C.4.4 Pipe Tunnel 791',

• C.4.5 Backwash Tank Cubicle, and

• C.4.7 Recirculating Pump Cubicle.

Zone C.5.8 Pipe Tunnel 803'-3" has no RWCU high energy piping, but it can experience environmental transients due to steam introduced from adjacent zones. For this zone, only the temperature profile is changed in that the maximum temperature of 223°F is held for a longer duration (i.e., 1000 seconds vs 120 seconds) to account for the longer break duration.

Page 12

ATTACHMENT 1 Evaluation of Proposed Change 3.4.2 Internal Flooding Analysis Calculations addressing the effects of internal flooding due to breaks in RWCU piping were reviewed to identify where the differential flow setpoint is credited as the means for triggering break isolation. Specifically, the calculation that documents the internal flooding analysis to determine maximum flood levels in subcompartments both inside and outside containment was reviewed. Only the RWCU line breaks inside containment credit differential flow as the means for detection and isolation of breaks. The calculation was revised to address releases corresponding to double ended guillotine breaks (i.e., isolated by the short timer) and the maximum release that will be isolated by the long timer. The calculation evaluates both steady-state flood levels due to flow in and out of a cubicle, and flood levels due to total released inventory. Where steady state levels are considered, the double-ended guillotine break with fast isolation is bounding due to the higher flow rates. Where total released inventory is considered, the new setpoint release is bounding due to larger volume.

The calculation results in increased calculated flood levels in zones shown in Table 2 below.

Table 2: Environmental Zones with Increased Flood Levels Environmental Previous Updated Plant Area Zone Code Flood Level Flood Level RWCU Backwash Rec. Tank Room C4.5 75" 91" Regen. And Non-Regen. Heat Exchanger C5.3 12" 22" Room A Regen. And Non-Regen. Heat Exchanger C5.4 12" 22" Room B Filter Demineralizer Holding Pump Room C5.6 81" 104" Filter Demineralizer Valve Room C5.7 8" 9" Filter Demineralizer Vessel Room C5.9 29" 69" Regen. And Non-Regen. Heat Exchanger C5.12 12" 22" Valve Room A Regen. And Non-Regen. Heat Exchanger C5.13 12" 22" Valve Room B The flood level increase was due, in part, to correcting a legacy error that was recently identified in the analysis. There are two impacts of increased flood levels: (1) effects on safe shutdown equipment, and (2) larger structural loads. These impacts are further discussed below.

Flooding Effects on Safe Shutdown Equipment A calculation has been performed to evaluate safe shutdown equipment in the Environmental Zones discussed above to ensure that a safe shutdown method is available for a pipe break in any given zone. Table 2 above shows the Environmental Zones that had increased flood levels.

Of these, safe shutdown impacts in zones C5.3, C5.4, C5.12, and C5.13 were previously Page 13

ATTACHMENT 1 Evaluation of Proposed Change analyzed at higher water levels that bound the revised result. For the other zones, the calculation was revised to determine if any safe-shutdown equipment is adversely impacted.

The review found that flood level increases will not impact any safe-shutdown equipment.

Flooding Effects on Structural Analysis As discussed above in Section 3.4.1, the existing design basis analyses are bounding for compartment temperature and pressure. Therefore, the RWCU compartment structures do not require re-evaluation for changes in pressure or temperature. The increased flood levels were evaluated for impacts to the RWCU cubicles structure. The evaluation determined that the structures remain qualified for design basis loads.

3.4.3 Radiological Dose Analysis A dose analysis has been performed to determine dose consequences due to a postulated RWCU system cold leg leak. In a potential RWCU system line break, the leak would be detected by the differential flow measurement monitoring a failure in the system boundary. The high differential flow readings in excess of the flowrate and time delay setpoints would identify the leak. A leak flowrate of 235 gpm for 15 minutes was considered in the dose analysis.

The dose consequences were calculated to confirm that the current CPS design basis MSLB accident analysis remains bounding. More specifically, the exclusion area boundary (EAB), low population zone (LPZ), and MCR doses for the MSLB accident were verified to be larger than doses for the RWCU system leak. The activity available for release from the RWCU system leak is that present in the reactor coolant, with two cases (i.e., Case 1 and Case 2) based on the maximum equilibrium and pre-accident iodine spike concentrations of 0.2 Ci/gm and 4.0 Ci/gm dose equivalent I-131, respectively. A comparison of the current design basis MSLB accident dose and the RWCU system leak dose is shown in Table 3.

Table 3: Comparison of Current Design Basis MSLB Accident Dose and Postulated RWCU System Leak Dose Results Current Design Basis MSLB Dose for 235 gpm RWCU Location Dose (rem) Leak for 15 Minutes (rem)

Case 1 Case 2 Case 1 Case 2 EAB (2-hour) 8.35E-02 1.67 1.75E-03 3.50E-02 LPZ (30-day) 2.32E-02 4.63E-01 4.86E-04 9.72E-03 MCR (30-day) 1.93E-01 3.85 2.24E-02 4.49E-01 3.4.4 EQ Analysis As discussed in Section 3.4.1, the existing design basis analyses are bounding for compartment temperature and pressure. No other EQ parameters are affected by the proposed change.

Humidity is assumed to be saturated for these zones during accident conditions, and submergence is discussed above in Section 3.4.2. However, the duration of the HELB event Page 14

ATTACHMENT 1 Evaluation of Proposed Change requires evaluation of EQ equipment in the affected containment subcompartments. The evaluation found that affected EQ equipment remains qualified for the revised HELB conditions.

The review determined that the test accident conditions envelop the revised RWCU HELB environmental specifications for each equipment and the existing analysis in the binder is bounding. There is no reduction in the overall qualified life of EQ equipment.

The new equipment being installed to support the proposed change was evaluated for the applicable environmental conditions. Because the MCR is a mild environmental zone, the new equipment installed in the MCR does not require EQ evaluation. The replacement differential pressure transmitters 1E31-N076A/B, 1E31-N077A/B, 1E31-N075A/B are located in harsh environmental zones and have been evaluated for the environmental conditions to establish qualified life.

3.4.5 Seismic Qualification The seismic qualification of the replacement differential pressure transmitters 1E31-N076A/B, 1E31-N077A/B, 1E31-N075A/B and supporting instrument racks has been evaluated. Required Response Spectra (RRS) were developed for each of the mounting locations based on amplification factors from seismic tests of the instrument racks. The RRS was then compared to the Test Response Spectra (TRS) for the replacement transmitters based on the existing qualification. The replacement transmitters weigh slightly less than the existing transmitters, and therefore have negligible impact on the dynamic characteristics and qualification of the instrument racks.

Under CEG's design control process, the new equipment being installed in the MCR panels will be seismically qualified in accordance with the CPS design basis.

3.4.6 Setpoint Analysis As discussed in Section 3.1.2, the existing trip setpoints and timer settings for the RWCU leak detection system were determined by GE as documented in the Leak Detection System design specification and DSDS. The existing square root converters, 1E31-K602A/B, 1E31-K603A/B, 1E31-K605A/B; summer cards 1E31-K604A/B and alarm cards 1E31-N609A/B are not affected by the modification associated with proposed change. The differential pressure transmitters for recirculation suction, 1E31-N076A/B, feedwater return 1E31-N077A/B, and condenser return, 1E31-N075A/B are replaced as part of the modification with more accurate instruments to reduce the total instrument loop uncertainty. Therefore, the existing GE DSDS will remain valid for the uncertainty of the existing 59 gpm differential flow setpoint and 45 second timer setpoint.

A new flow uncertainty calculation (i.e., design analysis IP-C-0132, "RWCU Differential Flow Setpoint Analysis for Detecting Large Leaks," Revision 0) was developed for the new setpoint and allowable value which includes the loop of the existing flow elements and new differential pressure transmitters (i.e., 1E31-N076A/B, 1E31-N077A/B, 1E31-N075A/B), existing square root converters (i.e., 1E31-K602A/B, 1E31-K603A/B, 1E31-K605A/B), new summer cards (i.e., 1E31-K606A/B) and new alarm cards (i.e., 1E31-N611A/B). The calculation, which is provided in Attachment 4, was performed using the Instrument Society of America (ISA) 67.04 methodology. The calculation determined the Nominal Trip Setpoint (NTSP) is 164.2 gpm and the TS allowable value is 182.4 gpm.

Page 15

ATTACHMENT 1 Evaluation of Proposed Change A calculation has also been performed for the new timer (i.e., 1E31-R616A/B) uncertainty. The calculation (i.e., design analysis IP C 0096, "Setpoint Calculation Reactor Water Cleanup (RWCU) System Isolation-Differential Flow Timers, 1E31R615A(B), and 1E31R616A(B),"

Revision 0B) determined the NTSP is 14 minutes 0 seconds, and the TS allowable value is 14 minutes 23 seconds (i.e., 863 seconds). Design analysis IP-C-0096 is provided in .

4.0 REGULATORY EVALUATION

4.1 Applicable Regulatory Requirements/Criteria 10 CFR 50, Appendix A, "General Design Criteria for Nuclear Power Plants," Criterion 54, "Piping systems penetrating containment," requires that piping systems penetrating primary reactor containment shall be provided with leak detection, isolation, and containment capabilities having redundancy, reliability, and performance capabilities which reflect the importance to safety of isolating these piping systems. Such piping systems shall be designed with a capability to test periodically the operability of the isolation valves and associated apparatus and to determine if valve leakage is within acceptable limits.

10 CFR 50.36, "Technical specifications," paragraph (c)(3) requires that the TS contain surveillance requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met.

Based on the review of the above requirements, CEG has determined that the proposed change does not require any exemptions or relief from regulatory requirements, other than revising the TS as described, and does not affect conformance with GDC 54.

4.2 No Significant Hazards Consideration In accordance with 10 CFR 50.90, "Application for amendment of license, construction permit, or early site permit," Constellation Energy Generation, LLC (CEG) requests an amendment to Facility Operating License No. NPF-62 for Clinton Power Station (CPS), Unit 1. The proposed change revises the Reactor Water Cleanup (RWCU) system isolation functions that are listed in Technical Specifications (TS) 3.3.6.1, "Primary Containment and Drywell Isolation Instrumentation," Table 3.3.6.1 1, "Primary Containment and Drywell Isolation Instrumentation."

Specifically, the proposed change increases the allowable value for Function 4.b, "Differential Flow-Timer," and renames Function 4.b as "Differential Flow Timer - High." In addition, new functions are added for a Differential Flow - High-High trip and an associated Differential Flow High-High Timer.

According to 10 CFR 50.92, "Issuance of amendment," paragraph (c), a proposed amendment to an operating license involves no significant hazards consideration if operation of the facility in accordance with the proposed amendment would not:

(1) Involve a significant increase in the probability or consequences of any accident previously evaluated; or Page 16

ATTACHMENT 1 Evaluation of Proposed Change (2) Create the possibility of a new or different kind of accident from any accident previously evaluated; or (3) Involve a significant reduction in a margin of safety.

CEG has evaluated the proposed change, using the criteria in 10 CFR 50.92, and has determined that the proposed change does not involve a significant hazards consideration. The following information is provided to support a finding of no significant hazards consideration.

1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated because there are no changes to the RWCU process conditions that would increase the probability of a high energy line break. There is no increase in the probability of a failure to isolate because the new high differential flow instrumentation meets all design basis and licensing requirements for divisional separation, redundancy, electromagnetic capability, Class 1E safety related equipment, environmental qualification, and seismic qualification. There is no increase in consequences of a RWCU line break because the new differential flow setpoint and timer ensure that existing design basis analyses for radiological impacts, internal flooding, and containment structures remain bounding.

Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed change create the possibility of a new or different kind of accident from any accident previously evaluated?

Response: No The proposed changes do not create the possibility of a new or different kind of accident from any accident previously evaluated because there are no credible new failure mechanisms, malfunctions, or accident initiators that not considered in the design and licensing bases. The proposed changes do not change RWCU high energy line break locations or create a new type of line break accident initiator. The equipment selected to perform the new differential flow and timer functions meet all design and licensing basis requirements, which ensures there are no new credible failure mechanisms or malfunctions that would prevent the safety function from being performed.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any accident previously evaluated.

Page 17

ATTACHMENT 1 Evaluation of Proposed Change

3. Does the proposed change involve a significant reduction in a margin of safety?

Response: No The proposed changes do not involve a significant reduction in a margin of safety because the new differential flow setpoint and timer ensure that existing design basis analyses for a RWCU high energy line break are bounding. The radiological evaluations demonstrate that bounding analyses are performed for other accidents, such as a main steam line break accident. The internal flooding evaluations demonstrate that safe shutdown capability is maintained. The containment subcompartment structural evaluations demonstrate that structural component stresses continue to meet design basis and code limits. Equipment within the affected containment subcompartments remain able to perform their required safety functions due to changes in environmental conditions. Instrument uncertainties have been accounted for in setting the Technical Specification allowable values and instrument setpoints. Because the proposed change does not exceed or alter a design basis or safety limit, it does not significantly reduce the margin of safety.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

Based on the above evaluation, CEG concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92, paragraph (c),

and accordingly, a finding of no significant hazards consideration is justified.

4.3 Conclusions In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or the health and safety of the public.

5.0 ENVIRONMENTAL CONSIDERATION

CEG has determined that the proposed amendment would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, "Standards for Protection Against Radiation." However, the proposed amendment does not involve: (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluent that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22, "Criterion for categorical exclusion; identification of licensing and regulatory actions eligible for categorical exclusion or otherwise not requiring environmental review,"

paragraph (c)(9). Therefore, pursuant to 10 CFR 51.22, paragraph (b), no environmental impact statement or environmental assessment needs to be prepared in connection with the proposed amendment.

Page 18

ATTACHMENT 1 Evaluation of Proposed Change

6.0 REFERENCES

1. NRC Regulatory Guide 1.56, "Maintenance of Water Purity in Boiling Water Reactors,"

Revision 1, dated July 1978

2. NRC Regulatory Guide 1.26, "Quality Group Classifications and Standards for Water-,

Steam-, and Radioactive-Waste-Containing Components of Nuclear Power Plants,"

Revision 3, dated February 1976

3. NRC Regulatory Guide 1.29, "Seismic Design Classification," Revision 3, dated September 1978

4. Letter from M. D. Lyster (Centerior Energy) to U.S. NRC, "Technical Specification Change Request, Reactor Water Cleanup System Isolation Actuation Instrumentation,"

dated October 30, 1991

5. General Electric SIL No. 450, "RWCU Blowdown Flow Indication," dated April 10, 1987

6. General Electric SIL No. 451, "RWCU Differential Flow Leak Detection," dated May 27, 1987

7. General Electric SIL No. 604, "Reactor Water Clean-up System Break Detection," dated November 6, 1996 Page 19

ATTACHMENT 2 Markup of Technical Specifications Page Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 REVISED TECHNICAL SPECIFICATIONS PAGE 3.3-59

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 6)

Primary Containment and Drywell Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION F.1 REQUIREMENTS VALUE

3. RCIC System Isolation (continued)

j. Drywell Pressure - High 1,2,3 2 I SR 3.3.6.1.1 d 1.88 psig SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

k. Manual Initiation 1,2,3 1 J SR 3.3.6.1.6 NA

4. Reactor Water Cleanup (RWCU) System Isolation

a. Differential Flow - 1,2,3 2 I SR 3.3.6.1.1 d 66.1 gpm High SR 3.3.6.1.2 SR 3.3.6.1.6 SR 3.3.6.1.8

b. Differential Flow-Timer 1,2,3 2 I SR 3.3.6.1.2 d 47 seconds SR 3.3.6.1.4 Differential Flow Timer - High SR 3.3.6.1.6 863

c. RWCU Heat Exchanger 1,2,3 2 per I SR 3.3.6.1.1 d 205°F Equipment Room room SR 3.3.6.1.2 Temperature-High SR 3.3.6.1.5 SR 3.3.6.1.6

d. RWCU Pump Rooms 1,2,3 2 per I SR 3.3.6.1.1 d 202°F Temperature-High room SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

e. Main Steam Line Tunnel 1,2,3 2 I SR 3.3.6.1.1 d 171°F Ambient Temperature- SR 3.3.6.1.2 High SR 3.3.6.1.5 SR 3.3.6.1.6

f. Reactor Vessel Water 1,2,3 4 I SR 3.3.6.1.1 t -48.1 inches Level-Low Low, SR 3.3.6.1.2 Level 2 SR 3.3.6.1.3 SR 3.3.6.1.6 SR 3.3.6.1.8

g. Standby Liquid Control 1,2,3 2 L SR 3.3.6.1.6 NA System Initiation

h. Manual Initiation 1,2,3 2 J SR 3.3.6.1.6 NA (c) 2 N SR 3.3.6.1.6 NA (continued)

(c) During movement of recently irradiated fuel assemblies in the primary or secondary containment.

i. Differential 1,2,3 2 I SR 3.3.6.1.1 < 182.4 gpm Flow - High-High SR 3.3.6.1.2 SR 3.3.6.1.6 SR 3.3.6.1.8

j. Differential Flow 1,2,3 2 I SR 3.3.6.1.2 < 47 seconds Timer - High-High SR 3.3.6.1.4 SR 3.3.6.1.6 CLINTON 3.3-59 Amendment No. 216

ATTACHMENT 3 Markup of Technical Specifications Bases Pages Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 REVISED TECHNICAL SPECIFICATIONS BASES PAGES B 3.3-137 B 3.3-154 B 3.3-155 B 3.3-158

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES BACKGROUND 3. Reactor Core Isolation Cooling System Isolation (continued) pressure channels. The outputs from the turbine exhaust diaphragm pressure channels are connected into two two-out-of-two trip systems, each trip system isolating two RCIC valves. There is one manual isolation switch which can isolate only the outboard RCIC System containment isolation valves.

4. Reactor Water Cleanup System Isolation Most Functions receive input from two channels with each channel in one trip system using one-out-of-one logic.

Functions 4.c and 4.d (RWCU Heat Exchanger Room Temperature and RWCU Pump Room Temperature) have one channel in each trip system in each room for a total of four channels for Function 4.c and six channels for Function 4.d, but the logic is the same (one-out-of-one). Each of the two trip systems is connected to one of the two valves on each RWCU penetration so that operation of either trip system isolates the penetration. The exception to this arrangement is the Reactor Vessel Water Level-Low Low, Level 2 Function. This Function receives input from four reactor vessel water level channels. The outputs from the reactor vessel water level channels are connected into two two-out-of-two trip systems, each trip system isolating one of the two RWCU valves.

5. RHR System Isolation The RHR System Isolation Function receives input signals from instrumentation for the Reactor Vessel Water Level-Low Low Low, Level 1; Reactor Vessel Water Level - Low, Level 3; Drywell Pressure - High; Reactor Vessel Pressure - High; RHR Equipment Room Ambient Temperature - High; and Manual Initiation Functions. The Reactor Vessel Water Level-Low Low Low, Level 1; Reactor Vessel Water Level-Low, Level 3; Reactor Steam Dome Pressure-High; and Drywell Pressure-High Functions each have four channels. The outputs from the reactor vessel water level (level 1) and drywell pressure channels are connected in two one-out-of-two twice trip systems. The reactor vessel water level (level 3) is combined with the drywell pressure channels in two one-out-of-two twice trip systems and with the reactor vessel pressure channels in two one-out-of-two twice trip systems.

(continued)

Functions 4.a and 4.i (Differential Flow - High and Differential Flow - High-High) are also exceptions to this arrangement. These Functions have six channels, similar to Function 4.d, but the logic is different (one-out-of-two). If either Function 4.a or Function 4.i activates and remains active beyond the respective time-constraints (detailed in Functions 4.b and 4.j, respectively) the RWCU system will isolate.

CLINTON B 3.3-137 Revision No. 2-8

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES APPLICABLE 4. Reactor Water Cleanup System Isolation SAFETY ANALYSES, LCO, and 4.a. Differential Flow-High APPLICABILITY (continued) The high differential flow signal is provided to detect a break in the RWCU System. This will detect leaks in the RWCU System when area or differential temperature would not provide detection (i.e., a cold leg break). Should the reactor coolant continue to flow out of the break, offsite dose limits may be exceeded. Therefore, isolation of the RWCU System is initiated when high differential flow is sensed to prevent exceeding offsite doses. A time delay is provided to prevent spurious trips during most RWCU operational transients. This Function is assumed to mitigate breaks in the RWCU piping inside containment to preclude subcompartment overpressurization which could lead to containment failure (Ref. 1). This Function is not assumed in any USAR transient or accident analysis for pipe breaks outside containment, since bounding analyses are performed for large breaks such as MSLBs.

The high differential flow signals are initiated from two transmitters that are connected to the inlet (from the reactor vessel) and four transmitters from the outlets (to condenser and feedwater) of the RWCU System. The outputs of the transmitters are compared (in two different summers) and the outputs are sent to two high flow trip units. If the difference between the inlet and outlet flow is too large, each trip unit generates an isolation signal. Two channels of Differential Flow-High Function are available and are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function.

The Reactor Water Cleanup Differential Flow-High Allowable Value ensures that the break of the RWCU piping is detected.

4.b. Differential Flow-Timer Flow Timer - High Flow Timer - High The Differential Flow-Timer is provided to avoid RWCU System isolations due to operational transients (such as pump starts and mode changes). During these transients the inlet and return flows become unbalanced for short time periods and Differential Flow-High will be sensed without an RWCU System break being present. This function is assumed to mitigate breaks in the RWCU piping inside containment to preclude subcompartment overpressurization which could lead to containment failure (Ref. 1). Credit for this Function is not assumed in the USAR accident or transient analysis for pipe breaks outside containment, since bounding analyses are performed for large breaks such as MSLBs.

(continued)

CLINTON B 3.3-154 Revision No. 19-1

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES Flow Timer - High APPLICABLE 4.b. Differential Flow-Timer (continued)

SAFETY ANALYSES, LCO, and The Differential Flow Timer Allowable Value is selected to APPLICABILITY ensure that the MSLB outside containment remains the limiting break for USAR analysis for offsite dose calculations. Flow Timer - High Two channels for Differential Flow-Timer Function are available and are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function.

4.c, 4.d. Ambient Temperature-High Ambient Temperature-High is provided to detect a leak from the RWCU System. The isolation occurs even when very small leaks have occurred and is diverse to the high differential flow instrumentation for the hot portions of the RWCU System. If the small leak continues without isolation, offsite dose limits may be reached. Credit for these instruments is not taken in any transient or accident analysis in the USAR, since bounding analyses are performed for large breaks such as MSLBs.

Ambient temperature signals are initiated from temperature elements that are located in the room that is being monitored (three pump rooms and two heat exchanger rooms).

There are ten thermocouples that provide input to the Area Temperature-High Functions (two per area). Ten channels are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function.

The Ambient Temperature-High Allowable Values are set low enough to detect a leak equivalent to 25 gpm.

4.e. Main Steam Line Tunnel Ambient Temperature-High Ambient Temperature-High is provided to detect a leak in the RCPB and provides diversity to the high flow instrumentation. The isolation occurs when a very small leak has occurred. If the small leak is allowed to continue without isolation, offsite dose limits may be reached. However, credit for these instruments is not taken in any transient or accident analysis, since bounding analyses are performed for large breaks such as MSLBs.

Ambient temperature signals are initiated from thermocouples located in the area being monitored. Two channels of Main (continued)

CLINTON B 3.3-155 Revision No. 0

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES APPLICABLE 4.h. Manual Initiation (continued)

SAFETY ANALYSES, LCO, and irradiated fuel assemblies (i.e., fuel that has occupied APPLICABILITY part of a critical reactor core within the previous 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />) in primary or secondary containment. This Function initiates isolation of valves which isolate primary containment penetrations which bypass secondary containment.

Thus, this Function is also required under those conditions INSERT in which secondary containment is required to be operable.

5. RHR System Isolation 5.a. Ambient Temperature-High Ambient Temperature-High is provided to detect a leak from the associated system steam piping. The isolation occurs when a very small leak has occurred and is diverse to the high flow instrumentation. If the small leak is allowed to continue without isolation, offsite dose limits may be reached. This Function is not assumed in any USAR transient or accident analysis, since bounding analyses are performed for large breaks such as MSLBs.

Ambient Temperature-High signals are initiated from thermocouples that are appropriately located to protect the system that is being monitored. Two instruments monitor each area. Four channels for RHR Ambient Temperature-High Function are available and are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function.

The Allowable Values are set low enough to detect a leak equivalent to 25 gpm.

The RHR Equipment Room Ambient Temperature-High Function is only required to be OPERABLE in MODES 1, 2, and 3. In MODES 4 and 5, insufficient pressure and temperature are available to develop a significant steam leak in this piping and significant water leakage is protected by the Reactor Vessel Water Level-Low, Level 3 Function.

5.b, 5.c. Reactor Vessel Water Level-Low, Level 3 Low RPV water level indicates the capability to cool the fuel may be threatened. Should RPV water level decrease too far, fuel damage could result. Therefore, isolation of some reactor or vessel interfaces occurs to begin isolating the (continued)

CLINTON B 3.3-158 Revision No. 20-2

INSERT 4.i. Differential Flow - High-High The high-high differential flow signal is provided to detect a relatively large break in the RWCU System. This will detect leaks in the RWCU System when area or differential temperature would not provide detection (i.e., a cold leg break). Should the reactor coolant continue to flow out of the break, offsite dose limits may be exceeded. Therefore, isolation of the RWCU System is initiated when high-high differential flow is sensed to prevent exceeding offsite doses. A time delay is provided to prevent spurious trips during most RWCU operational transients. This function is assumed to mitigate breaks in the RWCU piping inside containment to preclude subcompartment overpressurization which could lead to containment failure (Ref. 1). This Function is not assumed in any USAR transient or accident analysis for pipe breaks outside containment, since bounding analyses are performed for large breaks such as MSLBs.

The high-high differential flow signals are initiated from two transmitters that are connected to the inlet (from the reactor vessel) and four transmitters from the outlets (to the condenser and feedwater) of the RWCU System. The outputs of the transmitters are compared (in two different summers) and the outputs are sent to two high-high flow trip units. If the difference between the inlet and outlet flow is too large, each trip unit generates an isolation signal. Two channels of Differential Flow - High-High function are available and are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function.

The RWCU Differential Flow High-High Allowable Value ensures that the large break of the RWCU piping is detected.

4.j. Differential Flow Timer - High-High The Differential Flow-Timer is provided to avoid RWCU System isolations due to operational transients (such as pump starts and mode changes). During these transients the inlet and return flows become unbalanced for short time periods and Differential Flow High-High will be sensed without an RWCU System break being present. This function is assumed to mitigate breaks in the RWCU piping inside containment to preclude subcompartment overpressurization which could lead to containment failure (Ref. 1). Credit for this function is not assumed in the USAR accident or transient analysis for pipe breaks outside containment, since bounding analyses are performed for large breaks such as MSLBs.

The Differential Flow Timer - High-High Allowable Value is selected to ensure that the MSLB outside containment remains the limiting break for USAR analysis for offsite dose calculations.

Two channels for Differential Flow Timer - High-High function are available and are required to be OPERABLE to ensure that no single instrument failure can preclude the isolation function.

ATTACHMENT 4 Design Analysis IP-C-0132, "RWCU Differential Flow Setpoint Analysis for Detecting Large Leaks," Revision 0

CC-AA-309-1001-F-01 Revision 0 Page 1 of 1 Design Analysis Cover Sheet Form Page 1 Design Analysis Last Page No. 6 86, Last Attachment Page: E2 Analysis No.: 1 IP-C-0132 Revision: 2 0 Major Minor

Title:

3 RWCU Differential Flow Setpoint Analysis for Detecting Large Leaks EC No.: 4 636711 Revision: 5 0 Station(s): 7 Clinton Power Station Component(s): 14 Unit No.: 8 01 1G33N035 1E31K602A,B Discipline: 9 INDC 1G33N011 1E31K603A,B Descrip. Code/Keyword: 10 M98 1G33N040 1E31K605A,B Safety/QA Class: 11 SR 1E31N075A,B 1E31K606A,B System Code: 12 LT 1E31N076A,B 1E31N611A,B Structure: 13 N/A 1E31N077A,B CONTROLLED DOCUMENT REFERENCES 15 Document No.: From/To Document No.: From/To Is this Design Analysis Safeguards Information? 16 Yes No If yes, see SY-AA-101-106 Does this Design Analysis contain Unverified Assumptions? 17 Yes No If yes, ATI/AR#: N/A This Design Analysis SUPERCEDES: 18 N/A in its entirety.

Description of Revision (list changed pages when all pages of original analysis were not changed): 19 Initial issue Preparer: 20 Digitally signed by LeRoy W Stahl (0R8005)

LeRoy Stahl LeRoy W Stahl (0R8005) Date: 2023.05.29 06:51:36 -04'00' (only Appendices 4, 5, 6)

Preparer: 20 Digitally signed by David Cujko (entire revision, except Appendices 4, 5, 6)

David Cujko David Cujko DN: cn=David Cujko, email=david.j.cujko@sargentlundy.com, c=US Date: 2023.05.26 13:24:10 -04'00' Print Name Sign Name Date Method of Review: 21 Detailed Review Alternate Calculations Calculatio io ons (attached)

Digitally signed by William Stathis Testing DN: cn=William Stathis, o=Sargent and Lundy, ou, Reviewer: 22 William Stathis email=william.stathis@exeloncorp.com, c=US Date: 2023.05.30 09:14:43 -04'00' Print Name Sign Name Date Review Notes: 23 Independent review Peer review The review was performed in accordance with CC-AA-309 and CC-AA-309-1001. The review comments have been incorporated appropriately.

(For External Analyses Only) Digitally signed by Angelo Emanuele (0L0576)

External Approver: 24 Angelo Emanuele (0L0576) Date: 2023.05.30 15:21:10 -05'00' Print Name Sign Name Date Digitally signed by Ruskowsky, Nicholas J Exelon Reviewer: 25 Ruskowsky, Nicholas J Date: 2023.05.31 09:43:24 -05'00' Print Name Sign Name Date rd Independent 3 Party Review Reqd? 26 Yes No George L. Hughes Digitally signed by George L. Hughes Date: 2023.06.05 09:01:58 -05'00' Digitally signed by Halverson, Eric Donald Exelon Approver: 27 Halverson, Eric Donald Date: 2023.06.24 15:36:58 -05'00' Print Name Sign Name Date

CC-AA-103-1003 Revision 16 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analyses Page 1 of 3 Design Analysis No.: IP-C-0132 ______________________ Rev: 0 ____ Page 1.1 Contract #: 00597084 _______________________________ Release #: 01071 No Question Instructions and Guidance Yes / No / N/A 1 Do assumptions have All Assumptions should be stated in clear terms with enough sufficient documented justification to confirm that the assumption is conservative.

rationale?

For example, 1) the exact value of a particular parameter may not be known or that parameter may be known to vary over the range of conditions covered by the Calculation. It is appropriate to represent or bound the parameter with an assumed value. 2) The predicted performance of a specific piece of equipment in lieu of actual test data. It is appropriate to use the documented opinion/position of a recognized expert on that equipment to represent predicted equipment performance.

Consideration should also be given as to any qualification testing that may be needed to validate the Assumptions. Ask yourself, would you provide more justification if you were performing this analysis? If yes, the rationale is likely incomplete.

Are assumptions Ensure the documentation for source and rationale for the 2 compatible with the assumption supports the way the plant is currently or will be way the plant is operated post change and they are not in conflict with any operated and with the design parameters. If the Analysis purpose is to establish a licensing basis? new licensing basis, this question can be answered yes, if the assumption supports that new basis.

3 Do all unverified If there are unverified assumptions without a tracking assumptions have a mechanism indicated, then create the tracking item either tracking and closure through an ATI or a work order attached to the implementing mechanism in place? WO. Due dates for these actions need to support verification prior to the analysis becoming operational or the resultant plant change being op authorized.

4 Do the design inputs The origin of the input, or the source should be identified and have sufficient be readily retrievable within Exelons documentation system.

rationale? If not, then the source should be attached to the analysis. Ask yourself, would you provide more justification if you were performing this analysis? If yes, the rationale is likely incomplete.

5 Are design inputs The expectation is that an Exelon Engineer should be able to correct and reasonable clearly understand which input parameters are critical to the with critical parameters outcome of the analysis. That is, what is the impact of a identified, if change in the parameter to the results of the analysis? If the appropriate? impact is large, then that parameter is critical.

6 Are design inputs Ensure the documentation for source and rationale for the compatible with the inputs supports the way the plant is currently or will be way the plant is operated post change and they are not in conflict with any operated and with the design parameters.

licensing basis?

CC-AA-103-1003 Revision 16 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analyses Page 2 of 3 Design Analysis No.: IP-C-0132 ______________________ Rev: 0 ____ Page 1.2 No Question Instructions and Guidance Yes / No / N/A 7 Are Engineering See Section 2.13 in CC-AA-309 for the attributes that are Judgments clearly sufficient to justify Engineering Judgment. Ask yourself, documented and would you provide more justification if you were performing justified? this analysis? If yes, the rationale is likely incomplete.

8 Are Engineering Ensure the justification for the engineering judgment Judgments compatible supports the way the plant is currently or will be operated with the way the plant is post change and is not in conflict with any design operated and with the parameters. If the Analysis purpose is to establish a new licensing basis? licensing basis, then this question can be answered yes, if the judgment supports that new basis.

9 Do the results and Why was the analysis being performed? Does the stated conclusions satisfy the purpose match the expectation from Exelon on the proposed purpose and objective of application of the results? If yes, then the analysis meets the Design Analysis? the needs of the contract.

10 Are the results and Make sure that the results support the UFSAR defined conclusions compatible system design and operating conditions, or they support a with the way the plant is proposed change to those conditions. If the analysis operated and with the supports a change, are all of the other changing documents licensing basis? included on the cover sheet as impacted documents?

11 Have any limitations on Does the analysis support a temporary condition or the use of the results procedure change? Make sure that any other documents been identified and needing to be updated are included and clearly delineated in transmitted to the the design analysis. Make sure that the cover sheet appropriate includes the other documents where the results of this organizations? analysis provide the input.

12 Have margin impacts Make sure that the impacts to margin are clearly shown been identified and within the body of the analysis. If the analysis results in documented reduced margins ensure that this has been appropriately appropriately for any dispositioned in the EC being used to issue the analysis.

negative impacts (Reference ER-AA-2007)?

13 Does the Design Are there sufficient documents included to support the Analysis include the sources of input, and other reference material that is not applicable design basis readily retrievable in Exelon controlled Documents?

documentation?

14 Have all affected design Determine if sufficient searches have been performed to analyses been identify any related analyses that need to be revised along documented on the with the base analysis. It may be necessary to perform Affected Documents List some basic searches to validate this.

(ADL) for the associated Configuration Change?

15 Do the sources of inputs Compare any referenced codes and standards to the current and analysis design basis and ensure that any differences are reconciled.

methodology used meet If the input sources or analysis methodology are based on committed technical and an out-of-date methodology or code, additional reconciliation regulatory may be required if the site has since committed to a more requirements? recent code

CC-AA-103-1003 Revision 16 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analyses Page 3 of 3 Design Analysis No.: IP-C-0132 ______________________ Rev: 0 ____ Page 1.3 No Question Instructions and Guidance Yes / No / N/A 16 Have vendor supporting Based on the risk assessment performed during the pre-job technical documents brief for the analysis (per HU-AA-1212), ensure that and references sufficient reviews of any supporting documents not provided (including GE DRFs) with the final analysis are performed.

been reviewed when necessary?

17 Do operational limits Ensure the Tech Specs, Operating Procedures, etc. contain support assumptions operational limits that support the analysis assumptions and and inputs? inputs.

18 Are the critical Identify the critical sections of the product and ensure those Yes No characteristics/attributes critical sections are not omitted and have sufficient detail to of the product support acceptability.

addressed acceptably?

Create an SFMS entry as required by CC-AA-4008. SFMS Number: ___________________ #73988

FORM PI-EXLN-003-3 Revision 0 Analysis No. IP-C-0132, Revision 0 Page 1.4 Licensed Engineer Certification Page Page 1 of 1 CERTIFICATION OF CALCULATION NUMBER(s): IP-C-0132, Revision 0 I certify that the Calculation(s) listed above was prepared by me or under my personal supervision or developed in conjunction with the use of accepted engineering standards and that I am a Licensed Structural Engineer under the laws of the State of Illinois.

cn=Aleksandar Z. Avramov, o=Sargent & Lundy, ou=NPG, email=Aleksandar.Z.Avramov@sarge ntlundy.com, c=US 2023.05.30 15:35:13 -05'00' 5/30/23 Certified by: __________________________________ Date: ___________________________

Seal Below Digitally signed by Aleksandar Z.

Avramov ESSION OF AL DN: cn=Aleksandar Z.

PR GINEER Avramov, o=Sargent LICENSED EN ALEKSANDAR Z. AVRAMOV & Lundy, ou=NPG, 062.072097 email=Aleksandar.Z.

Avramov@sargentlun dy.com, c=US Date: 2023.05.30 15:36:19 -05'00' 11/30/23 Expires: _______________

Sargent & Lundy LLC Illinois Department of Professional Regulation Registration Number is: 184-000106

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 2 of 86 TABLE OF CONTENTS SECTION PAGE NO.

DESIGN ANALYSIS COVER SHEET 1 OWNERS ACCEPTANCE REVIEW CHECKLIST FOR EXTERNAL DESIGN ANALYSES 1.1 - 1.3 LICENSED ENGINEER CERTIFICATION PAGE 1.4 TABLE OF CONTENTS 2 1.0 PURPOSE / OBJECTIVE 3 2.0 ASSUMPTIONS 4 3.0 METHODOLOGY AND ACCEPTANCE CRITERIA 6 4.0 INPUTS 7 5.0 OUTPUTS 10

6.0 REFERENCES

11 7.0 ANALYSIS AND COMPUTATION SECTIONS(S) 12 8.0 RESULTS 56

9.0 CONCLUSION

S 60 APPENDICES 1 APPENDIX 1 Scaling Equation for Summer 1E31-K606A&B 63 2 APPENDIX 2 Transfer Function for Square Root Extractors 1E31-K602A&B, 64 1E31-K603A&B, 1E31-K605A&B 3 APPENDIX 3 Transfer Function for Summer 1E31-N611A&B 67 4 APPENDIX 4 Operating Flow Rates 68 5 APPENDIX 5 Flow Element Uncertainty 72 6 APPENDIX 6 Process Measurement Accuracy (PMA) 85 ATTACHMENTS A Excerpt from Curtiss-Wright Qualification Report NUS-A042QA,Revision 0, (6 pages)

SAM/DAM2000-745 Signal/Dual Alarm Qualification Report (from Input 4.3.4)

B Excerpt from Curtiss-Wright Equivalency Review NUS-A042SA, Revision 1, (5 pages)

Equivalency Review for SAM/DAM2000-745 Signal/Dual Alarm Modules (from Input 4.3.5)

C Excerpt from Curtiss-Wright vendor information for the SUM2000-752 Four-Input (2 pages)

Summer (from Input 4.3.8)

D Excerpt from Rosemount Product Data Sheet 00813-0100-4853, Rev. AF, Rosemount (8 pages) 3153N Nuclear Qualified Pressure Transmitter (from Input 4.3.1)

E Correspondence Regarding Rosemount 3150 Series Nuclear Pressure Transmitter (2 pages)

Performance Specifications (Input 4.3.25)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 3 of 86 1.0 PURPOSE / OBJECTIVE This calculation is issued in support of EC Number 636711 (Input 4.1).

This calculation determines the nominal trip setpoint (NTSP), technical specification allowable value (AV), loop as-found tolerance (AFTL), and loop as-left tolerance (ALTL) for the Reactor Water Cleanup (RWCU) differential flow setpoint function that protects against exceeding the 235 gpm analytical limit (AL) as credited in Chapter 15 of the USAR (Input 4.1). As such, the calculation is prepared in accordance with Reference 6.1 for a setpoint category 1 function.

This calculation pertains to the following instrument:

Inlet Flow to RWCU 1G33-N035 Flow Element 1E31-N076A/B Flow Transmitters*

1E31-K602A/B Square Root Extractors RWCU Flow to Main Condenser 1G33-N011 Flow Element 1E31-N075A&B Flow Transmitters*

1E31-K605A&B Square Root Extractors RWCU Flow to Feedwater System 1G33-N040 Flow Element 1E31-N077A&B Flow Transmitters*

1E31-K603A&B Square Root Extractors 1E31-K606A&B Flow Summers (Differential Flow) 1E31-N611A&B Differential Flow Trip Bistables (High)

• Note: The three (3) A channel transmitter output current signals pass through device number 1E31-SRU1 and the three (3) B channel transmitter output currents pass through device number 1E31-SRU2. These devices are signal resistor units (SRUs) which are shown on elementary drawing E02-1LD99, Sheet 107 (Input 4.2.3). The SRUs are GE part number 195B9537P004 per Elementary Diagram Device List (EDDL) DL851E602AC (Input 4.3.24). Note that the 4-20 mA transmitter output signals pass through the SRU resistor circuitry to provide a 1-5 vdc input signal to the square root extractors. Errors associated with the SRUs are calibrated out of the instrument loops during calibration (Inputs 4.9.1 and 4.9.2), and therefore, SRU errors need not be considered within this analysis.

The above-listed square root extractors are existing devices. The above-listed summers and trip bistables are new devices that are implemented per Input 4.1. The above-listed transmitters replace the existing transmitters, and the replacement transmitters have a vendor reference accuracy that is better than that of the replaced transmitters (per Input 4.1). As such, this calculation will also determine calibration adjustment and calibration check / verification requirements for only the above-listed summers and trip bistables.

This analysis is limited to the leakage that can occur between the above-listed flow elements. Any leakage that might occur beyond the bounds of the above-listed flow elements is not considered by this analysis. [See Section 3.5, Methodology.]

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 4 of 86 This calculation will address only normal operating process and normal operating environmental conditions (see Section 3.6, Methodology). This calculation will consider seismic error effects during and after an SSE, because the analyzed setpoint is required to initiate RWCU primary containment isolation (Input 4.1 and Reference 6.5.1).

2.0 ASSUMPTIONS 2.1 3XEOLVKHGLQVWUXPHQWYHQGRUVSHFLILFDWLRQVDUHFRQVLGHUHGWREHYDOXHVXQOHVVVSHFLILFLQIRUPDWLRQLV

available to indicate otherwise. [Reference 6.1, Appendix I,Section I.11]

2.2 Temperature, humidity, power supply, and ambient pressure errors have been incorporated when provided by the manufacturer. Otherwise, these errors are assumed to be included in the manufacturer's accuracy or repeatability specifications. [Reference 6.1, Appendix I,Section I.11]

2.3 Changes in ambient humidity are assumed to have a negligible effect on the uncertainty of the instruments used in these loops. [Reference 6.1, Appendix I,Section I.11]

2.4 Normal radiation induced errors have been incorporated when provided by the manufacturer. Otherwise, these errors are assumed to be small and capable of being adjusted out each time the instrument is calibrated. Therefore, unless specifically provided, normal radiation errors can be assumed to be included within the instrument drift errors. [Reference 6.1, Appendix I,Section I.11]

2.5 If the manufacturers instrument performance data does not specify span, calibrated span, upper range limit, etc., the calculation will assume URL because it will result in the most conservative estimate of instrument uncertainty. In all cases, the URL is greater than or equal to the calibrated span (CS) and it is conservative to use the URL in calculating instrument uncertainties. This is because, by definition, URL is the maximum upper calibrated span limit for the device. [Reference 6.1, Appendix I,Section I.11]

2.6 This analysis assumes that the instrument power supply stability (PSS) is within +/-5% (+/-1.2 Vdc) of a nominal 24 Vdc. [Reference 6.1, Appendix I,Section I.11]

2.7 The effects of normal vibration (or a minor seismic event that does not cause an unusual event) on a component are assumed to be calibrated out on a periodic basis. As such, the uncertainty associated with this effect is assumed to be negligible and included within the instrument drift errors. Abnormal vibrations, e.g., levels that produce noticeable effects on equipment, are considered abnormal events that require maintenance or equipment modification. [Reference 6.1, Appendix I,Section I.11]

2.8 It is assumed that calibration tool errors are equal to, or better than, the vendor accuracy (VA) of the calibrated instrument to satisfy a 1:1 accuracy ratio to the instrument under calibration; and furthermore, calibration tool errors are FRQVLGHUHGWREHDYDOXHUHJDUGOHVVRIWKHFRQILGHQFHDVVRFLDWHGZLWKWKH

related VA term. [Reference 6.1, Appendix I, Assumption 2.11]

2.10 The effects of EMI and RFI are considered negligible for panel mounted meters in administratively controlled EMI/RFI environments, unless a specific uncertainty term is provided by the vendor.

[Reference 6.1, Appendix I,Section I.11]

2.11 If the instrument vendor provides no drift information and there is no clear basis for assuming drift is zero, it is assumed that the drift over the entire calibration period equals either; 1) vendor accuracy (i.e.,

VD = VA,  or +/- 0.5% of span (Reference 6.1, Appendix A, Section A.2.6). The method that provides bounding results will be applied in this analysis.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 5 of 86 2.12 Surveillance Testing Assumptions 2.12.1 Calibration Adjustments:

2.12.1.1 It is assumed that the calibration adjustments for the summer (1E31-K606A&B) are performed using the same method that is currently used for summer (1E31-K604A&B) which is described in Section 8.17 of Input 4.9.1. This method is defined as applying three (3) simulated 1 to 5 vdc input test voltages at input of the summer, while monitoring the summer output voltages for proper readings within an acceptable as-left tolerance.

2.12.1.2 It is assumed that the calibration adjustments for trip bistable (1E31-N611A&B) are performed using the same method that is currently used for trip bistable (1E31-N609A&B) which is described in Section 8.19 of Input 4.9.1. This method is defined as slowly raising a simulated input test voltage at the input of the trip bistable, while monitoring the trip bistable output for trip actuation within an acceptable as-left tolerance.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 6 of 86 3.0 METHODOLOGY AND ACCEPTANCE CRITERIA 3.1 This calculation is in accordance with CI-01.00, Instrument Setpoint Calculation Methodology, for a Setpoint Category 1 function. [Reference 6.1]

3.2 There are no acceptance criteria associated with the calculation results. Calculation results are to be implemented as determined.

3.3 Not Used 3.4 If a component of error contains both random and non-random components, the random component is LQGLFDWHGE\D³'SUHIL[DQGDQRQ-random component of error is indicated by a e prefix. Example:

A = random component of accuracy eA = non-random component of accuracy This is noted so that random and non-random errors can be considered separately when propagating errors through the square root extractor and summers as illustrated by Figure 1 of Section 7.2 and as defined by Appendix 2 (Equations 2.4 and 2.5) and Appendix 3 (Equations 3.1 and 3.2).

3.5 This analysis is limited to the leakage that can occur between the RWCU inlet flow element (1G33-N035) and the two (2) discharge flow elements (condenser discharge flow element 1G33-N011 and feedwater discharge flow element 1G33-N040). Any leakage that might occur beyond the bounds of the above-listed flow elements is not considered by this analysis. [Input 4.1]

3.6 The analyzed setpoint function is only required to operate during normal plant environments for power generation purposes (Input 4.1). Credit for the analyzed differential flow setpoint is considered in the safety analysis for isolating High Energy Line Breaks that are not otherwise detected by area temperature monitors (Input 4.1). The analyzed setpoint function will isolate large leaks. The differential flow setpoint for small leaks will ensure that the MSLB outside containment remains the limiting break for the USAR analysis for offsite dose calculations (Input 4.1 and Reference 6.5.1).

3.7 This analysis evaluates the effects of instrument loop errors at the following operating flow rates through each flow element. The bases for these operating flow rates is provided in Appendix 4.

Function Equipment Tag No. Operating Flow Rate Flow to Condenser 1G33-N011 0 Inlet Flow: 1G33-N035 327.24 gpm Flow to Feedwater 1G33-N040 92.24 gpm

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 7 of 86 4.0 INPUTS 4.1 Engineering Change (EC) 636711, Rev. 0, RWCU Differential Flow Modification 4.2 CPS Drawings 4.2.1 M10-9076, Sheet 2, Rev. B, P&ID/C&ID Diagram Reactor Water Clean-Up Sys. (RT) 4.2.2 M10-9076, Sheet 7, Rev. A, P&ID/C&ID Diagram Reactor Water Clean-Up Sys. (RT) 4.2.3 E02-1LD99, Sheet 107, Rev. G, Schematic Diagram Leak Detection System (LD) Leak Detection System (1E31-1050) 4.2.4 M06-1076, Sheet 11, Rev. Z, Reactor Water Cleanup 4.2.5 M06-1076, Sheet 15, Rev. AA, Reactor Water Cleanup 4.2.6 M27-1601-01A-K, Rev. Z, Control and Instr. Piping, Drywell - Area 1, EL 737-0 4.2.7 Isometric Piping Drawing RT19, Revision 5, RLN-016-87 4.3 Vendor Technical Information 4.3.1 Rosemount Product Data Sheet 00813-0100-4853, Rev. AF, Rosemount 3153N Nuclear Qualified Pressure Transmitter (see Attachment D for excerpt) 4.3.2 VTIP Manual 4575K10-100A, Installation & Service Manual, Type 750 Square Root Extractor (Factory Style 2) 4.3.3 VTIP Manual 4575K10-300F, Service Manual, Type 750 Square Root Extractor 4.3.4 Curtiss-Wright Qualification Report NUS-A042QA, Revision 0, SAM/DAM2000-745 Signal/Dual Alarm Qualification Report (see Attachment A for excerpt) 4.3.5 Curtiss-Wright Equivalency Review NUS-A042SA, Revision 1, Equivalency Review for SAM/DAM2000-745 Signal/Dual Alarm Modules (see Attachment B for excerpt) 4.3.6 Design Specification Data Sheet 22A3735AC, Rev.13, Leak Detection System Design Specification Data Sheet 4.3.7 Field Deviation Disposition Request (FDDR) No. LH1-5596, Rev. 0, Recalibrate Transmitters E31-N076A/B and E31-N077A/B for Water Temperature at 125° F 4.3.8 Curtiss-Wright vendor information for the SUM2000-752 Four-Input Summer (see Attachment C for excerpt) 4.3.9 Not Used 4.3.10 Drawing DL851E703AC, Rev. 26, Reactor Water Clean-up System EDDL (Elementary Diagram Device List) 4.3.11 Permutit Instruction Manual P175-000003, Flow Metering Section (1G33-N035)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 8 of 86 4.3.12 Permutit Drawing 556-30121, Rev. 3, Outline and Assembly Drawing 6 Flow Element 98VA0 4.3.13 Not Used 4.3.14 Purchase Specification Data Sheet 21A3544AA, Rev. 4, Flow Element, (Venturi) Reactor Water Cleanup 4.3.15 Purchase Specification Data Sheet 21A3548AA, Rev. 3, Flow Orifice Assembly 4.3.16 Purchase Specification Data Sheet 21A3548AC, Rev. 4, Flow Orifice Assembly 4.3.17 Drawing W7820044, 4 - 600 Carbon Steel Flex Wedge Gate Valve with SMB-00 and Indicator 4.3.18 Drawing 93-14647, Rev. A, 4 - 900 Weld Ends, Carbon Steel Wedge Gate Valve with SMB-00 Limitorque 4.3.19 Drawing VPF-5214-033, Rev. 002, Orifice Flange Union & MK-52 Orifice Plate (4 RF-WN 600# ASA) 4.3.20 Drawing VPF-5214-034, Rev. 003, Orifice Flange Union & MK-52 Orifice Plate (4 RF-WN 900# ASA) 4.3.21 Field Deviation Disposition Request (FDDR) No. LH1-5014, Rev. 0, Flow Curve for 1G33-N040 4.3.22 Permutit Curve 528-52486, N035 Calibration Curve 4.3.23 Permutit Curve 528-52489, N035 Temperature Curve 4.3.24 Drawing DL851E602AC, Rev. 26, Leak Detection System EDDL (Elementary Diagram Device List) 4.3.25 Correspondence regarding Rosemount 3150 Series Nuclear Pressure Transmitter Performance Specifications (Attachment E) 4.4 System Design Criteria 4.4.1 DC-ME-09-CP, Rev. 13, Equipment Environmental Design Conditions Design Criteria 4.5 Passport Information Obtained (Current Information) 4.5.1 Equipment Tags (Inlet Flow to RWCU):

1G33-N035 Flow Element 1E31-N076A&B Flow Transmitters 1E31-K602A&B Square Root Extractors 4.5.2 Equipment Tags (RWCU Flow to Main Condenser):

1G33-N011 Flow Element 1E31-N075A&B Flow Transmitters 1E31-K605A&B Square Root Extractors 4.5.3 Equipment Tags (RWCU Flow to Feedwater System):

1G33-N040 Flow Element 1E31-N077A&B Flow Transmitters 1E31-K603A&B Square Root Extractors

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 9 of 86 4.6 Calculations 4.6.1 Not Used 4.6.2 Calculation EPU-T0100, Rev. 0A, Extended Power Uprate Task T0100; Reactor Heat Balance 4.7 Equipment Qualification 4.7.1 Not Used 4.7.2 SQ-CL603, Rev. 16, Qualification for MCR Panels 4.7.3 Not Used 4.8 CPS Technical Specifications, Amendment 247, Surveillance Requirement (SR) SR 3.0.2 4.9 CPS Calibration Procedures 4.9.1 CPS 9432.19, Rev. 36a5:&8)ORZ(-N075A / 076A / 077A Channel Calibration 4.9.2 CPS 9432.20, Rev. 35e5:&8)ORZ(-N075B / 076B / 077B Channel Calibration; and the associated Channel Calibration Data Sheet (CPS 9432.20D001, Rev. 34a) 4.10 Instrument Data Sheets 4.10.1 PT036, Rev. F, Differential Pressure Transmitters, Instrument Data Sheet for 1E31N075A&B and 1E31N076A&B 4.10.2 PT037, Rev. E, Differential Pressure Transmitters, Instrument Data Sheet for 1E31N077A&B 4.11 CPS Operating Procedure 3303.01, Rev. 039C, Reactor Water Cleanup (RT)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 10 of 86 5.0 OUTPUTS 5.1 CPS Procedures 5.1.1 &365HYD5:&8)ORZ(-N075A / 076A / 077A Channel Calibration 5.1.2 &365HYH5:&8)ORZ1E31-N075B / 076B / 077B Channel Calibration; and the associated Channel Calibration Data Sheet (CPS 9432.20D001, Rev. 34a) 5.2 CPS Operational Requirements Manual (ORM), Rev. 94 5.2.1 Attachment 2, Table 7, Item 4.a, Reactor Water Cleanup (RWCU) System Isolation - Differential Flow High

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 11 of 86

6.0 REFERENCES

6.1 CI-01.00, Rev. 4, Instrument Setpoint Calculation Methodology 6.2 Meyer, C. A., McClintock, R. B., Silvestri, G. J., Spencer, Jr., R. C., Thermodynamic and Transport Properties of Steam Comprising Tables and Charts for Steam and Water, The American Society of Mechanical Engineers, New York, New York, 1967 6.3 ASME MFC-3M-1989, Measurement of Fluid Flow in Pipes Using Orifice, Nozzle and Venturi 6.4 ANSI/ASME PCT 19.1-1985, Measurement Uncertainty 6.5 CPS Technical Specification, Amendment 245 6.5.1 Section 3.3.6.1, Primary Containment and Drywell Isolation Instrumentation 6.5.1.1 Table 3.3.6.1-1, Item 4.a, RWCU System Isolation, Differential Flow - High 6.6 CPS USAR, Rev. 21, Section 7.6.1.4, Leak Detection System - Instrumentation and Controls 6.7 Chemical Rubber Company Handbook of Tables for Applied Engineering Science, 1970 6.8 ASME PTC 19.5-2004, Flow Measurement 6.9. The Engineering Tool Box, www.engineeringtoolbox/water

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 12 of 86 7.0 ANALYSIS AND COMPUTATION SECTIONS(S) 7.1 Loop Function The function of the subject instrument loop (as illustrated below in Section 7.2) is to provide a trip output on high RWCU differential flow for the purpose of detecting large RWCU leakage. [Input 4.1]

7.2 Loop Diagram and Environmental Data

[from Inputs 4.1, 4.2.3, 4.3.6, 4.5.1, 4.5.2, 4.5.3, 4.9.1, 4.9.2, 4.10.1, 4.10.2]

NOTE: For further instrument loop configuration information, see Section 1.0 for the discussion regarding GE signal resistor units (SRUs).

RWCU RWCU Inlet Flow to Flow To Condenser Flow to Feedwater RWCU FE FE FE G33-N011 G33-N040 G33-N035 0 to 216 inwc 0 to 197.5 inwc 0 to 291.6 inwc 0 to 260 gpm 0 to 350 gpm 0 to 350 gpm FT FT FT E31-N075A E31-N077A E31-N076A

[E31-N075B] [E31-N077B] [E31-N076B]

H22-P017 H22-P004

[H22-P055] Local [H22-P015]

MCR Pnl Racks 4 to 20 mA 4 to 20 mA 4 to 20 mA SRU E31-SRU1 [E31-SRU2]

1 to 5 vdc 1 to 5 vdc 1 to 5 vdc SQR SQR SQR E31-K605A E31-K603A E31-K602A

[E31-K605B] [E31-K603B] [E31-K602B]

1 to 5 vdc 1 to 5 vdc Summer 1 to 5 vdc E31-K606A

[E31-K606B]

Trip Output on Trip Bistable High E31-N611A H13-P632A 1 to 5 vdc

)ORZ [E31-N611B] [H13-P642A]

Figure 1 Brackets [ ] indicate Channel B equipment numbers.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 13 of 86 1E31N075A 1E31N077A Environmental Zone Aux. Bldg. H13, Inputs 4.4.1, 4.5.2, 4.5.3 Map Code A.1.8 Normal Temperature 40 to 110°F Input 4.4.1 Normal Humidity 5 to 90% RH Input 4.4.1 Normal Radiation 1.0E4 Rads Input 4.4.1 Shutdown Temperature 40 to 145°F Input 4.4.1 Shutdown Humidity 100% RH Input 4.4.1 1E31N075B 1E31N077B Environmental Zone Aux. Bldg. H11, Inputs 4.4.1, 4.5.2, 4.5.3 Map Code A.1.4 Normal Temperature 40 to 104°F Input 4.4.1 Normal Humidity 5 to 90% RH Input 4.4.1 Normal Radiation 1.0E4 Rads Input 4.4.1 Shutdown Temperature 40 to 118°F Input 4.4.1 Shutdown Humidity 100% RH Input 4.4.1 1E31N076A 1E31N076B Environmental Zone Cont. Bldg. H26, Inputs 4.4.1, 4.5.1 Map Code C.3.1 Normal Temperature 65 to 104°F Input 4.4.1 Normal Humidity 5 to 90% RH Input 4.4.1 Normal Radiation 1.0E4 Rads Input 4.4.1 1E31K602A&B 1E31K603A&B 1E31K605A&B 1E31K606A&B 1E31N611A&B Environmental Zone MCR M24, Inputs 4.1, 4.4.1, 4.5.1. 4.5.2, 4.5.3 Map Code D.6.2 Normal Temperature 65 to 104°F Input 4.4.1 Normal Humidity 5 to 60% RH Input 4.4.1 Normal Radiation 1.0E3 Rads Input 4.4.1 Seismic SQ-CL603 Input 4.7.2

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 14 of 86 7.3 Equations The following equations are from Reference 6.1. As used in the following equations, N represents the number of standard deviations with which the value is evaluated to (normally 2 standard deviations) and n represents the sigma value for each device. The individual terms and acronyms are defined in Reference 6.1.

7.3.1 Loop Accuracy (AL):

AL is defined as:

A = +/-A + A + A +. . . +/- B ()

Derived from the SSRS combination of loop components, where error attributed for each loop component is evaluated by:

VA ATE OPE SPE SE

+ + + +

A = +/-N n n n n n +/-B ()

RE HE PSE REE

+ + + +

n n n n 7.3.2 Loop Calibration Error (CL):

ALT C C C = +/-N + + ()

n n n 7.3.3 Loop Drift (DL):

D D D D = +/-N + +. . . + ()

n n n 7.3.4 Allowable Value (AV):

The allowable value may be calculated for an increasing trip as follows:

AV = AL - 1.645/N (SRSS of Random Terms) - Bias Terms This equation may be expressed as follows:

1.645 AV() = AL PMA + PEA + A B N

The allowable value may be calculated for a decreasing trip as follows:

AV = AL + 1.645/N (SRSS of Random Terms) + Bias Terms This equation may be expressed as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 15 of 86 1.645 AV() = AL + PMA + PEA + A + B N

Note: An (1.645/N) adjustment is applicable to setpoints that have a limit approach in one (1) direction (single sided interest).

7.3.5 Nominal Trip Setpoint (NTSP):

NTSP(INC) =AV - AFTL NTSP(DEC) =AV + AFTL 7.3.6 Device As-Found Tolerance (AFTi):

ALT D C AFT = +/-(N) + + ()

n n n Where:

ALTi = device As-Left Tolerance Di = device drift value Ci = errors of M&TE used to calibrate the device 7.3.7 Loop As-Found Tolerance (AFTL):

C D AFT = +/-(N) + ()

n n Where:

DL = loop device drift value, as defined in Section 7.3.3 CL = loop device calibration effect, as defined in Section 7.3.2 7.3.8 Device As-Found Tolerance (AFTi):

ALTi = +/-VAi 

7.3.9 Loop As-Left Tolerance (ALTL):

ALT ALT ALT ALT = +/-(N) + +. . . + ()

n n n

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 16 of 86 7.4 Determination of Uncertainties 7.4.1 Flow Transmitters (1E31-N075A&B, -N076A&B, -N077A&B):

x From Input 4.1, flow transmitters are Rosemount 3153ND2T for tags E31-N075A&B and E31-N077A&B and Rosemount 3153ND3T for tags E31-N076A&B, with all transmitters configured with Damping set for time response = 0.4 sec or greater.

Per Input 4.3.1:

URL for transmitters with range code of 2 = 250 inwc [E31-N075A/B and E31-N077A/B]

URL for transmitters with range code of 3 = 1000 inwc [E31-N076A&B]

Transmitter output code T = continuously adjustable damping x From Figure 1 of Section 7.2, calibrated input and output ranges are as follows:

Flow to condenser FT 1E31-N075A&B: input range of 0 to 216 inwc (span = 216 inwc) directly corresponding to output range of 4 to 20 mA (span = 16 mA) and 0 to 260 gpm RWCU inlet flow FT 1E31-N076A&B: input range of 0 to 291.6 inwc (span = 291.6 inwc) directly corresponding to output range of 4 to 20 mA (span = 16 mA) and 0 to 350 gpm Flow to feedwater FT 1E31-N077A&B: input range of 0 to 197.5 inwc (span = 197.5 inwc) directly corresponding to output range of 4 to 20 mA (span = 16 mA) and 0 to 350 gpm 7.4.1.1 Flow Transmitter Vendor Accuracy (VAFT)

Per Inputs 4.3.1 and 4.3.25, VAFT is determined for each transmitter as follows:

VAFT = +/-0.2% span >@

From Section 7.4.1, the output range for each transmitter is 4 to 20 mA (span = 16 mA). As such, VAFT = +/-0.2% * (16 mA)

VAFT = +/-0.032 mA >@

7.4.1.2 Flow Transmitter Accuracy Temperature Effect (ATEFT)

Per Inputs 4.3.1 and 4.3.25:

ATEFT = +/-(0.15%*URL + 0.6%*VSDQ 7  ) >@

By application of transmitter calibrated input spans and URLs from above Section 7.4.1, ATEFT for each transmitter is determined as follows:

a) Flow to condenser (FT 1E31-N075A&B), span = 216 inwc & URL = 250 inwc Per SHFWLRQWKHPD[LPXPERXQGLQJDPELHQWWHPSHUDWXUHFKDQJH 7 DWWUDQVPLWWHU

ORFDWLRQVLV 7LV)- 40°F = 70°F for 1E31-N075A).

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 17 of 86 ATEFT = +/-[0.15%*250 inwc + 0.6%*216 inwc]*(70°F)/(100°F)

ATEFT = +/-1.169700 inwc From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

ATEFT = +/-[(1.169700 inwc)*(16 mA)/(216 inwc)]

ATEFT = +/-0.086644 mA >@

b) RWCU inlet flow (FT 1E31-N076A&B), span = 291.6 inwc & URL = 1000 inwc Per SHFWLRQWKHPD[LPXPERXQGLQJDPELHQWWHPSHUDWXUHFKDQJH 7 DWWUDQVPLWWHU

ORFDWLRQVLV 7LV)- 65°F = 39°F for 1E31-N076A&B).

ATEFT = +/-[0.15%*1000 inwc + 0.6%*291.6 inwc]*(39°F)/(100°F)

ATEFT = +/-1.267344 inwc From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

ATEFT = +/-[(1.267344 inwc)*(16 mA)/(291.6 inwc)]

ATEFT = +/-0.069539 mA >@

c) Flow to feedwater (FT 1E31-N077A&B), span = 197.5 inwc & URL = 250 inwc Per SHFWLRQWKHPD[LPXPERXQGLQJDPELHQWWHPSHUDWXUHFKDQJH 7 DWWUDQVPLWWHU

ORFDWLRQVLV 7LV)- 40°F = 70°F for 1E31-N077A).

ATEFT = +/-[0.15%*250 inwc + 0.6%*197.5 inwc]*(70°F)/(100°F)

ATEFT = +/-1.092000 inwc From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

ATEFT = +/-[(1.092000 inwc)*(16 mA)/(197.5 inwc)]

ATEFT = +/-0.088466 mA >@

7.4.1.3 Flow Transmitter Overpressure Effect (OPEFT)

Per Section 1.0, this analysis considers only normal operating process conditions. Therefore, OPEFT = 0 7.4.1.4 Flow Transmitter Static Pressure Effect (SPEFT) 7.4.1.4.1 Zero Static Pressure Effect (SPEZ FT)

Per Inputs 4.3.1 and 4.3.25, the zero static pressure effect for transmitters with range codes of 2 and 3 for high static line pressure less than or equal to 2000 psi* is:

SPEZ FT = +/-(0.1%*URL)*(PD[operating pressure) / (1000 psi) >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 18 of 86

• Note: Per Appendix 4, the static operating pressure for each transmitter is less than 2000 psi.

By application of transmitter calibrated spans and URLs from above Section 7.4.1, SPEZ FT for each transmitter is determined as follows:

a) Flow to condenser (FT 1E31-N075A&B), span = 216 inwc & URL = 250 inwc From Appendix 4, operating pressure is 1250 psig. Therefore, SPEZ FT = +/-(0.1%*250 inwc)*[(1250 psig í)/(1000 psi)]

SPEZ FT = +/-0.312500 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SPEZ FT = +/-[(0.312500 inwc)*(16 mA)/(216 inwc)]

SPEZ FT = +/-0.023148 mA >@

b) RWCU inlet flow (FT 1E31-N076A&B), span = 291.6 inwc & URL = 1000 inwc From Appendix 4, operating pressure is 1100 psig. Therefore, SPEZ FT = +/-(0.1%*1000 inwc)*[(1100 psig í)/(1000 psi)]

SPEZ FT = +/-1.100000 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SPEZ FT = +/-[(1.100000 inwc)*(16 mA)/(291.6 inwc)]

SPEZ FT = +/-0.060357 mA >@

c) Flow to feedwater (FT 1E31-N077A&B), span = 197.5 inwc & URL = 250 inwc From Appendix 4, operating pressure is 1250 psig. Therefore, SPEZ FT = +/-(0.1%*250 inwc)*[(1250 psig í)/(1000 psi)]

SPEZ FT = +/-0.312500 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SPEZ FT = +/-[(0.312500 inwc)*(16 mA)/(197.5 inwc)]

SPEZ FT = +/-0.025316 mA >@

7.4.1.4.2 Span Static Pressure Effect (SPES FT)

Per Inputs 4.3.1 and 4.3.25, the span static pressure effect for transmitters with range codes of 2 and 3 is:

SPES FT = +/-(0.1%*URL + 0.1%*span)*(PD[operating pressure) / (1000 psi) >@

By application of transmitter calibrated spans and URLs from above Section 7.4.1, SPES FT for each transmitter is determined as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 19 of 86 a) Flow to condenser (FT 1E31-N075A&B), span = 216 inwc & URL = 250 inwc From Appendix 4, operating pressure is 1250 psig. Therefore, SPES FT = +/-(0.1% LQZF LQZF > SVLJí  SVL @

SPES FT = +/-0.582500 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SPES FT = +/-[(0.582500 inwc)*(16 mA)/(216 inwc)]

SPES FT = +/-0.043148 mA >@

b) RWCU inlet flow (FT 1E31-N076A&B), span = 291.6 inwc & URL = 1000 inwc From Appendix 4, operating pressure is 1100 psig. Therefore, SPES FT = +/-(0. LQZF LQZF > SVLJí  SVL @

SPES FT = +/-1.420760 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SPES FT = +/-[(1.420760 inwc)*(16 mA)/(291.6 inwc)]

SPES FT = +/-0.077957 mA >@

c) Flow to feedwater (FT 1E31-N077A&B), span = 197.5 inwc & URL = 250 inwc From Appendix 4, operating pressure is 1250 psig. Therefore, SPES FT = +/-(0. LQZF LQZF > SVLJí  SVL @

SPES FT = +/-0.559375 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SPES FT = +/-[(0.559375 inwc)*(16 mA)/(197.5 inwc)]

SPES FT = +/-0.045316 mA >@

7.4.1.4.3 Combined Random Static Pressure Effect (SPEFT)

SPEFT is determined by the SRSS combination of SPEZ FT and SPES FT as follows:

a) Flow to condenser (FT 1E31-N075A&B)

SPEFT = +/-[(SPEZ FT)0.5 + (SPES FT)0.5]0.5 SPEFT = +/-[(0.023148 mA)0.5 + (0.043148 mA)0.5]0.5 SPEFT = +/-0.048965 mA >@

b) RWCU inlet flow (FT 1E31-N076A&B)

SPEFT = +/-[(SPEZ FT)0.5 + (SPES FT)0.5]0.5 SPEFT = +/-[(0.060357 mA)0.5 + (0.077957 mA)0.5]0.5

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 20 of 86 SPEFT = +/-0.098591 mA >@

c) Flow to feedwater (FT 1E31-N077A&B)

SPEFT = +/-[(SPEZ FT)0.5 + (SPES FT)0.5]0.5 SPEFT = +/-[(0.025316 mA)0.5 + (0.045316 mA)0.5]0.5 SPEFT = +/-0.051908 mA >@

7.4.1.4.4 Bias Span Static Pressure Effect (SPEBS FT)

The calibrated spans for Rosemount transmitters 1E31-N076A&B and 1E31-N077A&B (as determined per Input 4.3.7 and as implemented per Inputs 4.9.1, 4.9.2 and 4.10.1, 4.10.2) do not consider span shift corrections when calibrating transmitters at ambient atmospheric pressure while operating at system static pressure conditions. Additionally, there is no indication that the calibrated span for Rosemount transmitters 1E31-N075A&B (as implemented per Inputs 4.9.1, 4.9.2, 4.10.1) considered the span shift corrections. From Section 7.4, the analyzed transmitters are Rosemount 3153ND2 and 3153ND3 which have range codes of 2 and 3, respectively. Per Input 4.3.1, Rosemount 3153 differential pressure transmitters with range codes 2 and 3 do not require correction for high static pressure span effects. (As indicated per Input 4.3.1, only differential pressure transmitters with range codes 4 and 5 experience a span shift when operating at high static line pressures.) Therefore, this analysis takes no credit for bias span shift effects. As such, a) Flow to condenser (FT 1E31-N075A&B)

SPEBS FT =0 [bias]

b) RWCU inlet flow (FT 1E31-N076A&B)

SPEBS FT =0 [bias]

c) Flow to feedwater (FT 1E31-N077A&B)

SPEBS FT =0 [bias]

7.4.1.5 Flow Transmitter Seismic Effect (SEFT)

From Section 7.4.1, Inputs 4.3.1 and 4.3.25, and by conservatively considering a bounding ZPA of 8.5 g (and with all transmitters configured with Damping set for time response = 0.4 sec or greater),

SEFT = +/-0.2% URL >@

By application of transmitter calibrated input spans and URLs from above Section 7.4.1, SEFT for each transmitter is determined as follows:

a) Flow to condenser (FT 1E31-N075A&B), span = 216 inwc & URL = 250 inwc SEFT = +/-(0.2%*250 inwc)

SEFT = +/-0.5 inwc [2@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 21 of 86 SEFT = +/-[(0.5 inwc)*(16 mA)/(216 inwc)]

SEFT = +/-0.037037 mA [2@

b) RWCU inlet flow (FT 1E31-N076A&B), span = 291.6 inwc & URL = 1000 inwc SEFT = +/-(0.2%*1000 inwc)

SEFT = +/-2.0 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SEFT = +/-[(2.0 inwc)*(16 mA)/(291.6 inwc)]

SEFT = +/-0.109739 mA [2@

c) Flow to feedwater (FT 1E31-N077A&B), span = 197.5 inwc & URL = 250 inwc SEFT = +/-(0.2%*250 inwc)

SEFT = +/-0.5 inwc >@

From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16mA). As such, the result is converted to units of mA as follows:

SEFT = +/-[(0.5 inwc)*(16 mA)/(197.5 inwc)]

SEFT = +/-0.040506 mA [2@

7.4.1.6 Flow Transmitter Radiation Effect (REFT)

Per Section 1.0, this analysis considers only normal operating environmental effects. From Section 7.2, the normal radiation at transmitter locations is 1.0E4 Rads (or 0.01 Mrads). From Input 4.3.1, there are no applicable vendor radiation error effects given for a normal radiation dose of 0.01 Mrads. As such, normal radiation errors are assumed to be included within the instrument drift errors [Assumption 2.4].

Therefore, REFT =0 7.4.1.7 Flow Transmitter Humidity Effect (HEFT)

Per Section 1.0, this analysis considers only normal operating environmental effects. From Section 7.2, the normal humidity at transmitter locations is 5 to 90% RH. From Input 4.3.1, transmitter humidity limits are 0 to 100% RH (NEMA 4X). As such, normal humidity error effects are considered to be either zero (0) or assumed to be included within the instrument drift errors [Assumption 2.2]. Therefore, HEFT =0 7.4.1.8 Flow Transmitter Power Supply Effect (PSEFT)

Per Inputs 4.3.1 and 4.3.25, PSEFT is less than 0.005% of span per volt. Per Inputs 4.5.1, 4.5.2, and 4.5.3, the power supply voltage is 24 vdc. Per Assumption 2.6, the power supply stability (PSS) is within +/- 1.2 vdc. From Section 7.4.1, the output range of the transmitter is 4 to 20 mA (span = 16 mA). Therefore, PSEFT is determined for each transmitter as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 22 of 86 PSEFT =+/-[(0.005% span)/(1 vdc)]*PSS PSEFT =+/-[(0.005%)*(16 mA)/(1 vdc)]*(1.2 vdc)

PSEFT =+/-0.000960 mA >@

7.4.1.9 Flow Transmitter RFI/EMI Effect (REEFT)

Per Assumption 2.10, the effects of RFI/EMI are considered to be negligible. Therefore, REEFT = 0 7.4.1.10 Flow Transmitter Bias Effect (BFT)

From Appendix C of Reference 6.1, flow transmitter bias is defined as a systematic or fixed instrument uncertainty that is predictable for a given set of conditions, because of the existence of a known direction (positive or negative). No such error is identified for the flow transmitters (Input 4.3.1). Therefore, a) Flow to condenser (FT 1E31-N075A&B)

BFT =0 [bias]

b) RWCU inlet flow (FT 1E31-N076A&B)

BFT =0 [bias]

c) Flow to feedwater (FT 1E31-N077A&B)

BFT =0 [bias]

7.4.1.11 Per Section 7.3.1, the accuracy associated with the flow transmitters is calculated below:

VA ATE OPE SPE SE

+ + + +

A = +/-N n n n n n +/-B []

RE HE PSE REE

+ + + +

n n n n a) From above for flow to condenser (FT 1E31-N075A&B):

VAFT = r0.032 mA (3V) Section 7.4.1.1 ATEFT = r0.086644 mA (3V) Section 7.4.1.2 OPEFT =0 Section 7.4.1.3 SPEFT = r0.048965 mA (3V) Section 7.4.1.4.3 SEFT = +/-0.037037 mA  Section 7.4.1.5 REFT =0 Section 7.4.1.6 HEFT =0 Section 7.4.1.7 PSEFT = r0.000960 mA (3V) Section 7.4.1.8 REEFT =0 Section 7.4.1.9 BFT =0 (bias) Section 7.4.1.10

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 23 of 86 Substituting:

0.032 0.086644 0.048965 0.037037

+ + (0) + +

A = +/-2 3 3 3 2 +0 []

0.000960

+(0) + (0) + + (0) 3 AFT = +/-0.078926 mA >@

eAFT = BFT = 0 [bias]

b) From above for RWCU inlet flow (FT 1E31-N076A&B):

VAFT = r0.032 mA (3V) Section 7.4.1.1 ATEFT = r0.069539 mA (3V) Section 7.4.1.2 OPEFT =0 Section 7.4.1.3 SPEFT = r0.098591 mA (3V) Section 7.4.1.4.3 SEFT = +/-0.109739 mA (2V) Section 7.4.1.5 REFT =0 Section 7.4.1.6 HEFT =0 Section 7.4.1.7 PSEFT = r0.000960 mA (3V) Section 7.4.1.8 REEFT =0 Section 7.4.1.9 BFT =0 (bias) Section 7.4.1.10 Substituting:

0.032 0.069539 0.098591 0.109739

+ + (0) + +

A = +/-2 3 3 3 2 +0 []

0.000960

+(0) + (0) + + (0) 3 AFT = +/-0.137722 mA >@

eAFT = BFT = 0 [bias]

c) From above for flow to feedwater (FT 1E31-N077A&B):

VAFT = r0.032 mA (3V) Section 7.4.1.1 ATEFT = r0.088466 mA (3V) Section 7.4.1.2 OPEFT =0 Section 7.4.1.3 SPEFT = r0.051908 mA (3V) Section 7.4.1.4.3 SEFT = +/-0.040506 mA (2V) Section 7.4.1.5 REFT =0 Section 7.4.1.6 HEFT =0 Section 7.4.1.7 PSEFT = r0.000960 mA (3V) Section 7.4.1.8 REEFT =0 Section 7.4.1.9 BFT =0 (bias) Section 7.4.1.10

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 24 of 86 Substituting:

0.032 0.088466 0.051908 0.040506

+ + (0) + +

A = +/-2 3 3 3 2 +0 []

0.000960

+(0) + (0) + + (0) 3 AFT = +/-0.082293 mA >@

eAFT = BFT 0 [bias]

7.4.1.12 3URSDJDWLQJ5DQGRP)ORZ7UDQVPLWWHU$FFXUDF\7KURXJK6TXDUH5RRW([WUDFWRU $FT PROP SQR)

Random flow transmitter accuracy (from Section 7.4.1.11) is propagated through the square root extractor at the specified operating flow rate points of interest by application of Equations 2.4 and 2.6 (as applicable) from Appendix 2 as follows:

a) Flow to condenser (FT 1E31-N075A&B) at 0 gpm operating point per Section 3.7:

$FT = +/-0.078926 mA >@

From Appendix 2, an operating flow rate value of 0 gpm provides corresponding I value of 4 mA, which results in a negative value for the denominator of Equation 2.4 of Appendix 2.

Therefore, Equation 2.6 of Appendix 2 is applied as follows:

$FT PROP SQR = +/-[((I -  _AFTl)0.5 - (I - 4)0.5]

By substitution,

$FT PROP SQR = +/-[((4 - 4) + l0.078926l)0.5 - (4 - 4)0.5]

$FT PROP SQR = +/-0.280938 vdc >@

b) RWCU inlet flow (FT 1E31-N076A&B) at 327.24 gpm operating point per Section 3.7:

$FT = +/-0.137722 mA >@

From Appendix 2, an operating flow rate value of 327.24 gpm provides corresponding I value of 17.986745 mA, which does not result in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

A A =

2 I 4 By substitution,

+/-0.137722 A = = +/-0.018413 vdc [2]

2 17.986745 4

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 25 of 86 c) Flow to feedwater (FT 1E31-N077A&B) at 92.24 gpm operating point per Section 3.7:

$FT = +/-0.082293 mA >@

From Appendix 2, an operating flow rate value of 92.24 gpm provides corresponding I value of 5.111277 mA, which does not result in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

A A =

2 I 4 By substitution,

+/-0.082293 A = = +/-0.039032 vdc [2]

2 5.111277 4 7.4.1.13 3URSDJDWLQJ5DQGRP)ORZ7UDQVPLWWHU$FFXUDF\7KURXJK6XPPHU $FT PROP SUM)

Random flow transmitter accuracy (from Section 7.4.1.12) is propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Flow to condenser (FT 1E31-N075A&B):

VXPPHULQSXW$ $FT PROP SQR = +/-0.280938 YGF $ >@

RWCU inlet flow (FT 1E31-N076A&B):

VXPPHULQSXW% $FT PROP SQR = +/-0.018413 YGF % >@

Flow to feedwater (FT 1E31-N077A&B):

VXPPHULQSXW& $FT PROP SQR = +/-0.039032 YGF & >@

$FT PROP SUM >  % 2 +  $ 2 +  & 2]0.5

$FT PROP SUM = [(1.590909*(+/-0.018413 vdc))2 + (1.181818*(+/-0.280938vdc))2

+ (1.590909*(+/-0.039032 vdc))2]0.5

$FT PROP SUM = +/-0.339042 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

$FT PROP SUM = +/-(0.339042 vdc)*(100% span) / (4 vdc)

$FT PROP SUM = +/-8.476050% span >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 26 of 86 7.4.2 Square Root Extractors (1E31-K602A&B, -K603A&B, -K605A&B) x From Inputs 4.5.1, 4.5.2, and 4.5.3, square root extractor equipment tag numbers are Bailey Type 750.

x From Figure 1 of Section 7.2, the calibrated input and output ranges are as follows:

Calibrated Input: 4 to 20 mA transmitter output range (span = 16 mA) directly corresponds to 1 to 5 vdc square root extractor input range (span = 4 vdc) as the transmitter current signals pass through the GE signal resistor units (SRUs) as discussed in Section 1.0.

Calibrated Output: 1 to 5 vdc (span = 4 vdc) 7.4.2.1 Square Root Extractor Vendor Accuracy (VASQR)

Per Inputs 4.3.2, 4.3.3 and Assumption 2.1, vendor accuracy is determined for each square root extractor as follows:

For outputs equal to or above 25% span:

VASQR = +/-0.5% span [2@

For outputs below 25% span:

VASQR = +/-1.5% span >@

From above Section 7.4.2, the output range of each square root extractor is 1 to 5 vdc (span = 4 vdc).

From Section 3.7, the operating flow rates to be considered when determining errors are as follows:

a) Flow to condenser (FT 1E31-N075A&B)

Operating Flow Rate = 0 gpm (from Section 3.7)

Since 0 gpm is below 25% of output span, the +/-1.5% span accuracy specification is utilized.

Therefore, VASQR = +/-1.5% span VASQR = +/-1.5%

• 4 vdc VASQR = +/-0.06 vdc >@

b) RWCU inlet flow (FT 1E31-N076A&B)

Operating Flow Rate = 327.24 gpm (from Section 3.7)

From Figure 1 of Section 7.2, the flow rate range is 0 to 350 gpm (span = 350 gpm). As such, the 327.24 gpm operating flow rate is converted into corresponding square root extractor percent output span as follows:

% output span = (327.25 gpm)*(100 % span)/(350 gpm)

% output span = 93.5 % (which is greater than 25%)

Therefore, the +/-0.5% span accuracy specification is utilized.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 27 of 86 VASQR = +/-0.5% span VASQR = +/-0.5%

• 4 vdc VASQR = +/-0.02 vdc >@

c) Flow to feedwater (FT 1E31-N077A&B)

Operating Flow Rate = 92.24 gpm (from Section 3.7)

From Figure 1 of Section 7.2, the flow rate range is 0 to350 gpm (span = 350 gpm). As such, the 92.24 gpm operating flow rate is converted into corresponding square root extractor percent output span as follows:

% output span = (92.24 gpm)*(100 % span)/(350 gpm)

% output span = 26.354286% (which is greater than 25%)

Therefore, the +/-0.5% span accuracy specification is utilized.

VASQR = +/-0.5% span * (4 vdc)

VASQR = +/-0.5%

• 4 vdc VASQR = +/-0.02 vdc >@

7.4.2.2 Square Root Extractor Accuracy Temperature Effect (ATESQR)

Per Inputs 4.3.2, 4.3.3 and Assumption 2.1, vendor accuracy temperature effect is determined for the square root extractors as follows:

ATESQR = +/-0.5% for temperature variation of 80°F +/-40°F >@

Per Section 7.WKHPD[LPXPERXQGLQJDPELHQWWHPSHUDWXUHFKDQJH 7 DWVTXDUHURRWH[WUDFWRU

location is (104°F - 65°F = 39°F). By application of square root extractor calibrated output span of 1 to 5 vdc (Section 7.4.2) and application of Assumption 2.5, ATESQR is determined as follows:

ATESQR > 85/ 7  )- 40°F)]

ATESQR = +/-[(0.5%

• 5 vdc)*(39°F)/(80°F)]

ATESQR = +/-0.012188 vdc >@

7.4.2.3 Square Root Extractor Overpressure Effect (OPESQR)

Overpressure error effect is not applicable for square root extractors, because they have no interface with the process fluid. Therefore, OPESQR =0 7.4.2.4 Square Root Extractor Static Pressure Effect (SPESQR)

Static pressure error effect is not applicable for square root extractors, because they have no interface with the process fluid. Therefore, SPESQR = 0

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 28 of 86 7.4.2.5 Square Root Extractor Seismic Effect (SESQR)

The square root extractors have been seismically qualified using the manufacturer's published accuracy requirements (Inputs 4.3.2 and 4.3.3). Based on a review of Inputs 4.3.2 and 4.3.3, there are no additional error considerations that must be considered for seismic conditions. Therefore:

SESQR = 0 7.4.2.6 Square Root Extractor Radiation Effect (RESQR)

Per Section 7.2, the square root extractors are located in the main control room which is considered to be a mild environment per Input 4.4.1, and Inputs 4.3.2 and 4.3.3 do not provide a radiation error effect. As such, radiation errors are assumed to be included within the instrument drift errors [Assumption 2.4].

Therefore, RESRQ = 0 7.4.2.7 Square Root Exactor Humidity Effect (HESQR)

Inputs 4.3.2 and 4.3.3 do not provide a humidity error effect for the square root extractors. As such, humidity error effect is assumed to be included in the manufacturers accuracy specification [Assumption 2.2]. Therefore, HESQR = 0 7.4.2.8 Square Root Extractor Power Supply Effect (PSESQR)

Per Inputs 4.3.2 and 4.3.3 and Assumption 2.1, vendor power supply effect is determined for the square root extractor as follows:

PSESQR = +/-0.2% with a +/-2 vdc power supply voltage change from 24 vdc >@

Per Assumption 2.6, the instrument power supply stability (PPS) is within +/-1.2 vdc of a nominal 24 volt power supply. By application of square root extractor calibrated output span of 1 to 5 vdc (Section 7.4.2) and Assumption 2.5, PSESQR is determined as follows:

PSESQR = +/-[(0.2% URL)*(PPS)/(26 vdc - 22 vdc)] >@

PSESQR = +/-[(0.2%)*(5 vdc)]*(1.2 vdc)/(4 vdc)

PSESQR = +/-0.003 vdc >@

7.4.2.9 Square Root Extractor RFI/EMI Effect (REEFT)

Inputs 4.3.2 and 4.3.3 do not provide an RFI/EMI error effect for the square root extractors. As such, RFI/EMI error effect is assumed to be negligible [Assumption 2.10]. Therefore, REESQR =0 7.4.2.10 Square Root Extractor Bias Effect (BSQR)

From Appendix C of Reference 6.1, square root extractor bias is defined as a systematic or fixed instrument uncertainty that is predictable for a given set of conditions, because of the existence of a

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 29 of 86 known direction (positive or negative). No such error is identified for the square root extractors (Inputs 4.3.2 and 4.3.3). Therefore, BSQR =0 7.4.2.11 Per Section 7.3.1, the accuracy associated with the square root extractors is calculated below:

VA ATE OPE SPE SE

+ + + +

A = +/-N n n n n n +/-B []

RE HE PSE REE

+ + + +

n n n n From above:

VASQR = r0.02 vdc (2V) Section 7.4.2.1 (RWCU inlet and FW flows)

VASQR = r0.06 vdc (2V) Section 7.4.2.1 (flow to condenser)

ATESQR = +/-0.012188 vdc (2V) Section 7.4.2.2 OPESQR =0 Section 7.4.2.3 SPESQR =0 Section 7.4.2.4 SESQR =0 Section 7.4.2.5 RESQR =0 Section 7.4.2.6 HESQR =0 Section 7.4.2.7 PSESQR = +/-0.003 (2V) Section 7.4.2.8 REESQR =0 Section 7.4.2.9 BSQR =0 Section 7.4.2.10 Substituting:

a) Flows to condenser and feedwater (FT 1E31-N075A&B loop) 0.06 0.012188

+ + (0) + (0) + (0)

A = +/-2 2 2 +/- (0) []

0.003

+(0) + (0) + + (0) 2 ASQR = +/-0.061299 vdc >@

eASQR = BSQR = 0 [bias]

b) RWCU inlet flow (FT 1E31-N076A&B and FT 1E31-N077A&B loops) 0.02 0.012188

+ + (0) + (0) + (0)

A = +/-2 2 2 +/- (0) []

0.003

+(0) + (0) + + (0) 2

$SQR = +/-0.023612 vdc >@

eASQR = BSQR = 0 [bias]

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 30 of 86 7.4.2.12 Propagating Random Square Root Extractor $FFXUDF\7KURXJK6XPPHU $SQR PROP SUM)

Random square root extractor uncertainties (from Section 7.4.2.11) are propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Flow to condenser (SQR 1E31-K605A&B):

VXPPHULQSXW$ $SQR = +/-0.061299 vdc $ >@

RWCU inlet flow (SQR 1E31-K602A&B):

VXPPHULQSXW% $SQR = +/-0.023612 vdc % >@

Flow to feedwater (SQR 1E31-K603A&B):

VXPPHULQSXW& $SQR = +/-0.023612 vdc & >@

$SQR PROP SUM >  % 2 +  $ 2 +  & 2]0.5

$SQR PROP SUM = [(1.590909*(+/-0.023612 vdc))2 + (1.181818*(+/-0.061299 vdc))2

+ (1.590909*(+/-0.023612 vdc))2]0.5

$SQR PROP SUM = +/-0.089835 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

$SQR PROP SUM = +/-(0.089835 vdc)*(100% span) / (4 vdc)

$SQR PROP SUM = +/-2.245875% span >@

7.4.3 Summer (1E31-K606A&B) x From Inputs 4.1 and 4.3.8, summer equipment tag numbers are Curtiss-Wright Model SUM2000-752 (Four-Input Summer) x From Figure 1 in Section 7.2, the calibrated input and output ranges are as follows:

Three (3) 1 to 5 vdc input signal ranges (span = 4 vdc) directly correspond to one (1) 1 to 5 vdc output range (100% span) 7.4.3.1 Summer Vendor Accuracy (VASUM)

Per Input 4.3.8 and Assumption 2.1, vendor accuracy is determined for the summer as follows:

VASUM = +/-0.5% >@

By application of the summer calibrated output span of 1 to 5 vdc (Section 7.4.3) and application of Assumption 2.5, VASUM is determined as follows:

VASUM = +/-0.5% URL >@

VASUM = +/-0.5%

• 5 vdc VASUM = +/-0.025 vdc [2@

Converting from units of vdc to units of % span, where 100% span corresponds to an output span of 4 vdc (Section 7.4.3).

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 31 of 86 VASUM = +/-(0.025 vdc)*(100% span)/(4vdc) >@

VASUM = +/-0.625% span 7.4.3.2 Summer Accuracy Temperature Effect (ATESUM)

Input 4.3.8 does not provide a temperature error effect for the summer. As such, temperature error effect is assumed to be included in the manufacturers accuracy specification [Assumption 2.2]. Therefore, ATESUM =0 7.4.3.3 Summer Overpressure Effect (OPESUM)

Overpressure error effect is not applicable for the summer, because it has no interface with the process fluid. Therefore, OPESUM =0 7.4.3.4 Summer Static Pressure Effect (SPESUM)

Static pressure error effect is not applicable for the summer, because it has no interface with the process fluid. Therefore, SPESUM =0 7.4.3.5 Summer Seismic Effect (SESUM)

From an examination of Input 4.3.8, there are no additional error considerations that must be considered for seismic conditions. Therefore:

SESUM = 0 7.4.3.6 Summer Radiation Effect (RESUM)

Per Section 7.2, the summer is located in the main control room which is considered to be a mild environment per Input 4.4.1. Also, Input 4.3.8 does not provide a radiation error effect. As such, radiation errors are assumed to be included within the instrument drift errors [Assumption 2.4].

Therefore, RESUM = 0 7.4.3.7 Summer Humidity Effect (HESUM)

Input 4.3.8 does not provide a humidity error effect for the summer. As such, humidity error effect is assumed to be included in the manufacturers accuracy specification [Assumption 2.2]. Therefore, HESUM = 0 7.4.3.8 Summer Power Supply Effect (PSESUM)

Per Input 4.3.8 and Assumption 2.1, vendor power supply effect is determined for the summer as follows:

PSESUM = +/-0.1% with a +/-2 vdc power supply voltage change from 24 vdc >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 32 of 86 Per Assumption 2.6, the instrument power supply stability (PPS) is within +/-1.2 vdc of a nominal 24 volt power supply. By application of summer calibrated output span of 1 to 5 vdc (Section 7.4.3) and Assumption 2.5, PSESUM is determined as follows:

PSESUM = +/-[(0.1% URL)*(PPS)/(26 vdc - 22 vdc)] >@

PSESUM = +/-[(0.1%)*(5 vdc)]*(1.2 vdc)/(4 vdc)

PSESUM = +/-0.0015 vdc >@

Converting from units of vdc to units of % span, where 100% span corresponds to an output span of 4 vdc (Section 7.4.3).

PSESUM = +/-(0.0015 vdc)*(100% span)/(4vdc) >@

PSESUM = +/-0.0375% span 7.4.3.9 Summer RFI/EMI Effect (REESUM)

Input 4.3.8 does not provide an RFI/EMI error effect for the summer. As such, RFI/EMI error effect is assumed to be negligible [Assumption 2.10]. Therefore, REESUM =0 7.4.3.10 Summer Bias Effect (BSUM)

From Appendix C of Reference 6.1, summer bias is defined as a systematic or fixed instrument uncertainty that is predictable for a given set of conditions, because of the existence of a known direction (positive or negative). No such error is identified for the summer (Input 4.3.8). Therefore, BSUM =0 7.4.3.11 Per Section 7.3.1, the accuracy associated with the summer is calculated below:

VA ATE OPE SPE SE

+ + + +

A = +/-N n n n n n +/-B []

RE HE PSE REE

+ + + +

n n n n From above:

VASUM = r0.625% span (2V) Section 7.4.3.1 ATESUM =0 Section 7.4.3.2 OPESUM =0 Section 7.4.3.3 SPESUM =0 Section 7.4.3.4 SESUM =0 Section 7.4.3.5 RESUM =0 Section 7.4.3.6 HESUM =0 Section 7.4.3.7 PSESUM = +/-0.0375% span (2V) Section 7.4.3.8 REESUM =0 Section 7.4.3.9 BSUM =0 Section 7.4.3.10

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 33 of 86 Substituting:

0.625

+ (0) + (0) + (0) + (0)

A = +/-2 2 +/- (0) []

0.0375

+(0) + (0) + + (0) 2 ASUM = +/-0.626124% span >@

eASUM = BSUM = 0 [bias]

7.4.4 Trip Bistable (1E31-N611A&B) x From Inputs 4.1, 4.3.4, and 4.3.5, the trip bistable equipment tag numbers are Curtiss-Wright Model SAM2000-745 x From Figure 1 in Section 7.2, the calibrated input range and output are as follows:

1 to 5 vdc input range (100% span) with a corresponding trip output on high differential flow.

7.4.4.1 Trip Bistable Vendor Accuracy (VATB)

Per Inputs 4.3.4, 4.3.5 and Assumption 2.1, vendor accuracy is determined for the trip bistable as follows:

VATB = +/-0.5% span >@

From above Section 7.4.4, the input range for the trip bistable is 1 to 5 vdc (or 100% span). As such, VATB = +/-0.5% * (100% span)

VATB = +/-0.5% span >]

7.4.4.2 Trip Bistable Accuracy Temperature Effect (ATETB)

Per Input 4.3.5 and Assumption 2.1, vendor accuracy temperature effect is determined for the trip bistable as follows:

ATETB = +/-0.5% for temperature variation of 80°F +/-40°F >@

Per SHFWLRQWKHPD[LPXPERXQGLQJDPELHQWWHPSHUDWXUHFKDQJH 7 DWWULSELVWDEOHORFDWLRQLV

(104°F - 65°F = 39°F). From Section 7.4.4, the trip bistable calibrated input range is 1 to 5 vdc (where span = 4 vdc = 100% span). Section 5.12 of Input 4.3.4 states:

Temperature measurements of the stability of the alarm trip point of the module were made over the temperature range of 0°F to 140°F with the alarm threshold set at one half of input span. The deviation of trip point with temperature did not vary by more than +/-3 mv from the 80°F reference setting. The corresponding accuracy of the alarm trip point with temperature was thusly calculated as +/-3 mv out of a span of 4 volts, equivalent to +/-

0.1% from 0°F to 140°F. Scientech chooses to report the operative influences in NUS-A042SA as being the same as that of the original Bailey specification (+/- 0.5% over the temperature range of 80°F +/- 40°F).

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 34 of 86 Since the above paragraph specifically relates this error effect to a 4 volt span, ATETB is determined as a percentage of instrument span as follows:

ATETB = +/-[(0.5%

• span)*(39°F)/(120°F - 40°F)]

where, span = (5 vdc - 1 vdc) = 4 vdc = 100% span ATETB = +/-[(0.5% * (100% span)*(39°F)/(120°F - 40°F)]

ATETB = +/-0.243750% span >@

7.4.4.3 Trip Bistable Overpressure Effect (OPETB)

Overpressure error effect is not applicable for the trip bistable, because it has no interface with the process fluid. Therefore, OPETB = 0 7.4.4.4 Trip Bistable Static Pressure Effect (SPETB)

Static pressure error effect is not applicable for the trip bistable, because it has no interface with the process fluid. Therefore, SPETB = 0 7.4.4.5 Trip Bistable Seismic Effect (SETB)

The trip bistable has been seismically qualified using the manufacturer's published accuracy requirements (Inputs 4.3.4, 4.3.5). Based on a review of Inputs 4.3.4, 4.3.5, there are no additional error considerations which must be considered for seismic conditions. Therefore:

SETB =0 7.4.4.6 Trip Bistable Radiation Effect (RETB)

Per Section 7.2, the trip bistable is located in the main control room which is considered to be a mild environment per Input 4.4.1, and Inputs 4.3.4, 4.3.5 do not provide a radiation error effect. As such, radiation errors are assumed to be included within the instrument drift errors [Assumption 2.4].

Therefore, RETB =0 7.4.4.7 Trip Bistable Humidity Effect (HETB)

Inputs 4.3.4, 4.3.5 do not provide a humidity error effect for the trip bistable. As such, humidity error effect is assumed to be included in the manufacturers accuracy specification [Assumption 2.2].

Therefore, HETB =0 7.4.4.8 Trip Bistable Power Supply Effect (PSETB)

Per Inputs 4.3.4, 4.3.5 and Assumption 2.1, vendor power supply effect is determined for the trip bistable as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 35 of 86 PSETB = +/-0.2% with a +/-2 vdc power supply voltage change from 24 vdc >@

Per Assumption 2.6, the instrument power supply stability (PPS) is within +/-1.2 vdc of a nominal 24 volt power supply. By application of trip bistable calibrated input range of 1 to 5 vdc (Section 7.4.4) and Assumption 2.5, PSETB is determined as follows:

PSETB = +/-[(0.2% URL)*(PPS)/(26 vdc - 22 vdc)] >@

PSETB = +/-[(0.2%)*(5 vdc)]*(1.2 vdc)/(4 vdc)

PSETB = +/-0.003 vdc >@

From Section 7.4.4, the input range of the trip bistable is 1 to 5 vdc (span = 100% span = 4 vdc). As such, the result is converted to units of % span as follows:

PSETB = +/-[(0.003 vdc)*(100% span)/(4 vdc)]

PSETB = +/-0.075% span >@

7.4.4.9 Trip Bistable RFI/EMI Effect (REETB)

Inputs 4.3.4 and 4.3.5 do not provide an RFI/EMI error effect for the trip bistable. As such, RFI/EMI error effect is assumed to be negligible [Assumption 2.10]. Therefore, REETB = 0 7.4.4.10 Trip Bistable Bias Effect (BTB)

From Appendix C of Reference 6.1, trip bistable bias is defined as a systematic or fixed instrument uncertainty that is predictable for a given set of conditions, because of the existence of a known direction (positive or negative). No such error is identified for the trip bistable (Inputs 4.3.4 and 4.3.5). Therefore, BTB =0 7.4.4.11 Per Section 7.3.1, the accuracy associated with the trip bistable is calculated below:

VA ATE OPE SPE SE

+ + + +

A = +/-N n n

n n

n +/-B []

RE HE PSE REE

+ + + +

n n n n From above:

VATB = r0.5% span (2V) Section 7.4.4.1 ATETB = r0.243750% span (2V) Section 7.4.4.2 OPETB =0 Section 7.4.4.3 SPETB =0 Section 7.4.4.4 SETB =0 Section 7.4.4.5 RETB =0 Section 7.4.4.6 HETB =0 Section 7.4.4.7 PSETB = r0.075% span (2V) Section 7.4.4.8 REETB =0 Section 7.4.4.9 BTB =0 Section 7.4.4.10

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 36 of 86 Substituting:

0.5 0.243750

+ + (0) + (0) + (0)

A = +/-2 2 2 +/- (0) []

0.075

+(0) + (0) + + (0) 2

$TB = +/-0.561283% span >@

eATB = BTB = 0 [bias]

7.4.4.12 Determining Loop Accuracy (AL)

From Section 7.3.1:

A = +/-A + A + A +. . .+/- B ()

By substitution, the above equation is rewritten and solved as follows:

A1 = AFT PROP SUM = +/-8.476050% span  [Section 7.4.1.13]

A2 = ASQR PROP SUM = +/-2.245875% span   [Section 7.4.2.12]

A3 = ASUM = +/-0.626124% span   [Section 7.4.3.11]

A4 = ATB = +/-0.561283% span   [Section 7.4.4.11]

B = bias =0 [Sections 7.4.1.11, 7.4.2.11, 7.4.3.11, 7.4.4.11]

Random Component of Error A = +/-(8.476050) + (2.245875) + (0.626124) + (0.561283) ()

A = +/-8.808771% span ()

Bias Component of Error eAL =B =0 (bias)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 37 of 86 7.5 Determination of Loop Calibration Error (CL)

Loop Calibration Error is determined by the SRSS of As-Left Tolerance (ALTi), Calibration Tool Error (Ci), and Calibration Standards Error (Ci STD) for the individual devices in the loop. The equation below is used to calculate this effect.

From Section 7.3.2:

ALT C C C = +/-N + + []

n n n 7.5.1 Calculating Loop ALTL 7.5.1.1 As-Left Tolerance for Flow Transmitter and Square Root Extractor String Calibrations (ALTFT/SQR)

From Inputs 4.9.1 and 4.9.2, the post-calibration adjustment verifications for the transmitters and associated square root extractors are tested and verified together by applying test pressures at the input of the transmitter while monitoring the output of the square root extractor for proper voltages within acceptable as-left tolerances. Therefore, this test verification configuration is considered to be one (1) device in accordance with Appendix K of Reference 6.1. From Inputs 4.9.1 and 4.9.2, the bounding as-left tolerances (which are considered to be YDOXHs per Reference 6.1) at the output of the square root extractor are, a) Flow to condenser (FT 1E31-N075A&B and SQR 1E31-K605A&B)

From Section 3.7, the specified operating flow rate point of interest is 0 gpm. From Inputs 4.9.1 and 4.9.2, the as-left tolerance at this point (zero flow rate) is, ALTFT/SQR = +/-0.070 vdc >@

b) RWCU inlet flow (FT 1E31-N076A&B and SQR 1E31-K602A&B)

From Section 3.7, the specified operating flow rate point of interest is 327.24 gpm. From Section 7.4.2.1, this operating point equates to 93.5% of output span. Therefore, from Inputs 4.9.1 and 4.9.2, the bounding as-left tolerance at this point is, ALTFT/SQR = +/-0.021 vdc >@

c) Flow to feedwater (FT 1E31-N077A&B and SQR 1E31-K603A&B)

From Section 3.7, the specified operating flow rate point of interest is 94.24 gpm. From Section 7.4.2.1, this operating point equates to 26.354286% of output span. Therefore, from Inputs 4.9.1 and 4.9.2, the bounding as-left tolerance at this point is, ALTFT/SQR = +/-0.028 vdc >@

7.5.1.1.1 Propagating Random ALTFT/SQR Uncertainties Through Summer (ALTFT/SQR PROP SUM)

Random uncertainties (from Section 7.5.1.1) are propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 38 of 86 Flow to condenser (FT 1E31-N075A&B and SQR 1E31-K605A&B):

summer input A= ALTFT/SQR YGF $ >@

RWCU inlet flow (FT 1E31-N076A&B and SQR 1E31-K602A&B):

summer input B = ALTFT/SQR = +/-0.021 YGF % >@

Flow to feedwater (FT 1E31-N077A&B and SQR 1E31-K603A&B):

summer input C = ALTFT/SQR = +/-0.028 YGF & >@

ALTFT/SQR PROP SUM >  % 2 +  $ 2 +  & 2]0.5 ALTFT/SQR PROP SUM = [(1.590909*(+/-0.021 vdc))2 + (1.181818*(+/-0.070 vdc vdc))2

+ (1.590909*(+/-0.028 vdc))2]0.5 ALTFT/SQR PROP SUM = +/-0.099721 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

ALTFT/SQR PROP SUM = +/-(0.099721 vdc)*(100% span) / (4 vdc)

ALTFT/SQR PROP SUM = +/-2.493025% span >@

7.5.1.2 As-Left Tolerances for Summer (1E31-K606AB) and Trip Bistable (1E31-N611A&B) (ALTSUM and ALTTB, respectively)

From the equation given in Section 7.3.8 and from Sections 7.4.3.1 and 7.4.4.1, ALTSUM = +/-VASUM = +/-0.625% span []

ALTTB = +/-VATB = +/-0.5% span []

7.5.1.3 Calculating Loop As-Left Tolerance (ALTL):

From Section 7.3.9, ALT = +/-ALT/ + (ALT) + (ALT ) []

From above results, ALTFT/SQR PROP SUM = +/-2.493025% span >@ Section 7.5.1.1.1 ALTSUM = +/-0.625% span >@ Section 7.5.1.2 ALTTB = +/-0.5% span >@ Section 7.5.1.2 By substitution, ALT = +/-(2.493025) + (0.625) + (0.5) []

ALTL = +/-2.618358% span >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 39 of 86 7.5.2 Calculating Loop Calibration Tool Error (C) 7.5.2.1 Calibration Tool Error for Flow Transmitter and Square Root Extractor String Calibrations (CFT/SQR)

From Inputs 4.9.1 and 4.9.2, the post-calibration adjustment verifications for the transmitters and associated square root extractors are tested and verified together by applying test pressures at the input of the transmitter while monitoring the output of the square root extractor for proper voltages within acceptable as-left tolerances. Therefore, this test verification configuration is considered to be one (1) device in accordance with Appendix K of Reference 6.1.

Per Assumption 2.8, calibration tool errors associated with the pressure test gauge and the DMM, used for measuring voltage, are both considered to be equal to the vendor accuracy (VA) of the calibrated instrument to satisfy a 1:1 accuracy ratio to the instrument under calibration; and furthermore, calibration tool HUURULVFRQVLGHUHGWREHDYDOXHUHJDUGOHVVRIWKHFRQILGHQFHDVVRFLDWHGZLWKWKHUHODWHG9$WHUP

As such, calibration standard errors are not applicable, because they are considered to be included in the calibration tool error. Therefore, Flow Transmitter VA: VAFT = +/-0.2% span [Section 7.4.1.1]

VAFT = +/-0.25% span (used for conservatism to >@

allow for added flexibility for test gauge selection)

Square Root Extractors VA: VASQR = +/-0.5% span IRURXWSXWVVSDQ [Section 7.4.2.1]

VASQR = +/-0.5% span >@

Therefore, calibration tool error for flow transmitter and square root extractor string calibrations (CFT/SQR) is as follows:

Transmitter Input Pressure Measurement CIN FT/SQR: = +/-0.25% span >@

COUT FT/SQR: = +/-0.5% span >@

7.5.2.1.1 Input Calibration Tool Error for Flow Transmitter and Square Root Extractor String Calibrations (CIN FT/SQR)

From 7.5.2.1, CIN FT/SQR = +/-0.25% span >@

7.5.2.1.1.1 Propagating CIN FT/SQR Uncertainties Through Square Root Extractor (CIN FT/SQR PROP SQR)

From information provided by Figure 1 of Section 7.2 and Inputs 4.9.1 and 4.9.2, CIN FT/SQR (from Section 7.5.2.1.1) is determined and FRQYHUWHGIURPDYDOXHWRDYDOXHDVIROORZV

CIN FT/SQR = +/-(2/3)*[0.25%*(20 mA - 4 mA)]

CIN FT/SQR = +/-0.026667 mA >@

The above CIN FT/SQR uncertainty is propagated through the square root extractor at the specified operating flow rate points of interest by application of Equations 2.4 and 2.6 (as applicable from Appendix 2) as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 40 of 86 a) Flow to condenser (FT 1E31-N075A&B) at 0 gpm operating point per Section 3.7:

From Appendix 2, an operating flow rate value of 0 gpm provides corresponding I value of 4 mA, which results in a negative value for the denominator of Equation 2.4 of Appendix 2.

Therefore, Equation 2.6 of Appendix 2 is applied as follows:

CIN FT/SQR PROP SQR = +/-[((I -  _CIN FT/SQRl)0.5 - (I - 4)0.5]

By substitution, CIN FT/SQR PROP SQR = +/-[((4 - 4) + l0.026667l)0.5 - (4 - 4)0.5]

CIN FT/SQR PROP SQR = +/-0.163300 vdc >@

b) RWCU inlet flow (FT 1E31-N076A&B) at 327.24 gpm operating point per Section 3.7:

From Appendix 2, an operating flow rate value of 327.24 gpm provides corresponding I value of 17.986745 mA, which does not result in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

C /

C / =

2 I 4 By substitution,

+/-0.026667 C / = = +/-0.003565 vdc [2]

2 17.986745 4 c) Flow to feedwater (FT 1E31-N077A&B) at 92.24 gpm operating point per Section 3.7:

From Appendix 2, an operating flow rate value of 92.24 gpm provides corresponding I value of 5.111277 mA, which does not result in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

C /

C / =

2 I 4 By substitution,

+/-0.026667 C / = = +/-0.012648 vdc [2]

2 5.111277 4 7.5.2.1.1.2 Propagating CIN FT/SQR PROP SQR Uncertainties Through Summer (CIN FT/SQR PROP SUM)

Random uncertainties (from Section 7.5.2.1.1.1) are propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Flow to condenser (FT 1E31-N075A&B and SQR 1E31-K605A&B):

summer input A= CIN FT/SQR PROP SQR = +/-0.163300 YGF $ >@

RWCU inlet flow (FT 1E31-N076A&B and SQR 1E31-K602A&B):

summer input B = CIN FT/SQR PROP SQR = +/-0.003565 YGF % >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 41 of 86 Flow to feedwater (FT 1E31-N077A&B and SQR 1E31-K603A&B):

summer input C = CIN FT/SQR PROP SQR = +/-0.012648 YGF & >@

CIN FT/SQR PROP SUM = >  % 2 +  $ 2 +  & 2]0.5 CIN FT/SQR PROP SUM = [(1.590909*(+/-0.003565 vdc))2 + (1.181818*(+/-0.163300 vdc))2

+ (1.590909*(+/-0.012648 vdc))2]0.5 CIN FT/SQR PROP SUM = +/-0.194120 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

CIN FT/SQR PROP SUM = +/-(0.194120 vdc)*(100% span) / (4 vdc)

CIN FT/SQR PROP SUM = +/-4.853000% span >@

7.5.2.1.2 Output Calibration Tool Error for Flow Transmitter and Square Root Extractor String Calibrations (COUT FT/SQR)

From Section 7.5.2.1, COUT FT/SQR = +/-0.5% span >@

7.5.2.1.2.1 Propagating COUT FT/SQR Uncertainties Through The Summer (COUT FT/SQR PROP SUM)

From information provided by Figure 1 of Section 7.2 and Inputs 4.9.1 and 4.9.2, COUT FT/SQR (from Section 7.5.2.1.2) is determined and FRQYHUWHGIURPDYDOXHWRDYDOXHDVIROORZV

COUT FT/SQR = +/-(2/3)*[0.5%*(5 vdc - 1 vdc)]

COUT FT/SQR = +/-0.013333 vdc >@

The above COUT FT/SQR uncertainty is propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Flow to condenser (FT 1E31-N075A&B and SQR 1E31-K605A&B):

summer input A= COUT FT/SQR = +/-0.013333 YGF $ >@

RWCU inlet flow (FT 1E31-N076A&B and SQR 1E31-K602A&B):

summer input B = COUT FT/SQR = +/-0.013333 YGF % >@

Flow to feedwater (FT 1E31-N077A&B and SQR 1E31-K603A&B):

summer input C = COUT FT/SQR = +/-0.013333 YGF & >@

COUT FT/SQR PROP SUM >  % 2 +  $ 2 +  & 2]0.5 COUT FT/SQR PROP SUM = [(1.590909*(+/-0.013333 vdc))2 + (1.181818*(+/-0.013333 vdc))2

+ (1.590909*(+/-0.013333 vdc))2]0.5 COUT FT/SQR PROP SUM = +/-0.033884 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

COUT FT/SQR PROP SUM = +/-(0.033884 vdc)*(100% span) / (4 vdc)

COUT FT/SQR PROP SUM = +/-0.847100% span >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 42 of 86 7.5.2.1.3 Calculating Total CFT/SQR String Calibration Tool Error The total calibration tool error for the string calibration of the flow transmitters and the square root extractors is determined by the below equation. This error is the total string calibration error, and it is propagated through the summer (1E31-K606A&B).

CFT/SQR = [(CIN FT/SQR PROP SUM)2 + (COUT FT/SQR PROP SUM)2]0.5 From error values from above Sections 7.5.2.1.1.2 and 7.5.2.1.2.1, CFT/SQR = +/-[(4.853000% span)2 + (0.847100% span)2]0.5

= +/-4.926377% span >@

7.5.2.2 Calibration Tool Error for Flow Summer (1E31-K606A&B) Calibrations (CSUM)

From Assumption 2.12.1.1, the summer is calibrated by applying three (3) test voltages at the input of the summer, while monitoring the summer output voltages for proper readings within an acceptable as-left tolerance.

Per Assumption 2.8, calibration tool errors associated with the DMMs, used for measuring voltages, considered to be equal to the vendor accuracy (VA) of the calibrated instrument to satisfy a 1:1 accuracy ratio to the instrument under calibration; and furthermore, calibration tool error iVFRQVLGHUHGWREHD

value regardless of the confidence associated with the related VA term. As such, calibration standard errors are not applicable, because they are considered to be included in the calibration tool error.

Therefore, from Section 7.4.3.1, Summer VA: VASUM = +/-0.625% span >@

Therefore, calibration tool errors for the summer calibration (CSUM) is as follows:

Summer Input and Output Voltage Measurement CIN SUM : = +/-0.625% span >@

COUT SUM: = +/-0.625% span >@

7.5.2.2.1 Propagating Random CIN SUM Uncertainties Through The Summer (CIN SUM PROP SUM)

From information provided by Figure 1 of Section 7.2 and Inputs 4.9.1 and 4.9.2, CIN SUM (from Section 7.5.2.2) LVGHWHUPLQHGDQGFRQYHUWHGIURPDYDOXHWRDYDOXHDVIROORZV

CIN SUM = +/-(2/3)*[0.625%*(5 vdc - 1vdc)]

CIN SUM = +/-0.016667 vdc >@

The above CIN SUM is propagated through the summer by application of Equation 3.2 of Appendix 3, as follows:

Flow to condenser (FT 1E31-N075A&B and SQR 1E31-K605A&B):

summer input A= CIN SUM = +/-0.016667 YGF $ >@

RWCU inlet flow (FT 1E31-N076A&B and SQR 1E31-K602A&B):

summer input B = CIN SUM = +/-0.016667 YGF % >@

Flow to feedwater (FT 1E31-N077A&B and SQR 1E31-K603A&B):

summer input C = CIN SUM = +/-0.016667 YGF & >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 43 of 86 CIN SUM PROP SUM >  % 2 +  $ 2 +  & 2]0.5 CIN SUM PROP SUM = [(1.590909*(+/-0.016667 vdc))2 + (1.181818*(+/-0.016667 vdc))2

+ (1.590909*(+/-0.016667 vdc))2]0.5 CIN SUM PROP SUM = +/-0.042357 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

CIN SUM PROP SUM = +/-(0.042357 vdc)*(100% span) / (4 vdc)

CIN SUM PROP SUM = +/-1.058925% span >@

7.5.2.2.2 Random COUT SUM Uncertainty (COUT SUM)

From information provided by Figure 1 of Section 7.2 and Inputs 4.9.1 and 4.9.2, COUT SUM (from Section

 LVGHWHUPLQHGDQGFRQYHUWHGIURPDYDOXHWRDYDOXHDVIROORZV

COUT SUM = +/-(2/3)*(0.625% span)]

COUT SUM = +/-0.416667% span >@

7.5.2.2.3 Calculating Total CSUM Calibration Tool Error The total calibration tool error for the calibration of the summer is determined as follows:

CSUM = [(CIN SUM PROP SUM)2 + (COUT SUM)2]0.5 From error values from above Sections 7.5.2.2.1 and 7.5.2.2.2, CSUM = +/-[(1.058925% span)2 + (0.416667% span)2]0.5

= +/-1.137951% span >@

7.5.2.3 Calibration Tool Error for Trip Bistable (1E31-N611A&B) Calibrations (CTB)

From Assumption 2.12.1.2, the trip bistable is calibrated by slowly raising a simulated input test voltage at the input of the trip bistable, while monitoring the trip bistable output for trip actuation within an acceptable as-left tolerance.

Per Assumption 2.8, calibration tool errors associated with the DMM, used for measuring voltage, considered to be equal to the vendor accuracy (VA) of the calibrated instrument to satisfy a 1:1 accuracy UDWLRWRWKHLQVWUXPHQWXQGHUFDOLEUDWLRQDQGIXUWKHUPRUHFDOLEUDWLRQWRROHUURULVFRQVLGHUHGWREHD

value regardless of the confidence associated with the related VA term. As such, calibration standard errors are not applicable, because they are considered to be included in the calibration tool error.

Therefore, from Section 7.4.4.1, Trip Bistable VA: VASUM = +/-0.5% span >@

Therefore, calibration tool error for the trip bistable calibration (CTB) is as follows:

Trip Bistable Voltage Measurement CTB  : = +/-0.5% span >@

From information provided by Figure 1 of Section 7.2 and Inputs 4.9.1 and 4.9.2, CTB is determined and FRQYHUWHGIURPDYDOXHWRDYDOXHDVIROORZV

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 44 of 86 CTB = +/-(2/3)*(0.5% span)]

CTB = +/-0.333333% span >@

7.5.3 Calculating Loop Calibration Error (CL):

From Section 7.3.2, CL = [(ALTL)2 + (CFT/SQ)2+ (CSUM)2 + (CTB)2 + (CSTD)2]0.5 From above results, ALTL = +/-2.618358% span >@ Section 7.5.1.3 CFT/SQR = +/-4.926377% span >@ Section 7.5.2.1.3 CSUM = +/-1.137951% span >@ Section 7.5.2.2.3 CTB = +/-0.333333% span >@ Section 7.5.2.3 CSTD = N/A (Sections 7.5.2.1, 7.5.2.2, &7.5.2.3 By substituting, CL = +/-[(2.618358% span)2 + (4.926377% span)2+ (1.137951% span)2

+ (0.333333% span)2]0.5 CL = +/-5.703598% span >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 45 of 86 7.6 Dermination of Loop Drift (DL) 7.6.1 Flow Transmitter Drift (DFT): [E31-N075A&B, -N076A&B, -N077A&B]

Per Input 4.3.1, flow transmitter drift is +/-[0.1% URL + 0.1% span] per 30 months, which is a 

specification per Input 4.3.15. From Inputs 4.9.1 and 4.9.2, the required calibration interval for each flow transmitter is 18-months. Input 4.8 allows for the surveillance to be extended for up to 1.25 times the required interval for a maximum interval of 22.5 months (18 months

• 1.25 = 22.5 months). As such, the maximum allowed calibration interval is bounded by the vendor drift specification. From flow transmitter URL and span information provided in Section7.4.1, drift is determined for each flow transmitter as follows:

a) Flow to condenser (FT 1E31-N075A&B), span = 216 inwc, URL = 250 inwc per Section 7.4.1 DFT = +/-[(0.1%

• URL) + (0.1%

• span)]

DFT = +/-[(0.1%

• 250 inwc) + (0.1%

• 216 inwc)]

DFT = +/-0.466000 inwc >@

From Section 7.4.1, the output range for the flow transmitter is 4 to 20 mA (span = 16mA). As such, the above result is converted to units of mA as follows:

DFT = +/-[(0.466000 inwc)*(16 mA)/(216 inwc)]

DFT = +/-0.034519 mA >@

b) RWCU inlet flow (FT 1E31-N076A&B), span = 291.6 inwc, URL = 1000 inwc per Section 7.4.1 DFT = +/-[(0.1%

• URL) + (0.1%

• span)]

DFT = +/-[(0.1%

• 1000 inwc) + (0.1%

• 291.6 inwc)]

DFT = +/-1.291600 inwc >@

From Section 7.4.1, the output range for the flow transmitter is 4 to 20 mA (span = 16mA). As such, the above result is converted to units of mA as follows:

DFT = +/-[(1.291600 inwc)*(16 mA)/(291.6 inwc)]

DFT = +/-0.070870 mA >@

c) Flow to feedwater (FT 1E31-N077A&B), span = 197.5 inwc, URL = 250 inwc per Section 7.4.1 DFT = +/-[(0.1%

• URL) + (0.1%

• span)]

DFT = +/-[(0.1%

• 250 inwc) + (0.1%

• 197.5 inwc)]

DFT = +/-0.447500 inwc >@

From Section 7.4.1, the output range for the flow transmitter is 4 to 20 mA (span = 16mA). As such, the above result is converted to units of mA as follows:

DFT = +/-[(0.447500 inwc)*(16 mA)/(197.5 inwc)]

DFT = +/-0.036253 mA >@

7.6.1.1 Propagating Flow Transmitter Drift Through Square Root Extractor (DFT PROP SQR)

Flow transmitter drift (from Section 7.6.1) is propagated through the square root extractor at the specified operating flow rate points of interest by application of Equations 2.4 and 2.6 (as applicable) from Appendix 2 as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 46 of 86 a) Flow to condenser (FT 1E31-N075A&B) at 0 gpm operating point per Section 3.7:

DFT = +/-0.034519 mA >@

From Appendix 2, an operating flow rate value of 0 gpm provides corresponding I value of 4 mA, which results in a negative value for the denominator of Equation 2.4 of Appendix 2.

Therefore, Equation 2.6 of Appendix 2 is applied as follows:

'FT PROP SQR = +/-[((I - 4) + lDFTl)0.5 - (I - 4)0.5]

By substitution,

'FT PROP SQR = +/-[((4 - 4) + l0.034519 l)0.5 - (4 - 4)0.5]

'FT PROP SQR = +/-0.185793 vdc >@

b) RWCU inlet flow (FT 1E31-N076A&B) at 327.24 gpm operating point per Section 3.7:

DFT = +/-0.070870 mA >@

From Appendix 2, an operating flow rate value of 327.24 gpm provides corresponding I value of 17.986745 mA, which does not result in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

D D =

2 I 4 By substitution,

+/-0.070870 mA D = = +/-0.009475 vdc [2]

2 17.986745 mA 4 mA c) Flow to feedwater (FT 1E31-N077A&B) at 92.24 gpm operating point per Section 3.7:

DFT = +/-0.036253 mA >@

From Appendix 2, an operating flow rate value of 92.24 gpm provides corresponding I value of 5.111277 mA, which does not results in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

D D =

2 I 4 By substitution,

+/-0.036253 mA D = = +/-0.017195 vdc [2]

2 5.111277 mA 4 mA 7.6.1.2 Propagating Flow Transmitter Drift Through Summer (DFT PROP SUM)

Random flow transmitter drift (from Section 7.6.1.1) is propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 47 of 86 Flow to condenser (FT 1E31-N075A&B):

summer input A= DFT PROP SQR = +/-0.185793 vdc = A >@

RWCU inlet flow (FT 1E31-N076A&B):

summer input B = DFT PROP SQR = +/-0.009475 vdc = B >@

Flow to feedwater (FT 1E31-N077A&B):

summer input C = DFT PROP SQR = +/-0.017195 vdc = C >@

DFT PROP SUM = [(1.590909*(B))2 + (1.181818*(A))2 + (1.590909*(C))2]0.5 DFT PROP SUM = [(1.590909*(+/-0.009475 vdc))2 + (1.181818*(+/-0.185793 vdc))2

+ (1.590909*(+/-0.017195 vdc))2]0.5 DFT PROP SUM = +/-0.221784 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

DFT PROP SUM = +/-(0.221784 vdc)*(100% span) / (4 vdc)

DFT PROP SUM = +/-5.544600% span >@

7.6.2 Square Root Extractor Drift (DSQR): [1E31-K602A&B, -K603A&B, -K605A&B]

Inputs 4.3.2 and 4.3.3 do not provide a drift specification for the square root extractors. As such, drift is determined as follows in accordance with Assumption 2.11 and information provided in Section 7.4.2.1.

a) Flow to condenser (FT 1E31-N075A&B)

DSQR = VASQR = +/-0.06 vdc >@

b) RWCU inlet flow (FT 1E31-N076A&B)

DSQR = VASQR = +/-0.02 vdc >@

c) Flow to feedwater (FT 1E31-N077A&B)

DSQR = VASQR = +/-0.02 vdc >@

7.6.2.1 Propagating Square Root Extractor Drift Through Summer (DSQR PROP SUM)

Random square root extractor drift (from Section 7.6.2) is propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Flow to condenser (SQR 1E31-K605A&B):

summer input A= DSQR = +/-0.06 vdc =A >@

RWCU inlet flow (SQR 1E31-K602A&B):

summer input B = DSQR = +/-0.02 vdc =B >@

Flow to feedwater (SQR 1E31-K603A&B):

summer input C = DSQR = +/-0.02 vdc =C >@

DSQR PROP SUM = [(1.590909*(B))2 + (1.181818*(A))2 + (1.590909*(C))2]0.5

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 48 of 86 DSQR PROP SUM = [(1.590909*(+/-0.02 vdc))2 + (1.181818*(+/-0.06 vdc))2 + (1.590909*(+/-0.02 vdc))2]0.5 DSQR PROP SUM = +/-0.083981 vdc >@

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

DSQR PROP SUM = +/-(0.083981 vdc)*(100% span) / (4 vdc)

DSQR PROP SUM = +/-2.099525% span >@

7.6.3 Summer Drift (DSUM): [1E31-K606A&B]

Input 4.3.8 does not provide a drift specification for the summer. As such, drift is determined as follows in accordance with Assumption 2.11. Therefore, DSUM = VASUM = +/-0.625% span (from Section 7.4.3.1) >@

7.6.4 Trip Bistable Drift (DTB): [1E31-N611A&B]

Inputs 4.3.4 and 4.3.5 do not provide a drift specification for the trip bistable. As such, drift is determined as follows in accordance with Assumption 2.11. Therefore, DTB = VATB = +/-0.5% span (from Section 7.4.4.1) >@

7.6.5 Calculating Loop Drift (DL):

From Section 7.3.3, DL = [(DFT PROP SUM)2 + (DSQR PROP SUM)2+ (DSUM)2 + (CSTD)2]0.5 From above results, DFT PROP SUM = +/-5.544600% span >@ Section 7.6.1.2 DSQR PROP SUM = +/-2.099525% span >@ Section 7.6.2.1 DSUM = +/-0.625% span >@ Section 7.6.3 DTB = +/-0.5% span >@ Section 7.6.4 By substituting, DL = +/-[(5.544600% span)2 + (2.099525% span)2+ (0.625% span)2 + (0.5% span)2]0.5 DL = +/-5.982576% span >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 49 of 86 7.7 Determination of Process Measurement Error (PMA) 7.7.1 The PMA due to process fluid density changes resulting from changing process conditions from scaled process fluid conditions to operating process fluid conditions, at the analyzed operating flow rates (from Section 3.7), is determined for each flow element as follows 30$ :

a) Flow to condenser (FE 1G33-N011 & FT 1G31-N075A&B) at 0 gpm operating point per Section 3.7:

From Section 4.0 of Appendix 4, the differential pressure at operating process fluid conditions (dPoper) and at the analyzed operating flow rate of 0 gpm is, dP = 0 From Figure 1 of Section 7.2, the flow rate vs. differential pressure relationship at scaled process fluid conditions is, (260 gpm 0) = K (216 inwc 0)

Solving for K, 260 gpm K=

216 gpm By substitution and at an operating differential pressure (dPoper) of 0 inwc, the measured flow rate will be as follows; 350 gpm F = 0 0 291.6 inwc F = 0 The flow rate error (PMA) due to changing process density conditions (scaled density conditions and operating density conditions) at the analyzed flow rate of 0 gpm is, ePMA = Measured Flow Rate - True Flow Rate ePMA = 0 - 0 ePMA = 0 b) RWCU inlet flow (FE 1G33-N035 & FT 1G31-N076A&B) at 327.24 gpm operating point per Section 3.7:

From Section 2.0 of Appendix 4, the differential pressure at operating process fluid conditions (dPoper) and at the analyzed operating flow rate of 327.24 gpm is, dP = 194.3 inwc From Figure 1 of Section 7.2, the flow rate vs. differential pressure relationship at scaled process fluid conditions is, (350 gpm 0) = K (291.6 inwc 0)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 50 of 86 Solving for K, 350 gpm K=

291.6 gpm By substitution and at an operating differential pressure (dPoper) of 194.3 inwc, the measured flow rate will be as follows:

350 gpm F = 194.3 inwc 0 291.6 inwc F = 285.700292 gpm The flow rate error (PMA) due to changing process density conditions (scaled density conditions and operating density conditions) at the analyzed flow rate of 327.24 gpm is, ePMA = Measured Flow Rate - True Flow Rate ePMA = 285.700292 gpm - 327.24 gpm ePMA = -41.539708 gpm [biasí]

Note that this error has a negative bias (PMA-), because it could cause the true flow rate to be higher than the measured flow rate, which is a negative bias as defined by the sign convention provided by Figure C-2 of Reference 6.1.

c) Flow to feedwater (FE 1G33-N040 & FT 1G31-N077A&B) at 92.24 gpm operating point per Section 3.7:

From Section 4.0 of Appendix 4, the differential pressure at operating process fluid conditions (dPoper) and at the analyzed operating flow rate of 92.24 gpm is, dP = 11.6 inwc From Figure 1 of Section 7.2, the flow rate vs. differential pressure relationship at scaled process fluid conditions is, (350 gpm 0) = K (197.5 inwc 0)

Solving for K, 350 gpm K=

197.5 gpm By substitution and at an operating differential pressure (dPoper) of 11.6 inwc, the measured flow rate will be as follows:

350 gpm F = 11.6 inwc 0 197.5 inwc F = 84.822973 gpm

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 51 of 86 The flow rate error (PMA) due to changing process density conditions (scaled density conditions and operating density conditions) at the analyzed flow rate of 92.24 gpm is, ePMA = Measured Flow Rate - True Flow Rate ePMA = 84.822973 gpm - 92.24 gpm ePMA = -7.417027 gpm [biasí]

Note that this error has a negative bias (PMA-), because it could cause the true flow rate to be higher than the measured flow rate, which is a negative bias as defined by the sign convention provided by Figure C-2 of Reference 6.1.

Bias PMA-HUURUV (from above) are propagated through the summer as follows:

ePMA PROP SUM = [(PMA-N035) - (PMA-N011) - (PMA-N040)]

H30$PROP SUM = [(-41.539708 gpm) - (0) - (-7.417027 gpm)]

H30$PROP SUM = -34.122681 gpm [biasí]

From Appendix 1, the output range of the summer is 0 to 220 gpm (span = 220 gpm). As such, the result is converted to percent span as follows:

H30$PROP SUM = -(34.122681 gpm)*(100% span)/(220 gpm)

H30$PROP SUM = -15.510310% span [biasí]

7.7.2 The PMA due to flow element process tap elevation head differences at the analyzed operating flow rates (from Section 3.7), is determined for each flow element as follows (PMAEL):

a) Flow to condenser (FE 1G33-N011 & FT 1G31-N075A&B) at 0 gpm operating point per Section 3.7:

From Appendix 6, PMAEL =0 b) RWCU inlet flow (FE 1G33-N035 & FT 1G31-N076A&B) at 327.24 gpm operating point per Section 3.7:

From Appendix 6, the elevation head error (PMAEL) is as indicated in the below information. Per Figure 1 of Section 7.2, the output range of the transmitters is 4 to 20 mA (span = 16 mA) and the input range of the transmitters is 0 to 291.6 inwc (span = 291.6 inwc). Therefore, PMAEL is converted from units of inwc to mA as follows:

Random 30$EL = +/-0.03 inwc >@

30$EL = +/-0.03 inwc*(16 mA/291.6 inwc) 30$EL = +/-0.001646 mA >@

Bias ePMAEL = -3.83 inwc [biasí]

ePMAEL = -3.83 inwc*(16 mA/291.6 inwc) ePMAEL = -0.210151 mA [biasí]

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 52 of 86 Note that this bias error has a negative bias (ePMA-ELEV), because it could cause the true flow rate to be higher than the measured flow rate, which is a negative bias as defined by the sign convention provided by Figure C-2 of Reference 6.1.

c) Flow to feedwater (FE 1G33-N040 & FT 1G31-N077A&B) at 92.24 gpm operating point per Section 3.7:

From Appendix 6, PMAEL = 0 7.7.2.1. Propagating Random PMAEL (UURUV7KURXJK6TXDUH5RRW([WUDFWRU 30$EL PROP SQR)

Random PMAEL errors (from Section 7.7.2) are propagated through the square root extractor at the specified operating flow rate points of interest (from Section 3.7) by application of Equations 2.4 and 2.6 (as applicable) from Appendix 2 as follows:

a) Flow to condenser (FT 1E31-N075A&B) at 0 gpm operating point per Section 3.7:

PMAEL =0 Therefore, PMAEL propagated through the square root extractor is, PMAEL PROP SQR =0 b) RWCU inlet flow (FT 1E31-N076A&B) at 327.24 gpm operating point per Section 3.7:

PMAEL = +/-0.001646 mA >@

From Appendix 2, an operating flow rate value of 327.24 gpm provides corresponding I value of 17.986745 mA, which does not results in a negative value for the denominator of Equation 2.4 of Appendix 2. Therefore, Equation 2.4 of Appendix 2 is applied as follows:

PMA PMA =

2 I 4 By substitution,

+/-0.001646 PMA = = +/-0.000220 vdc [2]

2 17.986745 4 c) Flow to feedwater (FT 1E31-N077A&B) at 92.24 gpm operating point per Section 3.7:

PMAEL =0 Therefore, PMAEL propagated through the square root extractor is, PMAEL PROP SQR =0

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 53 of 86 7.7.2.2 Propagating Bias PMAEL Errors Through Square Root Extractor (ePMAEL PROP SQR)

Bias PMAEL errors (from Section 7.7.2) are propagated through the square root extractor at the specified operating flow rate points of interest (from Section 3.7) by application of Equation 2.5 of Appendix 2 as follows:

a) Flow to condenser (FT 1E31-N075A&B) at 0 gpm operating point per Section 3.7:

ePMAEL =0 Therefore, PMAELEV propagated through the square root extractor is, ePMAEL PROP SQR= 0 b) RWCU inlet flow (FT 1E31-N076A&B) at 327.24 gpm operating point per Section 3.7:

ePMAEL = -0.210151 mA [biasí]

ePMAEL PROP SRQ = [((I - 4) + ePMAEL)0.5 - (I - 4)0.5]

From Appendix 2, the value of I that corresponds to 327.24 gpm operating flow rate is 17.986745 mA. By substitution, ePMAEL PROP SRQ = -[((17.986745 mA - 4 mA) + 0.210151 mA)0.5

- (17.986745 mA - 4 mA)0.5]

ePMAEL PROP SRQ = -0.027991 vdc [biasí]

c) Flow to feedwater (FT 1E31-N077A&B) at 92.24 gpm operating point per Section 3.7:

ePMAEL =0 Therefore, PMAELEV propagated through the square root extractor is, ePMAEL PROP SQR= 0 7.7.2.3 Propagating Random PMAEL PROP SQR Errors Through Summer PMAEL PROP SUM)

Random PMAEL PROP SQR errors (from Section 7.7.2.1) are propagated through the summer by application of Equation 3.2 of Appendix 3 as follows:

Flow to condenser (FT 1E31-N075A&B):

VXPPHULQSXW$ PMAEL PROP SQR =0 $ >@

RWCU inlet flow (FT 1E31-N076A&B):

VXPPHULQSXW% PMAEL PROP SQR = +/-0.000220 vdc % >@

Flow to feedwater (FT 1E31-N077A&B):

VXPPHULQSXW& PMAEL PROP SQR =0 & >@

PMAEL PROP SUM >  % 2 +  $ 2 +  & 2]0.5 PMAEL PROP SUM = [(1.590909*(+/-0.000220 vdc))2 + (1.181818*(0))2 + (1.590909*(0))2]0.5 PMAEL PROP SUM = +/-0.000350 vdc >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 54 of 86 From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

PMAEL PROP SUM = +/-(0.000350 vdc)*(100% span) / (4 vdc)

PMAEL PROP SUM = +/-0.008750% span >@

7.7.2.4 Propagating Bias PMAEL PROP SQR Errors Through Summer (ePMAEL PROP SUM)

Bias PMAEL PROP SQR errors (from Section 7.7.2.2) are propagated through the summer by application of Equation 3.1 of Appendix 3 as follows:

Flow to condenser (FT 1E31-N075A&B):

summer input A= ePMAEL PROP SQR =0 = eA RWCU inlet flow (FT 1E31-N076A&B):

summer input B = ePMAEL PROP SQR = -0.027991 vdc = eB [biasí]

Flow to feedwater (FT 1E31-N077A&B):

summer input C = ePMAEL PROP SQR =0 = eC ePMAEL PROP SUM = [1.590909*(eB)] - [1.181818*(eA) + 1.590909*(eC)]

ePMAEL PROP SUM = [1.590909*(-0.027991 vdc)] - [(1.181818*(0) + 1.590909*(0)]

ePMAEL PROP SUM = -0.044531 vdc [biasí]

From Figure 1 of Section 7.2, the output range of the summer is 1 to 5 vdc (span = 4 vdc). As such, the result is converted to percent span as follows:

ePMAEL PROP SUM = -(0.044531 vdc)*(100% span) / (4 vdc) ePMAEL PROP SUM = -1.113275% span [biasí]

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 55 of 86 7.8 Determination of Primary Element Accuracy (PEA)

From Appendix 5, flow element uncertainty is as follows:

a) Flow to condenser (FE 1G33-N011)

PEAN011 = +/-1.2% flow >@

From Appendix 4, the operating flow rate considered for this analysis is 0 gpm. Therefore, PEAN011 = +/-1.2% *(0)

PEAN011 =0 >@

b) RWCU inlet flow (FE 1G33-N035)

PEAN035 = +/-0.5% flow >@

From Appendix 4, the operating flow rate considered for this analysis is 327.24 gpm.

PEAN035 = +/-0.5% *(327.24 gpm)

PEAN035 = +/-1.636200 gpm >@

c) Flow to feedwater (FE 1G33-N040)

PEAN040 = +/-1.3% flow >@

From Appendix 4, the operating flow rate considered for this analysis is 92.24 gpm. Therefore, PEAN040 = +/-1.3% *(92.24 gpm)

PEAN040 = +/-1.199120 gpm >@

Random flow element uncertainties (from above) are propagated through the summer as follows:

PEAFE PROP SUM = +/-[(PEAN035)2 + (PEAN011)2 + (PEAN040)2]0.5 >@

PEAFE PROP SUM = +/-[(1.636200 gpm)2 + (0)2 + (1.199120 gpm)2]0.5 PEAFE PROP SUM = +/-2.028556 gpm >@

From Appendix 1, the output range of the summer is 0 to 220 gpm (span = 220 gpm). As such, the result is converted to percent span as follows:

PEAFE PROP SUM = +/-(2.028556 gpm)*(100% span)/(220 gpm)

PEAFE PROP SUM = +/-0.922071% span >@

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 56 of 86 8.0 RESULTS 8.1 Calculating the Technical Specification Allowable Value (AV)

From application of the equation provided in Section 7.3.4, the AV is determined for trip actuations in the increasing direction as follows:

AV = AL - (1.645/N)*(PMA2 + PEA2 + AL2)0.5 í Bias where, AL = 235 gpm (where, 100% span = 220 gpm) Appendix 1 AL = 235 gpm *(100% span)/(220 gpm)

AL = 106.818182% span N =2 Section 3.1 30$EL PROP SUM = +/-0.008750% span  Section 7.7.2.3 3($FE PROP SUM = +/-0.922071% span  Section 7.8 AL = +/-8.808771% span  Section 7.4.4.12 ePMAEL PROP SUM = -1.113275% span (biasí) Section 7.7.2.4 H30$ PROPS SUM = -15.510310% span (biasí) Section 7.7.1 eAL =0 (bias+) Section 7.4.4.12 Since the purpose of this setpoint function is to protect against exceeding an analytical limit on high leakage (235 JSP , negative biased errors (biasí) are considered. By substitution, the above equation is rewritten and solved as follows:

AV = AL - (1.645/N)*[(30$EL PROP SUM)2 + (3($FE PROP SUM)2 + (AL)2]0.5 - (eAL)

í (H30$ PROP SUM) - (ePMAEL PROP SUM)

AV = (106.818182% span) - (1.645/2)*[(0.008750% span)2 + (0.922071% span)2 +

(8.808771% span)2]0.5 í(0) - (15.510310% span) - (1.113275% span)

AV = 82.909794% span Converting to units of flow gpm where 0 to 100% instrument range corresponds to 0 to 220 gpm flow range, AVGPM = 82.909794%*(220 gpm)

AVGPM = 182.401547 gpm AVGPM = 182.4 gpm (rounded downward in the conservative direction to the precision of 0.1 gpm that is provided by Reference 6.5.1.1)

Converting AVGPM to units of instrument units vdc where 1 to 5 vdc instrument range corresponds to 0 to 220% flow range, AVVDC = (182.4 gpm YGFíYGF  220 gpm) + 1 vdc AVVDC = 4.316364 vdc AVVDC = 4.316 vdc (rounded downward in the conservative direction to the precision of voltage measurements per Inputs 4.9.1 and 4.9.2)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 57 of 86 8.2 Calculating the Loop As-Found Tolerance (AFTL)

From application of the equation provided in Section 7.3.7, the AFTL is determined as follows:

AFTL = +/-[(CL)2 +(DL)2]0.5 

CL = +/-5.703598% span  Section 7.5.3 DL = +/-5.982576% span  Section 7.6.5 By substitution, the above equation is rewritten and solved as follows:

AFTL = +/-[(5.703598% span)2 +(5.982576% span)2]0.5 

AFTL = +/-8.265727% span 

Converting to units of flow gpm where 0 to 100% instrument range corresponds to 0 to 220 gpm flow range, AFTL GPM = +/-8.265727%*(220 gpm)

AFTL GPM = +/-18.184599 gpm AFTL GPM = +/-18.2 gpm (rounded upward in the conservative direction to the precision of 0.1 gpm that is provided by Reference 6.5.1.1)

Converting AFTL GPM to units of instrument units vdc where 1 to 5 vdc instrument range corresponds to 0 to 220% flow range, AFTL VDC = +/-(18.2 JSP YGFíYGF  JSP AFTL VDC = +/-0.330909 vdc AFTL VDC = +/-0.331 vdc (rounded upward in the conservative direction to the precision of voltage measurements per Inputs 4.9.1 and 4.9.2) 8.3 Calculating the Nominal Trip Setpoint (NTSP)

From application of the equation provided in Section 7.3.5, the NTSP is determined for trip actuations in the increasing direction as follows:

NTSP =AV - AFTL where, AV = 182.4 gpm Section 8.1 AFTL GPM = +/-18.2 gpm Section 8.2 By substitution, the above equation is rewritten and solved as follows:

NTSPGPM = 182.4 gpm - 18.2 gpm NTSPGPM = 164.2 gpm Converting NTSPGPM to units of instrument units vdc where 1 to 5 vdc instrument range corresponds to 0 to 220% flow range,

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 58 of 86 NTSPVDC = (164.2 JSP YGFíYGF  JSP YGF NTSPVDC = 3.985455 vdc NTSPVDC = 3.985 vdc (rounded downward in the conservative direction to the precision of voltage measurements per Inputs 4.9.1 and 4.9.2) 8.4 Calculating the Loop As-Left Tolerance (ALTL)

The ALTL was determined as follows:

ALTL = +/-2.618358% span () Section 7.5.1.3 Converting to units of flow gpm where 0 to 100% instrument range corresponds to 0 to 220 gpm flow range, ALTL GPM = +/-2.618358%*(220 gpm)

ALTL GPM = +/-5.760388 gpm ALTL GPM = +/-5.8 gpm (rounded upward in the conservative direction to the precision of 0.1 gpm that is provided by Reference 6.5.1.1)

Converting ALTL GPM to units of instrument units vdc where 1 to 5 vdc instrument range corresponds to 0 to 220% flow range, ALTL VDC = (+/-5.8 JSP YGFíYGF  JSP ALTL VDC = +/-0.105455 vdc ALTL VDC = +/-0.106 vdc (rounded upward in the conservative direction to the precision of voltage measurements per Inputs 4.9.1 and 4.9.2) 8.5 Calculating the Summer (1E31-K606A&B) and Trip Bistable (1E31-N611A&B) As-Left Tolerance (ALTSUM and ALTTB)

Summer and trip bistable as-left tolerances have been determined in above Section 7.5.1.2. Instrument span is 4 vdc (where instrument range is 1 to 5 vdc from Figure 1 of Section 7.2). Therefore, Summer ALTSUM = +/-0.625% span ALTSUM = +/-0.625%*(4 vdc)

ALTSUM = +/-0.025 vdc Trip Bistable ALTTB = +/-0.5% span ALTTB = +/-0.5%*(4vdc)

ALTTB = +/-0.02 vdc 8.6 Calculating the Summer (1E31-K606A&B) and Trip Bistable (1E31-N611A&B) As-Found Tolerance (AFTSUM and AFTTB)

Instrument span is 4 vdc (where instrument range is 1 to 5 vdc from Figure 1 of Section 7.2). From application of the equation provided in Section 7.3.6, Summer AFTSUM = +/-[(ALTSUM)2 + (DSUM)2 + (CSUM)2 + (CSTD)2]0.5

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 59 of 86 where, ALTSUM = +/-0.025 vdc Section 8.5 DSUM = +/-0.625% span Section 7.6.3 DSUM = +/-0.625%*(4 vdc)

DSUM = +/-0.025 vdc CSUM = +/-1.137951% span Section 7.5.2.2.3 CSUM = +/-1.137951%*(4 vdc)

CSUM = +/-0.045518 vdc CSTD =0 Section 7.5.2.2 By substitution, the above equation is rewritten and solved as follows:

AFTSUM = +/-[(0.025 vdc)2 + (0.025 vdc)2 + (0.045518)2 + (0)2]0.5 AFTSUM = +/-0.057636vdc AFTSUM = +/-0.058 vdc (rounded upward in the conservative direction to the precision of voltage measurements per Inputs 4.9.1 and 4.9.2 Trip Bistable AFTTB = +/-[(ALTTB)2 + (DTB)2 + (CTB)2 + (CSTD)2]0.5 where, ALTTB = +/-0.02 vdc Section 8.5 DTB = +/-0.5% span Section 7.6.4 DTB = +/-0.5%*(4 vdc) = +/-0.02 vdc CTB = +/-0.333333% span Section 7.5.2.3 CTB = +/-0.333333%*(4 vdc) = +/-0.013333 vdc CSTD =0 Section 7.5.2.3 By substitution, the above equation is rewritten and solved as follows:

AFTTB = +/-[(0.02 vdc)2 + (0.02 vdc)2 + (0.013333)2 + (0)2]0.5 AFTTB = +/-0.031269 vdc AFTTB = +/-0.032 vdc (rounded upward in the conservative direction to the precision of voltage measurements per Inputs 4.9.1 and 4.9.2

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 60 of 86

9.0 CONCLUSION

S 9.1 In accordance with the Section 1.0 purpose statement, the parameters established by this analysis are as follows:

a) The calculated technical specification allowable value for the analyzed setpoint function is, AV = 182.4 gpm (4.316 vdc) [Section 8.1]

b) The calculated nominal trip setpoint for the analyzed setpoint function is, NTSP = 164.2 gpm (3.985 YGF [Section 8.3]

c) The calculated loop as-found tolerance for the analyzed setpoint function is, AFTL = +/-18.2 gpm (+/-0.331 vdc) [Section 8.2]

d) The calculated loop as-left tolerance for the analyzed setpoint function is, ALTL = +/-5.8 gpm (+/-0.106 vdc) [Section 8.4]

The above results (i.e., AV, NTSP, AFTL, ALTL) are all determined based on the following specified operating flow (true flow) rate points of interest, as established in Appendix 4:

RWCU Inlet Flow (FT 1E31-N076A&B) = 327.24 gpm Feedwater Flow (FT 1E31-N077A&B) = 92.24 gpm Condenser Flow (FT 1E31-N075A&B) = 0 gpm An illustration of the above results is provided by the following Figure 2.

e) The calculated as-left and as-found tolerances for the summer (1E31-K606A&B] are, ALTSUM = +/-0.025 vdc [Section 8.5]

AFTSUM = +/-0.058 vdc [Section 8.6]

f) The calculated as-left and as-found tolerances for the trip bistable (1E31-N611A&B] are, ALTTB = +/-0.02 vdc [Section 8.5]

AFTTB = +/-0.032 vdc [Section 8.6]

9.2 This analysis addresses only normal operating process and normal operating environmental conditions.

[See Section 1.0.]

9.3 This analysis considers seismic error effects during and after an SSE. [See Section 1.0.]

9.4 This analysis is limited to the amount of the leakage that can occur between the RWCU inlet flow element (1G33-N035] and the two (2) RWCU discharge flow elements [1G33-N011 and 1G33-N040]. [See Section 1.0.]

9.5 This analysis considers the instrument loop configuration as depicted in Section 7.2. This analysis also considers all of the flow transmitters (1E31-N075A&B, -N076A&B, -N-77A&B) to be configured with Damping set for time response = 0.4 sec or greater as noted in Section 7.4.1.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 61 of 86 9.6 The established parameters listed above in Section 9.1 are valid provided the following assumptions are satisfied:

9.6.1 It is assumed that calibration tool errors are equal to, or better than, the vendor accuracy (VA) of the calibrated instrument to satisfy a 1:1 accuracy ratio to the instrument under calibration. [see Assumption 2.8.]

9.6.2 It is assumed that the calibration adjustments for the summer (1E31-K606A&B) are performed using the same method that is currently used for summer (1E31-K604A&B) which is described in Section 8.17 of Input 4.9.1. This method is defined as applying three (3) simulated 1 to 5 vdc input test voltages at input of the summer, while monitoring the summer output voltages for proper readings within an acceptable as-left tolerance. [See Assumption 2.12.1.1.]

9.6.3 It is assumed that the calibration adjustments for trip bistable (1E31-N611A&B) are performed using the same method that is currently used for trip bistable (1E31-N609A&B) which is described in Section 8.19 of Input 4.9.1. This method is defined as slowly raising a simulated input test voltage at the input of the trip bistable, while monitoring the trip bistable output for trip actuation within an acceptable as-left tolerance. [See Assumption 2.12.1.2.]

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 62 of 86 Figure 2 RWCU Differential Flow Setpoint - High Trip For Detecting Large Leaks Analytical Limit (AL) 235 gpm Instrument Upper Range Limit 220 gpm (5.000 vdc)

Tech Spec Allowable Value (AV) 182.4 gpm (4.316 vdc)

Margin = 0 gpm (0 vdc)

AFTL_HI 182.4 gpm (4.316 vdc)

ALTL_HI 170.0 gpm (4.091 vdc)

NTSP 164.2 gpm (3.985 vdc )

ALTL_LO 158.4 gpm (3.879 vdc)

AFTL_LO 146.0 gpm (3.654 vdc)

Instrument Lower Range Limit 0 gpm (1.000 vdc)

The above results (i.e., AV, NTSP, AFTL, ALTL) are all determined based on the following specified operating flow (true flow) rate points of interest, as established in Appendix 4:

RWCU Inlet Flow (FT 1E31-N076A&B) = 327.24 gpm Feedwater Flow (FT 1E31-N077A&B) = 92.24 gpm Condenser Flow (FT 1E31-N075A&B) = 0 gpm

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 63 of 86 APPENDIX 1 Scaling Equation for Summer 1E31-K606A&B The purpose of this Appendix 1 is to determine the scaling equation for the summer (1E31-K606A&B).

Per Section 1.0 and Input 4.1, the analytical limit associated with the differential flow setpoint function that is evaluated by this analysis is 235 gpm. As such, it is reasonable to select the output range for the summer to be set equal to 0 to 220 gpm (or 0 to 100% span), provided the calculated technical specification allowable value (as purposed by this analysis as noted in Section 1.0) is bounded by this output range.

From sheet 13 of Input 4.3.6 and Figure 1 of Section 7.2, the summer input flow ranges are as follows:

Input From Input No. Flow Range Flow to condenser A 0 to 260 gpm directly corresponding to 4 to 20 mA and 1 to 5 vdc RWCU inlet flow B 0 to 350 gpm directly corresponding to 4 to 20 mA and 1 to 5 vdc Flow to feedwater C 0 to 350 gpm directly corresponding to 4 to 20 mA and 1 to 5 vdc From sheets 12 and 13 of Input 4.3.6 and per Section 1.0 and Input 4.1, the summer performs its function by subtracting the summation of Inputs A and C from Input B to provide output differential flow range from 0 to 220 gpm (K). As such, the normalized scaling equation is determined as follows in accordance with Appendix K of Reference 6.1:

K = gainB*B - (gainA*A + gainC*C)

Where, gainA = (260 gpm)/(220 gpm) = 1.181818 gainB = (350 gpm)/(220 gpm) = 1.590909 gainC = (350 gpm)/(220 gpm) = 1.590909 As such, the normalized scaling equation is, K = 1.590909*B - (1.181818*A + 1.590909*C) [Equation 1.1]

Where, A = flow rate to condenser (or percent of flow span where flow range = 0 to 260 gpm)

B = RWCU inlet flow rate (or percent of flow span where flow range = 0 to 350 gpm)

C = flow rate to feedwater (or percent of flow span where flow range = 0 to 350 gpm)

K = flow rate differential (or percent of differential flow span where differential flow range = 0 to 220 gpm)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 64 of 86 APPENDIX 2 Transfer Function for Square Root Extractors 1E31-K602A&B, 1E31-K603A&B, 1E31-K605A&B 1.0 Purpose The purpose of this Appendix 2 is to determine the equations for propagating input errors through the square root extractors (1E31-K602A&B, -K603A&B, -K605A&B) at a specified operating point of interest.

2.0 Method for Propagating Random Input Uncertainties From Inputs 4.9.1 and 4.9.2, and Figure 1 of Section 7.2, the instrument loop configuration contains square root extractors that convert the 4 to 20 mA signal from the flow transmitters to a 1 to 5 vdc output signal. From this information, the transfer function to propagate input errors through the square root extractor is determined as follows in accordance with Appendix K of Reference 6.1. [Note: For further clarification, see Sections 1.0 and 7.4.2, and Figure 1 for discussions regarding the GE signal resistor units (SRUs) that are located within the instrument loops.]

V 1 = KI 4 [Equation 2.1]

Where V is the output in terms of vdc and I is the input current from the transmitter in terms of milliamps. By substitution and solving for K, 51 K= =1 [Equation 2.2]

20 4 Therefore, V 1 = I 4 [Equation 2.3]

Since this is a non-linear function, the error propagation from input to output depends on the operating point of interest. The transfer of the error at any point can be determined by taking the derivative of this function with respect to I (i.e., the operating point of interest). The result is as follows when propagating random input errors through the square root extractor (Appendix K of Reference 6.1),

dI dV = [Equation 2.4]

2I 4 Where dV is the random output uncertainty in terms of vdc, and G, is the random input uncertainty from the transmitter in terms of milliamps, and I is the input current from the transmitter at the operating point of interest in terms of milliamps.

3.0 Method for Propagating Non-Random Input Errors From Appendix k of Reference 6.1, the method used when propagating non-random input errors through the square root extractor is as follows: (Appendix K of Reference 6.1) edV = [((I - 4) + edI)0.5 - (I - 4)0.5] [Equation 2.5]

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 65 of 86 APPENDIX 2 Transfer Function for Square Root Extractors 1E31-K602A&B, 1E31-K603A&B, 1E31-K605A&B (Continued)

Where eV is the non-random output error in terms of vdc, and edI is the non-random input error from the transmitter in terms of milliamps, and I is the input current from the transmitter at the operating point of interest in terms of milliamps.

4.0 Method for Propagating Random Input Uncertainties when the Equation 2.4 Denominator is Zero (0)

When propagating random input uncertainties through the square root extractor and the denominator of Equation 2.4 is equal to zero (0), Equation 2.5 is applied and modified as follows:

dV = +/-[((I - 4) + lG,l)0.5 - (I - 4)0.5] [Equation 2.6]

Where V is the random output uncertainty in terms of vdcDQG³_G,_'LVWKHDEVROXWHYDOXHRIWKH

random input uncertainty from the transmitter in terms of milliamps, and I is the input current from the transmitter at the operating point of interest in terms of milliamps.

5.0 Determining the Values of I that Correspond to the Operating Flow Rates of Interest as Determined in Appendix 4 Converting flow rate (F) in units of gpm into units of I:

F = K*(I - 4)0.5 K = (flow span in gpm)/(20 mA - 4 mA)0.5 By substitution, F = [(flow span in gpm)/(16 mA)0.5]*( I - 4)0.5 Solve for I:

I = [(F)*[(16 mA)0.5]/(flow span in gpm)]2 + 4 mA I = [(F)*(4 mA)/(flow span in gpm)]2 + 4 mA [Equation 2.7]

From Appendix 4, the specific operating flow rates of interest to be used when determining error for this analysis shall be as follows:

Flow to condenser (FT 1E31-N075A&B)

Flow = 0 gpm RWCU inlet flow (FT 1E31-N076A&B)

Flow = 327.24 gpm Flow to feedwater (FT 1E31-N077A&B)

Flow = 92.24 gpm

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 66 of 86 APPENDIX 2 Transfer Function for Square Root Extractors 1E31-K602A&B, 1E31-K603A&B, 1E31-K605A&B (Continued)

The values of I (transmitter output current in mA) that corresponds with the above operating flow rates of interest are determined from above Equation 2.7 as follows:

Flow to condenser (FT 1E31-N075A&B)

Flow = 0 gpm Flow Range = 0 to 260 gpm (from Appendix 1)

I = [(F)*(4 mA)/(flow span in gpm)]2 + 4 mA I = [(0)*(4 mA)/(260 gpm)]2 + 4 mA I = 4 mA RWCU inlet flow (FT 1E31-N076A&B)

Flow = 327.24 gpm Flow Range = 0 to 350 gpm (from Appendix 1)

I = [(F)*(4 mA)/(flow span in gpm)]2 + 4 mA I = [(327.24 gpm)*(4 mA)/(350 gpm)]2 + 4 mA I = 17.986745 mA Flow to feedwater (FT 1E31-N077A&B)

Flow = 92.24 gpm Flow Range = 0 to 350 gpm (from Appendix 1)

I = [(F)*(4 mA)/(flow span in gpm)]2 + 4 mA I = [(92.24 gpm)*(4 mA)/(350 gpm)]2 + 4 mA I = 5.111277 mA

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 67 of 86 APPENDIX 3 Transfer Function for Summer 1E31-N611A&B The purpose of this Appendix 3 is to determine the equations for propagating input errors through the summer (1E31-N611A&B).

From Equation 1.1 of Appendix 1, the normalized scaling equation for the summer is, K = 1.590909*B - (1.181818*A + 1.590909*C)

Where, A = flow rate to condenser (or percent of flow span where flow range = 0 to 260 gpm)

B = RWCU inlet flow rate (or percent of flow span where flow range = 0 to 350 gpm)

C = flow rate to feedwater (or percent of flow span where flow range = 0 to 350 gpm)

K = flow rate differential (or percent of differential flow span where flow range = 0 to 220 gpm)

In accordance with Appendix K of Reference 6.1, the equation for propagating input errors through the summer can be determined by using partial derivatives. The partial derivative of the above equation with respect to A, B, and C is,

.  %- ( $+  &) [Equation 3.1]

From Appendix K of Reference 6.1, Equation 3.1 is used to propagate bias errors through the summer, and the following Equation 3.2 is used to propagate random uncertainties through the summer.

For propagating random uncertainties:

. = [( %)2 + ( $)2 + ( &)2]0.5 [Equation 3.2]

Where,

$ = input error associated with the flow rate to condenser (FT 1E31-N075A&B flow loop)

% = input error associated with the RWCU inlet flow rate (FT 1E31-N076A&B flow loop)

& = input error associated with the flow rate to feedwater (FT 1E31-N077A&B flow loop)

. = output error associated with the flow rate differential

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 68 of 86 APPENDIX 4 Operating Flow Rates 1.0 Purpose The purpose of this Appendix is to determine the normal operating flow rates and the flow element differential pressures to be used for determining the errors of the instruments associated with flow elements 1G33-N035, 1G33-N040, and 1G33-N011.

2.0 Methodology The differential pressure across reactor water cleanup input flow element 1G33-N035 is calculated at rated flow and temperature conditions listed in Extended Power Uprate Task T0100: Reactor Heat Balance (Input 4.6.2).

The differential pressure across the reactor water cleanup return to feedwater flow element 1G33-N040 is based on the rated system flow minus an analytic differential flow of 235 gpm (Appendix 1). The differential pressure across 1G33-N040 is calculated at normal operating temperature listed in Extended Power Uprate Task T0100:

Reactor Heat Balance (Input 4.6.2).

3.0 Flow Element 1G33-N035 Flow Element 1G33-N035 measures reactor water cleanup input flow from the reactor water recirculation system.

The flow element is venturi part number 21A3544AAP001 (DL851E703AC, Input 4.3.10).

Flow element operating data: (Permutit drawing 556-30121, Input 4.3.12)

Operating pressure: 1100 psig Maximum flow: 334 gpm Operating Temperature: 125° F to 540° F (540° F used in calculation)

Differential at Max Flow: 200 inches of water column Instrument Calibration (4 - 20 mA): (Ref. FDDR LH1-5596, Input 4.3.7)

Flow Rate: 0-350 gpm Differential Pressure: 0-291.6 INWC Temperature: 125° F Differential pressure at 350 gpm and 540°:

= 200 = 219.6 Parameters from EPU-T0100 (Input 4.6.2):

Reactor Steam Dome Pressure: 1040 psia WCS Flow: 1.240E05 lbs/hr WCS Inlet Temperature: 529.7° F Specific volume of water at 529.7° F vf = 0.021167 ft3/lb (interpolated from 1967 ASME Steam Tables for saturated steam and saturated water, Reference 6.2)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 69 of 86 APPENDIX 4 Operating Flow Rates (Continued) 1 ft3 = 7.4805195 gallons (liquid) (Reference 6.7)

WCS inlet flow at 529.7° F:

1.240E05

= 0.021167 7.4805195 = 327.24 60 Flow curve for flow element 1G33-N035 is calculated at 540° F per flow curve 528-52486 (Input 4.3.22) and purchase specification 21A3544AA (Input 4.3.14). Per the temperature correction curve, 528-52489 (Input 4.3.23), the correction for 530° F (rounded) is 0.994. Therefore, the differential pressure at 327.24 gpm and 530° F is:

= . = .

4.0 Flow Element 1G33-N040 Flow Element 1G33-N040 measures reactor water cleanup return flow to feedwater. The flow element is an orifice plate part number 21A3548ACP001 (DL851E703AC, Input 4.3.10).

Flow element operating data: (Ref. Purchase Specification Data Sheet 21A3548AC, drawing VPF-5214-034, FDDR LH1-5014) [Inputs 4.3.16, 4.3.20, 4.3.21, respectively]

Operating pressure: 1250 psig Maximum flow: 334 gpm Operating Temperature: 437° F Differential at Max Flow: 151.9 inches of water column Instrument Calibration (4 - 20 mA): (Ref. FDDR LH1-5596, Input 4.3.7)

Flow Rate: 0-350 gpm Differential Pressure: 0-197.5 INWC Temperature: 125° F Differential pressure at 350 gpm and 437° F:

350

= 151.9 = 166.8 334

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 70 of 86 APPENDIX 4 Operating Flow Rates (Continued)

The analytic limit for the high differential flow is 235 gpm (Appendix 1). Since the reactor water cleanup flows do not have temperature compensation, the analog flow signals are volumetric. A leak is postulated at normal operating conditions; therefore, all flow is returned to the feedwater system. A 235 gpm leak in the system would result from a return flow of 92.24 gpm (327.24 gpm minus 235 gpm).

The temperature of the reactor water cleanup flow to the feedwater system is 431.7° F (EPU-T0100, Input 4.6.2). Per FDDR LH1-5014 (Input 4.3.21), the temperature correction factor, FT, can be calculated by the following:

. ()

=

Specific volumes (1967 ASME Steam Tables, Reference 6.2):

39.2° F = 0.016019 ft3/lb Note: The density of water at 4°C is used to determine specific gravity.

431.7° F = 0.019125 ft3/lb (interpolated) 437° F = 0.019208 ft3/lb (interpolated)

Density (inverse of specific volumes):

39.2° F = 1/0.016019 ft3/lb = 62.42587 lb/ft3 431.7° F = 1/0.019125 ft3/lb = 52.28758 lb/ft3 437° F = 1/0.019208 ft3/lb = 52.06164 lb/ft3 The specific gravity is equal to:

=

52.28758

. = = 0.837595 62.42587 52.06164

= = 0.833975 62.42587 The correction factor at 431.7° F is:

0.833975

. = = 0.9978 0.837595 The differential pressure across flow element 1G33-N040 at 92.24 gpm and 431.7° F is:

= . = .

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 71 of 86 APPENDIX 4 Operating Flow Rates (Continued) 5.0 Flow Element 1G33-N011 Flow Element 1G33-N011 measures reactor water cleanup reject flow to the condenser. The flow element is an orifice plate part number 21A3548AAP001 (DL851E703AC, Input 4.3.10).

Flow element operating data: (Ref. Purchase Specification Data Sheet 21A3548AA, drawing VPF-5214-033)

[Inputs 4.3.15 and 4.3.19, respectively]

Operating pressure: 1250 psig Maximum flow: 250 gpm Operating Temperature: 125° F Differential at Max Flow: 200 inches of water column Instrument Calibration (4 - 20 mA): (Ref. Design Specification Data sheet 22A3735AC, Input 4.3.6)

Flow Rate: 0-260 gpm Differential Pressure: 0-216 INWC (ratioed up from 200 at 250 gpm)

Temperature: 125° F Flow is rejected to the main condenser only during plant startup. There is no flow during normal operation.

Therefore, the differential pressure across flow element 1G33-N011 during normal plant operation is zero.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 72 of 86 APPENDIX 5 Flow Element Uncertainty 1.0 Purpose The purpose of this Appendix is to determine the uncertainty of flow elements 1G33-N035, 1G33-N040, and 1G33-N011.

2.0 Methodology The uncertainty of the flow elements is determined using the methods and equations in ASME PTC 19.1-1985, Measurement Uncertainty, ASME PTC 19.5-2004, Flow Measurement, and ASME MFC-3M-1989, Measurement of Fluid Flow in Pipes Using Orifice, Nozzle, and Venturi. [References 6.4, 6.8, 6.3, respectively]

The uncertainty of flow elements is determined using PTC 19.1 (Reference 6.4) Equation 5.2 (flow venturi) and ASME PTC 19.5 (Reference 6.8) Equation 4-12.2 (flow orifice). The orifice flow coefficient uncertainty value used is dependent on the beta value (ratio of orifice diameter to pipe diameter) and the Reynolds number. The Reynolds numbers are calculated for flow orifices 1G33-N040 and 1G33-N011 (PTC 19.5, Equation 3-15.9) [Ref.

6.8] and the values compared to Reynolds number limitations specified in PTC 19.5 (Ref. 6.8) Section 4.9.

The upstream and downstream straight pipe lengths from each flow element are compared to the minimum recommended upstream and downstream straight pipe lengths in ASME MCF-3M-1989 (Ref. 6.3) tables 2 and 7 to determine if an additional 0.5% uncertainty should be added to the calculated flow uncertainty.

The total flow element uncertainty is considered a 2 sigma value.

3.0 Flow Element 1G33-N035 Uncertainty Flow Element 1G33-N035 measures reactor water cleanup input flow from the reactor water recirculation system.

The flow element is venturi part number 21A3544AAP001 (DL851E703AC, Input 4.3.10).

Flow element operating data: (Ref. P175-000003, Permutit drawing 556-30121, Purchase Specification 21A3544AA) [Inputs 4.3.11, 4.3.12, 4.3.14, respectively]

Operating pressure: 1100 psig Maximum flow: 334 gpm Pipe Line Size: 6 - Schedule 80 Nominal Size: 5.761 +/- 0.010 inches Bore Nominal Size: 1.903 +/- 0.003 inches Operating Temperature: 125° F to 540° F (540° F used in calculation)

Differential at Max Flow: 200 inches of water +20% / -5%

= 1.903/5.761 = 0.3303 Installed Accuracy: 1% at full flow

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 73 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

Instrument Calibration (4-20 mA): (Ref. FDDR LH1-5596, Input 4.3.7)

Flow Rate: 0-350 gpm Differential Pressure: 0-291.6 INWC Temperature: 125° F Flow Element Uncertainty Equation 5.3 in ASME PTC 19.1-1985 (Reference 6.4) provides the flow uncertainty of a venturi.

2 0.5 Bm B 2 24 BD 2 Bd 2 1 B 2 1 Bh 2 m

= 1 x CC + 1-4 x D

+ 4 x d

+ x

+ x h (Equation 1) 1- 2 2 Where:

= flow coefficient uncertainty

= ratio of bore diameter to pipe diameter

= pipe diameter uncertainty

= bore diameter uncertainty

= differential pressure uncertainty

= fluid density uncertainty This calculation is only concerned with the accuracy of the flow element itself. Hence, the density term and differential pressure term of the above equation drops out and the revised uncertainty equation for the primary element becomes:

= + + (Equation 2) 1G33-N035 Uncertainty Flow element 1G33-N035 calibration is based on similar calibrated venturi per P175-000003 (Input 4.3.11).

According to the calibration report in P175-000003 (Input 4.3.11), the flow element was calibrated over a pipe Reynolds number range of approximately 120,000 to 500,000. The mean Discharge Coefficient was calculated. A constant Discharge Coefficient of 0.9897 was observed above a Reynolds number of approximately 330,000.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 74 of 86 APPENDIX 5 Flow Element Uncertainty (Continued) 7KHUHIRUHDYDOXHRIZLOOEHXVHGIRU per PTC 19.5 (Ref. 6.8), paragraph 5.4.f.

= 0.3333%

= (0.010/5.761)*100 = 0.1736%

= (0.003/1.903)*100 = 0.1576%

Combining the values:

2 0.3303 2

= (0.3333%) + 0.1736% + 0.1576% .

1 0.3303 1 0.3303

= 0.461%

Per paragraph 9.8.4 of ASME MCF-3M-1989 (Ref. 6.3), an additional 0.5% uncertainty on discharge coefficient is added if the length of the straight piping upstream of the venturi meets the minimum recommended upstream straight length listed in Table 7.

The upstream and downstream straight lengths of piping from venturi 1G33-N035 are determined from drawing M06-1076, Sheet 15 (Input 4.2.5).

Flow element 1G33-N035 is shown on drawing M06-1076, Sheet 15 (Input 4.2.5) as shown below.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 75 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

EL 7% -5 tRTOIS 6 WELO E.NO !="OR SCI-IEC>. 80

• c~ .. 5-~i.~* Bont E"1DS SECTION . 2-2*

PL~N "A" SHT. I PLAN. B' 5HT. I The distance upstream of the flow element to the first elbow is approximately 738'-8" minus 732' : : : ; 6' . This is equivalent to 12.5 pipe diameters (6* 12/5.761). The distance downstream of the flow element to the first elbow is approximately 738' -8" plus 2'-2' minus 756'-5"::::::; 24' . This is equivalent to 50 pipe diameters.

The upstream distance exceeds the recommended minimum distance of 0.5D in ASME MFC-3M-1989 (Ref.

6.3), Table 7, "Recommended Straight Lengths for ASME Venturi Tubes (for 0.5% Additional Uncertainty)".

In addition, per MFC-3M (Ref. 6.3) paragraph 6.4.2, since the upstream straight length is " longer than twice the recommended, no additional uncertainty is indicated." The downstream elbow is >4D and therefore does not affect accuracy (MFC-3M, Section 9.8.5) [Ref. 6.3]. Therefore, no additional uncertainty is required and the Primary Element Accuracy (PEA) for flow element 1G33-N035 is +/-0.461%. This value is rounded up to

+/-0.5% for use in the setpoint calculation.

PEANoJs = +/-0.5% of flow (2o)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 76 of 86 APPENDIX 5 Flow Element Uncertainty (Continued) 4.0 Flow Element 1G33-N040 Uncertainty Flow Element 1G33-N040 measures reactor water cleanup return flow to feedwater. The flow element is an orifice plate part number 21A3548ACP001 (DL851E703AC, Input 4.3.10).

Flow element operating data: (Ref. Purchase Specification Data Sheet 21A3548AC, drawing VPF-5214-034, and FDDR LH1-5014) [Inputs 4.3.16, 4.3.20, and 4.3.21]

Operating pressure: 1250 psig Maximum flow: 334 gpm Pipe Line Size: 4 - Schedule 80 Nominal Size: 3.826 +/- 0.004 inches Bore Nominal Size: 2.536 +/- 0.003 inches Operating Temperature: 437° F Differential at Max Flow: 151.9 inches of water

= 2.536/3.826 = 0.6628 Installed Accuracy: 1% at full flow Instrument Calibration (4-20 mA): (Ref. FDDR LH1-5596, Input 4.3.7)

Flow Rate: 0-350 gpm Differential Pressure: 0-197.5 INWC Temperature: 125° F Per ASME PTC 19.5 (Reference 6.8) Equation 4-12.2, the uncertainty of a flow orifice is:

= + + + +

+ (Equation 3)

This calculation is only concerned with the accuracy of the flow element itself. Hence, the density term and differential pressure term of the above equation drops out and the revised uncertainty equation for the flow orifice.

= [ + + +

]. (Equation 4)

A limitation for the use of the flow coefficient uncertainty values listed in PTC 19.5 (Ref. 6.8) section 4.9 is that the Reynolds number is between 104 and 108. Therefore, the Reynolds number will be calculated at normal operating conditions and at the minimum flow rate which will initiate the delta flow logic.

Reynolds number at normal operating conditions:

The Reynolds number is calculated per PTC 19.5 (Ref. 6.8), Equation 3-15.9 following:

= (Equation 5)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 77 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

Where:

RD = Reynolds number qm = mass flow (lb/hr)

= Kinematic viscosity of water at operating temperature (ft2/sec)

= 3.14159 D = pipe diameter (inches)

The flow rate at normal operating conditions is 1.24 x 105 lb/hr at 431.7° F. (Input 4.6.2)

The kinematic viscosity of water at 437° F is 1.55 x 10-6 ft2/sec (Ref. 6.9)

Substituting into Equation 5 gives:

= = 8.87 x 107 The Reynolds number at normal flow conditions meets the limitation that the Reynolds number is between 104 and 108.

Operation at minimum the flow rate that will initiate the delta flow logic:

Per Appendix 4 of this calculation, the return flow rate through 1G33-N040 at maximum RWCU delta flow is 92.24 gpm at 431.7° F and the specific volume is 0.019125 ft3/lb.

Convert the gpm flow rate to lb/hr:

Note: 1 cubic foot = 7.4805195 gallon (liquid) (Input 6.7)

/( = 92.24 ()60 /()1/7.4805195 gallons/ )(1/0.019125 /)

/ = 38,685 /

Substituting the 38,685 lb/hr flow into Equation 5 gives:

= = 2.77 x 107 The Reynolds number at minimum flow conditions meets the limitation that the Reynolds number is between 104 and 108.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 78 of 86 APPENDIX 5 Flow Element Uncertainty (Continued) 1G33-N040 Uncertainty Per PTC 19.5 (Ref. 6.8) paragraph 4.9.b, is equal to when LVDQGWKH5H\QROGVQXPEHULV

4 8 between 10 and 10 .

= 0.6628%

is zero for water.

= (0.004/3.826)*100 = 0.1045%

= (0.003/2.536)*100 = 0.1183%

Combining the values in Equation 4:

2 0.6628 2

= (0.6628%) + (0) + (0.1045%)

+ ( 0.1183%)

1 0.6628 1 0.6628

= 0.726%

Per ASME MCF-3M-1989 (Ref. 6.3) an additional 0.5% uncertainty is added if the upstream and downstream straight pipe lengths meet the minimum recommended upstream and downstream straight pipe lengths in Table 2.

The upstream and downstream straight lengths of piping from orifice 1G33-N040 are determined from drawing RT19 (Input 4.2.7).

Flow element 1G33-N040 is shown on drawing RT19 (Input 4.2.7) as shown below.

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 79 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

Iii~

) cP1 The distance upstream of the flow element to the valve 1G33-F039 (gate valve per drawing 93-14647, Input 4.3 .18) is 6' -11 ". This is equivalent to 21. 7 pipe diameters (83"/ 3 .826" ). The distance downstream of the flow element to check valve 1G33-F051 is 2'-3". This is equivalent to 7 pipe diameters.

The recommended upstream and downstream distances are listed in ASME MFC-3M-1989 (Ref. 6.3), Table 2, "Recommended Straight Lengths for Nozzles and Orifice Plates for 0.5% Additional Uncertainty" .

For a beta of 0.66 (use 0.7 in table), the recommended distance to an upstream gate valve is 10D. The recommended downstream distance to all fittings listed in the table is 3.5D. Per MFC-3M-1989 (Ref. 6.3),

paragraph 6.4.2 no additional uncertainty is indicated if the straight lengths are equal to or longer than twice the values given in Table 2. Therefore, no additional uncertainty is added for the installed straight lengths.

However, Table 2 does not list a check valve. Therefore, for conservatism, an additional 0.5% will be added to the uncertainty due to the downstream check valve.

Therefore, the Primary Element Accuracy (PEA) for flow element 1G33-N040 is 0.727% plus 0.5% =

+/-1.227%. This value is rounded up to +/-1.3% for use in the setpoint calculation.

PEANo4o = +/-1.3% of flow (2o)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 80 of 86 APPENDIX 5 Flow Element Uncertainty (Continued) 5.0 Flow Element 1G33-N011 Uncertainty Flow Element 1G33-N011 measures reactor water cleanup reject flow to the condenser or radwaste. The flow element is an orifice plate part number 21A3548AAP001 (DL851E703AC, Input 4.3.10).

Flow element operating data: (Ref. Purchase Specification Data Sheet 21A3548AA, drawing VPF-5214-033)

[Inputs 4.3.15, 4.3.19, respectively]

Operating pressure: 1250 psig Maximum flow: 250 gpm Pipe Line Size: 4 - Schedule 80 Nominal Size: 3.826 +/- 0.004 inches Bore Nominal Size: 2.196 +/- 0.003 inches Operating Temperature: 125° F Differential at Max Flow: 200 inches of water

= 2.196/3.826 = 0.5740 Instrument Calibration (4-20 mA): (Ref. Design Specification Data sheet 22A3735AC, Input 4.3.6)

Flow Rate: 0-260 gpm Differential Pressure: 0-216 INWC (ratioed up from 200 at 250 gpm)

Temperature: 125° F Per Operating Procedure 3303.01 (Ref. 6.9), the reject flow to the main condenser is:

Low flow rate - §WR80 gpm High flow rate -- > 60 to 250 gpm In addition, the non-regenerative heat exchanger outlet temperature is limited to 120° F when rejecting to radwaste to prevent damage to a radwaste filter/demineralizer. Therefore, 120° F will be used to determine the mass flow rate and the Reynolds numbers.

Equation 4 is used to determine the flow orifice uncertainty.

= [ + + + ]. (Equation 4)

A limitation for the use of the flow coefficient uncertainty values listed in PTC 19.5 (Ref. 6.8) Section 4.9 is that the Reynolds number is between 104 and 108. Therefore, the Reynolds number will be calculated at the maximum flow rate (250 gpm) and the minimum flow rate (18 gpm) at a temperature of 120° F.

Reynolds number at maximum flow rate:

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 81 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

The Reynolds number is calculated per PTC 19.5 (Ref. 6.8), Equation 3-15.9 following:

=

(Equation 5)

Where:

RD = Reynolds number qm = mass flow (lb/hr)

= Kinematic viscosity of water at operating temperature (ft2/sec)

= 3.14159 D = pipe diameter (inches)

Convert the gpm flow rate to lb/hr:

The specific volume of water at 120° F is 0.016204 ft3/lb. (Ref. 6.2)

Maximum flow rate:

/( = 250 ()60 /()1/7.4805195 gallons/ )(1/0.016204 /)

/ = 123,748 /

Minimum flow rate:

/( = 18 ()60 /()1/7.4805195 gallons/ )(1/0.016204 /)

/ = 8,910 /

Kinematic viscosity of water at 120° F is 6.074 x 10-6 ft2/sec. (Ref. 6.9)

Reynolds number at maximum flow:

Substituting 123,748 lb/hr flow into Equation 5 gives:

= = 7.26 x 107 The Reynolds number at maximum flow meets the limitation that the Reynolds number is between 104 and 108.

Reynolds number at minimum flow:

Substituting 8,910 lb/hr flow into Equation 5 gives:

= = 1.63 x 106

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 82 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

The Reynolds number at minimum flow meets the limitation that the Reynolds number is between 104 and 108.

1G33-N011 Uncertainty Per PTC 19.5 (Ref. 6.8) paragraph 4.9.a, LVHTXDOWRIRUDQGWKH5H\QROGVQXPEHULV

4 8 between 10 and 10 .

= 0.60%

is zero for water.

= (0.004/3.826)*100 = 0.1045%

= (0.003/2.196)*100 = 0.1366%

Combining the values:

2 0.5740 2

= [(0.60%) + (0) +

(0.1045%) +

(0.1366%) ].

1 0.5740 1 0.5740

= 0.674%

Per ASME MCF-3M-1989 (Ref. 6.3), an additional 0.5% uncertainty is added if the upstream and downstream straight pipe lengths meet the minimum recommended upstream and downstream straight pipe lengths in Table 2. The upstream and downstream straight lengths of piping from orifice 1G33-N040 are determined from drawing M06-1076, Sheet 11 (Inputs 4.2.4).

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 83 of 86 APPENDIX 5 Flow Element Uncertainty (Continued)

Flow element 1G33-N011 is shown on drawing M06-1076, Sheet 11 (Input 4.2.4) as shown below.

// z~ 110: 1 U.;<U4C:P<I - ~ ~ ~

"-01 -

.  :* *~*i r;:;:;.J .

PLUG ~ .-

1, *:; "-~ "'

..::...1 ~

'15 SI.ff

.Q (3

I

,, A*_ ,,no "Lr * ~ . .

- - - .-1, ,_

~

"@0 , ---*l-c~ ,,.,osm,1,,

d

- --* - !t RT ~--=- .... ~l)C,.

• 1 I ~H T.11 uRT0.9010]~

__~ Tr:_~ ----- l ----jTp_-foq'.)04Jaj

.. 'oi!

(1AT230 14}-- , r-;l' -n'"' ...

- ,-!,--+-,-,. -* -**

_

• I ~ /t_"( JI<. 2801 r-4 lR T,_h-JC J 2ji]

1

. C-,l________r,;:T~

--~

WELD END TO MATCH FLOW e~, *

-- - - = - -- - f.. , _J. . 5 1;"11- I

-~r-t0 NOZ1LE *c.* DIM . : :1 . l'>'t r. " 3'f:-

(1RT 7 ! , ~)-1--- - ! . .. - - - - -- '-. ~00.$1RI l ~-;.~*:.~~-I tc.Tl°tE~i~~~o, I ' - - -

t - -,;., I

~ - Yff:{"-_-fi_c._*:__ * ,-r~--~-t=&ff!**.-=--'-'-'-"'"'--i*I o'

~

(iRn~*

I

-, ~,;- -~ -

TOP CO~N _J j~ ,i

' ~ *?

---

'0 1* Fla?M

>/!OWN

' I The distance upstream of the flow element to the valve 1G33-F034 (gate valve per drawing W7820044, Input 4.3.17) is approximately 6' -11 " . This is equivalent to 21.7 pipe diameters (83"/ 3.826" ). The distance downstream of the flow element to the pipe elbows is approximately 2'. This is equivalent to 61/4 pipe diameters.

The recommended upstream and downstream distances are listed in ASME MFC-3M-1989 (Ref. 6.3), Table 2, "Recommended Straight Lengths for Nozzles and Orifice Plates for 0.5% Additional Uncertainty".

For a beta of 0.57 (use 0.6 in table), the recommended distance to an upstream gate valve is 7D and the recommended distance to all fittings is 3.5D.

The upstream and downstream distances exceed the recommended minimum distances in ASME MFC-3M-1989 (Ref. 6.3), Table 2. Therefore, the Primary Element Accuracy (PEA) for flow element 1G33-N011 is 0.674% plus 0.5% = +/-1.174%. This value is rounded up to +/-1.2% for use in the setpoint calculation.

PEAN011 = +/-1.2% of flow (2o)

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 84 of 86 APPENDIX 5 Flow Element Uncertainty (Continued) 6.0 Symbols C = coefficient of discharge D = diameter of pipe P, p = pressure Q, q = flow Re = Reynolds number T = temperature V, v = velocity d = diameter of meter bore u = uncertainty, %

v = specific volume w, qm = mass flow

 GLDPHWHUUDWLRG'

 GLIIHUHQFHRSHUDWRU

 H[SDQVLRQIDFWRURIDIORZLQJFRPSUHVVLEOHIluid

 NLQHPDWLFYLVFRVLW\

 GHQVLW\

= constant, 3.14159

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 85 of 86 APPENDIX6 Process Measurement Accuracy (PMA) 1.0 Purpose The purpose of this Appendix is to determine the process measurement accuracy associated with flow elements 1G33-N035, 1G33-N040, and 1G33-N01 l.

2.0 PMA- Flow Element 1G33-N035 Flow Element 1G33-N035 measures reactor water cleanup input flow from the reactor water recirculation system .

The flow element is venturi part number 21A3544AAP001 (DL851E703AC, Input 4.3.10).

The flow venturi is located in the drywell at elevation 738' -8" (drawing M06-1076, Sheet 15, Input 4.2.5). The high-pressure tap is at elevation 738 ' -l 1" and the low-pressure tap is at 739 ' -21/2" (drawing M27-1601-01A-K).

(Input 4.2.6)

Drawing M27-1601-01A-K (Input 4.2.6) shows the elevation of the instrument taps .

. , .**, . /~ -~: ,...: -..,.*,,*.-:-* ,L .** V ,* *.:: >

dl2TOI B 6

... -.. ,.*~ ;.-. *,: -.., ' ,*' .,:..!,.. -

'""':~,.,~!" e:~ ;it-*~~~';:::~7 .*. '

• ****.:*:4;,, .

.;o~ <L The normal minimum temperature is 100° F and the normal maximum temperature is 150° F (environmental design criteria DC-ME-09-CP, Input 4.4.1). PMA will be based on the average of the minimum and maximum normal temperatures (125° F).

The specific volume of water (1967 ASME Steam Tables, Ref. 6.2) at the normal environmental conditions is:

68° F -- 0.016046 ft3/lb 100° F -- 0.016130 ft3/lb 125° F -- 0.016225 ft3/lb (interpolated) 150° F -- 0.016343 ft3/lb The elevation difference between the low-pressure and high-pressure tap is 31/2" (739' -21/2" minus 738 ' -11 ").

Design Analysis No.: IP-C-0132 Revision: 0 Page No.: 86 of 86 APPENDIX 6 Process Measurement Accuracy (PMA)

(Continued)

The bias due to the difference between the taps is:

68

=

125 0.016046

= = 3.83 0.016225 The random portion of the PMA is:

68 68

=

125 150 0.016046 0.016046

= = 0.03 0.016225 0.016343

= +/- . . (2) 3.0 PMA - Flow Element 1G33-N040 Flow Element 1G33-N040 measures reactor water cleanup return flow to feedwater. The flow element is an orifice plate part number 21A3548ACP001 (DL851E703AC, Input 4.3.10).

The flow element in located in the Aux. Building steam tunnel at elevation 763 (RT19, Input 4.2.7). Flow element 1G33-N040 is an orifice plate and the sensing lines are at the same elevation. Therefore, there is no PMA associated with this flow element.

= . (2) 4.0 PMA - Flow Element 1G33-N011 Flow Element 1G33-N011 measures reactor water cleanup reject flow to the condenser. The flow element is an orifice plate part number 21A3548AAP001 (DL851E703AC, Input 4.3.10).

The flow element in located in the Aux. Building steam tunnel at elevation 762 (M06-1076, Sheet 11, Input 4.2.4). Flow element 1G33-N011 is an orifice plate and the sensing lines are at the same elevation.

Therefore, there is no PMA associated with this flow element.

= . (2)

I I I Instrumentation and Controls Division CURTISS SAM/DAM2000-745 Single/Dual Alarm Qualification Report

,~WRIGHT YFtow Control Company ..------------ NUS-A042QA Rev 0 SCIENTECH ATTACHMENT A Page 1 m20 Analysis No. IP-C-0132, Revision 0 Page A1 of A6 SAM/DAM2 000-745 Single/Dual Alarm Qualificatio n Report NUS-A042Q A Revision 0

I Instrumentation and Controls Division 1~'flR'llfn.

~;Flow Control Company SAM/DAM2000-745 Single/Dual Alann Qualification Report NUS-A042QA Rev 0 SClE.NTEOi Page2 of20 ATTACHMENT A Record of Revisions Analysis No. IP-C-0132, Revision 0 Page A2 of A6 Reason for Revision: Initial Issue Issued for Use -~""""'~'l"""!"~""""'"""'""""-----~

RevO Reviewed by / Date t2-l'I-II Proprietary Information Notice This document is the property of Scientech, a business unit of Curtiss-Wright Flow Control Service Corporation, and any form of replication and/or distribution of the information and/or the content contained in this document is expressly prohibited without prior written consent from the manufacturer: Scientech, 200 South Woodruff Avenue, Idaho Falls, ID 83401. The information in this document may not be copied or reproduced or distributed or used in any way that is detrimental to, or infringes upon, the rights and/or interests of Scientech.

I Instrumentation and Controls Division CURTISS

~WRIGHT _ _ _ _ _ _ _ _ _s_A_M_1o_A_M_2_0_01111 0-.1.45._Single/Dual Alarm Qualification Report

~;Flow Control Company NUS-A042QA Rev 0 SCIEi"'IJTECH ATTACHMENT A Page 3 of 20 Analysis No. IP-C-0132, Revision 0 Page A3 of A6 Contents

1. Introduction ........... .................................................................................................................... 5

2. Description of Qualified Equipment.. .......................................................................................... 6

3. Specifications ............................ ................................................................................................ 6 3.1. Acceptance Criteria ....... ................................................................................................................. 6 3.2. Class 1E Safety Function ............................................................................................................... 7 3.3. Qualified Life ................................................................................................................................... 7 3.4. Mounting ......................................................................................................................................... 7

4. Qualification Plan ...................................................................................................................... 8 4.1. Aging and Seismic .......................................................................................................................... 9 4.2. Components Not Requiring Artificial Aging .................................................................................... 9 4.3. Components Requiring Artificial Aging ........................................................................................... 9 4.4. Mechanical vibration ..................................................................................................................... 1O 4.5. Scientech Sequence ..................................................................................................................... 10 4.6. Qualification Plan .... ...................................................................................................................... 10

5. Environmental Qualification Results ........................................................................................ 10 5.1. Test Specimen .............................................................................................................................. 12 5.2. Input Signal .................................. _ ............................................. .................................................... 12 5.3. Output Signal ................................................................................................................................ 12 5.4. Alarm Point ................................................................................................................................... 12 5.5. Accuracy (at 24 Vdc and 80°F) ..................................................................................................... 12 5.6. Dead Band Adjustment. ........................................................................_........................................ 12

5. 7. Relay Response Time ......................... ............ .................. ............................... ............ ............... . 12 5.8. Relay Contact Rating .................................................................................................................... 13 5.9. Power Supply Requirement .......................................................................................................... 13 5.10. Power Supply Operative Limits ................................................................... ................................. 13 5.11. Operating Influences on Modules Internal Power Supplies .......................................................... 13 5.12. Ambient Temperature Operative Limits ........................................................................................ 13 5.13. Seismic Response ........................................................................................................................ 14

6. Analysis Results ...................................................................................................................... 14 6.1. Pressure Effect ............................................................................................................................. 14 6.2. Humidity Effect. ....................................... ...................................................................................... 14 6.3. Radiation Effect ............................................................................................................................ 14

7. Seismic Qualification Results .................................................................................................. 15

8. Conclusion ....................... ............................................................................................. .......... 15

9. References Documents ........................................................................................................... 16 9.1. Scientech ...................................................................................................................................... 16 9.2. U.S Nuclear Regulatory Commission ........................................................................................... 16 9.3. Institute of Electrical and Electronics Engineers .......................................................................... 16 9.4. Other ............................................................................................................................................. 16 - Qualification Plan ................................................................................................... 17 - Environmental Qualification Test Data ................................................................... 18 - Seismic Qualification Report ............................... ....................... ............................ 19

I Instrumentation and Controls Division

~'fl.TJl1rr SAM/DAM2000-745 Single/Dual Alarm Qualification Report OF/ow Control Company NUS-A042QA Rev 0 SCII.NTECH ATTACHMENT A Page 6 of20 Analysis No. IP-C-0132, Revision 0

2. Description of Qualified Ee

._ Page A4 of A6 The SAM/DAM2000-745 Single/Dual Alarm Modules are designed to alarm when certain conditions are met. In the single unit, the alarm may be either high or low. The dual unit has two reference signals with the same input signal and may be used to effect a high and low alarm, two levels of high alarm, or two levels of low alarm.

A voltage sensitive, solid-state comparator is used in these units to energize or de-energize an integral electromechanical relay when an input signal of 1-5 Vdc exceeds or falls below a preset alarm-point value. The alarm points are continuously adjustable over the input range from the front of the unit.

When an alarm condition is reached, a relay is de-energized and two contacts change state. These contacts are independently selected by jumpers to be either normally open or closed.

The SAM/DAM2000-745 series of modules have part number NUS-A042PA-n. The "n" identifies the different assembly options, 1, 2, 3, or 4. This qualification report covers only modules with the -3 and

-4 options, which are safety related and have special locking features for securing the module to its associated rack. The "-3" option specifies that the module is a safety related Dual Alarm Module and the "-4" option specifies that the module is a safety related Single Alarm Module.

3. Specifications The specifications for functional testing are found below.

3.1. Acceptance Criteria Ta bl e 1 - Ven1e "fi d b1y Inspecf 10n

.' Para..-/ . *' ', AcceptancEt°' Criteria Width 1.4" (Rack Mount)

Height 7" (Rack Mount)

Lenoth 11.5" (Rack Mount)

Weight Net 1 lb. (Rack Mount)

Output Signal su ression.

Alarm Point Ad"ustable 1 to 5Vdc Accurac at 24 Vdc and 80°F

<100 ms 0.24 to 10 seconds. Jum er enabled standard module feature.

Rela Contact Ratin 2 am /120 Vac, 50/60Hz; 2 am /24 Vdc non-inductive Power Supply Requirements 150 mAdc @24 Vdc (single alarm); 200 mAdc @24 Vdc, (dual alarm Operating Influences on Modules Supply voltage: +/-0.2% for 24 +/- 2 Vdc supply variation.

Internal Power Su lies

I Instrumentation and Controls Division CURTISS 1~WRIGHT SAM/DAM2000-745 Single/Dual Alarm Qualification Report

"§d; Flow Control Company NUS-A042QA Rev 0 SCLENTECH Page 7 of 20 Ambient Temperature Operating Ambient Temperature: 80° +/- 40°F; Operative Limits 20°F to Limits 140°F Seismic Response Scientech Composite RRS per Test Plan NUS-A042LA Ta bl e 3 - Ver11e I *

"f d bIV A na1vs1s Parameter 'Analysis Acceptance Criteria Pressure Effect No effect on accuracy Humidity Effect No effect on accuracv Radiation Effect No effect on accuracy Table 4 - Environmental Limits Parameter' Allowable Railge i Temperature Range Storage: -40°F to 180°F; 0 to 120°F Recommended.

Operating: 40°F to 120°F Extremes: 20°F to 140°F, (will meet performance specifications).

Humidity Range 5 to 95% RH, non-condensing Pressure Range Atmospheric Radiation Limits <104 Rad TID aamma at <5mRad/hr 3.2. Class 1 E Safety Function The safety function of the SAM/DAM2000-745 is to provide outputs, defined by its configuration, in the

~ form of opened or closed contacts, before, during, and after a seismic event. The seismic event shall consist of five Operational Basis Earthquakes and one Safe Shutdown Earthquake, as defined in IEEE standard 344-1975/1987.

3.3. Qualified Life The qualified life of the module is 40 years based on equipment manufacturer's information, the service conditions specified above, and periodic testing and maintenance. Testing and maintenance shall be as instructed in the NUS-A042MA Operation and Maintenance Manual, latest revision.

Test/Calibration data shall be maintained in order to check for degradation of the performance specifications of each SAM/DAM2000-745 Module.

3.4. Mounting The module is only qualified when used in the orientation and with equivalent mounting as that used in the seismic tests. The module must be mounted in a Bailey Type 761 rack as shown in Figure 1.

The SAM/DAM2000-745 Modules are secured to the rack by means of a lock on the front panel, located below the handle.

I I ATTACHMENT A Analysis No. IP-C-0132, Revision 0 Page A5 of A6

I Instrumentation and Controls Division CURTISS

~WRIGHT SAM/DAM2000-745 Single/Dual Alarm Qualification Report

'yF/ow Control Company NUS-A042QA Rev 0 SClF.NTECH Page 13 of20 When the module is in the ADJUSTABLE mode (time delay switches at their TD position), an RC

'--" delay network, having an adjustable time constant, is added to the signal path. In this mode the minimum adjustable delay was measured as 0.17 seconds, and the maximum delay as 11.3 seconds.

These values comfortably envelope the modules specified delay span of 0.25 to 5 Seconds.

5.8. Relay Contact Rating The relays used in the module are rated by their manufacturer for 4 amp at 250 Vac, 60 Hz & 3 amp at 30 Vdc non-inductive. The relay contacts are gold clad allowing near dry circuit operation (100 uA minimum). All contacts have been type tested with a load current of 2 amps at 120 Vac 60Hz to qualify the voltage withstand and current carrying capacity of the modules wiring associated with the relays and their contacts.

5.9. Power Supply Requirement The type tested dual alarm module had a measured power supply current requirement of 124 mA at 24 Vdc. Scientech chooses to report this current requirement in the equivalency document NUS-A042SA as being the same as that of the original Bailey specification (150 mAdc @ 24 Vdc, (single alarm), and 200 mAdc@24 Vdc, (dual alarm)].

5.10. Power Supply Operative Limits The internal power supplies of the module were monitored while the input power supply voltage to the module was varied from 30 Vdc to 14 Vdc. The lower acceptable limit of input power supply voltage was chosen to be that input voltage that caused a +/-2 mv change in any one of the modules internal power supply voltages. The internal -12 V supply changed by 2 mv for an input voltage of 18 Vdc.

The same change occurred at the internal +12 V supply for an input voltage of 17 Vdc and the internal

+10 volt supply changed for an input voltage of 14 Vdc. Given the criteria used for this test (internal supply change of+/- 2mv), one could reasonably state that the operative limits for the module tested at 18 to 30 Vdc. Scientech chooses to report the operative limits in NUS-A042SA as being the same as that of the original Bailey specification {22 to 28 Vdc).

5.11. Operating Influences on Modules Internal Power Supplies Based on the data presented in section 5.10. above, for a 30 to 18 Volt change of the input power supply voltage (equiv. to 24 +/- 6 V), the -12 V internal supply varies by 2 mv out of a total of 12 V, equivalent to 0.02%. Scientech chooses to report the operative influences in NUS-A042SA as being the same as that of the original Bailey specification(+/- 0.2% for 24 +/- 2 Vdc supply variation).

5.12. Ambient Temperature Operative Limits Temperature measurements of the stability of the alarm trip point of the module were made over the temperature range of 0°F to 140°F with the alarm .threshold set at one half of input span. The deviation of trip point with temperature did not vary by more than +/-3 mv from the 80°F reference setting. The corresponding accuracy of the alarm trip point with temperature was thusly calculated as

+/-3 mv out of a span of 4 volts, equivalent to +/- 0.1 % from 0°F to 140°F. Scientech chooses to report the operative influences in NUS-A042SA as being the same as that of the original Bailey specification

(+/- 0.5% over the temperature range of 80°F +/- 40°F).

I I ATTACHMENT A Analysis No. IP-C-0132, Revision 0 Page A6 of A6

I I I CURTISS ATTACHMENT B i~WRIGHT Analysis No. IP-C-0132, Revision 0 YFlow Control Company SCIENTECH Page B1 of B5 EQUIVALENCY REVIEW FOR SAM/DAM2000-745 SINGLE/DUAL ALARM MODULES NUS-A042SA REVISION 1

ATTACHMENT B Analysis No. IP-C-0132, Revision 0 Record of Revisions!*____"'!"'"_ _ _ _ _ _ _ __.I Page B2 of B5 REV SIGNATURES DATE Reason for Revision Original issue - issued for use Feb25 2003 vc Engineer L. Kent Davies 2/25/03 0 Reviewer Jim Larson 2/25/03 Project Manager L. Kent Davies 2/25/03 Quality Assurance N/A Added QA signature, revised Analyzed Specificationb Reason for Revision Comparison Table - Issued for use - £1 lS Ztm Preparer

J.1u~. t'1./1 4h \

1 Reviewer ~- ~*A,I_.J 1:i./1it/l1 Project Manager t (L,. /1}1 t{. ht.1i vr 7

1<2 Quality Assurance t/ ~ -

~- - - ~

- 12.-1'1,//

Reason for Revision Preparer 2 Reviewer Project Manager Quality Assurance Reason for Revision Preparer 3 Reviewer Project Manager Quality Assurance PROPRIETARY INFORMATION This document is the property of Scientech, a business unit of Curtiss-Wright Flow Control Service Corporation, and any form of replication and/or distribution of the information and/or the content contained in this document is expressly prohibited without prior written consent from the manufacturer: Scientech, 200 South Woodruff Avenue, Idaho Falls, ID 83401. The information in this document may not be copied or reproduced or distributed or used in any way that is detrimental to, or infringes upon, the rights and/or interests of Scientech.

Rev. 1 NUS-A042SA Page2of6

I I ATTACHMENT B Analysis No. IP-C-0132, Revision 0 Page B3 of B5 Equivalency Review This review describes the equivalency between the NUS Instruments (NUS!) and the Bailey Type 745 Single/Dual Alarm. Through out this document the term Bailey is to be recognized as a trademark of Babcock & Wilcox and the Type 745 Series Single/Dual Alarm, a module designed and manufactured by Babcock & Wilcox. Specifications for the Type 745 Series Single/Dual Alarm are taken from Bailey publication 4574K15-100 published 1979 and Product Specification E92-745 and are used here for reference purposes and form the basis for equivalency review.

Description of Bailey Equipment:

Bailey Type 745 Single/Dual Alarm is a 1-1/2 inch-wide rack-mountable model. In the single unit, the alarm may be either high or low. The dual unit has two reference signals with the same input signal and may be used to effect a high and low alarm, two levels of high alarm, or two levels oflow alarm. The modules incorporate an electromechanical sealed relay which energizes or de-energizes when an input signal of 1-5 Vdc exceeds or falls below a preset alarm-point value. The alarm points are continuously adjustable over the input range from the front panel of the unit. When the alarm condition is reached, the relay is de-energized and two contacts change state. These contacts are independently selected by jumpers to be either normally open or normally closed.

The front panel contains alarm point adjustment pots and test jacks for measuring the input voltage.

Description of Replacement NUSI Equipment:

SAM/DAM2000-745 Series Modules, NUSI part number NUS-A042PA-n, with "n" representing the different assembly options.

NUSI has approached the design using modem components and equivalent design concepts.

A major consideration at all times, during the design, was to use high quality passive and active components operated at voltages and/or wattage well below each components specified maximum. 1%

metal film resistors having established reliability and 50 ppm temperature coefficients have been used throughout. Established reliability bypass capacitors are used throughout.

Plant Application:

The NUSI SAM/DAM2000-745 Series Modules can be purchased as non-Class IE replacements (DAM2000-745-01 & SAM2000-745-02) and as Class IE (DAM2000-745-03/N & SAM2000-745-04/N) for the purpose of replacing the obsolete Bailey modules. It is equivalent in form, fit and function to the obsolete device.

Rev. 1 NUS-A042SA Page 3 of 6

I I ATTACHMENT B Analysis No. IP-C-0132, Revision 0 Page B4 of B5 I d Sipec1'fl1cations C ompar1son:

Ana1yze SPECIFICATION BAILEY74S NUSI SAM/DAM2000-74S REPLACEMENT MODULE Input Signal 1-5 Vdc. Same as Bailey Input resistance exceeds 1 megohm Output Signal Plug-in relay, 2 sets Form A or Form Same as Bailey, but relays are PC B contacts/channel with RC arc board type in sealed plastic suppressor package.

Alarm Point Adjustable 1-5 V de Same as Bailey Dead Band Adjust 0.5% to 5% of span, (0.02 to 0.20 Same as Bailey Vdc Relay Response Time < 100 milliseconds Same as Bailey Constant Adjustable Relay 0.25 to 5 second with option Same as Bailey except option is a Response Time Option installed standard feature of module.

Relay Contact Rating 2 amp/120 V AC, 50/60 Hz By test same as Bailey. Relays 2 amp/24 Vdc non-inductive have actual specification of 4 amp/250 V AC & 3 Amp/30 V de non-inductive. (Gold clad contacts rated lOOµA min).

Accuracy (at 24 Vde and +/-0.5% of span Same as Bailey gooF)

Power Supply 150 mAdc@ 24 Vdc, (single alarm) Same as Bailey Requirements 200 mAdc @ 24 V de, ( dual alarm)

Rev. 1 NUS-A042SA Page 4 of 6

ATTACHMENT B Analysis No. IP-C-0132, Revision 0 Page B5 of B5 SPECIFICATION BAILEY745 NUSI SAM/DAM2000-745 REPLACEMENT MODULE Design Conditions Supply Voltage: 24 +/-2 V de Same as Bailey Operative limits: 22 to 28 V de Ambient Temperature: 80°F +/- 40°F Same as Bailey Operative Limits: 20°F to 140°F I

Recommended storage Storage Temperature: -70°F to 180°F temperature: -40°F to 180°F Operating Influences Supply voltage: +/-0.2%, for 24+/-2 Same as Bailey V de supply variation Ambient Temperature: +/-0.5%, for temperature variation of 80°F +/-

40°F Physical Aspects Size: 1.4" W x 7" H x 11.5" D Same as Bailey Weight: Net 1 lb NUSI DAM2000-745-03/N and SAM2000-745-04/N have a Mounting: Rack mounting only in different faceplate to type 761 Rack accommodate a fastening knob for seismic qualifications. Note:

Legend: Legend plate holder is faceplate on all NUSI SAM2000-integral with the withdrawal handle. 745 and DAM2000-745 have the same physical outlined dimensions, namely 1.4" W x 7"H x 11.5"0 NUS Instruments Composite Seismic No Specification Required Response Spectra (RRS) per Test Plan NUS-A042LA Rev. 1 NUS-A042SA Page 5 of 6

CURTISS-WRIGHT ATTACHMENT C Analysis No. IP-C-0132, Revision 0 Page Cl of C2 NUSI 2000 Series Four-Input Summer I

SUM2000-752 Four-Input Summer NUS l}" .*...* --.

lnitrumet1ts The SUM2000-752 Four-Input Summer replaces the obsolete Bailey

• . *~!'-*

SJ!!\'ER Type 752 summer while retaining the functions of the Bailey module. ' l'IJ T ~,~(,; '* ' -. ---nr

-,; : *,~,-d:). ,,: *°!'"(: l:P

,o --=- ~~*~-'--~/2:~,~';- /. :' i

!r.:!~tl The SUM2000-752 accepts input signals and adds or subtracts those signals from each other to obtain an output signal of 1 V to 5 '*' '"G :~ffi~--- -.;;~::::~~ :,t iJ E:(I Vdc that is proportional to the sum or difference of the input signals. <l ~,<:4

. .,_, ll. .-~.:~i~ii=

The SUM2000-752 is available with either two, three, or four inputs. E:(S

"' IElc(l The SUM2000-752 summation circuitry can perform the following E(l ~!f .-*: -  :.,... .,.,. *

"t-t,o :k:.~ ~~ -

functions:

• Add or subtract a common bias voltage to or from the applied

• • G

' o,,o  ; : t-;;:,:** . . . ::i <::~

"G input signals. <.In \ ~

• Scale each individual input signal , (0 to 1), to put the input llll variables into identical units for addition or subtraction.

• Multiply the net result by an adjustable constant, (0.25 to 10).

• Add or subtract an output bias voltage.

The SUM2000-752 provides improved accuracy and drift specifications, and jumper-selectable level "auctioning" at all inputs. SUM2000-752 Front panel test jacks are provided for: input voltages before and after scaling ; input bias voltage; fine gain voltage; signal output; and common voltage. Adjustments for scaling of each input, fine gain, and output bias are accessible through the face plate.

r

, . 4*

..= 1 11 .36 m 0

- -- - -~*

ID

• ~ * ...

ID

..Im a~~

a

-co El ID mil l 1~~. 1 . . =GD~ Gm~

~

c::c:::J 7.00 I~ I 5.25 I~ *~*t:m:::rn... * ~ * * -©-

~ Cl.II 1ml

-~@1 l!!IIO O ~

CCII ID Nuclear Division CWNUCLEAR .COM I

E32

NUSI 2000 Series ATTACHMENT C Four-Input Summer Analysis No. IP-C-0132, Revision 0 Page C2 of C2 SPECIFICATIONS Input Signal: 1 V to 5 Vdc normal; +/-10 Vdc maximum Number of Inputs: Two, three, or four Input Auctioning: Input auctioning selectable for each input by individual jumpers Auctioning level adjustable from 0 V to + 3 Vdc, (nominal)

Input Resistance: Auctioning disabled: Exceeds 1 M Auctioning enabled: Exceeds 1 M when input level > auctioning level Not less than 6 k for input level < auctioning level Output Signals: 1 V to 5 Vdc normal; +/-10 Vdc maximum Allowable Load: 1.5 k minimum Accuracy (at 24 Vdc input, 80 °F): 0.5% or better for all gains Dynamic Response: 3 db down at 24 Hz (nominal), phase angle < 80° Adjustments: Gain: 0.25 to 10 Input Bias: 0 V to +/-5 Vdc Output Bias: 0 V to +/-5 Vdc Residual Bias: 0 V to +/-5 Vdc Scaling: 0 to 1.0 (each input)

Auctioning levels: 0 V to 3 Vdc, (nominal)

Power Supply Voltage: 0.15 A @ 24 V +/-2 Vdc (22 V to 28 Vdc operative limits)

Operating In"uence: Supply Voltage: 24 V +/-2 Vdc (+/-0.1%)

Ambient Temperature: 40 °F to 120 °F (5 °C to 49 °C) (normal operation) 20 °F to 140 °F (7 °C to 60 °C (operative limits) 70 °F to 180 °F (57 °C to 82 °C) (storage)

Dimensions: 1.4 in x 7 in x 11.5 in Weight: Rack-mounted: < 1 lb Mounting: Bailey Type 761 Rack Unit Legend: Legend plate holder is integral with the withdrawal handle For more information please request a Summer Module Operation & Maintenance Manual.

CONTACT INFORMATION: Curtiss-Wright Nuclear Division / I&C Products 1350 Whitewater Drive, Idaho Falls, ID, 83402 T: (208) 497.3333 E33

Product Data Sheet ATTACHMENT D 00813-0100-4853 Rev AF Analysis No. IP-C-0132, Revision 0 June 2020 Page D1 ofD8 Rosemount 3153N Rosemount 3153N Nuclear Qualified Pressure Transmitter INDUSTRY LEADING PERFORMANCE

• Qualified per:

o IEEE Std 323'-1974/1983/2003 o IEEE Std 344'-1975/1987/2004

• 36 Mrad (360 kGy) TIO Gamma Radiation

• 8.5g ZPA Seismic

• 333°F (167 .2°C) Steam/Temperature

• 0.2% Reference Accuracy Contents Introduction .......................... .............................................................. page 2 Transmitter Description ..... ....... .. ...... .. ...... .. ....... .. ...... .. ...... .. ...... .. ...... .. ....... .. ......... page 2 Operation ................................. ........ ........ ......... ........ ........ ........ ......... ........ ........... page 2 Dimensional Drawings .... .... .... .... .... .... .... .... ..... .... .... .... .... .... .... .... .... .... .... .... .... ... .. page 3 Nuclear Specifications .............. ... .. .. .... .. ..... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. ...... page 5 Performance Specifications ..... .... .... .... .... ... .... .... .... .... .... .... .... .... .... .... .... .... .... ... ... page 8 Functional Specifications ........ ........ ........ ........ ........ ........ ........ ........ ........ ............. page 9 Physical Specifications ... ......... ........ ........ ........ ........ ......... ........ ........ ........ ........... page 11 Ordering Information ..... .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. .... .. .. ...... page 14 EMERSON .

Product Data Sheet ATTACHMENT D 00813-0100-4853 Rev AF Analysis No. IP-C-0132, Revision 0 June 2020 Page D2 of D8 Rosemount 3153N SPECIFICATIONS During and after exposure to an additional TID of 35 Mrads (350 kGy) at a dose rate of 1.0 Mrads/hr (10 Nuclear Specifications kGy/hr), accuracies are as shown in the following Qualified according to: table:

IEEE Std 323'-1974/1983/2003, Output Range IEEE Std 344'-1975/1987/2004 Radiation Effect Code Code As documented in Rosemount report D2013004 R & T (1) ALL +/-(0.5% URL + 1.5% span)

(1) With damping set for time response = 0.4 sec or less.

Seismic When exposed to a disturbance defined by the Steam Pressure/Temperature and Post DBE required response spectrum with a ZPA of 8.5g Operation (see Figure 3), accuracies are as shown in the During and after exposure to steam at the following following table: temperatures and pressures (see Figure 4):

Triaxial Random Multifrequency (1) 333°F (167.2°C), 81 psig (503.3 kPa) for 2 minutes Output Range 318°F (158.9°C), 73 psig (503.3 kPa) for 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> 8.5g ZPA Code Code 265°F (129.4°C), 24 psig (165.5 kPa) for 56 hours6.481481e-4 days <br />0.0156 hours <br />9.259259e-5 weeks <br />2.1308e-5 months <br /> During After 212°F (100°C), 0 psig (0 kPa) for 216 hours0.0025 days <br />0.06 hours <br />3.571429e-4 weeks <br />8.2188e-5 months <br /> Within reference 1 +/-1.75% URL accuracy Accuracies are as shown in the following tables:

Within reference 2 +/-0.5% URL R accuracy First 64 hour7.407407e-4 days <br />0.0178 hours <br />1.058201e-4 weeks <br />2.4352e-5 months <br />s:

Within reference 3-4 +/-0.3% URL Steam accuracy Output Transmitter Range Within reference Pressure/Temperature 5-6 +/-0.2% URL Code Type Code accuracy Effect Within reference 3153ND 1 +/-(3.0% URL + 3.5% span) 1 +/-0.4% URL &

accuracy T (2) 3153NG 2-6 +/-(2.5% URL + 2.5% span)

Within reference R & T (1) 2-6 +/-0.2% URL 3-4 +/-(4.0% URL + 4.0% span) accuracy (1) Specifications also apply to the effects of Safety Relief 3153NA 5-6 +/-(2.5% URL + 2.5% span)

Valve (SRV) Load and Chugging Loads.

(2) With Damping set for time response = 0.4 sec or greater. (1) With damping set for time response = 0.4 sec or less.

Radiation During and after the remaining 216 hour0.0025 days <br />0.06 hours <br />3.571429e-4 weeks <br />8.2188e-5 months <br />s:

Exposed to a Total Integrated Dose (TID) of 36 Output Range Steam Pressure/Temperature Effect Mrads (360 kGy), consisting of 1 Mrad (10 kGy) Code Code (remaining 216 hours0.0025 days <br />0.06 hours <br />3.571429e-4 weeks <br />8.2188e-5 months <br />) (1) background radiation followed by 35 Mrads (350 R & T (2) ALL +/-(0.5% URL + 2.0% span) kGy) accident radiation.

(1) Test profile supports one year post accident conditions at During and after initial exposure to a TID of 1 Mrad 120 ºF (48.9 ºC).

(10 kGy) at a dose rate of 0.1 Mrads/hr (1 kGy/hr), (2) With damping set for time response = 0.4 sec or less.

accuracies are as shown in the following table:

Output Range Radiation Effect Code Code R & T (1) ALL +/-(0.1% URL + 0.15% span)

(1) With damping set for time response = 0.4 sec or less.

5

ATTACHMENT D Product Data Sheet Analysis No. IP-C-0132, Revision 0 00813-0100-4853 Rev AF Rosemount 3153N Page D3 of D8 June 2020 Performance Specifications associated with the High Static Line Pressure Zero Effect is as follows:

Based on zero-based calibration spans under reference conditions. For high static line pressure (Ps) less than or equal to 2000 psi (13.79 MPa):

Accuracy Range High Static Line Pressure Zero Effect Code Ps 2000 psi (13.79 MPa)

Range Code Accuracy 1 +/-0.25% URL per 1000 psi (6.89 MPa) 1-5 +/-0.2% of calibrated span 2-5 +/-0.1% URL per 1000 psi (6.89 MPa) 6 +/-0.25% of calibrated span This specification may be linearly interpolated in 1000 psi Includes the effects of linearity, hysteresis, and repeatability. (6.89 MPa) increments.

Drift For high static line pressure (Ps) greater than 2000 Range Code Drift Effect per 30 months psi (13.79 MPa):

Range High Static Line Pressure Zero Effect 1 +/-0.2% URL Code Ps > 2000 psi (13.79 MPa) 2-6 +/-(0.1% URL + 0.1% span) 1 Not Applicable 2-5 +/-(0.2 + (0.2(Ps-2000 psi)/1000 psi))% URL Temperature Effect This specification may be linearly interpolated in 1000 psi (6.89 MPa) increments.

Temperature Effect Range Code (per 100ºF (55.6ºC) Temperature Shift)

High Static Line Pressure Span Effect 1 +/-(0.55% URL +1.0% span) 2-6 +/-(0.15% URL + 0.6% span) 3153ND Ranges 1, 2 and 3:

AP Range 3 +/-(0.6% URL + 0.5% span) Range High Static Line Pressure Span Effect Code per 1000 psi (6.89 MPa)

AP Range 4/5 +/-(0.25% URL + 0.5% span) 1 +/-(0.4% URL + 0.4% span)

This specification may be linearly interpolated down to 50ºF (27.8ºC) temperature interval. 2, 3 +/-(0.1% URL + 0.1% span)

Overpressure Effect (1) 3153ND Ranges 4 and 5:

Rosemount 3153ND ranges 4 and 5 experience a Based on full overpressure limits: span shift when operated at high static line x Range 1: 2000 psig (13.79 MPa) pressure. It is linear and correctable during x Range 2-5: 3626 psig (25.00 MPa) calibration.

x Range 6: 6000 psig (41.37 MPa)

If no correction for the systematic High Static Line 3153ND: Pressure Span Effect is performed, the error is as Range Overpressure Effect follows:

Code One-Sided Two-Sided Sequential Range High Static Line Pressure Span Effect Code Error per 1000 psi (6.89 MPa) 1-3 +/-0.25% URL +/-0.5% URL 4, 5 +/-0.3% URL +/-2.0% URL 4 -1.0% +/- 0.2% input reading 5 -1.25% +/- 0.2% input reading 3153NG and 3153NA:

Range One-Sided Overpressure Effect If the correction procedure as outlined in the 3150 Code Series Reference Manual 00809-0100-4835 is 1-3 +/-0.25% URL applied, the remaining correction uncertainty for the 4-6 +/-0.3% URL High Static Line Pressure Span Effect for ranges 4 (1) Overpressure specifications does not apply to transmitters and 5 is as follows:

with P9 option - please contact Rosemount Nuclear for additional information.

Range High Static Line Pressure Span Correction Code Uncertainty per 1000 psi (6.89 MPa)

High Static Line Pressure Zero Effect (3153ND only) 4, 5 +/-0.2% input reading The High Static Line Pressure Zero Effect can be It is possible to improve the accuracy of the calibrated out by the customer (see 3150 Series 3153ND at high static line pressure for applications Reference Manual 00809-0100-4835 for additional requiring enhanced performance. Please contact information). If it is not calibrated out, the error Rosemount Nuclear for additional information.

8

Product Data Sheet ATTACHMENT D 00813-0100-4853 Rev AF Analysis No. IP-C-0132, Revision 0 June 2020 Page D4 ofD8 Rosemount 3153N Power Supply Effect Functional Specifications Less than 0.005% of span/ volt Service Load Effect Liquid , gas, vapor Less than 0.0001 % of span/ohm based on resulting change in terminal voltage to the transmitter. Output 4-20 mA Electromagnetic Compatibility Satisfies requirements defined in : Power Supply

• US NRC Regulatory Guide 1.180 Rev 1 Maximum supply voltage

• EN 61326-1 :2006 and EN 61326-2-3:2006

• 48 VDC Maximum allowable supply voltage ripple Mounting Position Effect

• less than 1 volt peak-to-peak ripple for No span effect; zero shift of up to 1.5 inH2O (0.37 ripple frequency less than or equal to 120 kPa) which can be calibrated out. Hz Load Limits See Figure 5 Dielectric Withstand Test 707 VDC, 60 seconds, leakage less than 1 mA Insulation Resistance Test 500 VDC , 60 seconds, IR greater than 100 MOhm Figure 5 - Transmitter Load Limits vs . Power Supply Voltage 2500 DES IGN REGION 2 150 2000 IEEE QUALIFIED REGION 1725

-;;, 1500 E

.c:

Q.

-g 1000

.3 500 0 i,-::::,.::s.>,'"''f),>Y::: , ..c: , I I /

12 15 20 25 30 35 40 45 50 55 38 43 48 53 13.5 Power Supply (VDC) 9

ATTACHMENT D Product Data Sheet Analysis No. IP-C-0132, Revision 0 00813-0100-4853 Rev AF Rosemount 3153N Page D5 of D8 June 2020 Span and Zero Adjustments Turn-On Time External adjust; non-interacting for standard 2 seconds maximum adjustments Maximum Working Pressure Zero Elevation, Zero Suppression Larger of Static Line Pressure Limit or Upper Range Maximum Zero Elevation Limit (URL)

Zero is adjustable to the Lower Range Limit (LRL) Pressure Ranges Adjustable within the range shown; Upper Range Maximum Zero Suppression Limit (URL) is the highest pressure shown Zero is adjustable to 90% of the Upper Range Limit (URL) (80% for Range 1) 3153ND and 3153NG:

Range Range Down Code Pressure Range 10:1 (5:1 for Range 1) 1 0-5 to 0-25 inH2O (0-1.25 to 0-6.23 kPa) 2 0-25 to 0-250 inH2O (0-6.23 to 0-62.3 kPa)

Response Time 3 0-100 to 0-1000 inH2O (0-24.9 to 0-249 kPa)

Time constant (63.2%) at 100ºF (37.8ºC) 4 0-30 to 0-300 psi (0-206.8 to 0-2068 kPa)

Output Code R:

5 0-200 to 0-2000 psi (0-1379 kPa to 0-13.79 MPa)

Fixed Time Response (Max)

Range Code DP / GP AP 0-400 to 0-4000 psi (0-2758 kPa to 0-27.58 MPa) 6 Range 6 not available on 3153ND 1 2.0 sec N/A 2 0.5 sec N/A 3153NA (1):

3-6 0.2 sec 0.2 sec Range Pressure Range Code Output Code T (Adjustable Damping): 3 0-100 to 0-1000 inH2O abs (0-24.9 to 0-249 kPa)

Minimum Time Response in the 4 0-30 to 0-300 psia (0-206.8 to 0-2068 kPa)

Range Code Max Damping Position 5 0-200 to 0-2000 psia (0-1379 kPa to 0-13.79 MPa) 1 2.00 sec 6 0-400 to 0-4000 psia (0-2758 kPa to 0-27.58 MPa) 2-6 1.2 sec (1) Extended operation below 0.5 psia absolute pressure (3.5 Note: In the Minimum Damping Position, the values for Fixed kPa) is not recommended.

Time Response apply.

Temperature Limits Static Line Pressure Limits (3153ND only)

Normal Operating Limits: 40ºF to 200ºF Range Static Line Pressure Limit (4.4ºC to 93.3ºC) Code 1 0.5 psia to 2000 psig (3.45 kPa to 13.79 MPa)

Qualified Storage Limits: -40ºF to 120ºF 2-5 0.5 psia to 3626 psig (3.45 kPa to 25.00 MPa)

(-40.0ºC to 48.9ºC)

Overpressure Limits Humidity Limits Range Overpressure Limit 0 to 100% relative humidity (NEMA 4X) Code 1 2000 psig (13.79 MPa)

Enclosure Rating 2-5 3626 psig (25.00 MPa)

NEMA 4X (IP 66) 6 6000 psig (41.37 MPa)

Volumetric Displacement Burst Pressure Less than 0.005 in3 (0.082 cm3)

Minimum burst pressure is 10,000 psig (68.95 MPa) 10

ATTACHMENT D Product Data Sheet Analysis No. IP-C-0132, Revision 0 00813-0100-4853 Rev AF Rosemount 3153N Page D6 of D8 June 2020 ORDERING INFORMATION Model Transmitter Type Range Code 1 2000 psig (13.79 MPa) Static Pressure Limit 3153ND Nuclear Differential Pressure Transmitter Range Codes 2-5 3626 psig (25.00 MPa) Static Pressure Limit 3153NG Nuclear Gauge Pressure Transmitter 3153NA Nuclear Absolute Pressure Transmitter PRESSURE RANGES (1)

Code Differential Gauge (2) Absolute (3)

Lower Range Limit (LRL) to Upper Range Limit (URL) / Minimum Span (4)

-25 to 25 inH2O / 5 inH2O -25 to 25 inH2O / 5 inH2O 1(22) N/A

(-6.23 to 6.23 kPa/1.25 kPa) (-6.23 to 6.23 kPa/1.25 kPa)

-250 to 250 inH2O / 25 inH2O -250 to 250 inH2O / 25 inH2O 2 N/A

(-62.3 to 62.3 kPa/6.23 kPa) (-62.3 to 62.3 kPa/6.23 kPa)

-1000 to 1000 inH2O / 100 inH2O -393 to 1000 inH2O / 100 inH2O 0 to 1000 inH2O abs / 100 inH2O abs 3

(-249 to 249 kPa/ 24.9 kPa) (-97.9 kPa to 249 kPa/24.9 kPa) (0 to 249 kPa abs/24.9 kPa abs)

-300 to 300 psi / 30 psi -14.2 to 300 psig / 30 psi 0 to 300 psia / 30 psia 4

(-2068 to 2068 kPa/206.8 kPa) (-97.9 kPa to 2068 kPa/206.8 kPa) (0 to 2068 kPa abs/206.8 kPa abs)

-2000 to 2000 psi / 200 psi -14.2 to 2000 psig / 200 psig 0 to 2000 psia / 200 psia 5

(-13.79 to 13.79 MPa/1379 kPa) (-97.9 kPa to 13.79 MPa/1379 kPa) (0 to 13.79 MPa abs/1379 kPa abs)

-14.2 to 4000 psig / 400 psig 0 to 4000 psia / 400 psia 6 N/A

(-97.9 kPa to 27.58 MPa/2758 kPa) (0 to 27.58 MPa abs/2758 kPa abs)

Code Transmitter Output R 4-20mA Analog T 4-20mA Analog with Adjustable Damping Code Isolating Diaphragm 2 316L SST Code Process Flange Type / Material Process Connection Vent/Drain Orientation Traditional / SST (5) (5)

F0 1/4 - 18 NPT 1/4 - 18 NPT Drain Hole See Figure A (meets EN 61518 / IEC 61518)

Traditional / SST F1 1/4 - 18 NPT (5) Welded Vent/Drain Valve See Figure A (meets EN 61518 / IEC 61518)

(5)

F2 Traditional / SST Welded 3/8 inch Swagelok 1/4 - 18 NPT Drain Hole See Figure A F3 Traditional / SST Welded 3/8 inch Swagelok Welded Vent/Drain Valve See Figure A F4 Traditional / SST Welded 3/8 inch Swagelok Welded 3/8 inch Swagelok See Figure A Traditional / SST F5 1/4 - 18 NPT (5) Welded Vent/Drain Valve See Figure B (meets EN 61518 / IEC 61518)

(5)

F6 Traditional / SST Welded 1/4 inch Swagelok 1/4 - 18 NPT Drain Hole See Figure A F7 Traditional / SST Welded 1/4 inch Swagelok Welded Vent/Drain Valve See Figure A F8 Traditional / SST Welded 1/4 inch Swagelok Welded 1/4 inch Swagelok See Figure A See 3159 Product Data Sheet See 3159 Product Data Sheet See 3159 Product Data Sheet S1 Remote Seal, One Sided (00813-0100-4859) (00813-0100-4859) (00813-0100-4859)

See 3159 Product Data Sheet See 3159 Product Data Sheet S2 Remote Seal, Two Sided N/A (00813-0100-4859) (00813-0100-4859)

Continued on Next Page 14

Product Data Sheet ATTACHMENT D 00813-0100-4853 Rev AF Analysis No. IP-C-0132, Revision 0 June 2020 Page D7 ofD8 Rosemount 3153N PROCESS CONNECTION (LOW PRESSURE I

~

PROCESS CONNECTION (HIGH PRESSURE)

FIGURE A FIGURE B Code Electronics Housing, Conduit Connection A Aluminum, 1/2-14 NPT B Aluminum, M20-1.5 C Aluminum, PG13.5 D Aluminum, G1/2 Code Mounting Bracket< 61 0 No Bracket 5 Traditional Process Flange Bracket, CS Panel , SST Mounting Hardware (7>

7 Traditional Process Flange Bracket, SST Panel, SST Mounting Hardware 8 Traditional Process Flange Bracket, SST 2" Pipe, SST Mounting Hardware Code Standard Options C2 Connector-Unassembled (provided separately in package) , Connector P/N Must be Specified '8>

C3 Connector-Assembled to Transmitter on Zero/Span Adjustment Side of Housing , Connector Part Number Must be Specified '91 C4 Connector-Assembled to Transmitter Opposite Zero/Span Adjustment Side of Housing, Connector Part Number Must be Specified '91 D2 90° Rotatable Conduit Elbow-Unassembled (provided separately in package) 18>

D3 90° Rotatable Conduit Elbow-Assembled to Transmitter on Zero/Span Adjustment Side of Housing <9>

D4 90° Rotatable Conduit Elbow-Assembled to Transmitter Opposite Zero/Span Adjustment Side of Housing <9>

E2 CSA Ordinary Location Approval ,10> ,11 >

E5 Canadian Registration Number E6 CSA Explosion Proof Approval (11 ><12>

PA Extended 30 Minute Hydrostatic Test (standard hydrostatic test completed on every transmitter is 10 minutes in duration)

P4 Calibration at Static Line Pressure (13>

P5 Process Seal Helium Leak Test P6 Extended Upper Range Limit (14>

P8 Time Response Test <131 pg Extended Overpressure up to 4,500 psi (31.03 MPa) <151 08 Material Certification for Process Wetted and Pressure Retaining Parts 09 Special Documentation I Certification (in addition to standard material listed on page 17) -Consult Factory for Details Continued on Next Page 15

ATTACHMENT D Product Data Sheet Analysis No. IP-C-0132, Revision 0 00813-0100-4853 Rev AF Rosemount 3153N Page D8 of D8 June 2020 Code Standard Options - Continued from Page 15 R1 Sensor Module Rotated 180º from Standard Orientation (16) (17)

R4 Electronics Housing Rotated 180º from Standard Orientation (16) (18)

R5 Electronics Housing Rotated 90º Clockwise from Standard Orientation (16) (18)

R6 Electronics Housing Rotated 90º Counter Clockwise from Standard Orientation (16) (18)

(5) (19) (20)

V4 Threaded Drain / Vent Valve(s) (1/4-18 NPT)-Unassembled (provided separately in package)

V5 External Ground Screw Kit W1 Additional Customer Tagging Information-Permanent Tag Attached to Electronics Housing (see Figure 2)

W2 Additional Customer Tagging Information-Wire-on Tag Attached to Nameplate (see Figure 2)

ERD Range 1 Extended Range Down (21) (22)

Typical Model Number: 3153N D 2 R 2 F1 A 1 C3 W1 Notes:

(1) 3150 Series transmitter calibrations which include a Lower Range Value (LRV), Upper Range Value (URV), or span that are within

+/-5% of the published limits are acceptable.

(2) 3153NG Lower Range Limit (LRL) varies with atmospheric pressure.

(3) Extended operation below 0.5 psia absolute pressure (3.5 kPa) is not recommended.

(4) Maximum span is equal to the Upper Range Limit (URL); i.e. the maximum span of a 3153 range code 2 transmitter is 250 inH2O (62,3 kPa)

(5) Customer assumes responsibility for qualifying interfaces on these options.

(6) To comply with the REACH regulation, Rosemount Nuclear discontinued use of cadmium plated, carbon steel mounting hardware. As a result, mounting bracket codes 1, 2, and 3 are no longer available and have been removed from the ordering information table.

Mounting bracket codes 5, 7, and 8 provide the same mounting bracket with stainless steel mounting hardware.

CS Mounting Hardware Equivalent SST Mounting Hardware Bracket Code Bracket Code 1 5 2 7 3 8 (7) Mounting bracket code 5 is not available with process flange codes S1 and S2.

(8) Qualification of the connector installation and instrument/connector interface is the responsibility of the end user.

(9) Installation will be performed at Rosemount Nuclear. Certification of the connector installation and instrument/connector interface will be provided by Rosemount Nuclear.

(10) Connector options C2, C3, and C4 are only allowed with E2 if the connector is also CSA Approved.

(11) E2 and E6 are only available with electronics housing codes A and B.

(12) Connector (C2, C3, C4) and conduit elbow (D2, D3, D4) options are not allowed with E6 unless specifically authorized by the end user.

(13) Requires Configuration Data Sheet. Please contact Rosemount Nuclear for details.

(14) Extended Upper Range Limit (URL) varies by pressure range code, please contact Rosemount Nuclear for details. All specifications including a %URL term will be based on the revised URL.

(15) Please see Rosemount Specification Drawing 03150-1001 for applicable overpressure effect specifications.

(16) Rotation options R1, R4, R5, and R6 cannot be combined with one another.

(17) For rotation option R1, when used with gauge transmitter type, the calibration must be reverse acting (pressure will be applied to low side of the sensor module).

(18) The standard transmitter orientation is shown in Figure 2a. While rotation of the electronics housing in the field is possible with special instructions, it is not recommended by Rosemount Nuclear. If an alternative orientation is required for your application, please include the appropriate rotation option in the transmitter model number.

(19) Quantity is two for DP type transmitters and one for GP/AP type transmitters.

(20) V4 is not available with process flange codes S1 and S2. Vent/drain valve(s) option V4 may be selected in the 3159 Remote Seal model number.

(21) ERD option is only available with model 3153ND, pressure range code 1, and allows calibration to a minimum span of 1 inH 2O (0.25 kPa) with a revised LRL of -5 inH2O (-1.2 kPa) and URL of +5 inH2O (+1.2 kPa). It is not available with transmitter output code T, process flange codes S1 and S2, or standard options P4, P6, and P9. Please see Rosemount Specification Drawing 03150-1009 for applicable specifications and Rosemount Report D2017020. Note the ERD option code must be at the end of the transmitter model number.

(22) Additional special considerations are needed when calibrating draft range pressure transmitters. See Manual Supplement 00809-0800-4835.

16

ATTACHMENT E Rosemount Nuclear Instruments, Inc.

Analysis No. IP-C-0132, Revision 0 8200 Market Boulevard Chanhassen , MN 55317 USA Page El ofE2 EMERSON . ....__ _ _ _ _____. Tel 1 (952) 949-5210 Fax 1 (952) 949-5201 www. Rosemou ntN uclear. com November 16, 2018 To: Emerson Automation Solutions I Rosemount Nuclear Customer

Subject:

Rosemount 3150 Series Nuclear Pressure Transmitter Performance Specifications The purpose of this letter is to clarify the statistical basis of product specifications for the 3150 Series family of nuclear qualified pressure transmitters (including models 3152N, 3153N, 3154N and 3155N) as published in applicable Product Data Sheets.

The conclusions listed below are based on manufacturing testing and screening, final assembly acceptance testing, periodic (typically quarterly) product audit testing of transmitter samples and limited statistical analysis. Please note that all performance specifications are based on zero-based calibration ranges under reference conditions (ambient temperature and pressure). Additionally, there are no conclusions inferred with respect to confidence levels associated with any specifications.

Performance Specifications

1. Reference Accuracy All (100%) 3150 Series transmitters are tested to verify accuracy to +/-0.2% of span at 0%, 20%, 40%, 60%,

80%, and 100% of span . Therefore, the published reference accuracy specification is considered to be

+/-3<J.

2. Drift The tolerance interval was determined by enveloping the observed shifts from type tests. Based on the type test sample, the published drift specification is considered to be +/-2a.

3. Ambient Temperature Effect All (100%) 3150 Series transmitters are tested following final assembly to verify compliance with the published temperature effect specification . Therefore, the published ambient temperature effect specification is considered to be +/-3cr.

4. Overpressure Effect Testing of this specification is performed at the sensor module sub-assembly level. All (100%) range 1 through 6 sensor modules are tested for compliance to specifications. Based on the production sub-assembly test and periodic audit test performance, the published overpressure effect specification is considered +/-3cr.

5. Static Line Pressure Effect Testing of this specification is performed at the sensor module sub-assembly level. All (100%) range 1 through 5 sensor module sub-assemblies are tested for compliance with static pressure zero effect specifications (SLP effect is not applicable for range 6). Periodic product audit testing performed on all differential ranges (1 through 5) has also shown compliance with static pressure zero and span effect specifications. Therefore, the published static pressure effect specification is considered to be +/-3cr.

ROSEMOUNr Nuclear Page 1 of 2

6. Power Supply Effect Testing for conformance to this specification is performed on all transmitters undergoing periodic product audit testing. Based on audit test results, the published power supply effect specification can be considered +/-3cr.

Nuclear Specifications Seismic, Radiation, Steam Pressure/Temperature, Post DBE: The tolerance interval was determined by enveloping the observed shifts from qualification type tests. Based on the type test sample, the published specification is considered to be +/-2a.

For any additional questions, please contact your Emerson Automation Solutions I Rosemount Nuclear business partner or our technical support team at RNll.info@emerson.com or by phone at 1-952-949-5207 .

Thank you, lQ Brian Kocher I Sr. Principal Application Engineer Emerson Automation Solutions I Rosemount Nuclear 8200 Market Blvd Chanhassen MN 55317 USA Brian.Kocher@Emerson.com ATTACHMENT E Analysis No. IP-C-0132, Revision 0 Page E2 ofE2 ROSEMOUNr Nuclear Page 2 of 2

ATTACHMENT 5 Design Analysis IP-C-0096, "Setpoint Calculation Reactor Water Cleanup (RWCU) System Isolation-Differential Flow Timers, 1E31R615A(B), and 1E31R616A(B)," Revision 0B

CC-AA-309-1001-F-01 Revision 0 Design Analysis Cover Sheet Form Design Analysis Last Page No. 6 26, Attachment 3, Page 1 Analysis No.: 1 IP-C-0096 Revision: 2 0B Major Minor

Title:

3 Setpoint Calculation Reactor Water Cleanup (RWCU)

System Isolation-Differential Flow Timers, 1E31R615A(B), and 1E31R616A(B)

EC No.: 4 636711 Revision: 5 0 Station(s): 7 CPS Component(s): 14 Unit No.: 8 01 1E31R615A 1E31R615B Discipline: 9 INDC 1E31R616A 1E31R616B Descrip. Code/Keyword: 10 M98 Safety/QA Class: 11 SR System Code: 12 LD Structure: 13 N/A CONTROLLED DOCUMENT REFERENCES 15 Document No.: From/To Document No.: From/To IP-C-0089 From CPS Operational Requirements Manual (ORM) To 3C10-1182-001 From 3C10-0377-001 From IP-C-0132 From Is this Design Analysis Safeguards Information? 16 Yes No If yes, see SY-AA-101-106 Does this Design Analysis contain Unverified Assumptions? 17 Yes No If yes, ATI/AR#:

This Design Analysis SUPERCEDES: 18 IP-C-0096 Rev. 0A in its entirety.

Description of Revision (list changed pages when all pages of original analysis were not changed): 19 Revise calculation in its entirety to add timers 1E31R616A and 1E31R616B.

Preparer: 20 William Stathis Print Name Sign Name Date Method of Review: 21 Detailed Review Alternate Calculations (attached) Testing Reviewer: 22 LeRoy Stahl Print Name Sign Name Date Review Notes: 23 Independent review Peer review (For External Analyses Only)

External Approver: 24 Print Name Sign Name Date Exelon Reviewer: 25 Print Name Sign Name Date rd Independent 3 Party Review Reqd? 26 Yes No Exelon Approver: 27 Print Name Sign Name Date

CC-AA-103-1003 Revision 16 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analyses Page 1 of 3 Design Analysis No.: IP-C-0096 Rev: 0B _____ Page 1.1 Contract #: 00597084 ____________________________________ Release #: 01071 No Question Instructions and Guidance Yes / No / N/A 1 Do assumptions have All Assumptions should be stated in clear terms with enough sufficient documented justification to confirm that the assumption is conservative.

rationale?

For example, 1) the exact value of a particular parameter may not be known or that parameter may be known to vary over the range of conditions covered by the Calculation. It is appropriate to represent or bound the parameter with an assumed value. 2) The predicted performance of a specific piece of equipment in lieu of actual test data. It is appropriate to use the documented opinion/position of a recognized expert on that equipment to represent predicted equipment performance.

Consideration should also be given as to any qualification testing that may be needed to validate the Assumptions. Ask yourself, would you provide more justification if you were performing this analysis? If yes, the rationale is likely incomplete.

Are assumptions Ensure the documentation for source and rationale for the 2 compatible with the assumption supports the way the plant is currently or will be way the plant is operated post change and they are not in conflict with any operated and with the design parameters. If the Analysis purpose is to establish a licensing basis? new licensing basis, this question can be answered yes, if the assumption supports that new basis.

3 Do all unverified If there are unverified assumptions without a tracking assumptions have a mechanism indicated, then create the tracking item either tracking and closure through an ATI or a work order attached to the implementing mechanism in place? WO. Due dates for these actions need to support verification prior to the analysis becoming operational or the resultant plant change being op authorized.

4 Do the design inputs The origin of the input, or the source should be identified and have sufficient be readily retrievable within Exelons documentation system.

rationale? If not, then the source should be attached to the analysis. Ask yourself, would you provide more justification if you were performing this analysis? If yes, the rationale is likely incomplete.

5 Are design inputs The expectation is that an Exelon Engineer should be able to correct and reasonable clearly understand which input parameters are critical to the with critical parameters outcome of the analysis. That is, what is the impact of a identified, if change in the parameter to the results of the analysis? If the appropriate? impact is large, then that parameter is critical.

6 Are design inputs Ensure the documentation for source and rationale for the compatible with the inputs supports the way the plant is currently or will be way the plant is operated post change and they are not in conflict with any operated and with the design parameters.

licensing basis?

CC-AA-103-1003 Revision 16 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analyses Page 2 of 3 Design Analysis No.: IP-C-0096 Rev: 0B Page 1.2 No Question Instructions and Guidance Yes / No / N/A 7 Are Engineering See Section 2.13 in CC-AA-309 for the attributes that are Judgments clearly sufficient to justify Engineering Judgment. Ask yourself, documented and would you provide more justification if you were performing justified? this analysis? If yes, the rationale is likely incomplete.

8 Are Engineering Ensure the justification for the engineering judgment Judgments compatible supports the way the plant is currently or will be operated with the way the plant is post change and is not in conflict with any design operated and with the parameters. If the Analysis purpose is to establish a new licensing basis? licensing basis, then this question can be answered yes, if the judgment supports that new basis.

9 Do the results and Why was the analysis being performed? Does the stated conclusions satisfy the purpose match the expectation from Exelon on the proposed purpose and objective of application of the results? If yes, then the analysis meets the Design Analysis? the needs of the contract.

10 Are the results and Make sure that the results support the UFSAR defined conclusions compatible system design and operating conditions, or they support a with the way the plant is proposed change to those conditions. If the analysis operated and with the supports a change, are all of the other changing documents licensing basis? included on the cover sheet as impacted documents?

11 Have any limitations on Does the analysis support a temporary condition or the use of the results procedure change? Make sure that any other documents been identified and needing to be updated are included and clearly delineated in transmitted to the the design analysis. Make sure that the cover sheet appropriate includes the other documents where the results of this organizations? analysis provide the input.

12 Have margin impacts Make sure that the impacts to margin are clearly shown been identified and within the body of the analysis. If the analysis results in documented reduced margins ensure that this has been appropriately appropriately for any dispositioned in the EC being used to issue the analysis.

negative impacts (Reference ER-AA-2007)?

13 Does the Design Are there sufficient documents included to support the Analysis include the sources of input, and other reference material that is not applicable design basis readily retrievable in Exelon controlled Documents?

documentation?

14 Have all affected design Determine if sufficient searches have been performed to analyses been identify any related analyses that need to be revised along documented on the with the base analysis. It may be necessary to perform Affected Documents List some basic searches to validate this.

(ADL) for the associated Configuration Change?

15 Do the sources of inputs Compare any referenced codes and standards to the current and analysis design basis and ensure that any differences are reconciled.

methodology used meet If the input sources or analysis methodology are based on committed technical and an out-of-date methodology or code, additional reconciliation regulatory may be required if the site has since committed to a more requirements? recent code

CC-AA-103-1003 Revision 16 ATTACHMENT 2 Owners Acceptance Review Checklist for External Design Analyses Page 3 of 3 Design Analysis No.: IP-C-0096 Rev: 0B Page 1.3 No Question Instructions and Guidance Yes / No / N/A 16 Have vendor supporting Based on the risk assessment performed during the pre-job technical documents brief for the analysis (per HU-AA-1212), ensure that and references sufficient reviews of any supporting documents not provided (including GE DRFs) with the final analysis are performed.

been reviewed when necessary?

17 Do operational limits Ensure the Tech Specs, Operating Procedures, etc. contain support assumptions operational limits that support the analysis assumptions and and inputs? inputs.

18 Are the critical Identify the critical sections of the product and ensure those characteristics/attributes critical sections are not omitted and have sufficient detail to of the product support acceptability.

addressed acceptably?

Create an SFMS entry as required by CC-AA-4008. SFMS Number: ___________________

FORM PI-EXLN-003-3 Revision 0 Design Analysis No.: IP-C-0096 Rev. 0B Page 1.4 Licensed Engineer Certification Page Page 1 of 1 CERTIFICATION OF CALCULATION NUMBER(s): IP-C-0096, Rev. 0B I certify that the Calculation(s) listed above was prepared by me or under my personal supervision or developed in conjunction with the use of accepted engineering standards and that I am a Licensed Structural Engineer under the laws of the State of Illinois.

Certified by: __________________________________ Date: ___________________________

Seal Below Expires: _______________

Sargent & Lundy LLC Illinois Department of Professional Regulation Registration Number is: 184-000106

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 2 of 26 TABLE OF CONTENTS CALCULATION COVER SHEET.1 TABLE OF CONTENTS..2 1.0 OBJECTIVE ........................................................................................................... 3 2.0 ASSUMPTIONS...................................................................................................... 3 3.0 METHODOLOGY ................................................................................................. 5 4.0 INPUTS.................................................................................................................... 6 5.0 OUTPUTS................................................................................................................ 8

6.0 REFERENCES

........................................................................................................ 9 7.0 ANALYSIS AND COMPUTATION SECTION(S)........................................... 10 8.0 RESULTS .............................................................................................................. 20

9.0 CONCLUSION

S ................................................................................................... 24 ATTACHMENTS ATTACHMENT 1, Scaling 1 pg ATTACHMENT 2, Results Summary 1 pg ATTACHMENT 3, Cal Lab MEL Sheet, Cole Parmer Model 8668 1 pg

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 3 of 26 1.0 OBJECTIVE 1.1 Determine the instrument uncertainty, Setpoint, As-Found Tolerance (AFT) and As-Left Tolerance (ALT) for the Reactor Water Cleanup (RWCU) System Isolation

- Differential Flow Timers. This includes instruments 1E31R615A, 1E31R615B (short timer), and 1E31R616A, 1E31R616B (long timer).

1.2 This calculation evaluates the adequacy of the current setpoints (E31R615A/B) and new setpoints (E31R616A/B) in relationship to the results of 1.1 above.

2.0 ASSUMPTIONS 2.1 Published instrument vendor specifications are considered to be 2 values unless specific information is available to indicate otherwise.

2.2 Temperature, humidity, power supply, and ambient pressure errors have been incorporated when provided by the manufacturer. Otherwise, these errors are assumed to be included in the manufacturer's accuracy or repeatability specifications.

2.3 Normal radiation induced errors have been incorporated when provided by the manufacturer. Otherwise, these errors are assumed to be small and capable of being adjusted out each time the instrument is calibrated. Therefore, unless specifically provided, normal radiation errors can be assumed to be included within the instrument drift errors.

2.4 The effects of normal vibration (or a minor seismic event that does not cause an unusual event) on a component are assumed to be calibrated out on a periodic basis.

As such, the uncertainty associated with this effect is assumed to be negligible and included within the instrument drift errors. Abnormal vibrations, e.g., levels that produce noticeable effects on equipment, are considered abnormal events that require maintenance or equipment modification.

2.5 Evaluation of M&TE errors is based on the assumption that the test equipment listed in Analysis Section 7.0 is used. Use of test equipment less accurate than that listed will require evaluation of the effect on calculation results.

2.6 It is assumed that the M&TE listed in Section 7.0 is calibrated to the required manufacturer's recommendations and within the manufacturer's required environmental conditions. Temperature related errors are based on the difference between the Calibration Lab temperature and the worst case temperature at which the device is used.

2.7 It is assumed that the reference standards used for calibrating M&TE or Calibration tools shall have uncertainty requirements of not more than 1/4 of the tolerance of the equipment being calibrated. A greater uncertainty may be acceptable as limited by State of the Art. It is generally accepted that the published vendor accuracy of

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 4 of 26 the M&TE or Calibration tool includes the uncertainty of the calibration standard M&TE when the 4:1 accuracy standard is satisfied. Hence, Calibration Standard uncertainty is considered negligible to the overall calibration error term and can be ignored. This assumption is based primarily upon inherent M&TE conservatism built into the calculation. Per assumption 2.8, this calculation considers the combined M&TE vendor or reference accuracy used for calibration satisfies 1:1 accuracy ratio to the instrument under calibration. This ratio bounds the upper accuracy limit on Calibration tool equal to the Vendors Accuracy (VA) specification for the device under calibration. Use of M&TE more accurate than 1:1 is conservative to this assumption and thereby acceptable without impacting the results of this calculation.

2.8 It is assumed that when M&TE is not specified uniquely in a controlling calibration procedure (e.g., Surveillance Procedure or Preventive Maintenance Procedure), the combined M&TE vendor or reference accuracy used for calibration satisfies a 1:1 accuracy ratio to the instrument under calibration. This accuracy ratio establishes the limit on selected M&TE equal to the Vendors Accuracy (VA) requirement.

Further, M&TE uncertainty assumed per this discussion, is considered a 3 value regardless of the confidence associated with the related VA term.

2.9 The effects of EMI and RFI are considered negligible for panel mounted meters in administratively controlled EMI/RFI environments, unless a specific uncertainty term is provided by the vendor.

2.10 If the instrument vendor provides no drift information and there is no clear basis for assuming drift is zero, it may be conservatively assumed that the drift over the entire calibration period equals Vendor Accuracy (i.e., VD = VA 2 ).

2.11 The 5 minutes per HELB/Flooding calculations, Reference 4.6.2, 4.6.3, 4.6.5, 4.6.6.

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 5 of 26 3.0 METHODOLOGY This calculation will determine the instrument uncertainty associated with the RWCU Differential Flow Timers. The Evaluation will determine the As-Found and As-Left tolerances, and loop setpoint for the RWCU Differential Flow Timers. Instrument uncertainty will be determined in accordance with CI-01.00, Instrument Setpoint Calculation Methodology (Reference 6.1). The evaluation will then compare the current setpoint with the results determined by this calculation.

M&TE error will be determined from the results of Calculation IP-C-0089 (Input 4.6.1) which uses building temperature minimum and maximums to develop the uncertainty, and review of the corresponding loop and device calibration procedures (Input 4.9.1).

The RWCU system is not required for safety purposes, nor required to operate after the design basis accident. The reactor water cleanup system is required to operate in the normal plant environment for power generation purposes only (Ref.

6.2.5). The RWCU flow transmitters are part of the Leak Detection System (LDS) and are safety related. Upon detection of high differential leakage, the RWCU delta flow logic provides an isolation signal to the Containment and Reactor Vessel Control System (CRVICS) which is an Engineered Safety Feature (ESF)

System (Ref. 6.2.2 and 6.2.10).

Credit for the differential flow setpoint is considered for isolating High Energy Line Breaks that are not otherwise detected by area temperature monitors. Large (double-ended guillotine) breaks will continue to be isolated by the original (short) Differential Flow Timer Allowable Value (45 seconds + 2 seconds for uncertainty). The new (longer) Differential Flow Timer Allowable Value for smaller leaks is selected to ensure that the MSLB outside containment remains the limiting break for USAR analysis for offsite dose calculations (Ref. 6.3.1).

For instruments 1E31R615A and 1E31R615B, there was no Analytical Limit (AL) used to establish the Allowable Value (AV) of 47 seconds (Input 4.6.2).

Therefore, Per 6.1, Section 4.5.3, the setpoint will be calculated using Channel Uncertainty (see Sections 7.3.4 and 7.3.5 for equations).

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 6 of 26 5 minutes per Assumption 2.11. The AV for these instruments is determined by accounting for bounding response time delays as documented in Appendix C, Section 2.0 of Reference 4.6.3:

Signal Generation: 1 second Diesel Generator Start: 12 seconds Bounding RT Valve Closure: 24 seconds Total Response Time Delay: RT = (1 + 12 + 24) = 37 seconds AV = AL - RT = 15:00 - 00:37 = 14:23 Therefore, the AV for 1E31R616A and 1E31R616B is 14:23 (min:sec).

4.0 INPUTS 4.1 P&IDs 4.1.1 M10-9076, Sheet 2, Rev. B, P&ID/C&I Diagram Reactor Water Clean-Up Sys.

(RT).

4.2 Technical Manuals 4.2.1 K2801-0172, Rev. 79, Tab 26, Instruction Manual For Vendor Supplied Instruments Volume II, GEK-75666.

4.3 System Design Criteria 4.3.1 DC-ME-09-CP, Rev. 13, Equipment Environmental Design Conditions Design Criteria, (Zone Code M-24, Map Code D.6.2, Main Control Room & Electric Panel Room, El. 800-0, page 48).

4.4 CPS Drawings 4.4.1 E02-1LD99 Sheet 107, Rev. G, Schematic Diagram Leak Detection System (LD), Leak Detection System (1E31-1050).

4.4.2 E03-1P632 Sheet 001, Rev P, Internal Wiring Diagram, Div. 1 Leak Detection Panel 1H13-P632.

4.4.3 E03-1P642 Sheet 003, Rev G, Internal Wiring Diagram, Div. 2 Leak Detection Panel 1H13-P642.

4.4.4 E30-1004-00A-EI, Rev. G, Electrical Installation Main Control Room Control Bldg. EL. 800-0.

4.4.5 145C3043 Sheet 1, Rev. 14, Timer, Motor Driven. For Information Only 4.4.6 145C3043 Sheet 2, Rev. 14, Timer, Motor Driven. For Information Only 4.4.7 PL368X535AC, Rev. 21, Div 1 Leak Detection (VB) Parts List.

4.4.8 PL368X539AC, Rev. 18, Div 2 Leak Detection (VB) Parts List.

4.4.9 DA304A3630 Shts 1-3, Rev. 0, Timer, Mtr Driven (Type HP-5).

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 7 of 26 4.5 Passport (D030), For Information Only 4.5.1 EIN 1E31R615A, Reset Timer, Eagle Signal, Model No. HP51A6 4.5.2 EIN 1E31R615B, Reset Timer, Eagle Signal, Model No. HP51A6 4.6 Calculations 4.6.1 Calculation IP-C-0089, Rev. 0, M&TE Uncertainty Calculation.

4.6.2 Calculation 3C10-1182-001, Rev. 2, RWCU Line Break Inside Main Steam Tunnel in Containment.

4.6.3 Calculation 3C10-0377-001, Rev. 4, Containment Subcompartment Analyses -

RWCU Line Break 4.6.4 Calculation IP-32-0132, Rev. 0, RWCU Differential Flow Setpoint Analysis for Detecting Large Leaks.

4.6.5 3C10-0182-003, Rev, 3, Containment Subcompartment Parameters for Environmental Qualification of Equipment 4.6.6 3C10-0485-001, Rev. 11, Internal Flooding Analysis 4.7 Equipment Qualification 4.7.1 SQ-CL699, Rev. 1, General Electric Co./Eagle - Timer (Motor Driven).

4.8 Design Specifications/Data Sheets 4.8.1 Design Specification 22A3735, Revision 5, Leak Detection System.

4.8.2 DSDS 22A3735AC, Rev 13, Leak Detection System Design Spec Data Sheet 4.9 Calibration Procedures 4.9.1 CPS 9432.50, Rev. 34e, RWCU Differential Flow Timer E31-R615A(B)

Calibration.

4.9.2 CPS 9432.50D001, Rev. 33c, RWCU Differential Flow Timer E31-R615A Data Sheet.

4.9.3 CPS 9432.50D002, Rev. 33c, RWCU Differential Flow Timer E31-R615B Data Sheet.

4.10 Cal Lab MEL Sheet, Cole Parmer, Model 8668, dated 3/30/95 (Attachment 3)

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 8 of 26 5.0 OUTPUTS 5.1 CPS 9432.50A/B, RWCU Differential Flow Timer E31-R615A(B), E31-R616A(B) Calibration.

5.2 CPS 9432.50D001, Rev. 33c, RWCU Differential Flow Timer E31-R615A Data Sheet.

5.3 CPS 9432.50D002, Rev. 33c, RWCU Differential Flow Timer E31-R615B Data Sheet.

5.4 CPS Operational Requirements Manual (ORM), Rev. 34, 5.4.1 Attachment 2-14, Table 7, Item 4.b, Reactor Water Cleanup (RWCU) System Isolation - Differential Flow Timer.

5.5 CPS 9432.50D003, Rev. 00, RWCU Differential Flow Timer E31-R616A Data Sheet.

5.6 CPS 9432.50D004, Rev. 00, RWCU Differential Flow Timer E31-R616B Data Sheet.

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 9 of 26

6.0 REFERENCES

6.1 NSED-S-CI-01.00, Rev. 4, Instrument Setpoint Calculation Methodology 6.2 CPS USAR, Rev. 22 6.2.1 CPS USAR Section 7.1.2.1.22, Reactor Water Cleanup (RWCU) System -

Instrumentation and Controls 6.2.2 CPS USAR Section 7.3.1.1.2.4.1.9, Reactor Water Cleanup (RWCU) System -

High Differential Flow 6.2.3 CPS USAR Section 7.6.1.4.3.5, Reactor Water Cleanup System Leak Detection 6.2.4 CPS USAR Section 7.7.1(8), Control Systems not Required for Safety 6.2.5 CPS USAR Section 7.7.1.8, Reactor Water Cleanup (RWCU) System -

Instrumentation and Controls 6.2.6 CPS USAR Section 7.7.2.8, Reactor Water Cleanup System - Instrumentation and Controls 6.2.7 CPS USAR Table 6.2-47, Isolation Value Summary for Line Penetration Containment - Pen. # 60, 61, 64, & 86.

6.2.8 CPS USAR Figure 3.11-13, Environmental Zone Map, Control Building, Main Floor Plan El. 800-0.

6.2.9 CPS USAR Figure 5.4-16, Reactor Water Cleanup System P&ID.

6.2.10 CPS USAR Section 7.1.2.1.24, Leak Detection Systems - Instrument and Controls 6.3 CPS Technical Specification, Amendment 216 6.3.1 Section 3.3.6.1, Primary Containment and Drywell Isolation Instrumentation.

(Including the associated Bases) 6.3.1.1 Table 3.3.6.1-1, Item 4.b, Reactor Water Cleanup (RWCU) System Isolation -

Differential Flow Timer 6.4 CPS Procedure 1512.01, Rev. 18, Calibration and Control of Measuring and Test Equipment

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 10 of 26 7.0 ANALYSIS AND COMPUTATION SECTION(S) 7.1 LOOP FUNCTION (Ref. 6.2.2)

High differential flow in the reactor water cleanup system could indicate a breach of the pressure boundary in the RWCU system. The RWCU system flow at the inlet to the system (suction from reactor recirculation lines) is compared with the sum of the flows at the outlets of the system return to feedwater and flow to the Main Condenser). High differential flow initiates isolation of the RWCU system.

Reactor water cleanup system high differential flow trip is bypassed by an automatic timing circuit during normal reactor water cleanup system surges. This time delay bypass prevents inadvertent system isolation during system operational changes.

7.2 LOOP DIAGRAM Each loop is comprised of a single device, the RWCU Differential Flow Timer.

There are no other components in the loop. Loop input is a digital logic level (on/off) signal and the timer output is also a logic level (on/off) signal according to Input 4.2.1. As such, there is no loop diagram for the RWCU Differential Flow Timers.

Per Inputs 4.4.2, 4.4.3, 4.4.7 and 4.4.8, the RWCU Differential Flow Timers are installed in 1H13-P632 and 1H13-P642. Per Input 4.4.4 and Ref. 6.2.8, 1H13-P632 and 1H13-P642 are located in the Main Control Room (MCR). Per Input 4.3.1 the environmental conditions in the MCR are:

Normal Temperature 65 to 104 F Normal Humidity 5 to 60% RH Normal Radiation 1 103 Rads Accident Temperature 65 to 104 F Accident Humidity 5 to 60% RH Accident Radiation 1 103 Rads

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 11 of 26 7.3 EQUATIONS 7.3.1 Loop Accuracy (AL):

2 2 2 2 2 VAi ATEi OPEi SPEi SEi n n n n n Ai N 2 2 2 2 B 2 REi HEi PSEi REEi n n n n Derived from the SSRS combination of loop components, where error attributed for each loop component is evaluated by:

AL is defined as:

2 2 2 AL A1 A2 A3 ... B 2 7.3.2 Loop Calibration Error (CL):

2 2 2 ALTi Ci C i STD CL N 2 n n n 7.3.3 Loop Drift (DL):

2 2 2 D1 D2 Dn DL N ... 2 n n n 7.3.4 Calculation of Channel Uncertainty (CE):

CE = (1.645/N)(SRSS OF RANDOM TERMS) BIAS TERMS 7.3.5 Nominal Trip Setpoint Calculation The Nominal Trip Setpoint (NTSP) should be calculated using the equations below depending on the direction of process variable change when approaching the Allowable Value.

For process variables that increase to trip:

NTSP(INC) = AV - CE For process variables that decrease to trip:

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 12 of 26 NTSP(DEC) = AV + CE 7.3.6 Calculation of As-Found Values The device As-Found Tolerance will be determined via the Square-Root-Sum-of-the-Squares (SRSS) of the devices As-Left Tolerance, its drift, and the M&TE error used to calibrate the device.

2 2 2 ALTi Di Ci AFTi N 2 n n n Where:

ALTi = devices As-Left Tolerance Di = devices drift value Ci = errors of M&TE used to calibrate the device The loop As-Found Tolerance (AFT) will be calculated as follows:

2 2 CL DL AFTL N 2 n n Where:

DL = Loop devices drift value, as defined in Section 7.3.3 CL = Loop devices calibration effect, as defined in Section 7.3.2 7.3.7 Calculation of As-Left Values The loop As-Left Tolerance (ALT) will be calculated as follows:

2 2 2 ALT 1 ALT 2 ALTn ALTL N ... 2 n n n Where: ALTi VAi 2

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 13 of 26 7.4 DETERMINATION OF UNCERTAINTIES 7.4.1 Eagle Signal Controls HP5 Timers:

Component EIN 1E31R615A, B 1E31R616A, B Input 4.2.1, 4.4.5 thru 4.4.9 4.2.1 Model/Part No. HP51A634/145C3043P003 HP55A6 HP51A6/ DA304A3630P003 Dial 0-60 seconds 0-30 minutes Min. Setting 2 seconds 1 minute Dial Division 1 second 1/2 minute Repeat Accuracy +/-0.15 seconds +/-9 seconds (145C3043P003)

+/-0.3 seconds (DA304A3630P003)

Operating Temp.32-140 degF 32-140 degF Reset Time 0.5 second @ max. setting 0.5 second @ max setting 7.4.1.1 Vendor Accuracy (VATimer) - Per Input 7.4.1, Assumption 2.1, and the most conservative vendor model number accuracy:

VATimer(615) = 0.3 seconds (2 )

VATimer(616) = 9.0 seconds 7.4.1.2 Accuracy Temperature Effect (ATETimer) - Per Assumption 2.2, ATETimer = 0.

ATETimer = 0 7.4.1.3 Humidity Effect (HETimer) - Per Assumption 2.2, HETimer = 0.

HETimer = 0 7.4.1.4 Radiation Effects (RETimer) - Per Assumption 2.3, RETimer is included in drift.

RETimer = 0

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 14 of 26 7.4.1.5 Power Supply Effects of level transmitters (PSE Timer) - Per Assumption 2.2, PSETimer = 0.

PSETimer = 0 7.4.1.6 Static Pressure Effect (SPETimer) - SPE is not applicable to Timers.

SPETimer = 0 7.4.1.7 Overpressure Effect (OPETimer) - OPE is not applicable to Timers.

OPETimer = 0 7.4.1.8 Seismic Effect (SETimer) - The Timers have been seismically qualified using the manufacturers published accuracy requirements (Input 4.7.1). Based on a review of Input 4.7.1 and Assumption 2.4, there are no additional error considerations which must be considered for seismic conditions. Therefore:

SETimer = 0 7.4.1.9 RFI/EMI Effect (REETimer) - Per Assumption 2.9, the effects of EMI and RFI are considered negligible.

REETimer = 0 7.4.1.10 Bias (BTimer) - From Reference 6.1, Appendix C, Section 1.2 Bias is described as a systematic or fixed instrument uncertainty that is predictable for a given set of conditions because of the existence of a known direction (positive or negative). No such error was identified for the timers. Therefore:

BTimer = 0 7.4.1.11 Per Section 7.3.1, the accuracy associated with the differential pressure transmitters is calculated below.

2 2 2 2 2 VAi ATEi OPEi SPEi SEi n n n n n Ai N 2 2 2 2 B 2 REi HEi PSEi REEi n n n n From above:

VATimer(615) = 0.3 seconds (2 ) Section 7.4.1.1 VATimer(616) = 9.0 seconds (2 ) Section 7.4.1.1 ATETimer =0 Section 7.4.1.2

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 15 of 26 OPETimer =0 Section 7.4.1.7 SPETimer =0 Section 7.4.1.6 SETimer =0 Section 7.4.1.8 RETimer =0 Section 7.4.1.4 HETimer =0 Section 7.4.1.3 PSETimer =0 Section 7.4.1.5 REETimer =0 Section 7.4.1.9 BTimer =0 Section 7.4.1.10 Substituting:

( ) =+/- + ( ) +( ) +( ) + ( ) + ( ) + ( ) +( ) +( ) +( )

A(615) = 0.30 seconds (2 )

9.0

( ) =+/- + ( ) +( ) +( ) + ( ) + ( ) + ( ) +( ) +( ) +( )

A(616) = 9.00 seconds (2 )

7.4.2 Loop Accuracy Since, there is only one component in the loop, the loop accuracy is the same as the device accuracy.

AL(615) = 0.3 seconds (2 )

AL(616) = 9.0 seconds

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 16 of 26 7.5 LOOP CALIBRATION ERROR (CL)

Loop Calibration Error is determined by the SRSS of As-Left Tolerance (ALT i),

Calibration Tool Error (Ci), and Calibration Standards Error (Ci STD) for the individual devices in the loop. The equation below is used to calculate this effect.

From Section 7.3.2:

2 2 2 ALTi Ci Ci STD CL N 2 n n n 7.5.1 As-Left Tolerance (ALTL)

From Section 7.3.7, loop As-Left Tolerance (ALT) will be calculated as follows:

2 2 2 ALT 1 ALT 2 ALTn ALTL N ... 2 n n n Where: ALTi VAi 2 From Section 7.4.1.1, VATimer(615) = 0.3 seconds and VATimer(616) = 9.0 seconds.

For E31R615A/B, the existing ALT tolerance band was verified to be -0.0 to 0.6 seconds per Input 4.10.1; i.e., a 0.6 second tolerance band. A symmetric tolerance of one-half of this tolerance band will be used. Therefore:

ALTTimer(615) = 0.6 seconds/2 ALTTimer(615) = 0.3 seconds For E31R616A/B, the ALT tolerance band is assumed to be equal to the instrument VA per guidance in Section 4.3.3 of Reference 6.1. Therefore:

ALTTimer(616) = VATimer(616) = 9.0 seconds Since there is only one device in the loop, the ALT for the loop (ALT L) is the same as for the device:

ALTL(615) = 0.3 seconds (2 )

ALTL(616) = 9.0 seconds

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 17 of 26 7.5.2 Calibration Tool Error (Ci)

Per Section 7.0 of Input 4.9.1, the RWCU Differential Flow Timers are calibrated with a 0-60 minute Stopwatch (specified as a Cole Parmer Model 8668) with a 0.01 second resolution.

Accuracy: 0.1 sec/60 min at 70 to 80 F Accuracy: 0.2 sec/60 min at 15 to 70 F and 80 to 145 F Per Ref. 6.1, Appendix H, Section H.2.1, in order to verify that the 1:1 criteria is met for M&TE, perform the following:

VATimer (MTEI2 + MTEO2)1/2 1E31R615A/B: 0.3 sec 0.1 sec 1E31R616A/B: 9.0 sec 0.1 sec Ci = [VA2 +ATE2 + IRE2 + ALT2]1/2 Where, from above:

(VA + ATE) = 0.2 sec IRE = 0.01 sec ALT = 0.1 sec Substituting:

Ci = [0.22 + 0.012 + 0.12] 1/2 Ci = 0.2238 sec 7.5.3 Calibration Standard Error (CSTD)

Per Assumption 2.8 Calibration Standard Error is considered negligible for the purposes of this analysis.

CSTD = 0

NF-161.01 Revision 0 DE~T/DIV CALCULATIONNO. IP-C-0096 REVISION OB Page C/NSED 18 of 26 7.5.4 Loop Calibration Error (C1)

From above:

ALTL(615) = +/- 0.3 sec (2cr) Section 7.5.1 ALTL(616) = +/- 9.0 sec (2cr) Section 7.5.1 Ci = +/- 0.2238 sec (3cr) Section 7.5.2 CSTD =O Section 7.5.3 Substituting terms:

C =+ 2 ( 0.3 sec ) 2 ( 0.2238 sec ) 2 + 0 2 l (615) - 2 + 3 C L(6I5) = +/- 0.3351 seconds (20')

C =+ 2 ( 9 .0 sec ) 2 ( 0 .223 8 sec ) 2 + 0 2 l (616) - 2 + 3 CL(6I6) = +/- 9.0012 seconds (20')

7.6 LOOP DRIFT 7.6.1 Timer Drift (Di)-Per Assumption 2.10, VD= VA at 2o-.

DTimer(615) = +/- 0.3 seconds (20')

DTimer(616) = +/- 9.0 seconds (20')

7.6.2 Loop Drift (D1)

Since there is only one device in the loop, the ALT for the loop (ALT1) is the same as for the device:

D L(6I5) = +/- 0.3 seconds (20')

DL(6I6) = +/- 9.0 seconds (20')

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 19 of 26 7.7 PROCESS MEASUREMENT ERROR (PMA)

Per Reference 6.1, process measurement accuracy (PMA) is defined as Process measurement effects aside from the primary element and the sensor.

Inaccuracies associated with measurement of the process are not applicable since there is no process measurement. The RWCU Differential Flow Timers are time delay relays actuated by a logic level (on/off) input. Therefore; PMA = 0 7.8 PRIMARY ELEMENT ACCURACY (PEA)

Per Reference 6.1, primary element accuracy (PEA) is defined as The accuracy of the device (exclusive of the sensor) which is in contact with the process .

Inaccuracies associated with the primary element are not applicable since there is no primary element. The RWCU Differential Flow Timers are time delay relays actuated by a logic level (on/off) input. Therefore; PEA = 0

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 20 of 26 8.0 RESULTS 8.1 Allowable Value (AV)

Per Input 4.6.2, the Allowable value for 1E31R615A and 1E31R615B is established as 47 seconds. Therefore, AV(615) = 47 seconds Per Methodology Section 3.0 and Input 4.6.2, the Allowable Value for 1E31R616A and 1E31R616B is established as 14:23 (min:sec). Therefore, AV(616) = 14:23 (min:sec) 8.2 Calculation of the Channel Uncertainty (CE)

From Section 7.3.4, CE = (1.645/N)(SRSS OF RANDOM TERMS) BIAS TERMS Where:

AL(615) = 0.3000 sec (2 ) Section 7.4.2 AL(616) = 9.0000 sec (2 ) Section 7.4.2 DL(615) = 0.3000 sec (2 ) Section 7.6.2 DL(616) = 9.0000 sec (2 ) Section 7.6.2 CL(615) = 0.3351 sec (2 ) Section 7.5.4 CL(616) = 9.0012 sec (2 ) Section 7.5.4 PMA = 0 Section 7.7 PEA = 0 Section 7.8 B = 0

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 21 of 26

=+/- + + + + +/-

( )=+/- + + . + . + . +/-

CE(615) = 0.4447 seconds

( )=+/- + + . + . + . +/-

CE(616) = 12.8221 seconds 8.3 Calculation of the Nomial trip Setpoint (NTSP)

From Section 7.3.5, the equation for determining the NTSP for an increasing trip is as follows:

NTSP(INC) = AV - CE Where:

AV(615) 47 seconds Section 8.1 CE(615) = 0.4447 seconds Section 8.2 And:

AV(616) 14:23 (min:sec) Section 8.1 CE(616) = 12.8221 seconds Section 8.2 The negative side of the As-Found tolerance is of significance in calculating the NTSP for an increasing trip.

Substituting:

Timers 1E31R615A and 1E31R615B:

NTSP(615) = AV - CE

= 47 sec - 0.4447 sec

= 46.5553 seconds

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 22 of 26 The ORM value of 45 seconds is conservative to the calculated NTSP and therefore the setpoint of 45 seconds is retained.

NTSP(615) = 45 seconds Timers 1E31R616A and 1E31R616B:

NTSP(616) = AV - CE

= 14:23 - 12.8221 sec

= 14:10.1779 (min:sec)

Conservatively, the NTSP for timers 1E31R616A and 1E31R616B is established as:

NTSP(616) = 14:00 (min:sec) 8.4 Calculation of As-Found Values From Section 7.3.6, both Instrument loop and device As-Found Tolerances should be calculated. However, since there is only one device in the loop, only the loop tolerance will be calculated. The loop As-Found Tolerance will be determined via the Square-Root-Sum-of-the-Squares (SRSS) of the loop drift and the loop calibration error.

2 2 CL DL AFT L N n n Where:

DL(615) = 0.3000 sec (2 ) Section 7.6.2 DL(616) = 9.0000 sec (2 ) Section 7.6.2 CL(615) = 0.3351 sec (2 ) Section 7.5.4 CL(616) = 9.0012 sec (2 ) Section 7.5.4

=+/- +

Therefore, Timers 1E31R615A and 1E31R615B:

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 23 of 26

( ) =+/- +

AFTL(615) = 0.4498 sec Per Ref. 6.1, this value is to be rounded to the procedure precision.

Therefore:

AFTL(615) = 0.45 seconds (2 )

Timers 1E31R616A and 1E31R616B:

( ) =+/- +

AFTL(616) = 12.7288 sec Per Ref. 6.1, this value is to be rounded to the procedure precision.

Therefore:

AFTL(616) = 13.00 seconds (2 )

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 24 of 26

9.0 CONCLUSION

S Timers 1E31R615A and 1E31R615B:

This calculation determined an NTSP(615) of 45 seconds for RWCU Differential Short Flow Timers. The ORM value (Output 5.4.1) of 45 seconds is conservative and therefore retained. The symbol will be dropped from the ORM as this calculation establishes a symmetrical As-Found tolerance.

NTSP(615) = 45 seconds (2 )

The current Allowable Value of 47 seconds was not evaluated in this calculation.

AV(615) 47 seconds (2 )

Timers 1E31R616A and 1E31R616B:

This calculation determined an NTSP(616) of 14:00 (min:sec) for RWCU Differential Long Flow Timers. This value will be included in the ORM (Output 5.4.1). The symbol will not be used in the ORM as this calculation establishes a symmetrical As-Found tolerance.

NTSP(616) = 14:00 (min:sec) (2 )

The current Allowable Value of 14:23 (min:sec) seconds is evaluated in this calculation (Section 3).

AV(616) 14:23 (min:sec) (2 )

Scaling is not required because the RWCU Differential Flow Timer Loop input is a digital logic level (on/off) signal and the timer output is also a logic level (on/off) signal. This loop is a function of time and does not convert process measurements (temperature, pressure, differential pressure, etc.) from engineering units (°F, psig, etc.) into analog electrical units (VDC, mADC, etc.). A Results Summary is included in Attachment 2 to this calculation to provide as summary.

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 25 of 26 FIGURE 1 - RWCU Differential Short Flow Timers (1E31R615A/B)

Maximum Instr. Range 60 seconds Analytical Limit (AL) NA Allowable Value (AV) 47 seconds AFT (+) 45.45 seconds ALT (+) 45.3 seconds NTSP 45 seconds ALT (-) 44.7 seconds AFT (-) 44.55 seconds Minimum Instr. Range 0 seconds

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B Page C/NSED 26 of 26 FIGURE 2 - RWCU Differential Long Flow Timers (1E31R616A/B)

Maximum Instr. Range 30 minutes Analytical Limit (AL) 15 minutes Allowable Value (AV) 14:23 (min:sec)

AFT (+) 14:13 (min:sec)

ALT (+) 14:09 (min:sec)

NTSP 14:00 (min:sec)

ALT (-) 13:51 (min:sec)

AFT (-) 13:47 (min:sec)

Minimum Instr. Range 0 seconds

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B SHEET C/NSED ATTACHMENT 1 1 of 1 THERE IS NO SCALING FOR THE RWCU DIFFERENTIAL FLOW TIMERS

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION 0B SHEET C/NSED ATTACHMENT 2 1 of 1 RESULTS

SUMMARY

The following tables list the applicable results of this calculation:

Individual Component Setting Tolerances Component EIN As-Found As-Left 1E31R615A and 1E31R615B +/-0.45 seconds +/-0.30 seconds 1E31R616A and 1E31R616B +/-13.0 seconds +/-9.0 seconds Trip Setpoint and Loop Setting Tolerances Component EIN Setpoint As-Found As-Left (divisions) 1E31R615A and 1E31R615B 45 seconds +/-0.45 seconds +/-0.30 seconds 1E31R616A and 1E31R616B 14:00 (min:sec) +/-13.0 seconds +/-9.0 seconds M&TE Used In Calculation (if specified in calculation)

Manufacturer Model Number Range Total Accuracy (Eng. Units)

Cole Parmer 8668 0 - 60 minutes 0.224 sec per 60 min (or equivalent) (15 F to 145 F)

FSAR/Technical Specification Setpoints Component EIN Allowable Value / FSAR/Technical Specification Design Setpoint Section 1E31R615A and 1E31R615B 47 seconds/45.0 seconds Tech. Spec. Table 3.3.6.1-1 1E31R616A and 1E31R616B 14:23/14:00 (min:sec) Item 4.b /

ORM Table 7, Item 4.b (1E31R615A/B only)

NF-161.01 Revision 0 DEPT/DIV CALCULATION NO. IP-C-0096 REVISION OB SHEET C/NSED ATTACHMENT 3 1 of 1 1vuJ.e !"armer MODEL NO.: *-g(,(,,J RANGE: 0 to 60 minutes with 0.01 second resolution ACCURACY:

• t0.10 sec/60 minutes at 70°F - 80°F

• +/-0.20 sec/60 minutes at 15°F - 70°F and 80°F - 145"F CALlllRATION: 937500 nsec (Internal Clock) tlO nsec at 70°F - 80°F

• The above stated accuracies are for the stopwatch only and do not take into account the reaction time of the individual who is operating the stopwatch or any inaccuracies that may be introduced by the operator.