westinghouse class 3 reactor vessel level …

WESTINGHOUSE CLASS 3

REACTOR VESSEL LEVEL INSTRUMENTATION SYSTEM Wl.NUAL

MICROPROCESSOR EQUIPMENT 3 D/P CELL DESIGN

Prepared by NTD Systems Integration S. G. Scaqlia C. S. Hauser D. R. Henricks

June, 1983

WESTINGHOUSE ELECTRIC CORPORATION Nuclear Energy Systems

P.O. Box 355 · Pittsburgh, PA 15230

6 040404.., 9404160oc1~ o500027D~R PDR AD p

. I

p

TABLE OF CONTENTS

• Section Title Page

1 SYSTEM DESCRIPTION Tab 1

1-1. General Description 1-1 1-2. Detailed System Description 1-1

1-3. Different i a 1 Pressure Measurements 1-1 1-4. System Layout 1-4 1-5. Microprocessor RVLIS 1-7 1-6. RVLI S Inputs 1-7 l-6A. Wide Range Reactor Coolant Pressure 1-12 1-7. Density Comoensation System 1-12 1-8. Plant Ooerator Interface and Displays 1-17 1-9. Setpoints 1-22

1-10. Resistance Temperature Detectors (RTD) 1-22 1-11. Aging 1-23 1-12. Radiation 1-23 1-13. Seismic 1-23 1-14. High Eneroy Line Break Simulation 1-23

1-15. Reactor Vessel Level Instrumentation System Valves 1-25

1-16. Transmitters, Hydraulic Isolators, and Sensors 1-25 1-17. Differential Pressure Transmitters 1-25 1-18. Hydraulic Isolator 1-26 1-19. High Volume Sensor 1-26

1-20. Test Programs 1-28 1-21. Forest Hi 11 s 1-28

1-22. Reactor Vessel .Simula tor 1-30 1-23. Installation 1-31 1-24. Filling Operation 1-31

1-25. Plant Startup Calibration 1-32 1-26. Operating Performance 1-33 1-27. Semiscale Tests 1-36 1-28. RVLIS Analysis 1-19

1-29. Transients Investigated 1-41 1-30. Case A 1-42 1-31. Case B 1-44 1-32. One Inch Cold Leg Break 1-46

J..

Section

2

3

4

5

6

TABLE OF CONTENTS

Title

1-33. Observations of the RVLIS Study 1-47

1-34. Conclusions 1-35. References

RVLIS MICROPROCESSOR SYSTEM PROCEDURES AND GUIDELINES

2-1 • Purpose 2-2. De~cription

2-3. RVLIS Startup Calibration

2-4. Normal Plant Operation

2-5. Refue 1 i ng 2-6. Periodic Testing 2-7. Plant Startup 2-8. Failure Events/Symptoms 2-9. Troubleshooting, Plant at Power

RVLIS INSTALLATION CRITERIA

REACTOR VESSEL LEVEL I~STRUMENT SYSTEM INITIAL FILL INSTRUCTIONS

4-1. Introduction 4-2. Prefill Visual Inspections

4-3. Purge Test

4-4, Pressure Test 4-5. Electrical Checks 4-6. System Evacuation

4-7. Syste~ Fill 4-8, Fill Verification/Hydro Test

GENERIC SCALING PROCEDURE

TRANSMITTER CALIBRATION BASES

1-53 1-54

Tab 2

2-1

2-1 2-5

2-10 2-11

2-12 2-13

2-13 2-25

Tab 3

Tab 4

4-1

4-1

4-1

4-2 4-4 4-4 4-12

4-13

Tab 5

Tab 6

6-1. Introduction 6-1 6-2. Calibration Level Differential Pressures 6-1 6-3. Wide Range D/P Calibration 6-4 6-4. Reference Column 6-5 6-5. Critical Operating Pressures n-9

( (

TABLE OF CONTENTS

Section Title

7

8

6-6. Sample Calibration Calculations 6-7. Example l RVLIS Transmitter

Scaling, Non-UHi Plant

HYDRAULIC ISOLATOR/SENSOR CAPILLARY CALIBRATION PROCEDURE

7-1. Introduction 7-2. Function 7-3. Normal Operation

7-4. General 7-5. Transmitter·Displacement 7-6. Pressure Effects 7-7. Thermal Expansion

7~8. Calibration 7-9. Hydraulic Isolator Status Indication 7~10. Troubleshooting 7-11. Sensor and Process Connections

7-12. Fill Volumes 7-13. Sensor Volumetric Displacement

MAINTENANCE INSTRUCTIONS USING TRANSMITTER ACCESS ASSEMBLY

6-13

6-13

Tab 7

7-1. 7-1 7-2

7-2

7-3 7-6 7-8 7-10 7-11

7-12 7-13 7-14

7-14

Tab 8

8-1 • Purpose 8-1 8-2. Description 8-1

8-3. Installation (Filling Operation) 8-4 8-4. Maintenance 8-4 8-5. Removal of Water (Counterclockwise

HI Indication) 8-4 8-6. Addition of Water for Clockwise

Hydraulic Isolator Indication 8-6.

8-7. Refilling (After Transmitter Replacement)

8-8. Calibration 8-9. Instruction and Repair Parts for ENERPAC

8-10, Procedure for Vacuum Fillinq Sealed Liquid Level Measurina Syst~ms

8- l 0. 1 Scope 8-10.2. Material List

( ( (

8-7 8-11 8-15

8-15 8-15

8-15

- i

• TABLE OF CONTENTS

Section Title Page

8-10.3 Preparation 8-20 8-10.3. l Vacuum Pump 8-20 8-10.3.2 Fill Bottle P~eparation 8-20 8-10.3.3 Fluid for level Measuring

·System 8-20

8-10.4 Filling Operation 8-21 8-10. 4. l Initial Settings 8-21 8-10.4.2 Evacuation of System 8-21 8-10.4.3 Vacuum Test 8-21 8-10.4.4 Filling System 8-22

9 RECOMMENDED SPARE PARTS LIST Tab 9

10 RECOMMENDED MAINTENANCE AND TEST EQUIPMENT Tab 10

11 DRAWINGS Tab 11

12 EQUIPMENT INSTRUCTION MANUALS Tab 12

H'

•

Figure

1-1

1-2

1-3

1-4

1-5

1-6

1-7

1-8

1-9

1-10

1-11

1-12

1-13

1-14

1-15

1-16

1-17

1-18

1~19

1-20

LIST OF ILLUSTRATIONS

Title Page

Reactor Vessel Level Instrument System 1-2

Process Connection Schematic Diagram, Train A 1-3

Typical Plant Arrangement for RVLIS 1-6

Reactor Vessel Level Instrument System Block Diagram (One Set of Two Redundant Resets Shown)" 1-8

Remot~ Display Module (Control Board) 1-9

Typical Plant Arrangement for RVLIS 1-11

Surface Type Clamp-On Resistance Temperature . Detector 1-13

Block Diagram of Compensation Function 1-14

Simplified Schematic Diagram of Density of Compensation System 1-15

Vessel Level Summary Display 1-19

Vessel Level Trend Display 1-20

Typical Vessel Level Sensor Status Display 1-21

HELB Simulation Profile 1-24

ITT Barton Hydraulic Isolator Internal 1-27

ITT Barton High Volume Sensor Bellows Check Valve 1-29

·Comparison of RVLIS Narrow Range With Two-Phase Mixture Level Determined From Densitometer Indications for Test S-UT-8 1-57

Sensitivity to·Break Size and Slowdown 1-58

Case A - Th~ee-Locip, Three Inch Cold Leg Break, Pum~ Trip, RVLIS Reading and Vessel Mixture Level 1-59

Total Vessel Mass 1-60

Three Loop Plant,.Two Inch Cold Break, Pumps Runnin~ Jhroughout the Transient, No Safety Injection is Available

\'

1-61

•

•

Figure

1-21

1-22

1-23

1-24

3-1

4-1

4-2

4-3

4-4

4-5

6-1

6-2

6-3

6-4

6-5

6-6

7•1

7-2

• 7-3


Title Page

One Inch Cold Leg Break, ICC Case, RVLIS Reading and Mixture Level . 1-62

One Inch Cold Leg Break, ICC Case, Mixture Level, RVLIS Reading and Measured Inventory 1-63

Case D, One Inch Cold Leg Break, ICC Case, RVLIS Reading and Mixture Level 1-64

Differential Pressure Measurement Sensitivity to Flow Blockage 1-65

Typical Capillary Tubing Layout 3-8

Liquid Temperature Versus Saturated Vapor Pressure 4-6

Sensor and Inline (Operating Deck) Evacuation and Fill Schematic Diagram 4-8

Isolator Bypass Evacuation and Fill Schematic Diagram

Schematic Diagram of the Transmitter Fill Connection

Vent Connection Schematic Diagram of the In-Core Detector Conduit Annulus

-Level System Calibration Dimensions

RVLIS Reference Column Installation Dimensions

Reference Column Compensation

Upper Range and Full Range D/P Level Variation With Reactor Coolant Temperature

Dynamic Head D/P Level and Flow Variation With Reactor Coolant Temperature

Level System Calibration Dimensions, Example 1 -Non-UH! Plants

Hydraulic Isolator Volume Measurements

Transmitter/Isolator Displacement for Pumps On and Standard Configuration

Compressibility of Water

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4-9

4-11

4-16

6-2

6-6

6-8

6-11

6-12

6-15

7-4

7-7

7-9

•

•

Figure

7-4

8-1

8-2

8-3

8-4

8-5

8-6

8-7

10-1

10-2

10-3


Title

Resistance Forces for Displacements

Aisembly Drawing of the Transmitter Access Assembly (Drawing 2656Cl2)

Calibration Fixture

Transmitter, TAA, and Calibration Fixture

Transmitter Calibration

Schematic Diagram of the Transmitter Fill Connection

Configuration for Repressurization of D/P Cell System

Valve Lineu~ for Calibration of D/P Transmitter

Tools and Test Fittings for On-Site Servicing

Adapter Seal Plug

Fill Valve Instructions

l' ( {

7-16

8-2

8-3

8-5

8-9

8-10

8-13

8-14

10-6

10-7

l 0-8

•

•

Table

1-1

2-1

6-1

7-1

10-1

10-2

LIST OF TABLES

Title

Transients Investigated

Troubleshooting Chart

Critical RCS Pressures Versus Containment Postaccident Temperitures

Approximate Volumetric Displacement of RVLIS Transmitters

Service and Testing Equipment

Materials Needed for Vacuum Fill of Capillary Tubing

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Page

1-56

2-27

6-13

7-5

10-2

10-3

• SECT ION 1

SYSTEM DESCRIPTION

i-1. GENERAL DESCRIPTION

The reactor vessel level instrumentation system (RVLIS) uses differential pressure (d/p) measuring devices to measure vessel level or relative void content of the circulating primary cool ant system fluid. The system is ·

' . redundant and includes automatic compensation for potential temperature variations of the impul_se 1 i nes. Essentia 1 information is displayed in the main control room in a form directly usable by the operator.

The functions performed by the RVLIS are as follows:

1 Assist in detecting the presence of a gas bubble or void int.he reactor

vessel

1 Assist in detecting the approach to Inadequate core Cooling (ICC)

1 Indicate the fonnation of a void. in the RCS during forced flow conditions

1-2. DETAILED SYSTEM DESCRIPTION

1-3. Differential Pressure Measurements

The RVLIS (figure 1-1) utilizes two sets of three d/p cells. These cells measure the pressure drop from the bottom of the reactor vessel -to the top of the vessel~ and from the hot legs to the top of th~ vessel.

This d/p measuring system uti 1 i zes cells of differing ranges to cover different flow behaviors with and without pump operation as follows:

I Reactor Vessel - Upper Range (~Pa). The d/p cell ~Pa shown in figure' 1-1 provides a measurement of reactor vessel level above the hot leg pipe when the reactor coolant pump (RCP) in the loop with the hot leg connection is not operating.

1-1

17,917-1

•

Reactor Core

Train A Train B

Figure 1-1. Reactor Vessel Level Instrument System

1-2

•

HEAD PENETRATION

SEAL TABLE CONTAINMENT WALL

Figure 1-2. Process Connection Schematic Diagram, Train A

1-3

• Reactor Vessel - Full Range (oPb). This measurement provides an indication of reactor vessel level from the bottom of the reactor vessel to the top of the reactor during natural circulation conditions.

1 Reactor Vessel - Dynamic Head (APc). This instrument provides an indication of reactor core and internals pressure drop for any combination of operating RCPs. Comparison of the measured pressure drop with the normal, single-phase pressure drop prov'ides an approximate indicatioA of the relative void content or density of the circulating fluid. This instrument monitors coolant condition~ on a continuing basis during forced flo~ conditions.

To provide the required accuracy for level measurement, temperature measurements of the impulse lines are provided. These measurements, together with the existing reactor coolant temperature measurements and wide range RCS pressure, are employed to compensate the d/p transmitter outputs for differences in system density and ~eference leg density, particularly during the hange in the environment inside the containment structure following an

accident.

The d/p cells are located outside of the containment to eliminate the large reduction (approximately 15 per-Cent) of measurement accuracy associated with the change in the containment environment (temperature, pressure,· radiation) ouring an accident~ The cells are also located outside of containment so that system operation including calibration, cell replacement, reference leg checks, and filling are made easier.

1-4. System Layout

A schematic diagram of the system layout for the RVLIS is shown in figure 1-2. There are four RCS penetrations for the cell reference lines: one reactor head connection at a spare penetration near t.he center of the head or the reattor vessel head vent pipe, one connection to an incore instrument conduit at the seal table, and connections into the side of two RCS hot leg

~ipes/RTD bypass manifolds.

1 -.l ,

•

•

The pressure sensing lines extending from the RCS penetrations are a combination of 3/4 inch Schedule 160 piping and 3/8 inch tubing and include a 3/4 inch manual isolation valve as described in paragraph 1-15. These lines connect to six sealed capillary impulse lines (two at the reactor head, two at the seal table, and one at each hot leg) which transmit the pressure measure

ments to the d/p transmitters located outside the contairnnent building. The capillary impulse lines are sealed at the RCS end with a sensor bellows which serves as a hydraulic coupling for the pressure measurement. The impulse lines extend from the sensor bellows through the containment wall to t\Ydraul1c isolators, which also provide hydraulic coupling as well as a seal and isolation of the lines. The capillary tubing extends from the hydraulic isolators to the d/p transmitters, where instrument valves are provided for isolation.

Figure 1~3 is an elevation plan of a typical plant showing the routing of the impulse lines. The impulse lines from the vessel head connection must be

routed upward out of the refueling canal to the operating deck, then radially toward the seal table and then to the containment penetration. The connection to the bottom of the reactor vessel is made through an incore detector conduit which is tapped with a T-connection at the seal table. The impulse line from this connection is routed axially and radially to join with the head connection line in routing to the penetrations. Similarly, the hot leg connection impulse lines are routed toward the seal table/penetration routing of the other two connections.

The impulse lines located inside the containment building will be exposed to the containment temperature increase during a LOCA or HELP. Since the vertical runs of impulse lines form the reference leg for the d/p measurement, the change in density due to the accident temperature change must be taken into account in the vessel level determination. Therefore, a strap-on RTD is located on each vertical run of separately routed impulse lines to determine the impulse line temperature and correct the reference leg density contribu

tion to the d/p measurement. Temperature measurements are not required where all three impulse lines of an instrument train are routed together. Based on the studies of a number of representative plant arrangements, a maximum of seven independent vertical runs must be measured to adequately compensate for

density changes.

1-5

I

°'

• G_ S G· G_ S G

I I'

o';_ . -O'

0 -

•<' . ,, / ,·t- I.. •

" .. · •,, ).o ~!\ ·~

, 'I ;r () . 0 f ,

"-"'"")..,.......,...._~.~-~-~-~.~......,.,~.,._ ........ ,.....~,.,1,.~ ol..--.( •

0 ... "','\•.::::•o/ 1 :. Cn:. 11 ·)~'.'

0 \.) e 0 e rw:: :~1 ......,, '. ·~ !"..,,; I '~ (\ 0 \. "l 'll '.., o

• f_1 C• "~ , " ·.'~ r- '\ _., ,• (' \) r:"" I 0 •" ,..._ : ~ r . - .

Figure 1-3. Typical Plant Arrangement for RVLIS

I I I

L - -PROTECTED ENVIRONMENT

+65 FT

+ 40 FT

• .-I w en en w >a: a.. o> I-!:::. u <( w a:

' 0 FT

- 15 FT

•

• 1-5. Microprocessor RVLIS

The raicroprocessor RVLIS includes equivalent reactor vessel level indications on redundant flat panels with alphanumeric displays provided for control room installation in addition to having this information available for display at the microprocessor chassis. RVLIS is configured as two protection trains, in certain installation in separated sections of a single instrument rack and in other installations in two separated instrument racks. The envelope of an instrument rack occupies a space at the base of 30 by 30 ;nches with a height of 92 inches. The block diagram of the RVLIS using microporcessor equipment

is shown in figure 1-4. This diagram shows that in addition to the reactor ,~

vessel level (d/p) transmitter input, there are also temperature compensating

signals, reactor coolant pump running status inputs, and RCS parameter inputs

to each chassfs of the two r·edundant trains. The output of each set will be to displays and to a reactor, as well as an output for a serial data link. A

general display arrangement is shown in figure 1-5.

1-6. RVLIS Inputs - The microprocessor system inputs are as follows.

If existing unqualified inputs are used, isolation as required must be provided by the owner.

1 Differential Pressure Transmitters (Analog Input). The three d/p transmitters per train are used to measure the d/ps between the three pressure tap points on the primary system, as discu-ssed below.

6Pa is connected between the pressure tap on the head of the vessel and tap on the hot RTD Bypass Manifold leg of one of the coolant loops, which is typically about 4 feet or more above the top of the core.

On the redundant system ~Pa connects to a tap on the, same head

connection and a different hot leg pipe.

The direction of this transmitter's output is full scale (>20ma, dependent upon plant configuration)· with the vcissel full anrl :zero scale

1-7

•

•

REACTOR VESSEL LEVEL

TEMPERATURE COMPENSATION SIGNALS 171

IN CONTAINMENT

FROM EXISTING PLANT INSTRUMENTATION

OUT CONTAINMENT

I

"' I-::i ~ ;;:: "'j

REACTOR PUMP RUN STATUS

REACTOR COOLANT PARAMETERS

TH PWR

-INPUTS-

ELECTRONIC. CHASSIS

AID CONVERSION

PROCESSOR

D/A CONVERSION

POWER SUPPLIES

LOCAL DISPLAY_ AND CONTROLS

DISPLAY AND CONTROLS

INSTRUMENTATION CABINET

CONTROL ROOM

.. 0 0 )Jo

OUTPUT FOR DATA LlNJ< TO PLANT COMPUTER

TO RECORDER

Figure 1-4 Reactor Vessel Level Instrument System Block Diagram (One Set of Two Redundant Resets Shown)

1-8

r-- - - - -t.__-_-_@ __ -___ v_e_s_s_e_L_L_IE_v_e_L_M_o_N_•_T_o_R ___ -_-_-_-_-~~ _____ ~

L- - - - - -- - - - - - - - --- - - - - -- - - - - - - - - - - - _____ J

BB PROCESSOR

086 SENSOR STATUS

Figure 1-5 Remot~ Display Module (Control Board)

(4 ma) with the vessel emptied to the hot leg tap. These endpoints are nominal and are for low coolant temperatures. If nb pumps are operating,

APa gives an indication of level in the region above the hot leg.

If the pump is running in the l-0op with the hot leg connection, this indication will be invalid and most likely offscale. the reading would be flagged as invalid under these conditions. The effect on the indication from a pump not running in this loop, but running in other loops, is less

than 10 percent ·of the range.

APb is connected between the pressure tap at the top of the vessel and a pressure tap to one of the incore detector conduits at the seal table. The 1ncore conduit is water filled and connects to the bottom of the

vessel. The redundant system APb transmitter fs connected to the same two pressure tap points.

APb gives an indication of rector vessel level when no pumps are running. If one or more pumps are running, APb will be offscale and the reading invalid.

The sense of the APb output is such that a 20 ma signal is a nominally full vessel and a 4 ma signal is for a nominally empty vessel.

APc iia higher range d/p cell connected between the same two pressure taps as APb. APc covers the entire span of all pumps running to vessel empty. The sense of the APc.output is that 20 ma represents all pumps running and 4 ma is empty vessel. With all pumps running and no void fraction, the APc should read 100 percent at zero power. The reading at full power is slightly higher.

t Reference Leg Temperature RTD (Analog Input). The reference leg temperature RTDs are used to measure the temperature of the coolant in the capillary tube reference legs. These temperatures are used to compute the density of the reference leg fluid. A typical arrangement of the reference leg temperature RTDs is shown in figure 1-6.

1-1 !)

__J

• a,b,c

I -'

Figure 1-6. Typical Plant Arrangement for RVLIS

The conversion of RTD resistance to temperature covers the temperature range of 32° to 450°F.

The RTDs are 100-ohm platinum four-wire RTDs as shown in figure 1-7.

t Hot Leg Temperature (Analog Input). Either an existing or new wide range hot leg temperature sensor is used to measure the coolant temperature. This temperature is used to calculate coolant density. The wide range hot leg temperature sensor does not have to be located in the same loop as the d/p hot leg connection, but the THot inputs to each tr~ins should be from separate loops.

The block diagram of the compensation functions is shown in figure 1-8.

l-6A. Wide Range Reactor Coolant Pressure

t Either existing wide range pressure transmitters or new transmitters will be used to measure reactor coolant oressure. The pressure is used to calculate reactor coolant density. The block diagram of the comperi~ation function is shown in figure 1-9.

t Digital Inputs. The reactor coolant pump status signals (Class IE) indicate whether or not pumps are running. Recognizing that hydraulic isolators are provided on each impulse line for containment isolation purposes, each hydraulic isolator has limit switches to indicate they have

reached the limit of travel.

1-7. Density Compensation System

To provide the required accuracy for vessel level measurement, temperature measurements of the impulse lines are provided. These measurements, together with the existing reactor coolant temperature measurements and wide range RCS

_pressure, are employed to compensate the d/p transducer outputs for differences in system density and reference leg density, particularly during the change in the environment inside the containment structure following an accident. A simplified schematic diagram of the sensity compensation system is shown in figure 1-9. The d/p cells are located outside the containment.

The reference leg fluid density calculation covers a reference leg temperature range of 32° to 450°. The fluid is assumed to be compressed liquid water at 1200 psia.

1-12

_. I

•

Figure 1-7. Surface Type Clamp-On Resistance Temperature Detector

• a,b,c

17,917-7 a,b,c

Figure 1-8. Block Diagram of Compensation Function

1-14

• 17,917.8

a,c

•

• Figure 1-9. Simplified Schematic Diagram of Density of Compensation System

1-15

•

Each of the three d/p measurements will have density corrections from temperature measurements on sensing lines that affect d/p. Some of these will have a positive correction and some negative depending on the orientation of the impulse line where the temperature is being measured.

1 Vessel Liquid Density ·calculation.

1 Vessel Vapor Phase Density Calculation.

1 Vessel Level Calculation;

1 Pump Flow d/p Calculation.

1-16

a,c

a~

a,c

a,c

•

•

• Scaling of Displayed Values. Each of the three d/p measurements after the preceding calculations must be scaled to read in percent. With the vessel full of water and no pumps running, the outputs of 6Pa and 6Pb should read 100 percent.

l-8. Plant Operator Interface and Displays

Information displayed to the operator for the RVLIS is intended to be , unambiguous and reliable to ·minimize the potential for operato~ error or

misinterpretation. The redundant control board displays provide the following information:

1 An indication of reactor vessel level (full range) for each instrumented set displaying vessel level in percent from Oto 100 percent after compensation for the effects of the reactor coolant_ and capillary line temperature and density, when reactor coolant pumps are not operating. The display is scaled O - 120 percent.

1 An indication of reactor d/p (Dynamic Head) from each instrumented set displaying d/p in percent from 0 to 100 percent, after compensation for the effects of the reactor cool ant and capi 11 ary 1 i ne temperature and density effects, when reactor coolant pumps are operating at Tavg no-load conditions. At full power, the display reading will exceed 100

percent indication. The display is scaled O - 120 percent.

1 An indication of upper range vessel level on each of the two instrumented sets displaying vessel level in percent from 60 (dependent upon elevation of hot leg tap) to approximately 106 percent (dependent upon if vent top 1 s used or if CROM pipe .is used) after compensation for any reactor coolant and capillary line density effects, when reactor coolant pumps are not operating. The display is scaled 60 percent - 120 percent.

1-17

a,c

• Infonnation is transmitted to remote digital display units from each train via a serial data 11nk.

Redundant displays are provided for the two trains. Level infonnation based on all three d/p measurements is presented. Correction for reference leg

densities is automatic. Any error conditions such as out-of-range sensors or hydraulic isolators are automatically displayed on the affected measurements.

There are three display sheets for reactor vessel level: the first is a su11111ary sheet. the second is a trending of the three vessel level indications over a 20 minute period and the third is a sensor status sheet which indicates which sensors are out of range or offscale.

Each train includes digital to analog converters to provide three analog signals per train for a single three-pen strip chart recorder.

1 Display Functions for Remote Control Board. The prime display unit for the vessel level monitor is the 8-line. 32-character-per-line aphanumeric display which is located in the control board remote fror.i the main processing unit.

I Vessel Level Monitor Summary Display. Figures 1-5. 1-10, 1-11. and 1-12 give example displays. General arrangement is shown on figure 1-5. The

vessel level summary display is shown on figure 1-10.

1 Trend Display. The trend display for the vessel level monitor must use the format shown in figure 1-11.

• Sensor Status Display. The sensor status display.for the vessel level monitor is shown in figure 1-12.

I Displays on Main Processing Unit. The one-line 40-character alphanumeric display on the front panel of the main processing unit is used to display individual sensor inputs, calibration constraints, and co~pensated

outputs. The sensor is selected with a two-digit thumbwheel switch. The following information is given for each sensor:

1- lR

•

REACTOR VESSEL LEVEL SUMMARY

STATUS

OFF SCA

P U M P S A U N N I N G : No. 1 No. 2 No. 3 No. 4

• ISOLATOR ALARMS: LIJ

# DISABLED: TJ THl

Figure 1-10 Vessel Level Summary Display

• REACTOR VESSEL LEVEL TREND

TIME UPPER FULL DYNAMIC

MIN RANGE RANGE HEAD

0 73% 47% 110%

I 5 78% 49% 98% N CJ

10 79% 52% 97%

15 82% 56% 98%

20 97% 9.9% 99%0

. Figure 1-11 Vessel Level Trend Display

I N

VESSEL LEVEL SENSOR STATUS

OFFSCALE DP No. DISABLED DP No.

DP RTD4 1

RTD 7 1

Figure 1-12 Typical Vessel level Sensor Status Display

Sensor identification Input signal level Input signal converted to engineering units Status of sensor input

1 Disabled Inputs. Any inputs can be disabled by the operator. This action is under the control of a keyswitch on the front panel of the main computational unit and causes the processor to disregard the analog unit

for that variable.

1-9. Setpo1nts

There are no alarms or annunciators for the RVLIS System.

('

1 Out of Range Inputs. The control board display will indicate an out-of-range or limit of motion condition when the inputs reach the following setpoints:

a,c

1-10. Resistance Temperature Detectors ( RTD)

The resistance temperature detectors (RTD) associated with the RVLIS are

utilized to obtain a temperature signal for fluid-filled instrument lines· inside containment during normal and postaccident operation. The temperature measurement for all vertical instrument lines is used to correct the vessel level indication for density changes associated with the environmental temperature change.

The RTD assembly is a totally enclosed and hermetically sealed strap-on device

consisting of a thermal element, extension cable, and termination cable as indicated in figure 1-7. The sensitive portion of the device is mounted in a removable adapter assembly which is designed to conform to the surface of the

. 1-22

•

•

tubing or piping being monitored. The materials are all selected to be compatible with the normal and postaccident environment. Randomly selected samples from the controlled (such as material and manufacturing) production lot will be qualified by type testing. Qualification testing will include aging, radiation, seismic, and high energy line break simulation (paragraphs

1-11 through 1-14).

1-11. Aging

The thennal aging test wil 1 consist of operating the detectors in a high temperature environment - either 400°F for 528 hours or per other similar Arrhenius temperature/time relationship.

1-12. Radiation

The detectors must be irradiated to a total integrated dose (TIO) of 1.2 x

108 rads gamma radiation using a co60 source at a minimum rate of 2. O x 106 rads/hour and a maximum rate of 2.5 x, 106 rads/hour. Any externally exposed organic materials must be evaluated or tested to 9 x 108 rads TIO beta radiation. The energy of the beta particle must be 6 MEV for the first 10 MRad, 3 MEV for 340 MRad, and 1 MEV for 150 MRad.

1-13. Seismic

The detectors will be tested using a biaxial seismic simulation. The detectors must be'mounted to simulate a plant installation and will be energized throughout the test.

1-14. High Energy Line Break Simulation

The detectors must be tested in a.saturated steam environment using the

temperature/pressure curve shown in figure 1-13.

Caustic spray, consisting of 2500 ppm boric acid dissolved 'in water and adjusted to a pH 10.7 at 25°C by sodium hydroxide, must be applied during the

first ~4 hours. The test units will be energized throughout the test.

1-23

U: 0

w a: ::J t-c::(

I a: f'-} w .:::. Q._

:.? UJ t-

420

340

305

205

120

0 10

SEC

72PSIA ~1

J

MIN

I I I I I I I I

5

MIN

1:

0 10

SEC

TIME

CAUSTIC SPRAY

12 PSIA --1 .

-----<•-11...,.._ SATURATED ~t STEAM

I.

J MIN

I I I I I

------1

6

MIN

20 24

MIN .HOUR

16

OAY

•TIME BETWEEN TEMPERATURE TRANSIENTS MUST BE AT LIEAST ONE HOUR OR UNTIL TEST UNITS RETURN TO A SHADY s r A TE OtHPlH. TIME AUOVE 34a°F MUST BE FIVE. MINUTES on LESS.

Figure 1-13. HELB Simulation Profile

•

The RTD device is designed to operate over a temperature range of -58° to S00°F (the normal temperature range is 50° to 130°F).

1-15. Reactor vessel Level Instrumentation System Valves

Two types of valves are supplied for the RVLIS. The root valve (3/4 T78) is an ASME Class 2, stainless steel, globe valve. The basic function of the valve is to isolate the instrumentation from the RCS. The other valve (1/4 x 28 ID) is an instrumentation-type valve. It is a manually actuated ball valve . used to provide isolation in the fully closed position. The valve is hermetically sealed and utilizes a packless design to eHminate the possibility of fluid leakage past the stem to the atmosphere.

1-16. Transmitter, Hydraulic Isolators, and Sensors

1-17. Differential Pressure Transmitters

The d/p transmitters are a seismically qualified design as u~ed in numerous other plant applications. In the RVLIS application, accuracy considerations dictate a protected environment. Consequently, transmitters are rated for 40° to 130°F and 104 rad TIO.

Several special requirements for these transmitters are as follows:

1 Must withstand long term overloads of up to 300 percent with minimal effect on calibration

• · High range and bi di rec ti onal units re qui red for pump head measurements

1 Must displace minimal volumes of fluid in nonnal and overrange operating modes

The first two requirements are related to the vernier characteristic of the

pumps off level measurements and the wide range measurements, respectively. The third is related to the limited driving displacement of the hydraulic isolator when preserving margins for pressure and thennal expansion effects in

the coupling fluids.

1-25

• The d/p transmitters are rated 3000 psig working pressure and all units are tested to 4500 psig. Internal valving also provides overrange ratings to full working pressure.

1-18. Hydraulic Isolator

The hydraulic isolator is a high displacement d/p switch employed as a floating check valve which conveys pressures from the RCS ports to the remote transmitters.

The.isolators are rated at 3000 psig working pressure and are factory tested at 4500 psig. Principal gaskets are metallic for preservation of pressure boundaries through most severe postulated accident conditions. They are qualified for containment environment applications.

1-19. High Volume Sensor

aCCOlllllOdate

a,c

The sensor bellows unit employed in the RVLIS iS a new design to the special requirements of this application. Ja.c

1-26

q .c. "'

•

1-27

17,917.18

-ro c: ... C1l ... c:

.!::! ::l ro ...

"O > :r: c: 0 ... ... ro

co

~

'<:1" ,..... I

The sensor housings are rated for 3000 p_sig working pressure. All units are hydro tested at 4500 psig. The principal gasketing is metallic for ensured integrity in the event of accident exposures to either radiation.or high

I

temperatures.

1-20. Test Programs

A variety of test programs have been carried out to study the static and dynamic perfonnance at two test facilities. A test program is carried out at each reactor pl ant where the system is installed to calibrate the system over a range of nonnal operating conditions. These programs, which supplement the

vendors' tests of hydraulic and electrica-1 components, provide the appropriate verification of the system response to-accident conditions as well as the appropriate procedures for proper operation, maintenance, and calibration of the equipment. A description of these programs is presented in the following sections.

1-21. Forest Hills

A breadboard installation consisting of one train of an RVLIS was installed

and tested at the Westinghouse Forest Hills Test Facility. The system consisted of a full single train of RVLIS hydraulic components (sensor assemblies, hydraulic isolators, isolation valves and d/p transmitters) connected to a simulated reactor vessel. Process connections were made to simulate the reactor head, hot leg, and seal table connections. Capillary tubing, which in one sensing line simulated the maximum expected length (400 feet}, was used to connect the sensor assemblies to the hydraulic isolators and all joints were welded. Connections between the hydraulic isolators, valves, and transmitters utilized compression fittings in most cases. -Resi~tance temperat~re detectors, special large volume sensor-bellows, and

1-28

a,c

18.<191-1

• a,b,c

•

Figure 1-15. ITT Barton High Volume Sensor Bellows Check Valve

• 1-29

~olume displacers inside the hydraulic isolator assemblies, which are nonnally part of a RVLIS installation, were not included in the installation since

. elevated temperature testing was not.included in the program.

The hydraulic isolator assemblies and transmitters were mounted at an elevation slightly below the simulated seal table elevation.

The objectives of the test were as follows:

1 Obtain installation, filling, and maintenance experience

• Prove and es tab 1 i sh fil 1 i ng procedures for i ni ti a 1 fi 11 i ng and system maintenance

1 Establish calibration and fluid inventory maintenance procedures for shutdown and nonnaloperation conditions

Prove long tenn integrity of hydraulic components

1 Verify and quantify fluid transfer and makeup requirements associated with instrument valve operation

1 Verify leak test procedures for field use

1-22. Reactor Vessel Simulator

The reactor vessel simulator consisted of a 40-foot- long 2-i nch diameter stainless steel pipe with taps at the top, side, and bottom to simulate the reactor· head, hot leg, and focore detector thimble conduit penetration at the bottom of the vessel. Tubing (0.375 inch diameter) was used to connect this lower tap to the sensor at the simulated seal table elevation, and the hot leg

· senso~ to the head connection was simulated by 1-inch tubing which connected the sensor to the vessel.

The reactor vessel simulator was designed for a pressure rating of 1400 psig .to comply wHh local stored energy and safety code considerations.

1-30

1-23. Installation

The system was installed in the high bay test area of the Westinghouse Forest Hills Test Facility by Westinghouse personnel under the supervision of Forest Hills Testing Engineering. All local safety codes were considered in the

construction.

1-24. Filling Operation

1-3,. .

a,c

•

1-25 Plant Startup Calibration

During the plant startup, subsequent to installing the RVLIS, a test program will be carried out to confinn the system calibration. The program will cover nonnal- operating conditions and will provide a reference for comparison with a potential accident condition. The elements of the program are described below:

1 During refilling and venting or the reactor vessel, measurements of all six d/p transmitters would be compared to confinn identical level

indications.

1 During plant heatup with all reactor coolant pumps running, measurements would be obtained from the dynamic head d/p transmitters to confirm or correct the temperature compensation provided in the system electronics. The temperature compensation, based on a best estimate of the flow and pressure drop variation during startup, corrects the transmitter output so that the control board indication is maintained at 100 percent over the

entire operating temperature range.

1 At hot standby, measurements would be obtained fror:i a 11 transmitters with different combinations of reactor coolant pumps operating, to provide the reference data for comparison with accident conditions. For any pump operating condition, the reference data represent the nonnal condition, that is, with a water-solid system. A reduced d/p during an accident would be an indication of voids in the reactor vessel.

I At hot standby, measurements would be obtained from the reference leg RTDs to confinn or correct reference leg temperature compensation provided in the system electronics .

1-32

a,c

•

1-26. Oper~ting Perfonnance

Each train of the RVLIS 1s capable of monitoring coolant mass in the vessel from nonnal operation to a condition of complete uncovery of the reactor core. · This capabil 1ty is provided by the thre.e d/p transmitters, each transmitter covering a specific range of operating conditions. The three instrument ranges provide overlap so that the measurement can be obtained frrnn more than one display under most accident conditions. Capabilities of each of

the measurements are described as follows:

1 Reactor Vessel - Upper Range. The transmitter span covers the distance from the hot leg piping connection to the top of the reactor vessel. With

the reactor coolant pump shut down in the loop with the hot leg connecti~n, the transmitter output is an indication of the level in the upper plenum or upper head of the reactor vessel. The measurement will provide an accurate indication for guidance when operating the reactor vessel head vent. The measurement will also provide a confinnation that

the level is above the hot leg nozzles.

When the pump in the loop with the hot leg connection is operating, the d/p would be greater than the transmitter span, and the transmitter output would be delected from the remote digital.display. An invalid status

statement would be indicated.

1 Reactor Vessel - Full Range. The transmitter span covers the total height oE.the reactor vessel. With pumps shut down, the transmitter output is an indication of the collapsed water level, that is, as if the steam bubbles had been separated from the water volume. · The actual water level is slightly higher than the indicated water level since there will be some quantity of steam bubbles in the water volume .. Therefore, the RVLIS provides a conservative indication of the level effective for adequate

core cooling.

When reactor coolant pumps are operating, the d/p·would be greater than the transmitter span, and the transmitter output would be deleted from the digital display panel .

1-33

1 Reactor Vessel - Dynamic Head. The transmitter span covers the entire range of interest, from all pumps operating with a water-solid system to a completely empty reactor vessel and, therefore, covers the measurement spans of the other two instruments. Any reduction in d/p compared to the nonnal operating condition is an indication of voids in the vessel. The reactor.coolant pumps will circulate the water and steam as an essentially homogeneous mixture, so there would be no distinct water level in the vessel. When pumps a~e not _operating, the transmitter output is an additi~nal indication of the level in the vessel, supplemencing the indications from the other instruments.

The output of each transmitter is compensated for the density difference between the fluid in the reactor vessel and the fluid in the reference leg at the initial ambient temperature. The compensation is bas~d on a wide range hot leg temperature measurement or a wide range system pressure measurement, whichever. results in the highest value of water density and, therefore, the lowest value of indicated level. Compensation based on temperature is applied when the system is subcooled, and compensation based on pressure (saturated conditions) is applied if superheat exists at the hot leg temperature measurement point.

The output of each transmitter is also compensated for the density difference

between the fluid in the reference leg during an accident with elevated temperature in the containment and the fluid in the reference leg at the initial ambient temperature. The compensation is based on temperature measurements on the veritical sections of the reference leg.

The corrected transmitter outputs are shown on a digital display installed on the control board, one statement for each measurement in each train. A three-pen recorder is also provided on the control board to record the level or relative d/p and to display trends in the measurements. The display would also indicate which reactor coolant pumps are operating, and which level measurements are invalid due to pump operation.

During normal plant heatup or hot standby operation with all reactor coolant

[ ]a~

pumps operating, the dyna:n1c head d/p display would indicate percent on

1-34

•

•

WESTINGHOUSE PROPRIETARY CLASS 2

the display, an indication that the system is water-solid. If less than all pumps are operating, the display would indicate a lower d/p (detennined during the plant_ startup test program) that would also be an indication of a water-solid system. With pumps operating, the full range and upper range displays would indicate offscale.

If all pumps are shut down, at any temperature, the full range and upper range

[ ]a,c

displays would indicate percent, an indication that the· vessel full, The [ ]

a,c dynamic head d/p display would indicate about percent of the span of the display, which would be the value (detennined during the test program) corresponding to a full vessel with pumps shut down,

In the event of a LOCA where coolant pressure has decreased·to a predetennined setpoint~ existing emergency procedures would require shutdown of all reactor

coolant pumps. In these cases, a level will eventually be established in the reactor vessel and indicated on all of the displays. the plant operator would monitor the displays and the recorder to detennine the trend in fluid mass or level in the-vessel, and confinn that the ECCS is adequately compensating for the accident conditions to prevent ICC.

Future procedures may require operation of one or more pumps for recovery from certain types of accidents. When pumps are operating while.-voids are developing in the system, the pumps will circulate the water and steam as an

essentially homogeneous mixture. In these cases, there will be no discernible level in the reactor vessel. A decrease in the measured d/p

compared to the nonnal -~perating value will be an indication of voids in the syste~, and a continuously decreasing d/p will indicate tha~ the void content is increasing, that mass is being lost from the system. An increasing d/p will 'fndicat~ that the mass content is increasing, that the ECCS is effectively restoring the system mass content.

1-35

•

•

1-27 SEMISCALE TESTS

In order to demonstrate the performance of the Westinghouse RVLIS in providing an indication of the level in the vessel during transient conditions, the hydraulic components of the RV.LIS were installed at the Semiscale Test Facility in Idaho. The objective of the demonstration was to show that RVLIS measurements compare favorably with the Semiscale measurements during the tests.

The Semiscale Test Facility is a model of a 4-loop pressurized water reactor coolant system with elevation dimensions essentially equal to the dimensions of a full-size PWR. The reactor vessel contains an electrically heated assembly consisting of 25 rods with a heated length of 12 feet to represent the reactor core. Two reactor coolant loops are provided, each having a pump .and a steam generator with a full height tube bundle. One loop models the loop containing the pipe break, which can be located at any point in the loop. The other loop models the three intact loops. A blowdown tank collects and cools the fluid discharged from the pipe break during the simulated accident. Over 300 pressure, temperature, flow, level~ and fluid density instruments are installed in the reactor vessel and loops to record the fluid conditions throughout a test run.

Semiscale does not behave exactly the same· as a PWR under accident co~ditions due primarily to scaling and modeling difficulties. The comparison of the RVLIS indication with the Semiscale measurements is generally independent of the scaling differences, hnwever, and therefore provides a verification of the RVLIS effectiveness.

The RVLIS measurements obtained during each test run were compared with data obtained from existing instrumentation installed on the Semiscale reactor vessel. The Semiscale facility is instrumented for differential pressure measurements over eleven vertical spans on the reactor vessel to determine the collapsed liquid level within each span. The collapsed level within these

1-36

intermediate spans was compared to the RVLIS indication of the collapsed level in the vessel to verify that the RVLIS provides a good indication of the collapsed level. Additionally, gamma densitometers are installed at 12 eleva- · tions on the reactor vessel and thermocouples are installed on the heater rods. Data from these instruments were used to determine the two-phase mixture level in the vessel to verify that RVLIS provides a conservative underprediction of·the two-phase level in the vessel.

Other Semiscale facility measurements {flow, pressure, and temperature) provide supplemental information for interpretation of the test fluid conditions · and the level measurement. Tests included in the Semiscale test program during which the RVLIS measurements were obtained are listed in the following table. Except as noted, the non-UH! RVLIS configuration was used.

1 Miscellaneous steady state and transient tests to calibrate test facility heat losses

1 A cold leg break with a break area 2 1/2 percent of the cold leg flow area

1 5 percent cold leg break configuration

• 5 percent cold leg break with upp~r head injection-UHi RVLIS configuration

• 5 percent cold leg break with modified upper internal configuration to more accurately model a Westinghouse PWR

1 Two natural circulation test with a reduced Semiscale system

1 Natural circulation with a small leak and no ECCS

• 100 percent communicative cold leg break

1-37

The reactor coolant pumps were tripped early in the transient in these tests, so there was no data .available for evaluation of the RVLIS dynamic head indication. Also, water level stabilized at the elevation of the break on the cold leg, as expected, so ~here was no data available for evaluation of the upper range indication relative to the reactor vessel head vent procedure. Sufficient data were available for comparison of the full range RVLIS indication with the Semiscale measurements.

A comparison of the RVLIS indication and the two-phase mixture l~vel as determined from the gamma densitometer indications is shown in Figure 1-16. This comparison illustrates that the RVLIS.trends with the two-phase mixture level and consistently predicts a level below the two-phase level in the vessel.

The results of these tests confirm that the RVLIS provides a good indication of the collapsed level in the vessel and provides a conservative indication of the ve~sel mixture level necessary for adequate core cooling. The adeq~acy of RVLIS for measuring the level in the vessel was verified for a variety of . fluid conditions for the UHi and non-UHi RVLIS configurations. The RVLIS will

. provide an acceptable measurement of the vessel during small break transients, natural circulation conditions, and during the refilling portion of a large break transient.

1-38

• 1-28 RVLIS ANALYSIS

' In order to evaluate the effectiveness of the RVLIS in providing a measurement of the level~in the vessel·and in detecting the approach to inadequate core cooling (ICC), the response of the RVLIS under a variety of transient fluid conditions was determined. The RVLIS response was determined from the total vessel differential pressure calculated in the WFLASH and NOTRUMP codes for a number of small break transients. The total vessel differential pressure is the difference between the pressure at the top of the upper head and the pressure at the bottom of the lower plenum. The differential pressure was converted to a RVLIS reading using the saturation density at the fluid temperature in the upper plenum which is a good approximation of the conversion performed in the RVLIS electronics.

The total differential pressure corresponds to the_RVLIS full range indication - used when the reactor coolant pumps (RCPs) are not running - and the dynamic head indication - used when the RCPs are running - for non-UHi plants.

Under transient conditions, the RVLIS indications are used, along with other instrumentation in the emergency response guidelines to monitor the existence of or the appr~ach to inadequate core cooling.

Inadequate core cooling is defined as a high temperature condition in the core such that operator action is required to cool the core before sufficient damage occurs. In order to achieve ICC conditions, operator error or multiple failures in.the safeguards equipment must occur. The most obvious faflure that would lead to ICC for a small break LOCA, although highly unrealistic, is the loss of all high pressure safety injection.

The RVLIS full range scale is calibrated from zero percent, indicating that the vessel is empty, to 100 percent, indicating t~at the vessel is full of water~ The full range indication represents the equivalent collapsed liquid level in the vessel which is a conservative indication of the approach to

1-39

•

ICC. The RVLIS indication, along with the core exit thermocouplest alerts the operator that a condition of ICC is being approached. When the RCPs are operating, the full range meter will, generally, be pegged at full scale.

The dynamic head scale ranges from zero percent, indicating an empty vessel, to 100 percent, indicating a full vessel, with all of the reactor coolant pumps operating. The dynamic head is composed of the static head due to the presence of water in the vessel and to the flow pressure drop. The dynamic · head decreases approximately linearly as the void fraction in th_e vessel increases and is used as a symptom of degraded core cooling. The specific use of the RVLIS are discussed in the Emergency Response Guidelines for Inadequate Core Cooling.

The RVLIS upper range is not used during transient conditions.or for an indication of th~ approach to inadequate core cooling~ The upper range will be used for head venting operations.

During the early portion of a loss of coolant accident transient, the RVLIS full range will not provide an accurate indication of the level in the vessel due to rapid pressure fluctuations and flow coastdown and oscillations. The period of inaccurate indication is brief, however, and the RVLIS will provide an accurate indication before ICC conditions would exist. The time when the

. . RVLIS will provide an effective level indication as a function of the break size is illustrated in Figure 1-17. The shaded portion represents the time period when the RVLIS indication is in error by more than l foot (2.5 percent). -·As a basis for comparison the times when ICC conditions would exist for a one inch and four inch diameter break are denoted. This figure clearly illustrates that the RVLIS full range indication will be useful for detecting the approach to ICC.

For large breaks, the RVLIS will not provide a useful indication during the blowdown portion of the transient. The RVLIS will provide an indication of the level in the vessel during the reflooding portion of the large loss of coolant accident transient.

1-40

•

1-29 TRANSIENTS INVESTIGATED

A large number of ·transients, encompassing a variety of fluid and transient conditions, have been analyzed in order to determine the response of the RVLIS. These studies have verified that, under most conditions, the RVLIS proviijes a good indication .of the level in the vessel and can be used effectively in monitoring the approach to inadequate core cooling. The times when RVLIS does not provide an accurate indication of the level in the vessel are brief and when used along with other indications, as directed i~ the procedures, do not lead to an erroneous indication of the approach to inadequate core cooling. The situations where the RVLIS may be inaccurate are discussed in Section 1-33.

The transients which are presented here are summarized in Table 1-1. These

cases do not encompass all conditions for which the RVLIS would b~ used, but they are illustrative of the RVLIS performance under transient conditions. The transients presented here are for different plant types, but the RVLIS performance is generally independent of the number of loops, core power, etc. The RVLIS indication trends will be the same for all plant types.

1-~l

1-30 CASE A. 3 LOOP PLANT 3 INCH COLD LEG BREAK

The initiating event for this transient is a three ~nch break in the CQld leg. Consistent with the FSAR assumptions, the reactor coolant pumps are tripped early in the transient when the reactor trips and minimum safeguards are available.

After the.break opens, the system depressurizes rapidly to the steam generator secondary safety valve setpoint. The system pressure hangs up ~t the secondary setpoint until the loop seal unplugs at approximately 550 seconds, allowing steam to flow out the break and depressurization continues. The core uncovers while the loop seal is draining, then recovers when the loop seal

unplugs.

The core then begins to uncover again as more mass is being lost through the break than is being replaced by safety injection. The core begins to recover at about· 1500 seconds when the accumulators begin to inject •

.• This transient does not represent a condition that would lead to ICC but it does represent a break size in the range that would be most probable if a small break did occur. The response of the RVLIS for typical conditions for which it would be used can be investigated with this transient.

After the reactor coolant pumps trip, the RVLIS reading drops rapidly to the . full range scale.{see Fig~re 1-18). The RVLIS indication falls until the

pressure drop due to flow becomes insignificant compared to the static head of the fluid in the vessel; The first dip in the RVLIS reading is due to the behavior of the upper head.

When the upper head start~ to drain it behaves like~ pressurizer. The pressure in the upper head remains high until the mixture·-level drops to below the top of the guide tube where steam is allowed to flow from the upper head to the upper plenum. When this occurs the upper head pressure decreases -

1-42

• thereby increasing the vessel d/p - and the RVLIS reading again approaches its . expected value. This phenomenon is more prevalent for large-break sizes and the effect will be of brief duration for breaks in this range. Furthermore. the ICC guidelines require verification of the RVLIS reading through the use of the core exit thermocouples. During this phenomenon, the core exit thermocouples would read saturation temperature. Therefore, this early phenomenon in the upper head will not cause a false indication of ICC.

When the vessel begins to drain during the loop seal uncovery, the RVLIS reading trends in the same direction as the vessel level. The RVLIS reading remains below the vessel mixture level and is therefore a conservative indication of the level required to maintain adequate core cooling.

When the vessel mixture level increases after the loop seal unplugs, the RVLIS reading follows it. Then, RVLIS readings continue to follow the vessel mixture level throughout the transient while underpredicting the actual two-phase level. The wider difference between the RVLIS level and the two-phase level later in the transient is due to the system being at a lower pressure which allow~ more bubbles to exist in the mixture.

1-4 3

• 1-31 CASE. B. 3 LOOP PLANT PUMPS RUNNING

A two inch cold leg break with no safety injection availabl~ was analyzed with the reactor coolant pumps operating for a three loop plant. A two inch break was chosen for this study because it would be representative of a potential ICC condition if a total loss of high head safety injection occurred. The transient was analyzed from steady state condition~ through to complete voiding in the vessel~

Following the break· initiation, the pressure falls to approximately the secondary safety valve setpoint and hangs up at this value since the break is not capable of removing all the decay heat. Voiding occurs first in the core and upper plenum regions and then progresses smoothly to the remainder of the system. The operation of the RCPs tends to keep the system fairly well mixed. throughout the transient. Figure 1-19 shows a comparison of the RVLIS indication and the vessel mass inventory. This comparison verifies that the RVLIS trends well with the inventory when the RCPs are running.

A plot of the RVLiS dynamic head indication versus vessel void fraction is shown in Figure 1-20. This plot demonstrates that the RVLIS provides a good indication of the void.fraction in the vessel. The RVLIS dynamic head indication is a measurement of the total differential pressure across the reactor vessel. When the RCPs are running, the total vessel differential pressure is composed of the static head due to the presence of fluid in the vessel and the dynamic head due to flow induced frictional pressure drop. Both components of the RVLIS indication decrease approximately linearly with increasing vessel void fraction. Since there is a well behaved relationship between the RVLIS indication and the vessel void fraction, it is possible to define a RVLIS indication which corresponds to a void fraction of 50 percent that can be used as the kickout to the ICC procedure.

The RVLIS dynamic head indication corresponding to an average RCS void fraction of [ J8h~s been chosen as the symptom of degraded core cooling

1-44

•

•

WESTINGHOUSE PROPRIETARY CLASS 2

for the core cooling critical safety function. The operator is directed to exit the procedure in effect and to initiate the Response to Degraded Core Cooling Function Restoration Guideline. An average RCS void fraction of

[ Ja,c

greater than ~hsures that if all RCPs are subsequently stopped that the core will remain covered following phase separation in the vessel. It represents considerable margin to an ICC condition and allows for operator action time to prevent an approach to an ICC condition.

For the three loop plant, the RVLIS dynamic head indication which corresponds to a void fraction of [ rts approximately [ . . ref the steady state reading as indicated in Figure 1-20. Also marked on this figure are the

[ . ]\coid fraction and associated RVLIS indication. The[

Ja,c void fraction is a more representative low vessel inventory condition

that would result in an approach to ICC should the. RCPs be tripped. In other words, the vessel mixture level would fall to the midplane of the core if the RCPs were tripped at this void fraction. A level at the midplane of the core is included in the basis for the ICC kickout with no RCPs running. This illustrates the conservatism in the ICC kickout with the RCPs running and the significant margin to an actual ICC condition.

The RVLIS dynamic head injection which corresponds to an a¥erage void fraction [ Ja,c

of will vary for different plant types. The trend of the RVLIS indication with changing void fraction will be the same for all plant types. If less than all of the reactor coolant pumps are operating, the flow pressure drop will be less at a given void fraction. Consequently,_ the dynamic head indication will be less at all values of void fraction and the kickout to the degraded core cooling procedure will be a lower value for. the situation where all the pumps are operating.

· l-45

!

• 1-32 ONE INCH COLD LEG BREAK

This transient was analyzed with the NOTRUMP computer cod~ as part of an inadequate core cooling study. This case was a one inch cold leg break with the reactor coolant pumps tripped and no safety injection available. The water in the vessel drains down to the hot leg elevation early in the transient and then remains at this 1eve1 while the upper port ions of the RCS drain. Late in the transient, after th~ RCS has drained, the level in the vessel falls below the hot legs and, eventually the core uncovers (see figure 1-21).

The RVLIS full range reading is below the vessel mixture level throughout most of the transient and is therefore a conservative indication of the two-phase level required for adequate core cooling. The RVLIS reading follows the same trend as the vessel mixture level except for early in the transient when the mixture void fraction is fluctuating.

A comparison of the mass inventory in the core and upper plenum regions to the

•

RVLIS reading is shown in Figure 1-22. This comparison shows that the RVLIS

reading also corresponds very well with the relative vessel mass inventory. Figure 1-23 shows a comparison for the UHI and non-UH! RVLIS configurations. For the UH! RVLIS configuration, the pressure difference is measured from the hot leg to the lower plenum rather than the upper head.to lower plenum. This plot shows a very good comparison between the two systems, indicating that either will give a useful indication •

•

• 1-33 OBSERVATIONS OF THE RVLIS STUDIES

The RVLIS will provide useful information for breaks in the system ranging from small leaks to breaks in the limiting small-break range. For breaks in this range, the system conditions will change at a slow enough rate that the operator will be able to use the RVLIS information as a basis for some action.

For larger breaks, the response of the RVLIS will be more erratic, due to rapid pressure changes in the vessel, in the early portion of t~e blowdown. The RVLIS reading will be useful for monitoring accident recovery when other corroborative indications of ICC could also be observed.

Very few instances have been identified where the RVLIS may give an ambiguous indication. These include a break in the upper head, upper plenum injection, accumulator injection into a highly voided downcomer, periods of time when the upper head behaves like a pressurizer, and periods of void redistribution. The impact of flow reversal and core flow blockage on the RVLIS indication have also been addressed.

In order to assess the impact of a break in the upper head, a 2-3/4 11 break was investigated. This break·size corresponds to that expected in the event of a control rod ejection accident. This is the largest break size that is plausible in a non-UH! plant. A UHI line break in a UHI plant would result in

· a larger break, but since the RVLIS narrow range indication for UHI plants is measured from the hot leg to the bottom of the vessel, the RVLIS indication of vessel level is not significantly affected by the upper head conditions. This case represents the maximum impact on the RVLIS indication. As the break size decreases, the effect on the RVLIS indication diminishes.

Inunediately after the break occurs, subcooled liquid flows out the breaki this is followed by a brief period of two~phase break flow. During this early pe~iod, the flow to the upper head is sufficient to cause the RVLIS to read offscale high on the full range (there would still be an indication on the

1-~7

•

•

dynamic head scale after approximately·2 minutes). After 4 to 5 minutes, however, the upper head and upper plenum have drained sufficiently such that steam is flowing through the break, as well as from the upper plenum to the upper head. The system stabilizes in a quasi-steady state mode with the primary pressure slightly above the secondary pressure and the level in the vessel at the hot leg elevation. The RCS remains at these conditions until the upper portions of the RCS have drained. After approximately an hour, the vessel begins to drain.

During the vessel draining the RVLIS. trends with the two-phase mixture level. The RVLIS reads higher than it would if the break were located elsewhere in the RCS due to flow pressure drop through the guide tubes.

The RCS pressure remains near the secondary pressure throughout the transient since the secondary is required for decay heat removal. The pressure drop due to steam flow through the guide tubes at 1100 psi system pressure corresponds to an 11 percent error on the RVLIS indication •.

The RVLIS indication would still provide the operator with useful information concerning the trend in vessel level. The operator would still have sufficient information to diagnose the approach to ICC by using the RVLIS indication along with the core exit thermocouples.

The analysis and discussions presented here are applicable to all Westinghouse PWR plants, including those plants with upper plenum injection (UPI). The normal condition for continuous UPI occurs only with the operation of the low head safety injection pumps, which does not occur until a pressure of under 200 psi is _reached. The RVLIS may not accurately trend with vessel level during the initial start of UPI since, during this short period of time, the cold water being injected will mix with the steam in the upper plenum causing c6ndensatiort to accumulate. This condensation will form faster than the . sys_tem response. The system will equilibrate after a short period of time. Upon equilibrating, the system will continue to accurately trend with the reactor vessel level •

1-48

In the range of break sizes where RVLIS is most useful in detecting the approach to ICC, the system pressure will equilibrate at a level above the pressure where UPI will normally occur. It is important to note that the flow from the low head pumps is sufficient to recover the core and no operator action based·on the RVLIS indication will be necessary.

For the vast majority of small breaks, the condition of upper plenum injection does not cause a significant impact. For the remainder, the impact is very small and within tolerable limits.

When the downcomer is highly voided and the accumulators inject, the cold accumulator water condenses some of the steam in the downcomer which causes a local depressurization. The local depressurization will lower the pressure at the bottom of the vessel which will lower the d/p across the vessel, causing an apparent decrease in level indication. The lower pressure in· the downcomer also causes the mixture in the core to flow to the lower plenum, causing an actual decrease in level. The period of time when the RVLIS indication is lower than the actual collapsed liquid level will be brief.

An example of when this phenomenon may occur is when the reactor coolant pumps are running for· a long period of time in a small break transient. After the RCS loops have drained and the pumps are circulating mostly steam, the level in the downcomer will be depressed. A large volume of steam will be present in the downcomer, above the low mixture level, which allows a large amount of condensation to occur. For most small break transients, the reactor coolant pumps will be tripped early in the transient and the downcomer mixture level will remain high, even in cases where ICC occurs. When the downcomer level is high the effect of accumulator injection on the RVLIS indication will be.minor.

When the upper head begins to drain, the pressure in the upper head decreases at a slower rate than the pressure in the rest of the RCS. This is due to the upper head region behaving much like the pressurizer. The higher resistance across the upper support plate relative to the rest of the RCS prevents the

1-49

upper head from draining quickly. This situation only exists until the mixture level in the upper head falls below the top of the guide tubes. At this time, steam is allowed to flo~ from the upper plenum to the upper head and the pr~ssute ~quilibrates. While the upper head is behaving like a pressurizer, the vessel differential pressure is reduced and the RVLIS indicates a lower than actual collapsed liquid level.

Analyses have shown that the pressurizer effect has a small impact on the vessel d/p early in the transient and no impact on the results after the level drains below the top of the guide tubes. The pressurizer effect is believed to exist although the effect is somewhat exaggerated in the analysis, and it becomes more significant as break size increases. The interval of time when the upper head behaves like a pressurizer is brief and the RVLIS will resume trending with the vessel level after the top of the guide tubes uncover. The reduced RVLIS indication will not cause the operator to take any unnecessary action, even if a level below the top of the core is indicated, which is unlikely, since the core exit thermocouples are used as a corroborative indication of the approach to ICC.

During the time when the distribution of voids in the vessel is changing rapidly, there can be a large change in the two-phase mixture level with very little change in collapsed mixture level. The use of the RVLIS, in conjunction with the core exit thermocouples, is still valid for this situation, however. The only event that has been identified which could cause a large void redistribution is when the reactor coolant pumps are tripped when the vessel mixture is highly voided. After the pump performance has degraded enough that the flow pressure drop contribution to the vessel differential pressure is small, the change in RVLIS indication will be very small when the pumps are tripped. The approach to ICC would be indicated when the dynamic head indication corresponds to a [ rp~rcent void fraction. If the pumps were tripped at this time, the core would still be covered. The operator would know that the core may uncover if the pumps were tripped with a dynamic head indication lower than that value. Prior to pump trip, the core will remain

1-50

adequately cooled due to forced circulation of the mixture. When the pumps trip the two phase level may equilibrate ·at a level below the top o( the ~ore. The full range indication will provide an indication of core coolability at this time.

Reverse flows in the vessel will tend to decrease the d/p across the vessel which would cause the RVLIS to indicate a lower collapsed level than actually exists. The low indication would not cause the operator to take unnecessary actions, since the RVLIS would be used along with the core exit .thermocouples to indicate the approach to ICC. It is important to note that large reverse flows are not expected to occur for breaks smaller than 6 in. in diameter during the time that the core is uncovered. Large reverse flow rates may occur early in the blowdown transient for large diameter breaks, but, it is not necessary to use the RVLIS as a basis for operator action for breaks in this range.

Blockage in the core will tend to increase the frictional pressure drop and the total differential pressure across the vessel, resulting in a higher RVLIS indication. The increase in the RVLIS indication would be most significant under forced flow conditions when the reactor coolant pumps are operating.

In order for blockage to be present, the core would have to have been uncovered for a prolonged period of time. A low RVLIS indication along with a high core exit thermocouple indication would have occurred during this time, If the reactor coolant p~mps had been operating throughout the transient, there would have been sufficient cooling to prevent core damage and thus flow blockage. Therefore, for significant blockage to be present with pumps operating, the pumps would have been shut down initially and then restarted after an ICC condition had existed for a period of time. Based on the history of the transient, the operator would expect that the RVLIS. indication to assess the amount of damage to the core. Although the RVLIS would read high, it wou 1 d st il 1' fo 11 ow the trend in vesse 1 inventory and monitor the recovery from the accident.

1-51

•

•

Under natural circulation conditions, the impact of core blockage is not large. At a natural circulation flow of 4.5 percent, the RVLIS error due to flow would increase from 0.5 percent of the vessel height with no blockage to about 5 percent with 2/3 of the fuel assemblies completely blocked from top to bottom. Under an equilibrium boil-off condition, where flow supplied to the core equals the residual heat boil-off, the RVLIS error due to flow blockage is negligible. These sensitivities to flow blockage are illustrated on Figure 1-24. Therefore, even with a large amount of flow blockage, the resulting RVLIS error is minimal, and the RVLIS will trend with the vessel inventory and provide useful information for monitoring the recovery from ICC .

l -S2

1-34 CONCLUSIONS

The extensive testing and analytical programs concerning the RVLIS have verified its usefulness in providing an indication of the level or mass ·inventory in the vessel. The RVLIS, along with other available instrumentation, can be used to monitor the approach to inadequate core cooling and can be used to direct the operator to the appropriate procedure. When the reactor coolant pumps are not running, the RVLIS full range indication is used to measure the collapsed liquid level in the vessel. The collaJlSed liquid level is a conservative indication of the mixture level required for core cooling. When the reactor coolant pumps are running the RVLIS dynamic head indication is used to provide an indication of the mass inventory in the vessel.· The dynamic head indication will decrease approximately linearly with increasing void fraction for all pumps running combinations.

The situations where RVLIS does not provide an accurate indication of the vessel level or inventory are brief and will not cause an erroneous indication of inadequate core cooling.

1-53

•

1-35 REFERENCES

1. Westinghouse Evaluation of RVLIS Performance at the· Semi scale Test Facility," Westinghouse Electric Corporation, December 1981.

2. "Westinghouse Evaluation of RVLIS Performance at the Semiscale Test Facility for Test Test S-UT-8," Westinghouse Electric Corporation, January 1982.

3. "Westinghouse Evaluation of RVLIS Performance at the Semiscale. Test Facility for Test S-IB-1," We~tinghouse Electric Corporation, May 1982.

4. Thompson, C. M., et al, "Inadequate Core Cooling Studies of Sceriarios with Feedwater Available, Using the NOTRUMP Computer Code,: WCAP-9753 (Proprietary) ·and WCAP-9754 (Non-Proprietary), July 1980.

5. Mark, R. H., et al., "Inadequate Core Cooling Studies of Scenarios with Fedwater Available for UHi Plants, Using the NOTRUMP Computer Code," WCAP-9762 (Proprietary) and WCAP-9763 (Non-Proprietary), June 1980.

6. "Report on Small Break Accidents for Westinghouse Nuclear Steam Supply System," WCAP-9600 (Proprietary) and WCAP-9601 men-Proprietary), June 1979.

7. Esposito, v~ J., Kesavan, K., and Maul, B. A., "WFLASH - A FORTRAN-IV Computer Program for Simulation of Transients in a Multi-Loop PWR," WCAP-8200, Revision 2 (Proprietary) and WCAP-8261, Revision 1 (Non-Proprietary), July 1974.

8. Skwarek, R., Johnson, W., and Meyer, P., "Westinghouse Emergency Core Cooling System Small Break October 1975 Model," WCAP-8970 (Proprietary) and WCAP-8971 (Non-Proprietary), April 1977 •

1-54

•

•

9. "Transmittal of Volume III for the High-Pressure Version of Emergency Response Guidelines," OG-83, January 1983.

10. "Transmittal of Additional Material for the Low-Pressure Version of Emergency Response Guideline," OG-84, January 1983 •

1-55

•

TABLE 1-1

TRANSIENTS INVESTIGATED

Case Description

A 3-loop 2775 MWt plant - 3-inch cold leg break - reactor coolant pumps trip at reactor trip, minimum pumped safety injection available. WFLASH analysis.

B 3-loop 2775 MWt plant - 2-inch cold leg break - reactor coolant pumps operating throughout the transient, no safety injection available. WFLASH analysis.

4-loop 3441 MWt plant - 1-inch cold leg break - no safety injection available. NOTRUMP analysis •

1-56

150

100

50

z 0

_J w :> w _J

0 -50 ::J

I c·. L'1

_J .......

-100

-150

-200

• UESTINGllOUS[ NARROW RANGF RrAnrnr. (WVFSI V)

W lTH SEMI SCALE DENSITOMETER SHOTS (RV)

.----11-..----.-----r----1----r----·r----.-:--· -·- -

- FALLING FROTll LEVEL

- . ----- -----· - RI s ING morn LEVEL

--------- -----···· -

-----·- ------ ----- - --------1------·-----I

Clll~I

J 0 100 200 300 400 500 600 700 800

I Im. ('.:il:.LUNIJ'.:i)

111;1m[ l-lfi Comparison of RVLIS narrow ranqe with two-phase

mixture level determined from densitometer indic.cllinnc:-,

fm· I pr, f <:; -llT -H.

•

_. I

U1 co

--- ~ .

.,

3

2

AK S ll£ ANO BLWOCllN SENSITIVITY TO BR£

REGION OF EFFECTIVE

LEVEL INO I CA T ION

I FOOTI ILEVEL ERROR S

:-¢-'\

~ rcc • 1200°F

f<_:..0~_,-L6~6 ~~8;_ -.--,~ o.-~11 ?21 o. 2 ,, 0 .. 2 2

IHNlllfS llOllRS

r 1r;11111 l - I 7

•

3

I' Ln l.O

FI GllHE 1- IB Cilsr. A 3-Loop Plan I, J-lnch Cold Leg Break, Pump Trip, RVUS R1!i1di11!1 anrl Vessel Mix111rr. Le_vel

• a,b,c

I O"I Cl

• RVLIS DYNAMIC HEAD INDICATION

TOTAL VESSEL MASS

FIGURE 1-19

•• :a,b,c

I O'l

• •

FIGllHE 1-20

• a,b,c

_, I en N

•

F I !~I Jiff 1-21

• • ,a,b,c

1-lnch Cold Leg Break. ICC Case, RVLIS Readinq anrl llJlixturP. Level

_.. I

C1' w

•

)

• a,b,c

FI GIJRE I - 22 1-lnch Cold Le~ Break, ICC Case, Mixture Level, RVLIS Reading and Measured Inventory

• • a,b,c

rtGllHE 1-23 Case D 1-lnch Cold Leg Break, ICC Case, RVLIS Reading ami Mixcure Level

•

~ ( )

I 11

t I

I ::!: _. 111 4 I . ) (\.. °' <.Tl i1 en

n· ''-. l )

( I .

Cl . . -.. -Iii

111

I

"

20

15

lllFFEnEM rlAI. l'HFSSllBI: Ml: A~·~IJUl-"MI u I SEN~)' rrv1·1 ·,· ru 1-1 uw u1 oc1<Ahl"

8

. - - -· . - ··- . - -- . -- -·· .. -- --- - --· - -- -- L

'l.!-i~: Ml\ lllH /\I 1. IHl"lll A 11ur1 FI OW '

10 -----·-. ---- ----- - ··------ -···---··

0

. " 111 L! ( l

1:111~1

l\Ull.UFr rt ow

II I ·It I hll I (I

I I I w /\I < I /\ I \ I ( I ( I· I I I •.

r 1r.1mr 1-?11

I I

Hll

•

-.. !--.. ( )

•. _.I 11

( )

I

IJ I

- l r.; I I I ol ll

(}: ( )

11 · 11· 111

Ill

..---------------..,.--------------------------------- -------

•

2.0 RVLIS MICROPROCESSOR SYSTEM PROCEDURES AND GUIDELINES

2.1 PURPOSE

The objectives of these guidelines and instructions are to identify the requirements for the use and interpretation of the Reactor Vessel Level

Instrumentation System (RVLIS) which may be used by the utility to develop their training program, preparation of their detailed procedures, and their periodic test schedul~.

2.2 DESCRIPTION

General: The microprocessor equipment has a local control panel and a remote monitoring unit for each RVLIS train. The local control panel has a "central processing unit" to monitor various analog and digital inputs and to perform the necessary calculations for reactor vessel level. The local control panel

is equipped to select specific functions for specific hardware to enter the appr.opriate calibration data. The non~volatile memory stores the calibration data. The non-volatile memory is protected from inadvertent alternation by a keyswitch on the front of the local control panel. In the event of a loss of power, the contents of this memory is valid for a minimum of six months.

Any sensor input can be disabled by the operator under the control of a keyswitch on the front panel of the local control panel. A substitute value can be entered when a sensor is disabled. Substitute values should be updated as plant conditions change; otherwise, incorrect levels will be calculated. If the reactor coolant hot leg temperature or the reactor coolant wide range pressure signal is disabled, the auctioneer circuit disregards that input. If the two inputs Th, Pwr are disabled, a manually entered replacement temperat~re shall be used for the auctioneered circuit and the pressure function disregarded.

The local control panel and the remote monitoring unit each contains a red alarm, yellow caution and a green normal status lights. The percentage level

- setpoint for the Alarm and Caution status lights are set beyond the instrument

2-1

span so that the alanns will not operate. This is based on that the. RVLIS System is not a stand-alone system for detennining "Inadequate Core Cooling" conditions and therefore, RVLIS level alanns/cautions should not be used as stand-alone alanns/cautions.

The.caution status light (local and remote) is, however, used to detect

equipment failures, specifically:

t ·Hydraulic isolators

t Sensors·

t Software error (Detect PROM/RAM Check)

The Caution light is driven by a relay which in addition to the above equipment failure events the relay is also actuated by failure of the "Deadman

Cf rcui t 11 and "Loss of Power".

The operator can select a "Summary", "TREND", or "Sensor Status" display at the remote monitor unit. The Summary display pro vi des level readings information; TREND display provides level readings for the last 20 minute period and Sensor Status Display lists the sensors that have been disabled or

exceeded their.limit values. The Summary display should be the page nonnally selected by the operator for normal plant conditions or accident conditions. The trending display can be periodically selected only to ensure its operability or to obtain trending information during accident conditions.

SUMMARY DISPLAY

The summary page displays the level readings for upper Range (top of the vessel to the Hot Leg); full range (top of the vessel to the bottom of the vessel - without pumps); and Dynamic Head (top of the vessel to the bottom of the vessel - with pumps). The format for the surrmary page is shown below.

2-2

•

REACTOR VESSEL LEVEL SUMMARY

Upper Range

Full Range

Dynam:f c Head

Pumps Running: 1, 2, 3, and 4

*Isolator Alanns:

No. See Sensor Status

Actual

< 60 percent

>120 percent

107 percent

Nonnal

105 percent

120 percent

107 percent

Status

Invalid

Offsca

The percentage level readings can be set anywhere between -99 and +999. The

limit values selected for the level readings are as follows:

Upper Range

Ful 1 Range

Dynamic Head

Low

60 percent

0 percent

O percent

High

120 percent

120 percent

120 percent

The status flags"<",">", and "OFFSCA" are derived from the d/p cell output

signal. The limit values for the d/p cells are set for the following:

"<" (Low) = 2 ma

">" (High) = 24 ma

11 0FFSCA". flag is displ,ayed whenever the high or low d/p cell setpoin·t is

reached.

The "INVALID" flag is displayed only for the upper range level reading when

the RCP that is connected to the instrumented loop is running.

The 7th and 8th line of the screen is not displayed until the hydraulic

[ Ja,c

isolator d/p switch setpoints . are exceeded and when the limit

2-3

• values of the sensors are exceeded. The sensor values are valid for the ranges noted below:

1 Imp~lse line RTD's: 50 to 420°F

1 Wide range pressure: 0 - 3000 psig

The below display shows the expected normal level readings for various plant con·dftions. These readings are typical and plant specific readings must be used by the uti 1 i ty.

Plant Conditions Upper Range ! Full Range Dynamic Head

I I

l. Heat-Up

- No Pumps a,c i a:c a,c - - - -

- One Pump - Two Pumps "

I

I i

- Three Pumps I

- Four Pumps

2. T avg No-Load

3. Full Power - - L. -

*If one of the pumps running is in one instrumented loop, the reading is

[ J a,c

approximately percent. If the instrumented loop pump is not running, the

[ Ja,c

upper range will read approximately percent.

Response During Slowdown Phase: During the blowdown phase of LOCA, RVLIS indication will not provide an accurate indication of water level due to high flows through the reactor core. The duration of the blo\r1down phase is short and RVLIS would provide an accurate indication of level thereafter. For the

2-4

• smallest breaks~ the longer time for the flow through the core to decrease results from the reactor coolant pumps continue to operate until the pump trip conditions are reached. Before pumps are tripped, the dynamic head RVLIS would provide an indication o.f fluid mass. Within two minutes (for flow coastdown) after the pumps are tripped, the full .range reading would provide an accurate indication of level.

Based on 1 arge break test results at the Semi seal e Test Faci 1 ity, RVLIS performance was not erratic even during the rapid depressurization because of the long capillary lines appear to dampen the rapid transients. Within about

[ la,c

1 RVLIS was tracking water level during the core recovery phase.

Use of Level Readings: The Full range instrument top of vessel to bottom and the vessel without pumps is used used in the Emergency Response Guidelines as one of the kickout points for the Inadequate Core Cooling condition. Although RVLIS is used as a kickout point for ICC conditions, the operator should monitor the full and dynamic head readings for rapid o-r significant changes. Although there are no main control board RVLIS alarms to cause the operator to monitor the readings, other parameters/signals such as high head safety injection, containment pressure, containment sump level, Tsat meter, and core exit T/C should require the operator to monitor the level readings although an ICC kickout point may have not been reached. In addition the Emergency

Response Guideline for ICC uses status trees that uses RVLIS to determine the next action to be taken by the operator.

The RVLIS System includes a three-pen recorder connected to one of the trains for long tenn monitoring of the level readings.

2.3 RVLIS STARTUP CALIBRATION

Following completion of the RVLIS system (vacuum filled, scaled, and

calibrated) and du-ring subsequent plant heat-up, it is necessary to verify the density compensation function and the various level readings. Specifically the objectives and procedure for the RVLIS startup calibration are noted as follows:

2-5

•

•

•

2.3.1 OBJECTIVES

Note: Value of level readings are for illustration purposes only, plant specific values must be obta1ned and used.

(a) Verify/correct wide range compensation function so output reads 100

percent with all pumps on, from cold to hot standby.·

(b) Obtain wide range indications with 0, 1, 2, 3 pumps operating, in active and idle RVLIS loops, for later use in emergency procedures. During initial pump startup, consider obtaining some pump combination data at hot

standby to reduce uncertainties on measurements.

(c) Note full range and .upper range indications as pumps are first started.

(d) Confirm upper ~~nge indicates [ J~~rcent with pumps off and a low end

reading of[ ]percent with pumps off.

(e) Check hydraulic isolator displacements before pressurization, before and after pumps started and after system reaches 2250 psia. Confinn that displacements are consistent with theory. Record displacements (on data sheet), also note temperature in area where hydraulic isolators are located. Periodically check displacements during power operation.

(f) Check RTDs for proper outputs, at cold, hot and partway through heatup.

\'

2.3.2 PROCEDURE

(a) Prior to heatup, set up a datalogger (optional) to obtain the below items on both trains, to obtain data at least every 50°F throughout heatup, or

every hour, whichever is most convenient.

wide range dp output (filtered)

Indication Output to remote display

2-6

•

•

Thot wide range input to RVLIS

PRCS input to RVLIS on both trains.

(b) Prior to pump startup, obtain r.eadings:

all dp outputs

all indication outputs to remote display

Ref. leg RTD temperatures

Hydraulic isolator displacements, room temp.

(c) Initiate pump startups and obtain data after each pump startup.

Pump sequence recommended: RVLIS loop, Non-RVLIS loop, Non-RVLIS loop, RVLIS loop

Data: All dp outputs

All Level Indication Readings

T HWR PRCS

(d) After all pumps are operating, note that dynamic head percent readout does not fluctuate more than 1 percent peak to peak for each update.

Obtain hydraulic isolator displacement readings, room temp.

Initiate automatic data logger, continue until heatup is complete .

2-7

J

Do not attempt to_ correct Dynamic Head output if not 100 percent unless indication is off scale, >120 percent_

(e) At~ 300 - 400°F, obtain reference Jeg indi.cations.

(f) At end of heatup : 557°F, obtain following data.

Datalogg~d values

Ref. Leg RTDs

Hydraulic Isolator displacements, room temp.

(g) If pennitted, trip off one or more pumps in order used in step 2.3.2.(c),

to confinn dynamic head range values with less than all pumps on. These

values may exceed cold values by 1-2 percent •

. (h) As power is increased, dynamic head indication will increase. Record a

set of data at full power, for comparison with zero power.

(i) Over long tenn, check h}'draulic isolator displacements and room temperature. Watch for trends in changes which would indicate leakage -

from one line as room temperature change.

Note Dynamic Head output, THWR' Power Level periodically.

NOTE: Af':er heatup, compare data with generic dynamic head dp curve, adjust

curve or output gain to obtain 100 percent at zero power.

2.3.3 TYPICAL READINGS

The following outputs shown are typical readings and plant specific values

should be used for your plant.

2-R

• EXPECTED DYNAMIC HEAD OUTPUTS

Pumps on RVLIS A RVLIS B 0 0 - - a,c - a,c

RYLIS 'A 1

Another pump 2 Another pump 3

RVLIS B 4 (Full power) 4 -

EXPECTED UPPER RANGE OUTPUTS

Pumps On RVLIS A RYLIS B - a,c - a,c

0 0 RVLIS A 1

2

3

RVLIS B 4 - -

2-9

The Hydraulic Isolator estimated displacement readings are typical values and that plant specific readings should be used for your plant.

Isolator Pumps Off Pumps off Pumps On Pumps On (Connection) O psi 400 psi 400 psi 2235 psic

Top ·O [ r [ r [ r Hot Leg 0 Bottom 0

Above displacements in cubic inches, based on assumption that hydraulic . .

isolators, dp cells and capillary connecting remains at a constant temperature, which is the same as when the system was filled. Actually, temperature variations can displace isolator noticeably. A~ 20°F at isolator

[ Ja,c (largest volume) would move isolator cu. in. and vice versa.

2.4 NORMAL PLANT OPERATION

With the plant at power, the estimated level readings should be as noted below; however plant specific values obtained in Section 2.3 above should be used.

Dynamic Head

Full Range

Upper Range

t J~'~rcent (dynamic head reading will increase f.rom

J a,c [ Ja,c . percent to approximately percent with all pumps running, as reactor power is increased from zero to 100 percent).

120 percent

<64 percent

Any reduction in the dynamic head expected readings (with all pumps running) can only be caused by the presence of voids in the circulating water. Voids

2-10

• will not exist without reduced pressure which could trip the reactor, so all accident conditions will proceed from a cond~tion of zero power (100 percent reading on the dynamic head). Check that the pressure has decreased or that subcooling meter confinns saturation conditions exist; then readings below 100 percent are an indication of voids in the coolant.

If the actual readings differ from the expected readings by two percent for a

single train, refer to Troubleshooting (Paragraph 2.9).

If the indication for both trains differs from the expected readings, refer to the emergency operating instructions contained in Emergency Response

Guidelines for immediate and subsequent action.

2. 5 REFUELING

After depressurization and prior to lifting the reactor vessel head, perfonn

the following steps to prepare the RVLIS refueling disconnect tube/fittings

for removal:

2-, ,

a •. c

2.6 PERIODIC TESTING

A. Plant at Power

Perfonn monthly calibration checks (for monitoring systems, this also is referred to as channel checks) which can be made by comparing the appropriate level readin~s from trains A and B. If the two indicated

. level readings differ byl ]pecrcent~ recalibrate the equipment per the instructions of Westinghouse Manual 9002-VLM-001.

B. Refueling Outages

1. With RVLIS isolated from the reactor coolant system, open sensor vents and check the position of the sensor bellows with a ruler. Capillary fill volume is verified if sensor bellows position is within_: 1/16 inch compared to the initial.data for the system.

2. Record the appropriate hydraulic isolator readings and compare

results with the.initial data taken for the system. Readings should be witnin _: 0.1 in3•

3. Recalibrate d/p transmitter to ±0.5 percent of the span by applying the appropriate d/p at the sensor vents using instructions of the Barton Instruction Manual (Model 752) and tHe instructions contained in the RVLIS System Manual. Confi nn that

2-12

a,c

the d/p transmitter output equals the elevation head between sensors to within + 2 inches. Calibration of the d/p transmitter can also be accomplished through the transmitter access assembly. Once the initial data f s taken, both from the sensor and from the d/p transmitter access assembly, subsequent ~alibration checks can be made from the ~ransmitt~r access assembly.

4. Calibrate the microprocessor unit in accordance with Section 4 of Westinghouse Manual 9002-VLM-001.

5. At the RVLIS cabinets, compare the reference leg RTD channel outputs with ambient temperature measurements. Check the RTD resistance and adjust the RTD channel outputs if the temperature differs by more then~ S°F. If RTD channel outputs cannot be adju_sted, check the RTD for opens or shorts and replace if

necessary.

2.7 PLANT STARTUP

Verify the operability of the RVLIS system during the startup and heatup of the plant following a refueling by tracking the displays of the two trains.

a,c · Readings should be within~[ ]percent of the expected values.

2.8 FAILURE EVENTS/SYMPTOMS

2.8.1 This section describes postulated failure events as to the expected RVLIS response. This 1nfonnat1on should be used by the utility. in developing their operating procedures and training program. In addition, this section discusses failure symptoms, possible cause, and probable action.

A. Connections to Primary System

1. Break or leak fn a single connecting line between reactor vessel and sensor:

2-13

•

All connections to the reacto~ coolant system are orificed so that a break is not classified as a LOCA, and the charging pumps can make up .the leakage. The increased charging flow would be one confinning indication of leakage.

Indications for the three standard system instrument ranges during (1) nonnal operation, (2) with a break in a single connecting line in the upper location, and (3) with a break-in a single connecting line in the lower location are presented in the following table:

INSTRUMENT UPPER RANGE , FULL RANGE DYNAMIC HEAD

Nonnal indication, pumps on Off scale Lo Off scale Hi 100 percent Nonnal indication, pumps off 100 percent 100 percent 33 percent

Upper connection location Vessel Top Vessel Top Vessel Top Indication with break Off scale Hi Offscale Hi Offscale Hi

Lower connection location Hot Leg Vessel Bottom Vessel Bottom Indication with break Off scale Lo Offscale Lo Offscale Lo

Except for a break in a hot leg connection with pumps on, at least one display reading would provide a clear indication of a· break in any connection. If the common vessel top or bottom connection failed, both trains of connected instruments would indicate the failure. Additional confinnation of a break would be provided by checking the volumetric displacements at the hydraulic isolator gauges in the contairunent penetration area.

If a leak developed in a connection, the pressure drop of the leakage flow would move the indicators in the same direction as a break. Since the instrument spans are relatively small, very little leakage flow would be required to produce an offscale i ndi ca ti on •

2-1'1

•

•

•

In most cases, vessel level indication$ would not be available when a connection breaks or leaks, in which case the core exit thennocouples would provide the necessary indication for an ICC

condition.

In the system provided for plants equipped with UHi, the upper connection for the lower range and dynamic head range instruments is on the hot leg. The indications with a break in a connection would be the same as for the standard system indications in the

table above.

2. Failure of sensor diaphragm.

A crack or pinhole leak in the sensor diaphragm could only be detected during a calibration check at cold shutdown, by exerting a force on the diaphragm through the vent, and· detecting motion of the diaphragm rather than no motion (solid water condition) •

A crack or pinhole leak would have no effect on the differential pressure measurement. Volume displacements due to a change in pressure or differential pressure would either leak through the diaphgram or displace the diaphragm, then leak through later.

In the event of a break in the downstream capillary tubing, leakage through a crack or pinhole leak would probably not keep

up with the capillary leak, and the diaphragm would displace until the check valve closed, preventing further leakage.

3. Sticking of diaphragm (caused by perhaps ·over-pressurization in

one direction).

The system has been designed so that, once the system has been filled with the ~roper amount of water, there would be no mechanf sm to overdf spl ace or overpressuri ze the diaphragm. The check valve will limit the displacement and prevent overpressurizing the diaphragm in one direction, and the

2-15

• diaphragm expansion volume is sufficient to account for fluid thennal expansion. The valve on the hydraulic isolator would limit the volume introduced from the remainder of the system.

If a differential pressure were somehow applied, causing a deformation of the diaphragm, the diaphragm would still move, but more force (beyond the nonnal spring constant of the diaphragm) would be required, and this force would produce an error in the level indication. _The error would affect only one Instrument train, so that the problem would be detected by a difference between indications in the two trains, and a diagnosis effort would be required to deteniline the cause of the difference. If the damaged sensor affects more than one instrument in a train, the additional force would appear as a different percentage of the different instrument ranges, thus, helping to identify the pro bl em.

4. Plugging of impulse lines or ports.

Since the ports are in low velocity, subcooled water areas, there is no ~echanism that-would plug the lines. Even if a plugging mechanism were present, the lines must be completely plugged, like a closed valve, before the condition would affect the level indication. In such an event, any subsequent small pressure change would cause connected instruments to move off scale depending on which connection and which way the pressure changed. This condition would differ from a broken line since

. returning pressure to its original value would cause the connected instruments to move on scale again.

B. Connecting Lines Between Sensor and Hydraulic Isolators

1. Break or leak in each connecting line.

A break or leak in a capil_lary line would cause the sensor check valve to close, isolating the reactor from the leak. The leak

. 2-16

•

•

would also cause the connected d/p transmitter(s) to move offscale and the internal valve would close on the break side. The response of the 1 nstruments would be essentially the same as indicated by item A.l above, except only one train would be affected, and the other train would continue to operate nonnally. The affected instruments would remain out of service until the capi 11 ary 1 i ne was repaired.·

2. Failure of RTD on connecting lines.

A failure of an RTD would result in the input to the reference leg compensation becoming 50°F or 420°F, depending on the direction of failure. A level measurement error would result, and the magnitude would depend on the difference between the indicated and actual temperature, and on the length of vertical reference 1 eg to which the RTD is attached. The failure would affect one train only and this would be detected by an abnonnal difference between instrument indications in the two trains. The diagnosis procedure would include verifying the RTD outputs, starting with the RTD's on the longer reference leg sections. (The microprocessor display will auto~atically indicate out-of-range RTDs and flag the affected instruments). Until the RTD circuit is ·repaired, an artificial input can be substituted

for the RTD. The corresponding RTD on the other train WO\Jld provide the data for assigning a substitute value.

RTD's are attached to reference legs varying in length from short .as two feet to as long as 35 feet. If the RTD failed high on a 35 foot leg at 70°F and using error curves, the RVLIS error would be [ ]p'~rcent of the 40 fo~t full range span, but only' about

[ Ja,c percent of the 120 percent foot dynamic head span. If the

upper range is provided with a 35 foot reference leg sec ti on, the error would be [ )p~rcent of the 16 foot upper range span. Note that if the RTD failed low on a reference leg at S0°F, there would be no error. The magnitude of the error would be higher at higher RCS temperatures. If an RTD fails high during ilonnal

2-17

• operation, the failure may be detected as a change in the dynamic head reading if the reference leg section is long enough to cause a noticeable change. If the RTD fails low during nonnal operation when the reference legs are 70°F to 120°F, the failure would not be detected. If an RTD failed before or during an accident, differences in indications between trains would develop. If the difference were large enough, the operator would have to check the RTD's outputs in the racks, starting with the

_RTD's installed on long reference leg sections. Until the difference is resolved, the operator would be forced to use the

most conservative reading.

C. Hydraulic Isolator

1. Failure of diaphragm.

2-18

a,c

2. Failure of overpressurization limit switches.

3. Break or leak in connecting lines to the d/p transmitter.

A break or leak would first result in an indication from a t\Ydraulic isolator switch, then the isolator valv.e would close, isolating the leak. The connected d/p transmitter would ~ove offscale in the direction of the leak. These two indications

would identify the problem, and repairs could be made. The missing water would be added t~rough the transmitter access assembly on the d/p transmitter, and the system could be returned

to service.

4. Break or leak in valves in connecting lines to d/p transmitter.

The instrument valves installed at the d/p transmitter rack are hermetically sealed valves and would not leak to the environment.

2-19

a,c

The valves are also manual valves and would not be operated during nonnal operation except for calibration of the d/p transmitter, so no active failure need be considered.

D. D/P Transmf tter

l~ Failure of diaphragm.

The d/p transmitters are provided with overrange protection, i.e., internal valves that close when the transmitters move offscale. Therefore, no large differential pressure would be applied to the diaph~agm to cause a failure.

2. Plugging of connecting lines.

Since the system is filled with demineralized, deaerated water and sealed, there would be no mechanism to cause plugging.

3. Failure of transmitter (electronic)

The electronic transmitter is basically a loop current regulating device consisting of a current amplifier, regulator, power supply

·and load. Each transmitter loop circuit is independent so that failure in the loop circuit only affects its corresponding mafn control board display. The display of the second train is not affected. The operator can detect a difference of the same two readings (Train A and Train B) and can institute troubleshooting procedures to determine the faulty loop circuit during plant operations. During refueling/maintenance outage, a calibration

check is perfonned so that .any malfunction can be identified and corrected. The attached Table 2-1 lists some of the typical symptoms associated with the transmitter loops circuit failures.

2-20

8,C

-·

4. Improper connection of signal or power lines to transmitter.

An improper connection to the transmitter will result in no output of the transmitter. Such an improper connection can be detected when attempting to calibrate the transmitter.

If an improper connection is made after calibration, then the operator (main control board) will note a difference between the readings of the two trains and can initiate appropriate troubleshooting procedures.

5. Failure of connectors at transmitter.

Model 752 Barton d/p Transmitter uses a terminal block for hard wire connection fo~ the incoming leads and for the connection to the amplifier card. The terminal block is designed with melamine separation between connection studs to ensure that electrical separation is maintained.

A loose terminal connection can result in no output or erratic output of the d/p transmitter and can be detected by differences in the remote display readings by the operator and troubleshooting action can be initiated.

6. Fa i1 u re of s i g n a 1 o r power c ab 1 es .

Failure of the incoming cable to a d/p transmitter will result in no output or erratic output.of the d/p transmitter resultin~ in differences between readings in the main control board displays which can be detected by the operator.

2-21

••

•

E. Controls and Signal Processing

1. Fai 1 ure of Processor.

(a) Complete failure of the processor in the microprocessor RVLIS (Reactor Vessel Level Instrumentation System) is detected by a "deadman circuit" which, during nonpal operation, is reset by the processor at the completion of each update cycle. If the processor does not reset the deadman within 15 seconds, the deadman circuit will do the following:

( 1) Reset the processor. This wi 11 correct soft errors -ones which are the result of a noise spike or are otherwise transient in nature.

(2) Turn off the green "Run" loops and turn on the red "Stop" lamps on both the local processor drawer and on the remote display unit.

(3) Actuate the "Caution" level annunciator relay contacts.

(4) Blank- the remote display to prevent the usage of incorrect or "stale" (i.e., no update) readout displays.

(5) Set the analog level outputs to zero percent. These are normally connected to a recorder (one train only).

If the processor defect is transient, the conditions 2), 3), 4) and 5) will occur for about 10 to 20 sec. after which the unit will resume normal operation. All current displays and outputs will become operational but the historical data for the digital "Trend" display will be. set to zero. The strip chart wil 1 show a short-term drop in all levels to zero and then a return to current levels .

2-22

•• If the processor defect is pennanent, the conditions 2), 3),

4) and 5) will remain. The deadman will repeatedly attempt

to reset the processor. The conditions 2), 3), 4) and 5)

will only tenninate if the processor successfully resets and

completes two sequential data update cycles (the first will

not be displayed as the remote display is blanked by the

deadman until it is reset at the end of the first update).

(b) Partial processor failure.

At the end of each display update cycle, the processor

program perfonns a sequence of tests to detenni ne whether

the program memory (PROM) has any altered bits and whether

the read-write memory (RAM) has any faults. If faults are

detected, an error message is displayed on both the local

and remote digital displays and the caution level

annunciator relay is actuated.

The unit will remain with the error message displayed (the

deadman is periodically reset) until the processor "reset",

button on either the remote display or on the processor

drawer is pushed. The unit wi 11 then restart and continue

operation if the detected error was transient. If the

condition persists, the error message will return and no

1 eve l data wi 11 be displayed.

In cases of processor failure, both partial and complete,

the operator is alerted that the system is malfunctioning by.

the actuation of the caution level annunciator. Level

infonnation is not displayed by a malfunctioning system so

that incorrect data is not presented. If the malfunction is

temporary, data will be presented within 20 sec after the

problem has been corrected and in the case of a partial

failure, the reset button has been pushed. If the

malfunction is pennanent, no reactor level infonnation is

presented.

. 2-23

• 2. Failure of signal isolator.

The signal inputs to RVLIS from safety related Class lE signal sources are through qualified Class lE signal isolators installed in the cabinets with the signal sources such that a malfunction beyond the isolator (or in RVLIS) will not propagate back into the Class lE signal sources.

The Class lE signals input to RVLIS are wide range RCS pressure and wide range RCS hot leg temperature. Failure of the signal isolator would usually result in the loss of the input to one RVLIS train. In this case, the RVLIS density compensation would be based on the lowest input value for the density.function generator, zero psi g or 50°F, and the indicated level would be lower than the actual level. A comparison of the display readings for the two RVLIS trains would establish that a malfunction existed, and the

diagnostic procedure would identify the malfunction. In the microprocessor system, an out-of-range input signal would be identified on the RVLIS display.

In the event that a signal isolator failure would cause an offscale high input signal to RVLIS, there would be little or no effect on the RVLIS indicator since the inputs are auctioneered to select the density based on the 1 owe st saturation temperature. Thus, the calculated density, based on a high pressure or temperature input, would not be selected.

Th RVLIS outputs to the indicators and recorder are provided with signal isolators. A failure of one of these signal isolators would result in the.affected indicator moving off seal e 1 ow.

2-24

• 3. Sticking of analog meter indicators (Plants using analog indicators).

If one of the indicators truck during normal operation, the malfunction may not be detected until a transient occurred, 1.e., a change in reactor power would cause the wide range indication to change within the range of 100-110 percent. The malfunction would otherwise be detected during a periodic check of the RVLIS electronics, e.g., .when one train is taken out of service for testing.

If an indicator sticks during a transient, comparison with the other train's indicator and with the recorder would determine which indicator is stuck, if not already apparent from the transient. Tapping on the indicator will usually cause the indicator to return to normal operation.

2.9 TROUBLESHOOTING, PLANT AT POWER

If single reading varies from the expected value, check the following:

1. Hydraulic isolator status lights on Main Control Board should be off,

2. Compare hydraulic isolator dial reading with reading taken from diverse train and those taken at Tavg no-load conditions. Readings deviating by more than plus or minus 0.1 in. 3 may be indicative of potential capillary line leakage; however, it may not be the reason fo.r the deviation of the reading until the isolator reached the valve-off point.

3. Perform a calibration check of the microprocessor per the Westinghouse Instruction Manual 9002-VLM-001.

4~ Ch~ck the impulse line RTD's outputs at the RVLIS cabinets, starting with the RTDs installed on long reference leg sections.

2-25

•

If more than one indicator/display deviates from the diverse train or from Tavg no-load readings, check the following:

•

• Common isolator dial readings versus previous readings • D/P transmitter valve lineup

1 Process equipment power supplies

If repairs are required to the capillary lines, the system must be vacuum filled and calibrated per the instructions contained in Section 4 and the appropriate equipment instruction manuals •

2-26

7;,aL.: 2-1

Possible Symotom Sources ~~a 1 func:i ans =\e!ne'.'.ly

Power Supply 1 Blown Fuse - Rec lace Fuse' 1 Faulty Comoonent - Reoair Power Suoolv

'di ring • Loose Tenninal - Tighten Tenninal Connection Connection

1 Broken Wire - Rec 1 ace \~ire

'lo Transmitter Load 1 Blown Fuse - Replace Fuse Jutput 1 Faulty Component - Repair or Replace

Receiver or Load Transmitter • Loose Terminal - Tighten Terminal

• Faulty Component - Compare Measured Voltages with Nominal Voltages

• Reversed Power - Reverse Power I Connection Connection

I Power Source Low Voltaae Reoair Power Suoolv I

Load Resistance Resistance to Hi oh Reolace Load Resistance I Transmitter

• 11 Zeros" But Cable Resistance Length of Measure Cable Loop Cannot Get Full Cable jn Excess of Resistance and Bring ~ange Soecification Within Soecification

Amplifier Loss of Gain Reolace Hybrid Circuit (Zl)

Out of Electronic Component Value Shift Go Throuqh Calibration Calibration and Circuit Voltage to

Locate Faulty Component. Recalibrate.

Tenni na 1 Loose or Dirty Tighten and/or Clean, ' Connection As Reauired Erratic or

Intermittent Electronic Defective Component Diagnose by Circuit Ooeration Component Diagram by Measuring

Voltage at Appropriate . Points . Excess.Output Electronic Defective Component Repair or Replace (Will Not Zero) Circuit Board

2-27

• SECTION 3

RVLIS INSTALLATION CRITERIA

•

3-1

• WESTINGHOUSE REACTOR VESSEL LEVEL INSTRUtr'ENTATION SYSTEM INSTALLATIOI~ CRITERIA

The following is a list of requirements and recommendations for the installation of the Westinghouse RVLIS System:

A. General

1. Sensors shall be mounted on a wall or structure at the specified elevation, near the reactor head, hot leg or seal table connecti6n.

2. Capillary impulse lines inside containment are run from the sensors to a containment penetration. A typical capillary installation is illustrated in Figure 3-1. Temperature measurements for density compensation are required on vertical capillary runs before the capillaries in one train are brought together at one point or one common elevation, so the routing of capillaries should be selected to minimize the numberof independent vertical runs and the number of temperature measurements required. Temperature compensation is not required when all capillaries of one train are run together.

3. Hydraulic isolators shall be mounted outside containment at or near the containment penetration to minimize the length of capillary lines from the penetration to the isolato~s that must be protected from high

energy missiles or from damage by maintenance operations. The hydraulic isolator serves as the containment penetration isolation valve, and the connecting piping (capillary) must be suitably protected.

4. The differential pressure transmitters shall be located in a p~otected area outside containment, where temperature during an accident condition will not exceed 130°F and the total integrated radiation dose will not exceed l04R.

3-2

•

-·

••

B. Sensor Installations

1. Sensor Head:

vertical locations: At or above the inside top of the vessel head, but below the highest point in the head connection piping.

Seal Table: Same elevation as the connection tee. Hot Legs: Same elevation as the connection.

2. Sensors at hot leg connection and seal table connection are to be installed with the vent valve upward. The head connection sensor is to be installed with the vent valve downward.

3. Piping between head connection and head sensors should have a nominal downward slope of 1/2 inch per foot.

4. Sensors must be installed with at least 9 inches of free area from the capillary tubing ·under (over for head sensor) the sensor to the floor or similar obstruction for removal of the sensor bellows during maintenance or filling operations. Flexibility shall be provided in the capillary tubing to allow the sensor bellows to be removed without damaging the capillary line.

C. Capillary Tubing Installation

1. Horizontal runs of independent capillary tubing inside containment shall be level to a tolerance of ±. 3 inches up to the point where the 3 capillaries in one train are run together, to avoid the need for temperature compensation.

2. Minor loops up and down around obstructions 1n independent horizontal capillary runs are acceptable if uniform temperatures of the vertical runs can be demonstrated .

3-3

J

•

•

•

3. Independent vertical capillary runs requiring temperature measurements for density compensation shall be installed within instrument tubing channel to protect the capillary from jet impingement and local heat-. .

1ng of a vertical run. The objective of the protective channel is to assure that the vertical run of capillary tubing is. heated uniformly rather than locally. The temperature instrument (RTDs) installed for de~sity compensation should also be contained within the.protecting channel. RTDs must be located midpoint on vertical rises. Protective wire armor on capillary lines must be remo,ed in an area where the RTD

is to be installed.

4. All capillary tubing shall be appropriately protected from the surroundin~ environment, i.~., jet impingement, high energy missiles, maintenance operations, to the greatest practical extent.

5. The capillary line high point vent (on the vessel head connection line) should be located at or within one foot of the highest point in the system so that a fill b6ttle can be connected to this vent valve and located above the highest point in the system.

6. Train A and Train B capillary lines shall be separated by at least 18 inches to meet IEEE-279 train separation requirements. Train separations can be reduced to less than 18 inches if a suitabl~ barrier is

provided be~ween the trains~ -

7. Capillary routing from the seal table connection should not be routed above seal table connection elevation.

8. Containment pen~tration:

a. The three capillaries of one train can be run through one penetration •

3-4

•

•

b. Both gr9ups of three capillaries can also be run through one larger penetration if the groups are adequately separated within the penetration and at both ends.

c. Capillary tubing of 114 inch diameter should be used at the penetration point for improved penetration seal welding.

d. Tubing through penetration should not exceed 114 inch diameter in order to maintain the small fluid volume subject to thermal expansion.

9. Routing of capillary tubing from hydraulic isolators to DIP transmitters should avoid or minimize proximity to piping subject to temperature variations above ambient. This capillary length from the hydr~ulic isolators to the DIP transmitters is limited to a maximum of 100 feet.

10. The total capillary run from.the sensor to the DIP transmitter is nominally limited to 400 feet by the thermal expansion capacity of the sensor bellows. Lengths exceeding 400 feet may be acceptable, depending on the specific plant layout.

C. Hydraulic Isolators and DIP Transmitters

1. Hydraulic isolators and DIP transmitter elevations outside containment shall be ~elected, considering ele~ations of sensors inside containment, such that potential sub-atmospheric or vacuum conditions are minimized when sensor vents or DIP transmitter access valves are opened for calibration or fill adjustments. A location for the isolators and transmitters at or below the seal table elevation is recommended.

2. The magnex instrun1entation. valves are to be loiated within five feet of the DIP transmit~ers and at or below the transmitter elevation.

3-5

Installation of the valves should utilize panel mounting feature(s) to support the valve body. It is also recommended that the valve not be supported by the inlet/outlet tubing connections.

3. Adequate space shall be provided above the D/P transmitters for the access assemblies and the fixtures that will be attached during calibration.

D. Miscellaneous Installation Reconnnendations ·

•

•

1. All sensor.bellows need to be removed during capillary line installation and welding to prevent bellows damage.

2. The requirement to seal weld the caps on the capillary line vent/fill valves has been deleted •

3. It is recommended that the control board display for the RVLIS be located in an area of the control board which can easily be seen by the operator during post-accident maneuvers. Other indications of approach and confirmation of inadequate core cooling should be located in the same vicinity (Tsat monitor, core exit T/Cs) for ready · comparison by the operator.

4. For plants that have the RVLIS installed and the capillary lines not a,c _ [ .•. ]filled, the following precautions need to be taken:

a. The root valves must be closed at each of the RVLIS taps (head, hot leg, seal table) if the RCS is brought up to pressure prior to [ ]fill of the RVLIS.

a,c

b. The primary side (RCS) connection to the high volume sensor must be disconnected at the Swagelok fitting and the line capped to prevent possible liquid leakage. The sensor primary side inlet must also be plugged to prevent dust from getting into the sensor .

J-6

• These precautions should be taken to prevent damage to the sensor bellows should the root valves leak while the RCS is pressurized. Such a leak would not be a safety problem as it would cause the check valve device in the sensor to close; however, it would cause deformation of the sensor bellows, thus requiring replacement when the ~VLIS was placed into operation. Damage to the bellows can occur 1f a differential pressure is created across the bellows and both sides of the bellows are not liquid tilled.

3-7

w I ::0

•

REACTOR VESSEL.

•

RTD

FTfiUnEJ-1: TYPIC/\L C/\PILL/\RY TUBING l./\YOUT

CONTAINMENT PENETRATION

•

•

•

SECTION 4

REACTOR VESSEL LEVEL INSTRUMENT SYSTEM

INITIAL FILL INSTRUCTIONS

4-1. INTRODUCTION

The following instructions identify the steps for. the initial [ J~i11 procedure. Portions of these instructions may be utilized when subsequent maintenance/repair action is required. The list of equipment necessary for vacuum_ filling is contained in section 10.

4-2. PREFILL VISUAL INSPECTIONS

(1) Perform dye penetrant inspection on all capillary weld joints (exception may be taken {o factory inspected and tested welds).

(2) Visually inspect capillary, tubing, valves, isolator, and transmitter piping connections against drawings for proper arrangement. (Refer to Section 11).

4-3. PURGE TEST

(1) Remove sensor housing plate. Install bellows protectors then remove bellows from all sensor assemblies using Barton wrench 0353-1053C. Protect and store bellow assemblies and 0-rings from

{2)

bellows seat.

CAUTION: The nitrogen source should be bottled versus line supplied to insure miniwal moisture entry during piping checks and pressure tests.

Employing regulator and low pressure {2 to 5 psig) dry instrument air, or dry nitrogen, check continuity of capillary {to preclude any possibilities of closure during welding or cross connections

4-1

•

during welding or cross connections during _installation) by flow of air through the independent capillary sections.

(3) Remove fill valve cover caps and open respective fill valves with . a 1/S inch Allen Wrench. Use ihstiument air or dry nitrogen

connected by a 3/8 inch hose to fill port of fill valve on Hydraulic Isolators.

(4)

Flow instrument air from Hydraulic Isolator high pressure fill ports through capillaries to Train A and B sensors as follows: RV head isolator to head sensor; seal table isolator to seal table sensor; and hot leg isolator to hot leg sensor. Check that all identities and connections agree with installation drawings.

Moving the. above low pressure air or nitrogen hose connections to each hydraulic isolator low pressure ports sequentially, and opening respective Hydraulic Isolator fill valves, magnetic instrument block valves (Ref; Autoclave Dwg. 30-9480) and shutoff/purge valves on transmitter access assemblies, verify ·correctness of cap i 11 ary connections and f 1 ow communication per installation drawings to the transmitters as follows:

Train A and B Hydraulic isolator to LP port per drawing

RV Dynamic Head d/p RV Full range d/p Upper Range d/p

4-4. PRESSURE TEST

•

(1) Leak or pressure test both trains of the capillary system employing dry nitroge·n gas as !ol lows.

(2) Install ITT Barton seal plug adaptors (PN 5039.0087.Z + 0-ring) in place of bellows assemblies and reassemble sensor housings to protect items such as gasketing (snug but do not torque bolts) .

4-2

(3) With sensor. bellows seal plug adapters in place and employing fill valve tubing connection adapter assemblies P/N 0353. 1109.B, pressurize each line via hydraulic isolator HP port to 2400 psi (.:!:_100 psi). Note that the hydraulic isolator will valve off scale clockwise. A valve and pressure gage (0-3000 psig) must be employed downstream of the pressure regulator to isolate and observe pressure hold of injected gas. Examine all welds with Triton X-100 or equal leak detector fluid. Repair a}l leaks and retest as required~

(4) Disconnect and replace fill valve internals.· Repeat for each isolator/sensor line of respective trains.

NOTE: The above lines may be pressurized from the sensor end·with fill valves in place employing the sensor adapter plug, depending on convenience.

{S) Test the transmitter to isolator line sections by connecting the abo-ve pressure gage and valve to one of the capped d/p transm-itter ports. Open all Autoclave magnetic type instrument valves and close transmitter access v~lves such that all parts of the instrument/capillary system are conununicating and closed. Pressurize the transmitter/isolator system to 2400 psi (.:!:_100 psi). Note that hydraulic isolators are overranged counterclockwise. Examine all compression fittings and field welds with Triton·X-100 leak detector fluid or equal. Tighten or repair all leaks as required.

CAUTION: Use caution.in tightening fittings on Autoclave magnex valves. Employ a wrench on valve gland fittings to assure gland torque settings are not disturbed.

NOTE: As an alternative to the above, a complete train may be leak tested at the same time by effecting high pressure bypass connections around the hydraulic isolators

4-3

•

•

employing P/N 0.0353.11098 adapters and applying pressure at trari~mitters per above.

(6) After inspection remove high pressure and remove leak check high . pressure bypass.es above from hydraulic isolators and install fi 11 valve stems {seal caps removed).

4-5. ELECTRICAL CHECKS

(1) Use instrument calibrator check and set hydraulic isolator switch setpoints as requtced. (Factory set (+) and (-) [ ]~i~. 3 H2o)

(Approximately[ ]in. H2o applied to HP port for clockwise (+) [ rf~. 3 and same on LP port for counterclockwise (-)[ri~. 3 ).

(2) Check calibration of d/p transmitters to calibrations based on as-built elevations of vessel and hot leg connections and/or instrument specification sheets as applicable. {Refer to plant specific reactor vessel level schematic drawing for as-built dimensions).

NO.TE: Calculated Dynamic Head flow d/p value to be retained per specification sheet through initial startup testing {not affected by installation dimensions).

(3) Perform plant survey data dimensioning as-built elevations of all sensors for calibration following fill operations. The sensor elevation differences should be available to a certainty of 1/2 percent of RV Full range and upper range d/p transmitter elevation spans (head-to-seal table sensor a~d head-to-hot-leg sensors or hot-leg-to-seal table for upper head injection (UHI) plants).

4-6. SYSTEM EVACUATION

[ 4-4

r

•

Ln I.

'<:l'"

50

40 (.)

0 0

I-<t CJ I

~ 30 ~

w a: :::> (/) (/)

~ w

I a: O'I a.. 20

0 w I-<t a: :::> I-<t (/)

10

0

LIQUID STATE

VAPOR STATE WATER

30 40 50 60 70 80 90

TEMPERTURE (°F)

Figure 4-1. Liquid Temperature Versus Saturated Vapor Pressure

100

Ol w m ....

•

•

• Figure 4-2. Sensor and lnline (Operating Deck) Evacuation

and Fill Schematic Diagram

4-8

18,367

a,c

18,367

a,c

Figure 4-3. Isolator Bypass Evacuation and Fill Schematic Diagram

4-9

• •

0 .-

1 ~

18.367

• a,c

• Figure 4-4. Schematic Diagram of the Transmitter Fill Connection

4- 11

• a,c

4-7. SYSTEM FILL

a,c

• 4-12

• a,c

4-8. FILL VERIFICATION/HYDRO TEST a,c

•

• 4-13

• •

•

• Figure 4-5. Vent Connection Schematic Diagram of the In-Core

Detector Con du it Annulus

4-16

18,367

a,c

u. Cll

• • •

•

•

SECTION 5

GENERAL SCALING PROCEDURE

Refer to the Hunt Valley microprocessor instruction manual, 9002-VLM-OOl, for

scaling and calibration procedures •

5-1

•

•

SECTION 6

TRANSMITTER CALIBRATION BASES

6-1. INTRODUCTION

The transmitters are calibrated on the basis of reactor vessel and related connecting piping dimensions plus differential pressure resulting from reactor coolant pump operation. All of these are detennined under cold plant conditions which represent maximum instrument differential pressure (d/p) spans. Process electronics interpret measured differential pressures for reactor coolant and/or reference leg densities (temperatures) which may be different under nonnal operating and/or accident conditions.

6-2. CALIBRATION LEVEL DIFFERENTIAL PRESSURES

Figure 6-1 illustrates the pertinent physical dimensions employed in determining spans of _d/p instruments as follows:

1 Dimension A is the reference column dimension inside of vessel clad at the bottom of the vessel to high point of head piping connection.

1 Dimension B is the 100 percent level referred to dimension A and is vessel inside height at center.

1 Dimension C is the same as dimension A except it is referenced to hot leg tap.

• Dimension Dis the reactor-inside dimension at centerline to the centerline of the hot leg tap.

Dimension B is obtained from reactor vessel drawings and the balance of the -dimensions are obtained from design and/or as-built records .

6-1

•

A tREFERENCEI

CROM HOUSING OR VENT PIPE TYPICAL

C tREFERENCEI

f 0

1100% LEVEL)

FLOW B (100% LEVELi

Figure 6-1. Level System Calibration Dimensions

6-2

19,547-11

SENSOR tTYPICALI

' CROM UNCOVERY

SEE TEXT

•

•

•

It should be noted th~t d/p transmitter spans assume that a void exists in the vertical space of the CROM housing or vent pipe. In nonnal operation, this vertical section is water solid such that ~ctual differential pressures exceed nonnal in~trument spans and are overranged to the extent of this dimension. It should also be noted that water levels will have to drop below the vertical extension of the CROM into the vessel before a change in d/p is observed.

This extension into the vessel is typically of the order of[ ]f~r centrally located CRDMs (not applicable to vent pipe connections). On declining

vessel levels, an abrupt drop of a corresponding percentage would be noted at this uncovery point.

The level transmitters are reverse calibrated such that a maximum 20 ma signal is output for the lower d/p associ~t~d with the full condition as follows:

1 Upper range 20 ma = C-0 inches of water

1 · Full range 20 ma = A-B inches of water

Similarly, the empty vessel condition is the greater d/p and corresponds to the elev·ation head of the reference column and a corresponding low 4 rna signal:

1 Upper range 4 ma = C inches of water

1 Full range 4 ma = A inches of water

The cold d/p transmitter calibration thus becomes:

1 Upper range (C-D) tci C

1 Full range (A-B) to A

for a 4 to 20 ma output, respectively .

6-3

r---------------------------~----------

• 6-3. DYNAMIC HEAD D/P CALIBRATION

•

The dynamic head transmitters are ranged to include elevation head pl us fl ow differential pressures. With reactor coolant flow upward through the core (figure 6-1), the following impacts on measured differential pressures results:

1 Flow head to greater at the bottom of the vessel.

• Elevation head is greatest at the bottom of the vess~l.

1 Reference leg is equal to and offsetting maximum elevation head (cold) (d/p equal to zero for vessel and CROM full).

From the above, it can be seen that flow d/p increases the observed d/p in the same direction as the elevation head and increases from a zero d/p full vessel condition to a maximum under cold reactor coolant flow conditions. Con

versely, under no flow and an empty vessel condition, the observed d/p equals

[ J a,c

the reference column per above. The d/p instrument span therefore becomes

[ [ J

a,c for 4 to 20 ma whe_re is the flow d/p head under cold conditions.

The flow d/p head loss is initially a calculated value based upon reactor coolant pump head characteristics and flow resistances of the reactor vessel internals, nozzles, and the like. This value will be confin11ed in foitial and subsequent plant startups to correct for analytical uncertainties as well as changes in flow characteristics which may result from maintenance factors throughout plant lifetimes. Measured flowheads will be measured from cold through hot shutdown reactor coolant temperature to confinn compensating characteristics for normal flow conditions as well.

Reference is to be made to paragraph 6-6 for examples of typical calibrations and specifications .

6-~--

•

•

•

6-4. REFERENCE COLUMN

Figure 6-2 depicts pertinent dimensional parameters of the reactor vessel le~el schematic drawings required for scaling of process electronics reference compensation. While individual plants may differ somewhat. the ·principles apply to different configurations or installations. First it must be recognized that the reference column dimension is independent of routing. By definition, the dimension is the distance between the water trapped in the loop seal connection above the vessel to the low point connection. The downward routing of the piping at the vessel head from either the CROM housing or vent pipe retains the reference column fluid similar to a condensate pot in a conventional boiler application. In the case of RVLIS, this complete sector including the vertical housing or vent pipe is water solid during normal operation. Gases are dissolved and swept from the system, giving rise to

associated slight overranging of transmitters.

The REF dimension of figure 6-2 is affected by separated vertical routing seg~ents with dimensional identifications[ Ja'~outings along·. horizontal planes do not contribute to elevation heads and consequently do not affect the reference column. When all the water in the identified reference connection is at the same temperature (and pressure). the algebraic elevation head total around the loop equals to top to bottom head labeled [ J

a,c

[ Ja,c.

This holds true for the transmitters as the densities fro1:i the point of jointure of the two impulse line capillaries become equal and opposite under all condition of temperature, pressure, and routing direction.

RTDs are applied to the independent vertical routing to monitor for the purposes of correcting measured differential pressures for resulting density changes in the affected sections on an independent basis. This includes ambient temperature differences as well as greater differences. which may be associated with accidents. With information derived from the temperature measurements. The microprocessor compensates for temperatu~e changes so that

6-5

lO

Figure 6-2. RV LIS Reference Column Installation Dimensions

the vessel elevation head can be accurately determined. While processing

algorithms may differ, all arrive at the same answer so that

a,c

a~ . Dimension[ ]of figure 6-2 is a required as-built measurement for purposes of end-to-end calibration checks of the system. Upon completion of initial fill and at refueling shutdowns, elevation heads of the sensors should be measured at the transmitters as a check on the capillary isolator system. With valve

sensors offline ~nd with the hydraulic isolators at or near zero position ac ·

(plus or minus[ Jin.3), the sensor bellows free height dimension is checked through vent cap against initial fill measurements. Agreement within plus or minus 1/16 inch assures integrity of capillary fill.

Transmitter ma outputs are checked for agreement with dimension H elevation

head. Agreement within plus or minus[ J~;o (dependent on isolator reajing zero} verifies acceptable resistances within capillary system. A pneu

matic calibrator pressure signal, equal to dimension Hat the seal table sensor, is applied to verify that a transmitter signal corresponding to zero d/p and 100 percent 1evel exists to above tolerance.

Upper range transmitter system checks should be performed per the ~bove with equivalent elevation head data, and pneumatic calibrator ihputs shouid be

applied at the hot leg sensors.

The effect of compensation calculations per above can be seen in figure 6-3. If the reference column temperature increases, the actual observed d/p would be interpreted as an increased elevation head in the vessel (smaller effective

[ Ja,c

reference head). Alternatively, if sections only were heated, the

6-7

19.547-13

a,c

Figure 6-3. Reference Column Compensation

6-8

•

•

observed d/p would suggest a lower elevation ~ead in the vessel rather than higher. By monitoring respective sections and applying the known corrections for water densities, reactor vessel differential pressures are detennined. Then, water levels are detennined by subsequent data processing.

[Ja,c

The vertical section labeled between the head connection and the sensor is not addressed or included in the above analysis as this short loop is assumed to be at constant temperature. Plant layout guidelines require that this dimension be small so 1f the assumption is not accurate, the err~r will not contribute significantly to resultant head and level detenninations. From· figure 6-4, it can be seen that if the section head to sensor differed from the sensor/capillary vertical routing by 450°F, the resultant error could be[ Ja,c

ac . inches of water for a[Jcitmension of[]tt typical. Such a temperature cannot

[ J a,c

occur and an uncertainty of or so of head is accepted. a,c

When vertical runs (in loops or around obstacles) are required, sy~etri.c

cancellation can be used as_long as cancelling verticle runs are at the same tempera tu res.

The impact of certain postulated accidents may be determined from examination of impacted vertical sections A through Y above. Layout guidelines call for shielding against impingement to ensure ·representative temperature measurements. Examination of figure 6-3 and/or steam tables enables assessment of error factors related to local effects or gradients as related to the REF

[ Ja,c ·

dimension. Total dimensions of· are of the order of 120 ft typi-[ Ja,c [ 1oa,c [Ja,c [Ja,c cally for a ft REF dimension. A J F error in processing and dimen-

si011s could result in an error of[ ]ft {]~~rcent of[ Jf'~l. Such an a,c

example could not occur physically; however, it does illustrate the compensa-tion objective.

6-5. CRITICAL OPERATING PRESSURES

Because of the elevation heads involved in effecting reactor vessel connections per figure 6-2, temperatures, pressures, and vessel levels could exist where water in capillaries and/or seal table conduits could vaporize. These conditions exist outside the boundaries for system operation. However, user/operators should be aware of these limits.

6-9

•Water in the capillaries or seal table conduits vaporize if temperature anti pressure conditions reach the critical point. System operation under accident condition is dependent upon the reactor coolant pressure being greater than atmospheric pressure. With the core as the primary source of energy under reduced pressure accident conditions, it therefore follows that coolant system pressure is highest followed by containment pressure. Both of these will exceed the critical operating pressure limits of the system.

The concerns over operating pressure limits ~rise because of rou~ing the capillary upward out of the refueling canal and, to a lesser extent, the downward connection from the seal table to effect head and bottom of the vessel p~essure connections. Low pressure points result at these two high points.

Water vapor would be formed at the.seal table, for example, if the vessel were empty and at .atmospheric pressure, making the system inoperable.·

While conditions for vap~r fonnation should not occur in use, they could occur during installation checkout, particularly in.subatmospheric containment

· designs.

Table 6-1 lists critical RCS pressures for a typical plant installation and some containment po~taccident temperatures. The critical conditions are vapor formation in the operating deck capillary and reactor coolant level at the top of the core. It can be seen from the table that subcooling of the capillary will exist for all cases where core cooling adequacy is a question.

Process effects on d/p measurements are reflected in Figures 6-4 and 6-5.

Saturated conditions for liquid and steam are employed in process elect~onics to define collapsed levels or flowing void conditions, respectively. (Froth due to boiling may cause wetting above equivalent to collapsed level measured and indicated.)

6-10

O' I --' --'

• • a,c

Figure 6-4. Upper Range and Fu 11 Range d/p Level Variation With Reactor Coolant Temperature

O"I I

• a,c

Figure 6-5. DYNN1IC HEAD D/P LEVEL AtID FLO.•! VAfHATION \•!ITH REACTOR COOLANT TEMPERATURE

• TABLE 6-1

CRITICAL RCS PRESSURES VERSUS CONTAINMENT POSTACCIDENT TEMPERATURES

Containment Temperature(a) (OF)

a,c

Minimum

Reactor Coolant Pressure (psi a)

a,c

a. [ J'F'cand [ JF,cwould occur only under steam break conditions. Reactor

coolant pressure would remain high.

Figure 6-4 illustrates the effect of the CROM housing and piping reference column extension above the vessel and into the vessel (CROM only) on processed level measurements for the range of operating temperatures (saturated densi

ties) with pumps off.

Figure 6-5 illustrates similar relationships for dynamic head d/p and temperd

ture. These curves should be verified in startup from calculated values

employed for initial instrument calibration purposes.

6-6. SAMPLE CALI BRAT ION CALCULATIONS

6-7. Example 1 RVLIS Transmitter Scaling, Non-UHi plant (Figure 6-6)

6-13

a,c

u. ca

1-· -------.

19,54 7-16

• a,c

Figure 6-6. Level System Calibration Dimensions, Examrile 1 - Non-UHi Plants

• 6- 15

•

•

7-1. - INTRODUCTION

SECTION 7

HYDRAULIC ISOLATOR/SENSOR CAPILLARY

CALIBRATION PROCEDURE

These instructions provide users with general information relative to the application and use of the hydraulic isolator in conveyance of process pressures to measurement instruments. Instructions include inforination relative to behavior characteristics under various process and environmental conditions in sealed capillary systems. Maintenance and service instructions for the hydraulic isolator are contained in the a~plicable ITT Barton Instruction . Manua 1.

7-2. FUNCTION

The hydraulic isolator functionally performs ~s a diaphragm conveying process pressures to connected transmitters through volumetric displacements of fluid as necessary to balance calibration forces .

7-1

a,c

• 7~3. NORMAL OPERATION

7-4. GENERAL

The hydraulic isolator is ~alibrated in volume of fluid displaced in the isolator/transmitter connections. In the initial fill, the isolator is zeroed by equalizing connections across the isolator to ensure that the cortect volu~e of water is retained on the reactor coolant/sensor side of the process connection. This volume is permanently sealed with closure (seal welding of the fill valves is not requiredi.

When this (zeroing) fill condition is duplicated in subsequent system checks, the remote sensors bellows as well as the isolators should be at their normal equilibrium (zero resistive forces from either isolator or sensor) position. A dimensional check of sensor bellows (dimension through the sensor vent port)

_ confirms if any leakage has or has not occurred by comparison with original as-filled dimensional data on the sensor bellows. (Reference is to be made to the initial fill procedure.)

'The isolators are also zero when all connecting lines and the reactor coolant . system are filled (vented), at room temperatures and atmospheric pressure, provided correct fluid volumes exist in the transmitter/isolator connections. This is the design null condition of the complete sensor, capillary, isolator, and transmitter.

• Process at zero d/p o Sensor bellows at free height • Transmitters at mechanical zero • Isolator at mechanical zero

It should be noted that this is a theoretical null, in some respects as it is virtually impossible to obtain such balanced conditions in a plant owing to such factors as temperature variations. Unbalanced forces (a few inches of

7-2

••

•

water) are expected in the system and accounted for in system uncertainties. These unbalances that are associated with the hydraulic isolator are in direct relationship to the differences in their indicated volumetric displacements.

[ Ja,c [ ]a,c 3 (Approximately in H2o per in. unbalance betw~en two units employed for a specific dip measurement.)

The hydraulic isolator indicates fluid volume displaced to transmitters within bands of figure 7-1. Normal volumetric displacements of the isolator result from the following process effects:

• Transmitter Displacement - Fill fluid is displaced dependent upon volume/spring forces and direction of force unbalance required to effect measurements. In case of diffefential pressures, two isolators are affected in equal amounts but in opposite directions.

• Pressure - Fill fluid compresses on increasing process pressure. The isolator displaces clockwise proportional to pressure and total fluid volumes to transmitter.

• Thermal Expansion - The hydraulic isolator is deflected counterclockwise toward the sensor/process on increasing temperatures of fluid between th~ isolator and transmitters (and conversely). As in the case of pressure, the effect is proportional to volume and the nature of temperature increase (volume of fluid affected).

7-5. TRANSMITTER DISPLACH[NT

To effect measurements of pressure or differential pressures, the transmitters employed di~placed against calibration springs. Also, in the case of reactor level, some transmitters are normally overranged to mechanical stops. Knowing -these displacements can be useful in assessing operating status and systems abnormalities as reflected in the hydraulic isolator·sc~les. Variations occur from unit to unit so values are approximate and should be supplemented by observation of specific operating systems. Table 7-1 gives displacement values for units typically employed on RVLIS.

7 .. 3

19,547-18

• a,c

•

Figure 7-1. Hydraulic Isolator Volume Measurements

• 7-4

• TABLE 7-1

APPROXIMATE VOLUMETRIC DISPLACEMENT OF RVLIS TRANSMITTERS

Barton Model 752 (Level B)

FULL RANGE AND UPPER RANGE

a,c

Normal full scale

Overrange displacement

DYNAMIC HEAD RANGE a,c

-· Normal full scale

Overrange (NA)

7-5

~ F;gure 7-2 illustrates the total transm;tter displacements in comb;ned effects with reactor coolant pumps on. In this case, the upper range transmitter is overrange downscale. Volume displacement includes the total range plus over~ange displac~ment which is the worst case. The full range instrument is overrange upscale which involves only the overrange displacement (since its mechanical zero is 100 percent level). The dynamic head transmitter displacement is less than full scale as it is within its operating range and approxi

mate]y 66 percent displaced.

Two things should be noted from figure 7-2. First, isolator displacements are in opposing directions in effecting high side and low side pressure transmission to the transmitters. This causes small unbalanced forces of the order of

[ Ji~ch water per each[ Ji·~. 3 deflection in effecting d/p measurements. These are small with respect to instrument spans. However, their existence should be known and recognized. Second, where these isolator displacements are known to be large in one direction, fill fluid adjustments in the trans-

• mitter/isolator line s~ctions may be biased in an offsetting fashion to increase operating margins as desired.

7-6. PRESSURE EFFECTS

The fluid in the isolator low pressure port, capillary, tubing valves, and

transmitter compress on result, moves clockwise affected fluid volume. follows:

increasing process pressure. The isolator, as a (+) in an amount proportional to pressure and total This approximate volume affected can be determined as

• Isolator LP housing [

[

J~.c 3 in.

• dip transmitter (each) J ~.c 3 [ · Ja,c 1n. (approximately · in. 3 in

each port housing plus 1/2 of bellows fill)

7-6

•

•

HI

HI

HI

- 19,547-19

1

LO

UPPER RANGE

2 LO DYNAMIC HEAD

HI

3

LO

FULL P-ANGE

--INDICATES DIRECTION OF FLUID DISPLACEMENT

ISOLATOR

UNIT 1

UNIT 2

UNIT 3

IN3 DISPLACEMENT

r r

Figure 7-2. Transmitter/Isolator Displacement for Pumps On and Standard Configuration

7-7

• • Va 1 ves and d/p transmitter rack piping [

a,c · · t Capillary[ J in. 3 times

total length in ft. isolator to transmitter

J ~.c 3 in.

Knowing the fill volume above, the compression of the water fill for various pressures can be determined from figu~e 7-3 (approximately 1.0 percent at rated pressure). This compression causes a clockwise deflection o[cthe · hydraulic isolator dial (typical installations, approximately[ ]in. 3 for full· pressure). Figure 7-3 shows the compressibility effect is also constant with temperatures. This means that isolator incremental displacement effect due to pressure is constant (where it occurs on the dial may change with factors such as temperature, while the effect of pressure change is constant).

7-7. THERMAL EXPANSION

The same fill fluid volumes confined between the.isolator low pressure bellows and the transmitter varies with temperature as well as pressure above. A sizable portion of the fill fluid vo)ume i~ contained in the isolator low pressure housing. Total volumes are minimized to reduce effects of temperature variations. Similarly, system layout guidelines prohibit routings or locations subject to variable heating or high ambient temperatures.

A 50°F change in ambient temperature for the system produces an approximate percent change in volume. For a typical system {ricn.3), a[ ]j,~·3 increase in fill fluid volume could occur. This would be evidenced as a (-) counterclockwise displacement of the isolator dial. This expansion would also displace the sensor bellows as the expansion is taken up finally within the reactor coolant process.

If it is known that ambient temperatures during normal plant operation will greatly exceed those at the time of initial fil), the isolator null may be offset an equivalent amount clockwise toward the transmitter (reduced fill fluid) to increase operating margins. Alternately, operating points may be adjusted during calibratibn opportunities.

7-8

100

99.9

99.8

u. w 99.7 a: ~

;ii! 99.6 z a: w I- 99.5 <(

~ u. 0 >-

99.4 ........ I-I ...I \0

CD 99.3 (/) (/)

w a: c.. :E

99.2

0 (.)

99.1

99.0

98.9 0

• 110°F

0 130°F

6 100°F

0 70°F

1000

PRESS

Figure 7-3. Compressibility of Water

•

o~

2000 3000

-U)

't! .... I

"'

r

~If a line break imposes high temperatures on the isolator and/or the connecting capillary lines, the isolator is displaced counterclockwise and actuates the low switch on the isolator (dependent upon initial position determined by pressure and transmitter loads) indicating the condition to operators. The low switch would typically be actuated at exposures of the order of 200°F. Isolator stop valve action would occur at sustained temperatures between 300°F and 350°F dependent on operating conditions. Higher temperatures could be . . tolerated for short durations owing to insulation and thermal mass of-the isolator structure. This presumes the system pressure is sufficient to maintain stibcooling, which would be true of normal service.

7-8. CALIBRATION

The hydraulic isolator is calibrated in volumetric displacements of cubic inches (or cm3), R~sistive forces associated with the volumes are available in factory data sheets. These resistive forces are important because they affect transmitter outputs. The impact of the resistive forces can be determined by first performing calibration checks of the filled system from the in-containment sensors and then performing the calibration checks from the d/P transmitters.

Volumetric calibrations are of secondary importance as these relate to switch operations. Total volumes are related to physical dimensions of the bellows and bellows travels, which are not field adjustable.

Scale calibrations (linkages) relative to volume may be 10 percent in error without impact on the system. Isolator displacements per.above, relative to factors such as transmitter displacements and pressure, should be observed to determine any need for calibration adjustments.

Volumetric checks of the scale calibration and switch settings should be made following instructions for transmitter calibration during plant shutdowns. To do this, sensors must be at some pressure or elevation head (to preclude air entry into the system) relative to transmitter access ports such that fill fluid may be added or deleted to displace the isolators. Following instructions for letdown and fill additions, isolators are to be exercised to low and

7-10

•

•

•

high switch point settings. Volume displacement is measured by hand pump stroke counts and observed dial readings (0.152 in.3 per stroke in Westinghouse recommended pump). Reference is to be made to specific pump manuals or measurement made if a different unit is used. This should be supplemented by observation of calibration fixture sight glass height and computed letdown water volumes.

Hydraulic isolator calibrationadjustments are not expected to be required· unless observable effects on system calibration from the sensors are noted at the transmitters. In this case, replacement maybe required.

7-9. HYDRAULIC ISOLATOR STATUS INDICATION

Switches on the hydraulic isolator provide warning when fill fluid volume displacements are outside normal operating margins. This warning may be as a result of one of the following:

1 Low fluid in transmitter/isolator capillary connection (high switch) .

1 High temperatures in isolator/c~pillary (transmitter side) areas (low switch)

Low fluid (transmitter connections) actuates the isolator high ~witch and conversely.

These warnings are related only to the transmitter side of the isolator and do not provide warnings of happenings affecting the sensor/isolator capillary system. Loss of pressure from in-containment capillary/sensor fluid loss and the like are principally detected by offscale dynamic head transmitter signals during normal operation. The isolator scale may indicate this loss of pressure communication·by virtue of transmitter displacements. The use of the scale readings for detecting such loss is dependent on confident knowledge of fill volume adequacy, ambient temperatures, and process pressures. If a pres-

_ sure is lost in the direction of normal overrange of the upper range instrument- (downscale), the isolator is displaced from the normal operating point an

[ Ja,c

amount equal to fluid compressibility (approximately in.3). For this

7-11

• reason, hydraulic isolator dial indications should be observed periodically and logged (and/or marked on glass cover) for trouble diagnosis. As a minimum, two ~eadings a few days apart should be taken following return to normaJ ope~ation after transmitter calibrations. This is to ehsure that the system is leaktight.

7-10.. TROUBLESHOOTING

The existence o~ a dynamic head signal and a no-alarm indication from iiolators is an indication that systems are available when called upon to measure vessel levels~ The isolator dial indication also provides information relative to fluid volumes in the transmitter/isolator fill section. The scale readings should remain constant under .normal operating conditions. Changes in readings observed at calibration check intervals should be accompanied by analysis to determine the cause, and appropriate corrections must be made .

•

Individual isolator readings, as well as totals, should be observed in determining the cause of changes in readings. Totals become important in isolating troubles associated with leakage or fluid transfers as a result of calibration equalizing. Volume adjustments are not required unless displacements actuate alarm switches. Leakage from the system is the most probable problem and would be evidenced as a time-dependent shift on only the affected isolator. The following should be noted:

t Dynamic head d/p transmitter reading normal

t Clockwise shift in one isolator reading indicates leakage to the connected transmitter (in which case the frequency of observation is increased)

t Count ere 1 ockwi se shift approximately [ J ~·~. 3 on upper range i nstrument indicates loss of pressure from sensor (when other two isolators at prior normal indication)

•

Should the dynamic head d/p signal be lost, the isolator . observed for counterclockwise shift per above indicative · (leak in sensor capillary). .

scale should be of a loss of pressure

7-12

•• L_

If leakage (continuing clockwise shift of tsolator) is evidenced,

• Access valve closure must be tightened

1 Observation continued

t Compression fittings in affected tubing runs must be tightened

If all isolators on a train have similar shifts, the probable cause is an ambient temperature effect (normal operating pressure). Sensitivity in this regard is low, being[ ]

8

i~.3;[];Fc typically •. (Spec.ific installation sensitivities may be examined per methods described above.).

Isolator volume indications should agree within plus or minus O. 1 in. 3 of theoretical values determined per paragraph 7-3 on a specific installation basis (water volume consideration). Operating margins may be adjusted if desired by adjusting water volumes with the PD hand pump. It is desired to maintain ~solator readings at zero plus or minus [ J~~. 3 to achieve highest system accuracies under reactor-coolant-pumps-off condition and low ambi~nt pressures (100 psig).

7-11 •. SENSOR AND PROCESS CONNECTIONS

The high pressure (HP) port of the hydraulic isolator is coupled to the process via a high volume 12-convolution bellows, sensor housing, and capillary tubing system. This section of the pressure comr11unication system is vacuum filled with deaerated water.

Asstirance that fill volumes are correct Js fundamental (along with minimal resistance forces) in assuring proper operation. Volume adjustments in transmitter sections of the system are based upon confidence that sensor capillary fill quantities remain constant from initial fills through service lifetimes .

7-13

• 7-12. FILL VOLUMES

For the sensor/isolator section fill fluid volumes are minimized to reduce thermal expansion effects on measurement accuracies. Total volumes are as follows:

• Isolator HP port [ J~,c 3 rn •

• Cap.illary [ Ja,c in.3/ft

• Sensor bellows .[ J~,c 3 rn.

• Containment penetration [ r·c 3 in. /ft piping (1/4 in. capillary)

a,c · A volume of [ ]cubic inches would be typical for a reactor head connection.

[ Ja,c

About cubic inches of this would be in containment and subject to accident environments.

7-13. SENSOR VOLUMETRIC DISPLACEMENT

The sensor provides for all thermal expansion of fill fluid from the transmitter, isolator capillaries, and the like into the reactor coolant system. Similarly, it displaces to compress all confined fluid to the transmitter in response to process pressure increases. The bellows have a cross section area

[ Ja,c 2 [ Ja,c [ Ja,c 3 [. Ja,c of in. .and travels8.~p to inch in compression (· in. ) and inch in expansion ([ J in.3). Resistance forces for these displacem~nts are shown in Figure 7-4. These resistive values are useful in analysis of net resistive changes in the system in conveyance of pressures and differential pressure to connected transmitters.

In the case of differential pressures, the resultant bellows res·tstance errors are related to differences between two sensors rather than specific sensor resistances. The unbalanced sensor resistance force would result from differ-

• ent capillary lengths subject to accident environmental temperatures. For the representative volume example above ( J~~.3) in cont~inment expansion woulo

7-14

•

•

introduce[Jai~chesof water resistance forces at 400°F. If the capillary length to the seal table. were 1/2 the length of the above, this connection

[ Ja,c

would .. experience expansion resistances of the order of . inches with a resul-tant unbalance force (error) of[ririches of water ([ ]p~rcent). Similar analysis may be performed for different installation designs to assess contributory environmental errors from this source. As per the example, the effects are expected to. be minimal, principally based on symmetry •

7-15

19,54 7-22

a,b,c

Figure 7-4. Resistance Forces for Disf)lacements

• 7-1,6

SECTION 8

MAINTENANCE INSTRUCTIONS USING TRANSMITTER ACCESS ASSEMBLY .

8-1. PURPOSE

The transmitter access assembly (TAA) (figure 8-1, Westinghouse drawing 2656C12) is connected to one port of each differential pressure transmitter associated with the Reactor Vessel Level Instrumenation System. ·When used in conjunction with.additional external equipment, it enables the performance of various operations associated with the installation, maintenance, and calibration of the system. It is utilized for the filling operation during istallation or maintenance, for the addition or deletion of water during_ installation and normal maintenance operation, and to facilitate calibration of the transmitters. The procedures of this chapter does not use the d/p transmitter bypass valves. The bypass valves should either be torqued (valve is ineffective for normal operation) or the valves rer®ved. For the purpose of these procedures, the bypass valves are assumed to be removed.

8-2. DESCRIPTION

8-1

a,c

']:) I

,"J

Figure 8-1. Assembly Drawing of the Transmitter Access Assembly (Drawing 2656C12)

a,c

co I w

Figure 8-2. Calibration Fixture

• a,c

lO

INSTALLATION'(FILLING OPERATION)

L 8-4. MAINTENANCE

If it is necessary to remove water or add water to the transmitter side of the . HI, this can be accomplished under normal operating conditions or shutdown conditions by utilizing the TAA in conjunction with external equipment and the calibration fixture. All other transmitters associated with the train bein9 maintained should be isolated from the process. The procedure of adding or eliminating water from the transmitter side of the HI is as follows.

8-5~ REMOVAL OF WATER (COUNTERCLOCKWISE HI INDICATION)

• 8-~

a,c

a,c

•

Figure 8-3. Transmitter, T AA, and Calibration Fixture

8-5

19,54 7-25

a,c

a,c

8-6. ADDITION OF WATER FOR CLOCKWISE HYDRAULIC ISOLATION INDICATION a,c

8-6

a,c

8-7. REFILLING (AFTER TRANSMITTER REPLACEMENT)

a,c

8-7

\

co I

co

• 19,54 7-26

a,c

•

Figt.tre 8-4. Transmitter Calibration

19,547-27

• a,c

•

Figure 8-5. Schematic Diagram of the Transmitter Fill Connection

• 8-10

B-8. CALIBRATION

Transmitter span calibration can be performed on the transmitter by utilizing the calibration fixture in conjunction with an external calibrated pressure source. Refer to figures B-6 and 8-7 for connections to the d/p transmitters. The procedure for performing the latter calibration check is as follows:

8-11

a~

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CD I

w

• • • Figure 8-6

CONFIGURATION FOR REPRESSURIZATION OF 0/P CELL SYSTEM

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• Figure 8-7

VALVE LINEUP FOR CALIBRATION OF D/P _ T~NSMITTER_. __

a,c

•

8-9. INSTRUCTION AND REPAIR PARTS FOR ENERPAC

The following four pages contain instructions and repair parts for ENERPAC.

8-10. .PROCEDURE FOR VACUUM FILLING SEALED LIQUID LEVEL MEASURING SYSTEMS

8-10.l Scope

This specification covers the requirements and procedures for onsite filling of sealed filled instrum~nt systems.

8-10.2 Material List

• Fill Bottle, 2 each {l spare) Pyrex 0.5 gal. (2 liter)

1 Vacuum Pump/Motor, 1 each Sar-Vac Model 8804-B (or equiv.) 115V 60 Hz Motor, Sargent Welch Scienftific Co.

1 Vacuum Gauge, leach 0-20 MM Hg. Hastings Raydist VT-48 {or equiv.)

• Vacuum Probe, 2 each (l spare) Hastings DV-4D metal (or equiv.)

1 Tygon Tubing, 2 each, length as required, 5/8" D.D. x 3/8" I.D.

8-15

a~

MODEL NO. 11·.00 :LL UST RA TED

WESTINGHOUSE PROPRIETARY CLASS 2 .

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S1a119d 11..,.. ""'• lncludtd in Rep.Or l(iu.,

W l~RTANT: '•.am •O ID111h.fttJ l1 •111en-fi1• Mil'! turn :A (P"luon An'y.J and""''' be ,.,,1..,"' ....,_' ..,.,.1'111on Au'Y..J1 Wul~

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11\:ST RUCTIC:~S

r = [ L ·~-~:!: :.~,- ,. :;01:1 :~·RE: l!.~~e" ': ~ 'rr - Re~~ a.?I ir.:1ru:~=c~: U•C r..::, ~-: ! ==-t I~~, ~r~:~, 1C ..:u· r'"'-'~~-

f L Ul C:S ,.. 91: :..r , .. -: 1: ~·r ":~ :;-rn !:l ::1:!'\•~:1 urel. TU;:~.c.i:.:;::tC'TIC': 110.c:: r:1111 :c.:~ r~1 ,,,:i:!chl CD,...~ul1 •" C"5·"U'"'~ "•'•c:'~r-"" 01 &ht •1.,.c1 ~•""!w1u1r1 ta '· T"'" pump orlt1>I' •1>l•1t l•IC'fll :!31 ca..n"·-clccl .... ••• 10

oi!,· cDm::1ut1•hl\' D! 1 1::irc1!1t llwid ID~ uHd. Any ol llW "opr"-PDliliDn l•;;i•c:ain:11rly one hnnl. lo ... .;ng l'lyC::a.,ltc fluid1 ""~ft~: 2. RrmDwr gland ""' Cl1cm 111 .,nd plyg liiem 701 l1Dm pump

"'· \".'aier body Ci1nn 211. I. Solublr Oil:'" ail-ln· ... lttt -•1iClll. 3. ln1Ar1 c:rw:I of model u.\ 11 lubing ln01 l:r.nilhrd wilh C. Jeuolnlfft. pump) th•ou;h holt in glal'd nu1 li&c:m Hll anc: a«urr ,,.;111 D. tmu~ion1. ~1cr ;..., 1lcri-1li1rm19A - •hipp~. wi1rd lD ilrm 191. c \~atrr·1•ycD1s. . · 4. '°'iliDn rrod ol tubint in di.ch.,tp port ol ~~:i body 1..c!

'olyS'ycol' tl'ane ..,.,h gland noi: l'inr-r·tjsh1J. :1c: Sorne U.,id&, 1uch n U•ont 1eid1 and sea""'"'·"'"'

,011otlr 1he chulr. b~lh !i1tr'" 72, 2t •nd 79 a•e lype ~•O ":.inlpu urrll. 1,, 1uch cam, ii i1 •C"commPnck-d 1h1I 1hr ch..ck ~•lh br 1&:pl1crd -. olltn 11 rr1111i•ed r11hu lhan 1yu1111111i,,g cht'ck l11lh of 1o:nr Dlhn m~e•ial

GAUGE lll:ST AL LAT ION • ANDA RC: Th11 mt1hod i1 i"trndrd 101 111pliu1iDn1 in·

"ohring \uridrn prr11u11t char>vn. i.1~ 1n1in9 10 d11u.,c1ion lbut11 tnnl.

-.1. Turn pump •r~aw • .i .. (ilrftl 331 counttt-clockwi.i to · ogen po.i1ion i1op1osim11rly one hnnl •.

. 2. Runo.e gland ftUt li1rm 271 and plug litrm 711. . 1 Rrm- t.'"91 li1rm !51 lrom modrl •3·70t 11"91' ldacnm

· &lu1n~ wi1h 9a11~niu:Pp.cl mod•I• ont-11 and irnert end ~ : .. •' ;""" ad•PIOll 1hraugh hDle in gland""' Iii ... Z7J. . · 4. ~epleu "'"' li1em !iSl on end al P'IF IJCIAPICll- ·- , 5. P'oMlior\ ci1twr rnd OI pillJI ConnftlOll (.1 .... 5-tJ ;n· Pu9'

pcwt of·s-nP body arod MIQl••wtth ~• llln;1t-19'&J, I. '1ac1 p..ova on it.. Dlhlf rnd of ""9f CCllWWC'IW lillftl ~I ~ W'nl•• .,,.,h ,,..., nul 1r..,..,.1ifl'ltl, No1c.· Alty ENCA,AC ulinW ""' puge of approptiala

- cacaeci1y can ~ uwd.. · 7. T .,naen both gi.nd nuu ..;1h r"fh1 I01n°IOPlitct10•11-i · ·--~ DO NOl OVER· TIGHTEN •

BURST TEST SET·UI": Thil wt-uo ihould br uwd w"-1'1...., 1ud~ ptftlUflt dt0$8 atf an1icipa1rd, i.1., lftling Ylt1Mll ID

:leluuction. 1. UY any ENERPAC tiatnll'ss ll"4 ,..,., of appropri111 ~aoecity, p1elrt1tlly·onr hl'fing • muimum i:idicat1ng poinurr.

. l; Ima.II flUll" • ~in Oi~am A. TI'f' shlla-olf """"· · nodet 72-750 tncr1 fwnit.bd ••h pumpl, pra11CU the 9a1ge · •gainil 1rcoil d1mep when 1hr tnl ""\ff '"P"""· For mut·"""' pio1K1ioa, the Attu1-aH nhe. thould ~ . neatly closed.

·· m CONNECTION 11D.000 P'!1......., antyt: l~ TU." pu'"° , .. ,_ .,.._. fi._ J:n eau"'.-odOck.i.oi. IO

·., •op1tn• posi1ion l~oaim•llly OM &uml.

P.UXILIARY RESERVOIR ""'"i~hrd by u.erl I. Rrrnowt 1esrnroir d11in ,,1.,9 li1em 81. 'JDir: Any fluid in 1rvnroi1 •••ill rvn oul ,,.,,.,, me rrservo1r d1ain pl.,9 ;, •rmowrd. 2. Connwcl aYailiary •flenroir to •rHnroir c!:a.n pon or;'"

N.P.T.I . IMPORTANT: r.~rp 1u1i•:a1y 1r1e1woir fluid :r·:r! ~!ow •op ol pump 1nrnoi1.

PRESSURE TESTING OF LARGE VESSELS 1. lnuaU 1 tH a:Mf itwl-Dll ..... ,,. 11 ihown ir. Di1gram 8 . CAUTION: '"tu•• all riningl, ...... and plumb-~; Ill •llrd IO wilh"and 1h1 lftUimum P•n•u•t whidl 1hi pi.-:-:.;i can d1vt· •• lcOMUh pump,..,.., p!url. The fluircl •upe>iy s'"'.n-olf walwe IVM.lr.l. bit insullrd ~·wards in ll'lr •uaili.iry f<!! Ii~ '° 11'\e

val• iNes pan ,wiu bl wbjK11td ui 1hc tiigh u·r. "'"""'n.. %. A~·OU"'P 1...,,-oir 141111 Plut fallrn 2J 1"1l:i lill pymp .~ with 1ftl fklid.

1 To liP ltsl wnut: ~ Tiarrt Uie SNlftP 1eluaa .. ~ lilrrn 331 ::. mu°'""m

ctock..t.e ·ciosed- po1i1ion lli"9'Migln:. I. Opm lluicl 1up;:1ty 11'.u.1-oll """' ''" 01191 ;,-n 1!11. C.. Wherl Int 9ftMI ii filltd, clDM fluid 1u~:r ~-..:: ·Oii walvt .

- 4. Ope•••• pump un1il d1i111! ''""" 01n1ut1 i1 dr..r•o::iPd. CAUTION: The Ouid 1u;iply \hul·all ulwr "'"II rc~arn clcnrd 11 all 1ime1du1inv1tw pieuurr tnL S. Aller 1n1 i1 complr1rd, open pump 1rlnu "'""t !ill"' JJI. WARNING; Check ptnMllP 91u9f 10 br 1u1r 1v1:1-: hydraulot P1ftWfe hu drop!Md 10 rrro brl0tr 1u1mour; i: drain IHI

"""' or disconnect pump.

~MP' O,ERATION: · l. TO PRESSURIZE THE SYSTEM: Tu1n ~umc. •Ofltnr valvt

(itwn 331 to ma.simwm clockwi\I ·c1ovd· pm.~i°" 1fin91•· ligh&J. Os-tall 1hr pump handle un1il 1tw dnr:rd 1yurm pansu1e is 1u~ o• oorr11ion is nNT1Dlr1rd.

_;... ~·A--. fYnct nus la\eNI 1S .-1 plwf li•illii 2fll. llGM IJ!iill'P. ··' :·-: .. · ~ body lit"" 2H.

"2. TO REUEVE PRE!SURE F-ROM THE SYSTEM: Turn . S*"'P ,...._,,,...._Iii"" 331 C11U111ft<IOCk_ .. to •open-

• pm;1ion laooioaimslely - 1t11nl. •. lnvn end ol mocNf 45-111 ,....,,. ,., lhrough hole in 11.Md ""' Citem 191 ...ct Mal•• wi1h ''"" 1.11m 11A -a.hipped, wirl'<I 10 ham 191.

•· P'0ti1;on end ol tubint in ditetia1gr PGrt ol pump body and ttevllt with gland nut lfinpt·tithtl.

.£ Aurmblr 1pp1opri111 pipe UutllCI Ml1;i1ar (9J 10 IN other 1nd ol the lubitMJ, - ·

""'· TighHn bolh 9l1nd null .M1h light force appliitd to 1 '1'1011 wrirnch. DO NOT OVER·TIGHTEN.

1 ··Aiied! l'lcne 1•1 ta p:pr 1hrud 1dap1m, ~.,,,, ind;ca1rd wilh • 1w l•l 111 no1 lurni~ ,..,;1h pump. CeMUlt c11alQ9 IOI gcnrral inlarm11ion and rnodrl num~"-

1 -Spongy• purt10 1C1ion indica1a 1ha1 lhtt1 i1···1Gmtwhtrt .. ;,. lhlt p.m111 Of ••&arnll hyd1euhc 1y11rm.

TO 11'\JlllGE AIR FROM P\Jl.u>:

:A- Open pump rrluH ""',,. lillm 331 • a. LooMn tlancl nul li1iim 271. C. Cloy p11mp reluw .,,1,,, litrm 3'31. 0. OprraH pump handlr 1,;n1il air i1 uprllll'd.. E. Ti;hirn gland nut wi1h ligh1 loocr on a 'hon .. :r1nch. F. 0.Kll pump o~ra11on. f;1pu11bo•1 procrdu~ ii nrcr11ar(. G. H pu1n9 Klion c:on&inun 10 fut ·1;:1angy. • b!rrd ,,.,, t»

1ttnal 1y111rn..

• . ,. .. -.. .··- J '•: 8-, (l : ... + .. • ... ·~-:-·""' ....• ·,. .... ':' ... ·- ._ ........ . ·~ •· ...... .... ·- .. ~

:·--· .• ,. . . . ~ ,;-.· , .· .. ,

:.

•• -·--··-· _..,_ ·-·--··--,

.. .; . '·. ....

""llH' : Anenoif OilVal- I Pinon ClL~ter Un.I Pinon Stroke (lnJ . R.aU.., IPS It i C.paciry hr Suoke ... 0 ta IQ,000 PSI i •S cu. in. .. 0. 152 cu. in. I a.soo in D.780 in. .. . - ~~·- I

. -· ~IO ol0,000 l'SI : •5 C11. in. ; . 0.031 i_n. . J G.250 in. 0.710 in. rs--,: .Ss-01 I

IMPORTANT - USE.R SAF~TY ANO PROTECTION In s,aR>ng uP s-,.1.er"s 10 hr yoyi opcra&ions.c:are mull .. •»en 10 u•Kl 1r .. PIOOll' compotWftll and desi9ft ID insuo• IPP'OP'~• 1nt19r11oon w11n )'OUf opetaltona •- HrSllf>9 e<;ui.pr.i&nl ano ll\at a{I ulely measur• a •. be9t lataen 1e aVOoO lt'le risll of penonet in;wy .._ property ""'89• hons ~ 1ppliuhon or ~- .•.·

ENEAPAC: CANNOT BE RESPONSIBLE FOR aarAAG! Oil INJURY CAUSED B'I' UNS~ USE. MAINTEH.:.HCE OR APPLICATION CF ITS PRODUCTS. Pleue cor.&ac1 ENERPAC JOI 9uidancr •her )":lu are in doubt u 10 tne props ultly prKau&oor.1 ~c be

'.ATS, StRVICE ...-, _ _.,.. - ,._ tNlll~&C

. '&. - e ,, ... _ llllUAC ....... c-,_ , .... _ , .• ...,, ......... ,....,., .... .....,~.c .. ...,..,... - _ .. l"l•~AC ,,_,,.,_. .... ............. ,_,_...,, ~ ..... ..... , ... K'll9lli • ,. • ., ,...,.. .... n111 ,..,. .... s.,..,.. c .....

·-. -:--;:.~.~3'.=··: !-~~";":1 .' . __ .. ~; .. · . . •: •.. ,. ~ . .,. · ........ ; ........ . .. -~ :~ ~~ .. :.:·'.·. ·~~ .'~. . .. - .. ,. ··: .. :. .

.. -r~ .: ..... .. ! ......

·""' ~ .. • • ,, :-:0

-· &aklin In ~rtnint and UftVlg up your p.ar. oc:JIW applialion ·

WARRANTY

CNr"•~·~ ·--• •• ..,.._, _ .... ......... -~ ........... _ ... .... , ... _ ............ ., . ..-. ~ ....... --... .......... , ..... - Ir•••• ..... ,.,-··· ... .. ••. •bv••· ~ ............ ew,.. e&.1•4 ,,,..,_,, .. • v•e .. r....,_;a,ee AWll&, .

8-19 : • .r.' ..

WARRANTY RETURN PROCEDURE .. _ ......... 9' ._.._,ct ......... L .... •NI

··- •- ·1111 - la - -- ~•lll•&C •·-&Ill .... S.n4c• ............ __ ~ .... ·- ~-.. -•• ... .,. •"'-••~-care•--n--.c•••c.••••.,... .. .,.. •• ,...; Siil' ••••••Y.,,.,. '••11e,.'••• S••-"f• Cu111., ... "1,,;Uil 011 atll'\..&C.l l".1.•rS •"ECtlD - '"'""' .,.--.

• t Tygon Tubing, 1 each, length as required, 3/8 11 O.D. x 1/4 11 I.D.

t Tubing Clamp, 8 each, screw type, C~ntral No. 12266 (or equiv~)

t Vacuum Pump Oil, 1 gal. Duo seal (or equiv.)

t Valves, 2 each, with 1/411 tubing at acne port

CAUTION

If pump does not start immediately, open switch. Remove pulley and belt guard and rotate pulley by hand 2 or 3 revolutions, replace guard and close switch again. After testing, turn pump off until needed.

8-10.3 Preparation

8-10.3.1 Vacuum Pump ~Fill with vacuum pump oil to midpoint on ~auge. During use, on water filled systems, oil should be changed w.hen level reaches top of gauge. (Oil becomes saturated with fluid, raising level). Connect pump and filling system together tygon tubing with clamps or lockwire to prevent air leakage. Close switch on pump motor to test operation.

8-10.3.2 Fill Bottle Preparation - With tygon tubing, connect as shown in figure 8-5. Tygon tubing should be as short as possible.

8-10.3.3 Fluid for Level Measuring System - Deaerate deminer~lized water by filling Pyrex storage bottle to 0.5 gallon mark (2 Hters) and boil 5 minutes. After boiling, cover with vented stopper and let cool to room temperature befor~ using.

8-20

8-10.4 FILLING OPERATION

NOTE

Th~ fill bottle must be at a higher elevation than the highest part of the 'system to be filled. This difference in elevation should be at least 2 feet, but should not exceed 20 feet. If the fill bottle must be placed below any part of the system, it may be necessary to pressurize the bottle to properly fill the system. If additional pressure is necessary after exposing the fill bottle to atmospheric pressure, apply pressure at vent, 1 psig per 2 fee~ elevation.

8-10.4. 1 Initial Settings - Open all valves associated with the fill kit except for the valves associated with the fill bottle. Vacuum gauge po-inter should be on middle calibration dot with gauge switch off. ·With switch on, gauge should indicate ATM.

8-10. 4. 2

of[ If pump

valves,

Evacuation of System - Start ]a~ [

vacuum pump and operate until vacuum , - Ja,c

or less is obtained. continues gurgling after 3 to 5 minutes, check all and vent on pump. All should be securely closed.

tube connections,

8-10.4.3 Vacuum Test - After desired vacuum has been attained (4 to 12 hours depending upon tubing length), test by closing valve to pump. System should maintain vacuum below[ ]~Hg for a period of l minute. If desired

[ Ja,c

vacuum cannot be attained or will not remain below mm Hg, cneck entire system for leaks. ·

NOTE

Moisture or leaks in tubing, system connections, and the like prevent attaining desired vacuum condition. Correction of condition is required before filling .

. 8-21

8-10.4.4 Filling System - To fill the system, close the valve to the pump and vacuum gauge tube and open the valve connecting the system to the fill

-bottle. When the water stops flowing, slowly open the valve associated with the bottle vent to allow atmospheric air to enter the fill bottle and force fluid into the system. With both valves associated with the fill bottle fully open, the system should be water solid. Do not permit the water level in the tubing to recede b~low the tygon tubing associated with the quick connects.

Close all valves associated with the fill system and the transmitter ~ccess assembly. Open the isolation valves associated with the transmitter and verify that the hydraulic isolator indication has not increased in a clockwise direction more than 0.1 cubic inch from its previous indication. The hydraulic isolator indicator reading should be recorded. Excessive_ change is indicative of air in the system.

If for some reason a tomplete system fill is not obtained and air has reentered the system, it is necessary to drain the system and the~ thoroughly dry by purging with dry nitrogen and repeating the evacuation process.

Verify correct operation by comparing the reactor vessel water levei indications with the indications from the redundant train.

Remove the fill system and calibration fixture. Replace the TAA quick connect plug covers.

8-22

• SECTION 9

RECOMMENDED SPARE PARTS LIST

·-

• 9-1

l.O I

N

• Equipment

a,c·

• REACTOR VESSEL LEVEL SYSTEM RECOM~IENDED SPARE PARTS

Description

0-Ring (Transmitter Cover)

D/P Transmitter, Full Range

D/P Transmitter, Dynamic Head (Dynamic)

DIP Transmitter, Upper Range (Plenum Level)

Hydraulic Isolator

Lens Glass Gasket, Lens Gasket, Nickel 0-Ring, Cover 0-Ring, Plug

High Volume Sensor

Sensor Bellows Assembly 0-Ring, Sensor Housing, EPT Back Up Ring, Sensor Housing, EPT Nickel Gasket

Part Number

• Recommended

Quantity

a,c

UJ I w

. Equipment a,c

REACTOR VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS

Description

0-Ring, Valve Seat, EPT, Sensor

0-Ring, Valve Seat, EPT, Sensor Fi.11 Valve Assembly Fill Valves Fill Valve, 0-Ring

1 0-Ring, Fill Valve, EPT, Back-up Valve Stem, Fill Valve Cap, Fill Valve

3/16• to 3/16 11 Capillary Weld Fittings

3/16" to 1/4• Capillary Weld Adapters

RTD (for 3/16• Capillary) RTD (for 1" Conduit Tubing) RTD (for 1" Conduit Tubing with

75' Lead Cable for under. Vessel Location)

Part Number

• Reco1T111ended

Quantity a,c

• Equipment

• REACTOR VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS

Description a,c

Ba 11 Seat/UllMWPE

0-Ring, Unif No. 012/Ethylene Propylene

0-Ring, Unif No. 020/Ethylene Propylene

Valve, 1/4 x 281

Packing, Graphite Asbestos/ARCO Packing No. 515

Packing/Lo Chloride

Part Number Recommended

Quantity a,c

"° I U"1

• Equipment

a,c

REACTOR VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS

Description

Recorder 24"-PAM 3 Pen Red Ink Cartridges-Box/4 Blue Ink Cartridges-Box/4 Green Ink Cartridges-Box/4 Stylus Spring Squeeze Bulb Ink Tube Stylus fuse 1.0 AMP - 5/box Pen Drive Assembly No. 1 Pen Drive Assembly No. 2 P·en Drive Assembly No. 3 ·servo Amplifier Assy. Wire Harness Assy. (3 pen) Trimpot (7K) Bulk Head Connector End Plate Assy (0-10 vdc) Chart Motor Assy.


Quantity

•

REACTOR VESSEL LEVEL SYSTEM RECOM~[NDED SPARE PARTS MICROPROCESSOR EQUIPMENT

Recommended

Des er ipt ion Part Number Quantity

TERMINATION M -2388A92H04 2388A60G03 DC/DC CONVERT -2388A61Hl6 5Al2Rl5-15 DAUGHTERBOARD -2388A60H02 6090Dl1G03 CONNECTOR -6090011H03 87160-9 CAPACITOR -6090Dl 1H04 452-650BlA104K CAPACITOR -6090Dl 1H05 452-650B1Al06K l

CAPACITOR -6090Dl1H06 452-910BlC104K l .

I. C. -6090011H07 TL074BCJ I. c. -6090Dl1H08 AD581J RESISTOR -6090Dl1Hl4 8El6AlOK RESISTOR -G090D 11H16 GNL-5Cl00 TRANSISTOR -6090Dll Hl8 2N2222A TRANSORB -6090Dl1Hl9 1N6042A DIODE -6090DllH25 .F300 2 CAPACITOR -6090Dl 1H2G TT25XlOOB l -

CONN MOD ASSY -2388A60H07 3381C75G01 l .

CONNECTOR -3381C75H02 2VH43/1AE5 l TERMINAL BLOC -2388A60H08 RSBGSP221601NNN 2 TERMINATION M -2388A60G05 2388A60G05 1 CAPACITOR -2388A61H05 452-6308lA1061~ 1 RESISTOR -2388AG1H08 ~16A50 l FUSE -2388A6 l Hl l AGX 1/10 5 CONN MOD ASSY -2388A60H07 3381C75G01 1 TERMINAL BLOC -2388A60H08 RSB6SP22160 lNNN POWER SUPPLY -1065E32Hl5 RSl2N9 FAN . -6087055Hl 1 8500P RELAY, -6087D55Hl4 KHU17Dll-12V

9-6

REACTOR VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS MICROPROCESSOR EQUIPMENT (Cont.)

Recommended Description Part Number Quantity

FILTER, PWR LI -6087DSSH15 3Rl POWER SUPPLY -6087D55H17 RT151 5 AMP FUSE -6087DSSH19 MDXS CPU BD.ASSY -6087DSSH20 2388A45G01 RESISTOR PACK -2388A45H06 SBC902 MEM UTIL BD A -6087D55H21 6090D61G01 MEMORY, RANDOM ·-6090061H04 ER3400 CAPACITOR -609006 lHOS SXK333 HEX INVERTER -6090D61H06 SN74LS04J 4 BIT, BIDIREC -6090D61H07 08226 NAND GATE, 1-1 -6090D61H08 SN74LS133DC

• NANO GATE, 4-2 -6090D61Hl0 74LSOOJ HEX TRIG INV -6090D61H12 SN74LS14J BINARY COUNTER -6090D61H14 SN7493AJ QUAD COMPARAT -6090DG1H16 LM339J TRI-STATE BUF -6090D61Hl7 SN7425J TIMER -6090DG 1H 18 LM555 4 BIT COUNTER .:6090D61H19 SN74193J POWER SUPPLY -6090D61H20 VKSR15-15 DIODE -6090D61H24 IN4735 I.C. 14 PIN D -6090D61H25 SN74LS74AJ DECODER -6090D6 lH26 03205 l

RESISTOR PACK -6090D61H27 4310R-101-472 1 INVERTER, HEX -6090D61H34 SN74S05J PERIPHERAL I/ -6090D61H39 C8255A 1

SWITCH -6090061H40 76S808 1 DUAL INPUT NO -6090D61H42 SN7433J 1 MULTI VIBRATOR · ..;6090D61H43 SN74LS221J 1

QUAD DUAL INP -6090D61H44 sra4sooJ

• DRIVER -6090061H45 ULN2003Atl

9-7

• REACTOR VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS MICROPROCESSOR EQUIPMENT (Cont.)

Recommended

Description Part Number Quantity

INVERTER, HEX -6090D61H46 SN74S04J 1

NANO, 8 INPUT -6090D61H47 SN84S30J 1

SWITCH -6090D61H48 T02-121

EXP BD, MEMORY -6087D55H22 2388A46G01 1

EXP BD, 4 CHAN -6087D55H23 2388A47G01 I/0 BO ASSY -6087055H24 2388A49G01

I/0 EXPANSION -6087D55H25 2388A50G01 1

D/A CONVERTER -6087D55H26 2388A48G01

·DISPLAY -6087D55H27 3600-02-040

FILTER -6087D55H28 25383-07 S~IITCH .;6087D55H30 AML21FBA2DA 1

• LED IND-RED -6087D55H32 249-7871-3331-504 . l

LED IND-GREEN -6087D55H33 249-7871-3332-504 LED IND-YELLOW -6087D55H34 249-7871-3333-504 SWITCH, TOGGL -6087D55H35 AML33EBA4AA01 SWITCH, TOGGL -6087D55H36 5-51115-501 SH ITCH, TOGGL -6087D55H37 740l-J21-Z-Q-E SWITCH, THUMB -6087055H38 8078-2 SWITCH, THUMB -6087D55H39 8874-1

SWITCH, PUSH B -6087D55H64 AML21CBA2AA

LAMP -6087D55H77 AML91LA73

MOV -6087DSSH80 V150LA208 DIODE -6087D55HB2 1N914 1

TRANSLATOR AS -1065E32H22 6090D40G02 1 FILTER -6090D40H07 lEFl 1

FUSE -6090D40H09 AG Cl 1

CONNECTOR -6090D40H10 3303

BOARD ASSY -6090D40Hl2 1065E28G02 CAPACITOR -1065E28H09 452-65081Al04K 6

• CAPACITOR -1065E28Hl0 CMOSFD 1 O l J03 2

9-8

• REACTO~ VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS MICROPROCESSOR EQUIPMENT (Cont.)

Recommended

Des er ipt ion Part Number Quantity

CAPACITOR -1065E28Hll CM06FD102J03 1 DIODE -1065E28Hl2 1N4148 2 TRANS ORB -1065E28Hl3 ICT-5 1

. POWER SUPPLY -1065E28Hl4 MP15.300212.150 1 MOY -1065E28H15 V150LA20B VARISTOR -1065E28H16 V575LABOB I.c. -1065E28H23 HCPL-2601 3 I.c. -1065E28H24 MC1489L 1 J.C. -1065E28H25 MC1488L POWER SUPPLY -1065E28H26 MP545902 INTEG CIRCUIT -l065E28H27 SN74132J TRANSORB (15V) -1065E28H29 ICT-15C HEADER ASSY -l065E28H32 87216-4 2 TRANSLATOR AS -1065E32H23 1065E28G01 TRANS ORB -1065E28Hl3 ICT-5 l ' . '

POWER SUPPLY -1065E28H14 MPl.5.300212.150 1

MOV -1065E28Hl5 Vl50LA20B 1

VARISTOR -l065E28Hl6 V575LABOB l

J.C. -l065E28H21 AM26LS30DC

J.C. -l065E28H22 AM26LS32DC POWER SUPPLY -l065E28H26 MP.545902 INTEG CIRCUIT -l065E28H27 SN74132J l TRANS ORB -1065E28H28 I CT-BC 2 HEADER ASSY -l065E28H32 87216-4 l

• 9-9

• REACTOR VESSEL LEVEL SYSTEM RECOMMrnDED SPARE PARTS MICROPROCESSOR EQUIPMENT (Cont.)

Recommended

Description Part Number Quantity

FILTER, PWR LI -1065E32H26 3Rl 1

FUSE BLOCK -1065E32H27 4396

FUSE -1065E32H28 GLHlO 1

DISPLAY -6090D08H02 25291-02 1

POWER SUPPLY .. -6090D08H03 3096-22

FILTER. AMBER -6090D08H04 24511-01

SWITCH. TOGGL -6090008HOG AML33EBA4AA01 1

SWITCH -6090008H07 AML21FBA20A 1

SWITCH, PUSH B -6090D08H08 AML21CBA2AA 1

LAMP -6090D08H09 AML91LA73

POWER SUPPLY -6090008H30 81-12-215-1 1

~OWER SUPPLY -6090008H31 MPI-5, 300/2-12-150· l

FAN -6090008~:3 2 8500P FILTER, PWR LI -6090008H37 3Rl

FUSEHOLOER -6090008H38 HKl FUSE -6090D08H39 3AG312005 cormECTOR -6090008H41 OC375 l

INTERFACE 80 -6090008H42 2388A42G01 1

TRANSORB (15V) -2388A42H04 ICT-15C l

SEE I CT-BC -2388A42H05 ICTBC 1

CAPACITOR -2388A42H06 C77CC104M 1

RESISTOR PACK -2388A42H09 4310R-101-472 l

ENCODER, 8-3 L -2388A42Hl 1 SN74148J l

QUAD 2 INPUT -2388A42Hl 2 SN7408J l

RELAY -6090D08H60 KHU17Dll-12V l

CONNECTOR -l065E32H40 583717-7 BURNDY PLUG -10G5E32H50 G6Fl822SNH

• 9-10

·- REACTOR VESSEL LEVEL SYSTEM RECOMMENDED SPARE PARTS MICROPROCESSOR EQUIPM.ENT (Cont.)

Recommended Description Part Number Quantity

CONNECTOR -1065E32H58 583717-7 PWB ASSY, SIG -6090D38H03 6090D04G01 l HEADER -6090D04H03 87593-9 . 2 HEADER 87346-2 l PWB ASSY PWR BD 6090D06G01 CONNECTOR 2VH15/1AE5 HEADER 87593-9 UNIV TERM MOD -2388A92H02 2388A60G02 DIG I/O BD -2388A60H01 1065E47G01 CAPACITOR -1065E47H04 683J04MF700 3 CAPACITOR -1065E47H05 452-91081Cl04K l CAPACITOR -1065E47H06 M39006/09-4286 FUSE -1065E47H07 AGC2.5 l

FUSE CLIP -1065E47H08 122090 l CHOKE -1065E47HOS 5256

-DIODE -1065E47Hl0 1N5404 l

DC-DC CONVERT -1065E47H11 3A12R15-15 1 CONNECTOR -l065E47Hl2 87982-8 2 RECEPTACLE -1065E47Hl3 87105-1 10

TRANS ORB -l065E47H14 ICTE-15C l CONN MOD ASSY -2388A60H07 3381C75G01 ·1 CONNECTOR -33BlC75H02 2VH43/1AE5 l

TERMINAL BLOC -2388A60H08 RSB6SP22 l60 l NNti 2 CONNECTOR -6090D59H03 87160-9 3

CAPACITOR -6090D59H04 CW15C103K l DIODE ~6090D59H05 1N645 I.C. -6090D59H06 HCPL-2601 RESISTOR -6090D59H07 RCR32Gl82JS RESISTOR -6090D59H08 RN60Dl001F ••

9-11

• REACTOR VESSEL LEVEL SYSTEM RECOMti:NDED SPARE PARTS MICROPROCESSOR EQUIPMENT (Cont.)

Description Part Number

Recommended Quantity

DC/DC CONVERT -6090D59H09

CONNECTOR -6090D56H04

DIODE -6090D56H05

RELAY -6090D56H06 . TERMINATION M -2388A92H03

RECEPTACLE -l065E47Hl3 TRANSORB (15V -1065E47Hl4 TRANSORB (lSV -1065E47Hl5 CONN MOD ASSY -2388A60H07 TERMINAL BLOC -2388A60H08

9-12

3Al2R5 87233-9 1N645 922Al2C4C 2388A60G01 87105-1 ICT-lSC. ICT-lSC 3381C75G01 RS86SP221601Nl4N

l

l

l

l

•

•

SECTION 10

RECOMMENDED MAINTENANCE AND TEST EQUIPMENT

The recommended maintenance and test equipment are presented in tables 10-1 and 10-2 and figures 10-1 through 10-3 •

10-1

•

•

Equipment

Differential pressure transmitters

Hydraulic isolators

High volume sensors

TABLE 10-1

SERVICE AND TESTING EQUIP~[Nl

Oescr ipt ion

Removal Transmitter Calibration Fixture

·Texas Instrument Precision Pressure Test Set (or equivalent)

Tool Kit for Hydraulic Isolator (d/P Switches)

Test Fitting, Fill Valve

Wrench Be 11 ow s Spacer Assemblies Test Fitting, Sensor

Cap i 11 ary Test Fitting, Sensor Pipe

(Bench Testing) Test Fitting, 3/16 0.0.

Capillary Tubing Adaptor, Seal Plug, Sensor

Bellows Assy

10-2


Quantity a,c

TABLE 10-2

MATERIALS NEEDED FOR VACUUM FILL OF CAPILLARY TUBING

Description Part No. or Model

Equipment

Vacuum Pump, Sargent-Welch Scientific Co., Sar-Vac ·Model 8804-B, llSV, 60HZ Motor

Hydraulic Hand Pump, Enerpac Model 11-100, 0-3000 PSIG, _with Pressure Gage and 8 ft. Hydrau 1 ic Hose

Vacuum Gage, Hastings Raydist, 0-20 MM Hg., Expanded Scale with

·6 Detector Tubes #DV-4D

Fluke Model 8600A Multimeter

Vacuum Probes, Hastings DV-40 Metal

Wallace & Tiernan Suitcase Calibration STD (or equivalent)

Fill Bottles, 1 Gallon Capacity, Fisher

3/8" Tubing Clamps, Screw Type

3/8" Tubing Tees

3/8" Vacuum Valves (Plug Valves)

10-3


a,t:

•

•

TABLE 10-2 (cont)


Description Part No. or Model ·

Equipment

Pneumatic type gas compressor (optional)

Pressure regulator set for dry nitrogen bottle (leak check approx 2500 psi)

Vacuum hose

Tygon tubing

Tygon tubing

Valves, with 1/4" tubing at both ports

Vacuum pump oil

Tank dry nitrogen

Roll lock wire

Reactor coolant grade quality demineralized water

l 0-4


a,_c

L

TABLE 10-2 (cont)


Description Part No. or Model

Consumables (cont)

Bubble Type Leak Detector Fluid Triton X-100

Sound power- or equivalent communication system

Hot plate for deaeration of water (or carboy suitable for vacuum degassing)

Temporary power 117 vac for pumps and vacuum gages

Instrument quality air supply (for calibration)

10-5


a,c

19,54 7-28 a,c

•

Figure 10-1. Tools and Test Fittings for Onsite Servicing

10-6

19.S4 7-29

•

a,c

•

• Figure 10-2. Adapter Seal Plug

10-7

_, 0 I

CJ

• •

Figure 10-3. Fill Valve Instructions

• a,c

-I

·-SECTION 11

DRAWINGS

ll-1

REACTOR LEVEL INSTRUMENTATION DRAWING AtlD SCHEMATIC LISTING

DRAWING OR

TITLE/DESCRIPTION TYPE OF DRAWING DOCUMENT NO. a,c

• 11-2

• REACTOR LEVEL ltlSTRUMENTAT ION DRAWING AND SCHEMATIC LISTING

DRAWING OR

TITLE/DESCRIPTION TYPE OF DRAWING DOCUMENT NO. a,c

•

11-3

• REACTOR LEVEL INSTRUMENTATION DRAWING AND SCHEMATIC LISTING

TITLE/DESCRIPTION

11-4

DRAWING OR TYPE OF DRAWING DOCUMENT NO.

a,c

SECTION 12

EQUIPMENT INSTRUCTION MANUALS

•

12- l

•

I

l

INSTRUCTION MANUALS

MANUAL DESCRIPTION

Post Accident Monitoring Recorder

Vessel Level Monitoring System (Microprocessor)

Model 752 Differential Pressure Electronic Transmitter-Technical Manual (Installation and Operation)

Model 581 Hydraulic Isolator

Model 353 High Valve Sensor

Instrument Valves -- 1/4 x 281

Root Valves -- 3/4 T 78

Minco RTD

Transmitter Access Assembly

12-2

MANUAL NO.

I. B. 104-605

9002-VLM-001

79C2

81J4

81G3

DOCUMENT ORIGIN

Westinghouse

Westinghouse

ITT Barton

ITT Barton

ITT Barton

Autoclave

RockwellEdward

Minco

Autoclave

westinghouse class 3 reactor vessel level …

Documents