flowcheck user manual

8/10/2019 FlowCheck User Manual

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FlowCheck 3.0 User Manual

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Copyright

Kenonic Controls, Division of Emerson Electric Canada Limited

7175 12th Street SE Calgary, Alberta, Canada T2H 2S6

Telephone +1(403) 258-6234 Fax +1(403) 258-6201

Acknowledgements

AGA holds the copyright for some of the code in this product.

Mr. Warren Peterson is the author of a significant amount of theFlowCheck code.


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Table of Contents

Using This Manual ............................................................................................ 1

About the Icons ................................................................................................................ 1Program Operation.......................................................................................................1Special Attention...........................................................................................................1Reference Information................................................................................................. 1

Installation..........................................................................................................2

Installing FlowCheck........................................................................................................2

Uninstalling FlowCheck................................................................................................... 3

Registration ........................................................................................................4

Evaluation Run Mode ...................................................................................................... 5

Register FlowCheck..........................................................................................................5

How to Contact Us........................................................................................................... 7

Compatibility...................................................................................................... 8

Program Overview.............................................................................................. 9

Program Capabilities........................................................................................ 10

Supported Fluids.............................................................................................................10

Orifice Meters..................................................................................................................11

Turbine, Ultrasonic and PD Meters ............................................................................. 12

Flow Nozzles ...................................................................................................................12

Other Meters....................................................................................................................12

Pipe Provers.....................................................................................................................12

Basic Procedures .............................................................................................. 13

Program Startup..............................................................................................................13

General Navigation.........................................................................................................13

Detail View.......................................................................................................................14

FlowCheck Property Settings Window........................................................................14

Precision ...........................................................................................................................15

Display Units ...................................................................................................................15

Sound................................................................................................................................16

Selecting Meters and Fluids...........................................................................................16


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Working With Files .......................................................................................... 17

Performing Calculations.................................................................................................17

Viewing Results ............................................................................................................... 18

Printing.............................................................................................................................19

Copying Results............................................................................................................... 19

Meter Settings .................................................................................................. 20

Meter Settings Common to Most Types .....................................................................20

Calculation Results..........................................................................................................21

Orifice Meter ...................................................................................................................21

Pressure Settings..............................................................................................................23Thermal Corrections for Pipe and Plate Diameters .............................................. 24

Turbine Meters ............................................................................................................ 24Turbine Meter Settings............................................................................................... 25

Optional Turbine Meter Settings..............................................................................26

Pipe Provers.....................................................................................................................26

Prover Settings ............................................................................................................26Pipeline Volume Settings ...........................................................................................27

Elbow Meters ..................................................................................................................28

V-Cone Meters ................................................................................................................ 29

Nozzles.............................................................................................................................31

Fluid Settings ................................................................................................... 33

Fluid Selection .................................................................................................................33

Natural Gas Settings .......................................................................................................34

Detailed Composition Settings .....................................................................................35

Wet Gas Support............................................................................................................. 36

Isentropic Exponent and Viscosity ..........................................................................37Gross Volumetric Heating Value .............................................................................37Gas Density Equations ..............................................................................................39Liquid Hydrocarbon Settings ....................................................................................42

Tools................................................................................................................. 48

Inspection Form..............................................................................................................48

Gravity and Atmosphere................................................................................................49Fuel Gas Estimates .....................................................................................................50Engine Fuel Gas Estimates .......................................................................................50

Line Heater Fuel Gas Estimates ...............................................................................52Treater Fuel Gas Estimates ....................................................................................... 53

Unit Converters...............................................................................................................54


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Units and Conversion Factors.......................................................................... 55

Overview ..........................................................................................................................55

Data Sources....................................................................................................................55

Glossary ............................................................................................................ 57

Error Messages................................................................................................. 77

General Alarms................................................................................................................77

Copy Protection Alarms ................................................................................................77

Software License Agreement............................................................................ 79


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List of Figures

Figure 1 - FlowCheck Registration Dialog .........................................................................4

Figure 2 - Site Key Request Form........................................................................................5

Figure 3 - FlowCheck Dialog................................................................................................6

Figure 4 - Registration Completed Dialog..........................................................................7Figure 5 - Table of Fluid Calculations...............................................................................11

Figure 6 - Summary View....................................................................................................13Figure 7 - Detail View..........................................................................................................14

Figure 8 - FlowCheck Property Settings Window...........................................................15Figure 9 - Units of Measure Window................................................................................16Figure 10 - Detail View Showing Results .........................................................................18Figure 11 - Table of Print Options....................................................................................19Figure 12 - Table of Flowing Conditions .........................................................................20

Figure 13 - Orifice Meter Selections..................................................................................22

Figure 14 - Turbine Meter Settings....................................................................................25Figure 15 - Pipe Prover Settings.........................................................................................27Figure 16 - Elbow Meter Settings ......................................................................................29Figure 17 - V-Cone Meter Settings....................................................................................30Figure 18 - Natural Gas Settings ........................................................................................36Figure 19 - Table of GPA 2172 and AGA 5 Constants .................................................38Figure 20 - Engineering and Thermodynamic Values ....................................................42Figure 21 - Corrections for Temperature and Pressure..................................................43Figure 22 - Hydrocarbon Liquid (NGL) Settings............................................................44Figure 23 - Table 23E and 24E Coverage.........................................................................45

Figure 24 - Table 53 Coverage ...........................................................................................46Figure 25 - Table 54 Coverage ...........................................................................................46

Figure 26 - Water Settings...................................................................................................47Figure 27 - Inspection Form...............................................................................................48Figure 28 - Gravity and Atmosphere.................................................................................49Figure 29 - Engine Fuel Gas Estimates ............................................................................51Figure 30 - Line Heater Fuel Gas Estimates ....................................................................52Figure 31 - Treater Fuel Gas Estimates ............................................................................53Figure 32 - Unit Converter..................................................................................................54

Figure 33 - Table of Unit Conversions .............................................................................56Figure 34 - Table of Typical Values for Absolute Viscosity .......................................... 57

Figure 35 - Table of Temperature Coeffiecients for Pipe ..............................................60

Figure 36 - Table of Modulus of Elasticity.......................................................................71


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Using This Manual

Flow measurement calculations can be tricky, even for experiencedengineers and technicians. Meters, fluids, and flow computers can becombined in many ways. FlowCheck was designed to support as manyof these combinations as possible in a way that does not overwhelm theusers. By using this manual, the user can develop an understanding ofthe program and its features which then enables to user to make goodflow measurement calculations.

About the Icons

An icon next to a topic heading in this user manual means that the topichas special significance or contains background information.

Program Operation

Information for running the program.

Special Attention

Critical information necessary for accurate results.

Reference Information

Background information on the topic.


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Installation

The FlowCheck installation package is distributed over the World WideWeb or via CD. Review the installation instructions for either installationoption.

Installing FlowCheck

Read the Release Notes for information not present in the manualbefore installing FlowCheck.

To install FlowCheck from CD:

1. On the Start menu, click Run. The Run window appears.

2. Click the Browsebutton to navigate to the setup.exeon yourCD drive.

3. On the Run window, click OK. The install procedure will begin.

4. Follow the on-screen instructions.

When installation is complete, the FlowCheck icon is placed in the usersWindows Start menu.

To install FlowCheck from the Web:

1. Run the compressed file named fch30c.exe or similar, which is aself-extracting program file with FlowChecks setup files bundledinside.

2.A pop-up screen prompts the user to specify where the files canbe unzipped (for example, C:\windows\temp).

3.When the files are unzipped, on the Start menu, click Run. The

Run window appears.4. Click the Browsebutton to navigate to the setup.exe(from the

unzip folder specified in step 2).

5.When the install procedure begins, follow the on-screeninstructions.


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6.When installation is complete, the FlowCheck can be accessed viathe Windows Start menu.

Setup.exe automatically associates FlowCheck user files (.fch) with

the program and its icon. Double-click a FlowCheck data file to launchthe program with the file data loaded.

Uninstalling FlowCheck

In the majority of cases, the user can re-install or upgrade FlowCheckwithout requesting a new site key. It is possible to re-install FlowCheckat any time, to any directory on the hard disk that was used duringprogram registration.

For example, install the program to C:\program files\flowcheck orC:\measure\flowcheck and use the same registration data.

If the user moves the program to a different hard disk or logicalpartition, FlowCheck reverts to the evaluation mode.

If the user chooses to re-install FlowCheck to the original disk, it is bestto re-use the original registration data. Unless the user has re-formattedthe hard disk, the registration data will continue to work.

To remove FlowCheck:

1. From the Start menu, click the Settings button.

2. Click Control Panel, then double-clickAdd/RemovePrograms.

3. Follow the onscreen instructions for finding and removing thesoftware.


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Registration

Registration is a simple, one-time event for unlocking the full range ofprogram functions, including file saving and printing.

Before registering, the user can run FlowCheck in evaluation mode,whereby a registration dialog box appears each time the programlaunches. The user can either enter the registration data, or continueusing evaluation mode.

Note: Certain FlowCheck functions are enabled only through purchase andregistration.

Figure 1 - FlowCheck Registration Dialog


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Evaluation Run Mode

FlowCheck users can use the evaluation run mode in one of thefollowing scenarios:

while evaluating the features of FlowCheck while registering an additional copy under an existing corporate

license

Register FlowCheck

To register a copy of FlowCheck 3.0, request a site key and customerservice number from Kenonic Controls.

1. On the Helpmenu, click Registration, and then click Register

Now...The FlowCheck Registration dialog box appears, asshown in Figure 1.

2. Click the Request Site Keybutton. The Site Key Request Formappears, as shown in Figure 2.

Figure 2 - Site Key Request Form


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3. Enter data in all of the fields.

4. Click the Save Form to Filebutton. A FlowCheck dialog boxappears showing the path to where the copy of the registrationdocument has been saved, as shown in Figure 3.

Figure 3 - FlowCheck Dialog

5. Make a note of the path to the SITEKEY.TXT file, as it is

displayed on the FlowCheck dialog box.Note: The SiteKey.txt file is a plain text file .

6. Navigate to the file and print it out.

7. Fax the printout to Emerson Process Management, KenonicControls Division, at (403) 258-6201.

8. Kenonic Controls processes the application. A site key andcustomer service number for FlowCheck 3.0 will be sent to theuser.

After the user receives a site key and customer service number fromKenonic Controls, the registration process can be completed.

1. On the Helpmenu, click Register, and then click RegisterNow...The FlowCheck Registration dialog box appears, asshown in Figure 1.

2. Enter the site key in the Site Key field.

Note: The Site Key field is not case-sensi tive.

3. Enter the customer service number in the Customer Service #field.

4. Click the Register Nowbutton. A FlowCheck 3 dialog boxappears, as shown in Figure 4.


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Figure 4 - Registration Completed Dialog

5. Click the OKbutton to close the FlowCheck 3 dialog box.

6. FlowCheck 3.0 is now registered.

Note: Save the registration data for future reference.

How to Contact Us

To get support for registering or using a copy of FlowCheck 3.0, contactKenonic Controls via phone or e-mail:

FlowCheck SupportEmerson Process ManagementKenonic Controls DivisionPhone: (403) 258-6234Fax: (403) 258-6201E-mail: [email protected]


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Compatibility

FlowCheck runs under Windows 95 and Windows NT 4.0 (or later).Other operating systems such as MS-DOS, OS/2, or Windows 3.x arenot supported.

FlowCheck is designed to operate from a local hard disk. Although theuser can install or run the program while connected to a local areanetwork, do not install FlowCheck to a network volume.

FlowCheck is safe in a corporate computing environment for thefollowing reasons:

uses only standard C, C++, and Microsoft library functions makes no direct calls to hardware or the computers bios

makes no contact with third-party libraries, drivers, or network access

requires modest disk space

requires a small in-memory footprint and Windows resource load


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Program Overview

FlowCheck is a tool for users who specialize in gas and liquid petroleummeasurement, electronic flow measurement (EFM) and work withelectronic flow computers. FlowCheck combines a thoroughly-testedflow calculator with utilities for verifying instruments in the field oroffice.

FlowCheck is produced and supported by Kenonic Controls of Calgary,Alberta, Canada, an engineering company with a long history ofmeasurement expertise.

A number of valuable utilities are contained in the program, including ameasurement unit converter. FlowCheck can also perform reliableestimates of wet gas properties, combustion products, and fuel gasquantities for engines, line heaters, and treaters.


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Program Capabilities

FlowCheck solves many industry-standard equations used by the energyindustry to compute the flow of hydrocarbon gases or liquids throughorifice meters, turbine meters, flow nozzles, ultrasonic meters, V-conemeters, elbow meters, and pipe provers.

The user interface is optimized for field notebook computers. The menusystem, dialogs, and output windows are clear and simple. Bothkeyboard and mouse operations are fully supported.

FlowCheck supports SI units, metric units, and a wide variety oftraditional US units of measure. Unit preferences may be saved forfuture re-use. A unit conversion utility is included with the program.

FlowCheck provides freedom to experiment with different meterconfigurations and operating conditions but disallows situations

which could produce incorrect answers or system faults.

FlowCheck can store and recall information using files or printcalculation reports. The copy and paste function allows users totransfer results to programs such as Excel.

FlowCheck employs an unobtrusive form of security to protect

against unauthorized copying.

Supported Fluids

One of FlowChecks strengths is its emphasis on hydrocarbons.FlowCheck supports the following fluid types for all meter types:

1. natural gas

2. natural gas liquids (NGL)

3. crude oil and condensate4. gasoline and napthene

5. jet fuel and kerosene


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6. diesel fuel and fuel oil

7.water

8. lube oil

Note: Air can be calculated by selecting Natural Gas, and then list ing thecomposition of air in the FlowCheck Property Settings window.

The following table (Figure 5) describes the basis of the fluidcalculations.

Calculation Reference Standard

Natural gascompressibility andthermodynamicproperties

FlowCheck supports several equations of state, including AGA8 (1985 and 1994 editions), Redlich Kwong (with or withoutWichert-Aziz sour gas corrections), and NX-19. FlowCheckalso supports the velocity of sound and thermodynamicproperties calculations in for natural gas

Liquid hydrocarbontemperature correction

FlowCheck supports the following API temperaturecorrections:

Tables 53 and 54, solved by equation or look-up tables

Tables 23 and 24, supported by look-up tables

Tables 53A, 53B, 54A, and 54B, solved by equation

Tables 53D and 54 D, solved by equation. For moreinformation, refer to Figure 21.

Tables 23E and 24E, solved by equation

Liquid hydrocarbonpressure corrections

Calculated via API MPMS Chapters 11.2.1M and 11.2.2M. Forhigh-pressure measurements, FlowCheck computes base

density using an algorithm that simultaneously solves fordensity, compressibility, and vapor pressure.

Vapor Pressure Calculated with the GPA vapor pressure equation, TP-15.

Figure 5 - Table of Fluid Calculations

Orifice Meters

FlowCheck supports the following equations for flange-tapped orificemeters:

1.AGA 3 (1990), also known as ANSI/API 2530

2.AGA 3 (1985)

3. ISO-5167 (1991)

4. ISO-5167 (1998)


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Turbine, Ultrasonic and PD Meters

FlowCheck applies the following equations to turbine, PD or ultrasonicmeters:

1.AGA 7 (1996) for gas

2.API Chapter 12.2 for liquids

Flow Nozzles

FlowCheck applies the following equations to flow nozzles:

1. ISA 1932 nozzles for gas

2. ISA venturi tubes for gas

3.ASME/ANSI MFC-7M for critical flow nozzles for gas

4. Long radius nozzles

5.Thick orifice plates

Other Meters

FlowCheck supports the following additional meters:

1.V-Cone meter for gas or liquids2. Elbow meters for gas or liquids

Pipe Provers

FlowCheck can also validate calculations for conventional, ball-type pipeprovers with an API-compliant set of calculations. The pipe proversoftware can also be used to estimate the volume of gas or liquid withina pipe or other cylindrical vessel. For more information, see PipeProvers, page 26.


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Basic Procedures

Procedures for FlowCheck are similar to those of other Windowsprograms. User data is entered via menu selections and dialog boxes.

Program Startup

On startup, FlowCheck displays the results of its defaultconfiguration. There is no risk of accidental change to this startup data.Refer to the Working With Files section for more ideas on controllingFlowChecks startup.

General Navigation

The first view that appears when FlowCheck is opened is an untitledform. The default screen is a Summary View. It shows basic informationabout the meter and calculations, including the program executionstatus. The list of items changes according to the configuration.

Figure 6 - Summary View


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Detail View

To view more details than what are shown on the Summary View, selectDetail Viewfrom the Displaymenu. The Detail View shows ascrollable list of all possible FlowCheck inputs and outputs, their current

value, and the current unit of measure. Data is grouped by type.Information not applicable to the current meter setup is replaced bythree dots, and irrelevant data is not shown.

Figure 7 - Detail View

FlowCheck Property Settings Window

To access the FlowCheck Property Settings window, click the EditPropertiesbutton on the main toolbar.


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Figure 8 - FlowCheck Property Settings Window

The FlowCheck Property Settings window has two tabs; one for meter

settings and one for fluids. The calculation results are based on theinformation combined from both of these tabs.

Precision

The user can choose to display six- or nine-digit numbers on monitorsand printouts. The display precision does not affect the internal accuracyof the equations.

Display Units

FlowCheck generally uses the SI system internally but supports a widerange of measurement units for display purposes.

On the Displaymenu, click Units of Measure. The Units of Measuredialog box appears. The user can use this dialog to change display unitsfor all quantities simultaneously. When the user clicks one of the radio


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buttons, all display units are immediately set to a block of pre-definedtypes.

Units are saved with the data. To begin a calculation with a preferred setof units:

1. Load a previously saved data file.

2. Change the appropriate data.

Figure 9 - Units of Measure Window

Sound

The Sound On and Sound Off options help the user to controlFlowChecks annunciation sounds.

Selecting Meters and Fluids

Setting FlowChecks meter and fluid configuration is straightforward tousers who work regularly with EFM. FlowCheck uses standardterminology where possible.

1.To configure a meter, select a meter type from the Meter drop-

down on the toolbar.

2.To configure a fluid, select a meter type from the Fluid drop-down on the toolbar.

3.To view the settings for the selected meter and fluid, click theEdit Propertiesbutton on the toolbar. The FlowCheck PropertySettings window appears.


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Working With Files

FlowCheck is document-centric, which means that each meter istreated as a separate file or document. Although the user works withonly one meter at a time, the user can save and reload files at any time.FlowCheck files are identified by the .fch file name extension.

The file contains all input and output parameters of the calculation,including equation types, the program version, and user-entered data,such as tag names, location, etc. It is convenient to have a collection ofreusable files, each configured for a different meter. The long file namecapability of Windows enables descriptive file names. For example,

ChinookRiverRun2.fch is a legal file name.

After a calculation is performed, the configuration is marked as changed,and FlowCheck prompts the user to save the file before opening a newfile or finish the session.

To improve the accuracy and security of data in saved files, informationis stored in a non-editable binary format.

To open a specific file on startup, double click the icon of the

saved file.

Choose Save from the File menu when the user has a file loaded,to overwrite the file with current data.

Performing Calculations

Make basic metering and fluid selections from the main toolbar.Dialog boxes control detailed settings. Less familiar configuration items,

such as isentropic exponent, default to values recommended in industrystandards.

Calculations are programmed to occur frequently, to maintainconsistency in the data. Calculations automatically occur when:


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1. the Calculate button is clicked

2. the Exit button is clicked

3. a FlowCheck file is opened

4. the FlowCheck Property Settings window is either opened orclosed

5. either tab is selected on the FlowCheck Property Settings window

Performing a meter calculation triggers the following actions:

1. FlowCheck checks the inputs.

2. FlowCheck performs the calculation.

3. Dialog boxes and windows update, and the computer beeps.

If the calculation is unsuccessful, the results are not updated, FlowCheckgenerates a different sound, and a message box displays the error.

Viewing Results

Calculation results appear in two locations; on the Detail View and onthe FlowCheck Property Settings window.

Figure 10 - Detail View Showing Results


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Printing

FlowCheck supports basic printing functions. The print optionslisted in Figure 11 are located on the File menu.

Print Option Description

Print Snapshot Print snapshot contains detailed calculation results and itis formatted in the same style as the programs DetailView screen.

Print Inspection Report Print inspection report documents the EFM verificationactivity, identifies the meter under test, and shows theresults of the comparison.

Print Preview Print preview allows the user to view a snapshot of how

the current view would appear when printed.Print Setup Print setup is the standard Windows print setup feature

that allows the user to define the print criteria (forexample, paper size),

Figure 11 - Table of Print Options

Copying Results

FlowCheck results can also be copied onto the clipboard.

1. On the Editmenu, click Copy.

2. Open another program.

3. On the Editmenu, click Paste.


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Meter Settings

FlowCheck allows the user to calculate most combinations of meter typeand fluid type. (The primary exception to this is critical flow of liquidsthrough flow nozzle).

When the user selects a meter type only the meter data settings for thattype are displayed. For example, if an orifice meter calculation isselected, only orifice meter data settings are available. Conversely, ifeither Turbine or Pipe Prover is selected, specialized information relatingto these devices appears in the Property Settings window, meter settingstab.

Meter Settings Common to Most Types

There are some meter settings that are common to most meters inFlowCheck. These settings appear in the Flowing Conditions area on themeter tab of the FlowCheck Property Settings window.

Title Description

Differential Pressure Differential Pressure is the difference between the midstreamand downstream pressure.

Gauge Pressure Gauge Pressure is the measured pressure over and aboveatmospheric pressure. This is different from Absolute Pressure,which is the total fluid pressure, including gauge pressure andatmospheric pressure.

Flowing Temperature Flowing temperature is the measured heat intensity of a meteredfluid.

Base Pressure andBase Temperature

Base pressure and base temperature are the referenceconditions for defining volumetric quantities.

AtmosphericPressure

Atmospheric pressure is the pressure exerted by the earthsatmosphere. The actual value for meter calculations may comefrom measurements, estimates, or even contract definitions.

Flow Duration Flow duration is the elapsed time in which volume accumulates.

For example, a meter whose continuous, unchanging volumeflow rate is 100 E

3M

3/day has 100 E

3M

3of volume flow past in

24 hours.

To determine how much flow would accumulate over 1.5 hours,set the Flow Duration to 1.5 hours, and click the Calculatebutton. Note that the actual flow conditions are not perfectlysteady.

Figure 12 - Table of Flowing Conditions


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Calculation Results

Update results for each meter type by pressing Calculate. Because theterminology for gas and liquid measurement differs slightly, FlowCheckadjusts the labels to suit the fluid.

For natural gas, Corrected Gas Volume is the volume at the specifiedbase conditions which accumulates over the flow duration. UncorrectedGas Volume is the volume at the flowing conditions which accumulatesover the flow duration. To avoid confusion, the term standardconditions is not used.

For liquids, Net Standard Volume is the same as that defined in APIChapter 12.2. In effect:

Net Standard Volume = Indicated Volume x MF x Ctl x Cpl x Csw

The use of the term Gross Standard Volume in FlowCheck also agreeswith the API 12.2 definition.

Note: Gross Standard Volume is not interchangeable with Gross Volume atStandard Temperature.

Orifice Meter

To open the FlowCheck Property Settings window with the Orifice

Meter tab:

1. On the toolbar, select Orifice Meter from the Meter drop-down.

2. Click the Edit Propertiesbutton. The FlowCheck PropertySettings window appears.


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Figure 13 - Orifice Meter Selections

Calculation Methods in FlowCheck for orifice meter (flange-tapped

only) calculations are as follows:

AGA-3/ANSI/API 2530 (1990) Orifice Meter Standard

This 1990 edition of the American National Standard specifies how tomeasure the flow of Newtonian, single-phase, hydrocarbon fluids withconcentric, square-edged orifice meters. The standard is cooperativelyendorsed and supported by the American Petroleum Institute, the

American Gas Association, and the Gas Processors Association.

FlowCheck adheres to the implementation guidelines in Part 4 of thestandard, first published in 1992.

AGA-3/ANSI/API 2530 (1985) Orifice Meter Standard

The 1985 edition of the American National Standard uses the originalBuckingham-Bean data set and correlation to predict discharge


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coefficient. The document outlines three calculation approaches,including the direct solution method implemented in FlowCheck.

ISO 5167 (1991) International Standard

The full name of this 1991 edition of the International Standard isMeasurement of Fluid Flow by Means of Orifice Plates, Nozzles, and

Venturi Tubes Inserted in Circular Cross Section Conduits Running Full.FlowCheck 3.0 implements the flange-tapped orifice meter calculations.

ISO 5167 (1998) International Standard

The full name of this 1991 edition of the International Standard isMeasurement of Fluid Flow by Means of Orifice Plates, Nozzles, and

Venturi Tubes Inserted in Circular Cross Section Conduits Running Full.

FlowCheck 3.0 implements the flange-tapped orifice meter calculations.

Pressure Settings

The terminology for pressure measurements is a common sourceof confusion. Some calculations use absolute pressure; others use gaugepressure. The fact that differential meters have two pressuremeasurement points (one upstream of the plate and the otherdownstream) further complicates the issue.

The key to consistent accuracy is separation. Avoid combiningatmospheric or differential pressures with gauge pressure data.FlowCheck calculates absolute pressure from gauge, atmosphere, anddifferential pressures.

If pressure measurement is taken at the upstream tap, then:

absolute pressure = gauge + atmosphere

If the user is using AGA 3 (1985), the same formula is true for the

downstream pressure tap. FlowCheck calculates the Y1 or Y2 expansionfactor to suit the circumstance.

However, for AGA 3 (1990), the logic is slightly different. FlowCheckfollows the recommended guidelines for calculating the Y1 expansionfactor for flange taps. As such, absolute pressure is always referenced tothe upstream pressure tap.


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If a pressure measurement is taken at the downstream tap and are usingAGA 3 (1990), then:

absolute pressure = gauge + atmosphere + differential

The end effect of this logic difference is often small, but it isimportant that the calculations include the correct pressure tapconfiguration.

When absolute pressure transmitters are being used, enter zero foratmospheric pressure.

Thermal Corrections for Pipe and Plate Diameters

The diameters of orifice plates and meter runs change with temperature.Orifice meter standards provide methods to estimate diameter changes.

FlowChecks implementation of AGA 3 (1990) and ISO 5167 (1991 and1998) includes adjustments to the internal diameters of both orificeplates and meter tubes. AGA 3 (1985) compensates the plate diameterbut not the meter tube.

FlowCheck operates on the basis that metal in contact with moving fluidis equal to the flowing temperature of the fluid.

The corrections rely on metal type and the reference temperature atwhich the diameter was measured. Both are adjustable. The Detail Viewof the meter information shows the exact coefficients used.

Turbine Meters

FlowCheck supports turbine calculations for both gases and liquids. Thecorrect equations are automatically applied based on the current fluidtype.

AGA 7 (1996)

This 1996 edition of AGA-7 specifies how to use turbine meters tomeasure the flow of gas phase hydrocarbon fluids. The document ispublished and supported by the American Gas Association. Theseequations are also used for ultrasonic and PD and ultrasonic meters.


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API Chapter 12.2 (1981)

This 1981 edition of API MPMS Chapter 12.2 specifies how to useturbine meters to measure the flow of liquid hydrocarbons. Guidelinesfor provers, calculations, and documentation are also included.

Turbine Meter Settings

FlowChecks turbine calculation allows the user to enter pulse data in thefollowing ways:

1. by Frequency - if the meter is generating a continuous stream ofpulses, such as during typical service

2. by Pulse Count - if the user is calculating volume on the basis ofaccumulated pulses, such as during a proving cycle or from the

open/close readings from a delivery ticket

Figure 14 - Turbine Meter Settings


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Optional Turbine Meter Settings

FlowChecks turbine meter support includes special features toverify pulse output hardware and estimate the fluid velocity in the pipe.

Note that these features are completely optional and not required tocalculate flow.

If the turbine meter has a mechanical output drive and index, the usercan cross-check the electronics. Use a stopwatch and the MechanicalIndex Multiplier (also known as uncorrected or rear multiplier) to dothis. FlowCheck uses the index multiplier to estimate the Turbine IndexDial Rate, the time it should take for the index pointer to complete a fullrotation.

Enter the mechanical index multiplier to calculate the Turbine IndexDial Rate, which appears on the Detail View screen, in seconds perrevolution. Compare the calculation to an actual measurement made

with the stopwatch. The comparison works best if the flow is stable.

Pipe Provers

Prover Settings

There are not many configurable settings for pipe provers, so the default

properties are common to carbon steel. Confirm the specifications forthe prover before making assumptions about its material properties.


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Figure 15 - Pipe Prover Settings

Pipeline Volume Settings

FlowCheck allows the user to estimate the volume of fluids in cylinderslarger than pipe provers, such as pipelines. To estimate line pack, theuser needs to know the pipe diameter and section length and thepressure and temperature of the fluid.

To estimate corrected linepack:

1. Select the liquid from the liquid drop-down.

2. Select Pipe Prover from the meter drop-down.

3. Click the Edit Propertiesbutton to view the Pipe Prover data.

4. Enter the pipe data, fluid conditions, and base conditions.

5. Enter a Pipeline Volume Estimate.

6. Click the Estimate Nowbutton (the Estimated Static Volumeupdates).


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7. Click the Calculate button.

8. Observe the Corrected Volume in the Results area.

Alternatively, the user can enter the pipe material specifications such as

Wall Thickness and Gamma. The equations provide reasonable pressureand temperature compensation for the pipe.

Although FlowCheck 3.0 supports estimates for large pipeline sections,accuracy is better for smaller pipeline sections. No compensation isavailable for elevation changes, velocity heads, or temperature gradients.

Note: This utility is not derived from an industry standard. Users areencouraged to validate this procedure against their own policies and

procedures.

Elbow MetersElbow meters consisting of a 90elbow with taps on the inner and outer

radius at the 45point are implemented in FlowCheck 3.0. Required datais the radius of the elbow at the pipe center line, and pipe diameter.


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Figure 16 - Elbow Meter Settings

V-Cone Meters

V-Cone meters are proprietary meters which measure flow from adifferential pressure across a cone in the center of the pipe. Thecalculations are similar to orifice meters, except that the flow coefficient(analogous to the orifice meter coefficient of discharge) must bemanually entered.

FlowCheck 3.0 implements the equations provided by McCrometer, the

meter manufacturer. In most respects the data is the same as with orificemeters, with some exceptions.

These are entering the cone diameter (in place of the orifice diameter)and entering the flow coefficient, provided by the manufacturer or froma flow calibration.


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The beta ratio is calculated differently from orifice meters, but the resultis similar. A high beta ratio results from a small cone in relation to thepipe diameter.

Figure 17 - V-Cone Meter Settings


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Nozzles

Several types of nozzles are supported:

ASME toroidal and cylindrical throat nozzles described in

ASME/ANSI MFC 7M Venturi nozzles described in ASME MFC-3M and ISO 5167

long radius nozzles described in ISO 5167

ISA 1932 nozzles, described in ISO 5167

thick orifice plates (1-6d thick, beta


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velocity). These nozzles require an absolute pressure ratio of 0.5 forcritical flow to take place.

Critical flow nozzles require thermodynamic properties

calculations, which in turn, require that the AGA-8 (1994) Detailequation for compressibility be used. A full gas composition is required.


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Fluid Settings

Setting FlowChecks fluid configuration is the most technical part of theverification process. Several important properties are critical to volume,mass, or energy measurement. The user must also know which industry-standard equations are required by the application. Fortunately, the user

will probably use the same configurations repeatedly, which aidsefficiency.

Fluid Selection

The following fluids are available for calculation:


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natural gas

liquid petroleum gas (LPG)

natural gas liquids (NGLs)

crude oil condensate

gasoline

napthene

jet fuel

kerosene

diesel fuel

fuel oil

lube oil

water

air

Natural Gas Settings

Because FlowCheck offers many settings for natural gas, exercisecaution in this area.

The two basic types of gas quality data are:

detailed composition full analysis derived from gas chromatographs

bulk properties composite properties of the mixture, such asspecific gravity and heating value

If the user has the detailed composition available, FlowCheck 3.0 canuse the following equations to calculate compressibility, heating value,and relative density:


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AGA 8 (1994) Detail

AGA 8 (1985) Primary

Redlich-Kwong

Redlich-Kwong & Wichert-AzizFlowCheck 3.0 also calculates velocity of sound and thermodynamicproperties when a full composition is supplied and AGA 8 (1994)Detailis specified.

Detailed Composition Settings

For Natural Gas, adjust detailed composition by setting theamounts (in mole percent) for each component. FlowChecks default gas

composition matches the Amarillo example in AGA 8 (1994).

For an up-to-date indication of the total composition, press the Tabbutton. At calculation time, FlowCheck complains if the total does notadd up to 100 percent (+/- 0.01 percent).

To adjust only a few components, press Normalize to adjust theamounts of all (non-zero) components, returning the total to exactly 100percent. This is the easiest way to experiment with the effects of generalchanges in composition.

The fastest way to prepare the dialog box for a new set of data is bypressing Clear All, which forces all entries in the gas composition tozero.

If the user needs to abandon the changes and restart with the previouscomposition, click Reload. FlowCheck reloads the composition that wasactive when the dialog box was opened, not necessarily that which wasstored in the meter file. Reopen the file to start from scratch.


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Figure 18 - Natural Gas Settings

Wet Gas Support

The gas composition provided by commercial laboratories typicallyexcludes water vapor. To support water-saturated productionapplications, FlowCheck incorporates logic to estimate the water-saturated composition from pressure, temperature, and the dry gascomposition.

FlowCheck uses the vapor pressure of water to estimate concentration.

The general method is outlined in several industry sources, including theGPSA Engineering Data Book. The mathematical correlation for water

vapor pressure was adopted from US Weather Service so is not anofficial petroleum industry standard. FlowChecks results agree withtraditional McKetta-Wehe graphs, deviating slightly at very high waterconcentrations. Remember that solubility is affected by the presence ofcompounds such as CO2, H2S, and N2.


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From the Natural Gas Settings dialog box, press Saturate to calculate themaximum concentration of water vapor the gas will hold at the currentflowing conditions. The gas composition is automatically re-normalizedto include this water vapor.

Note: The water vapor content is not automatically recalculated when thepressure or temperatures change. Remember to press the button again ifthe items are changed.

The water vapor is included in subsequent density, heating value, andcombustion calculations.

If the user needs to report the flow of gas net of water, multiplygas quantities by Fwv, the water vapor shrinkage factor. This factor islisted on the Detail view screen, under the Wet Gas heading.

Isentropic Exponent and Viscosity

Also located in the Natural Gas dialog box are settings for Absolute (ordynamic) Viscosity of the gas and Isentropic Exponent (k). These valuesare calculated from the fluid properties that the user entered.Optionally, the user can manually enter values. Manual values may berequired when comparing a calculation from a source that uses thedefault values.

In the Detail view, use the calculated value (or the users manual entry)for k, as well as an estimate of the ideal gas specific heat ratio. Thistemperature and composition-dependent correlation is based on thefindings of McFall, Aly, and Lee.

Gross Volumetric Heating Value

For composition-based equations such as AGA 8 (1994) Detail, thevalues for heating value and density update automatically and includebase pressure and temperature, coordinated with the metering baseconditions.

If a compressibility equation requires such data as gross heating value orrelative density, manually set their values. These values provide inputsand must be determined in advance.


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Two common heating value standards used in the western hemisphereare GPA 2172 and the now obsolete AGA 5. The data of GPA 2172 isconsistent with AGA 8 (1994) and ISO Standard 6976-95.

Gas quality reference pressures and temperatures default to the metering

volume base and rarely need adjustment. To estimate the volumetricheating value for a different set of conditions than those used at themeter, adjust the meter base conditions. In terms of philosophy,FlowCheck cannot support mix-and-match base conditions for energyreporting.

FlowCheck applies methods outlined in AGA 8, Appendices C.4 andC.5, which provide good results for all typical base conditions, includingthe 60 F/14.696 psia conditions listed in GPA 2172. The table belowshows constants for each standard.

Compound Molar Ideal Gross HeatingValue (kJ/kmol) @ 25 C and101.325 kPa

AGA 5 Btu/cf perfectgas @ 60 F and 14.73psia

Methane 890.63 1012.1

Ethane 1560.69 1773.0

Propane 2219.17 2523.3

Iso-Butane 2868.20 3260.7

N-Butane 2877.40 3269.8

Iso-Pentane 3528.83 4009.7

N-Pentane 3535.77 4018.9

Hexane 4194.95 4764.4

Heptane 4853.43 5509.7

Octane 5511.80 6255.7

Nonane 6171.15 7012.7 (est.)

Deane 6829.77 7760.0 (est.)

Hydrogen 285.83 324.9

Carbon Monoxide 282.98 321.1

Hydrogen Sulfide 562.01 646.4

Figure 19 - Table of GPA 2172 and AGA 5 Constants


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Gas Density Equations

The twelve density equations for natural gas are listed here. Descriptionsfor each are listed below.

1.AGA 8 (1994), Detail2.AGA 8 (1994), HV/RD/CO2

3.AGA 8 (1994), RD/N2/CO2

4.AGA 8 (1985), Primary

5.AGA 8 (1985), Gravity/HV/CO2

6.AGA 8 (1985), Gravity/HV/CO2

7.AGA 8 (1985), Gravity/CO2/N2 Method8.AGA 8 (1985), HV/CO2/N2 Method

9.AGA 8 (1985), Gravity/Methane/CO2/N2 Method

10.AGA PAR NX19 GCN

11.Redlich Kwong

12.Redlich Kwong with Wichert-Aziz Sour Gas Corrections

AGA 8 (1994), DetailThis 1994 second printing of the industry standard specifies methods fordetermining compressibility factors for gas phase hydrocarbon fluids.

The standard is cooperatively endorsed and supported by the AmericanPetroleum Institute, the American Gas Association, and the GasResearch Institute. An earlier printing was produced in 1992, buttypographical and mathematical consistency issues prompted industry tocorrect and reprint the document in 1994.

The Detail method requires the full, detailed composition of fluid.

Volumetric heating value and relative density are calculated from thecomposition and base conditions.

This method applies to a wide range of pressures, temperatures, andfluid composition types. Calculation uncertainties increase for extremepressures and temperatures.


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AGA 8 (1994), HV/RD/CO2

This method, also known as Gross Method 1, requires valid inputs forthe gross volumetric heating value, real gas relative density, CO2concentration, and accompanying base condition data. All other

composition data is ignored.

Recommended ranges for pressure, temperature, and composition arerestricted to normal pipeline conditions. The authors of the equationsemphasize their formulas are not intended for extrapolation to otherconditions.

AGA 8 (1994), RD/N2/CO2

This method, also known as Gross Method 2, requires valid inputs forthe real gas relative density, CO2, and N2 concentrations, andaccompanying base condition data. All other composition data isignored.

Recommended ranges of pressure, temperature, and composition arerestricted to normal pipeline conditions. The authors of the equationsemphasize their formulas are not intended for extrapolation to otherconditions.

AGA 8 (1985), Primary

This method, derived from the first edition of the industry standard,specifies methods for determining compressibility factors for gas phasehydrocarbon fluids. This version of the standard was superseded in1992.

This version of the equations requires a full, detailed composition.

This method applies to a wide range of pressures, temperatures, andfluid composition types. Calculation uncertainties increase for extremepressures and temperatures.

AGA 8 (1985), GR/HV/CO2

This version of the equations requires valid inputs for the heating value,relative density, and CO2 concentration. All other composition data isignored. When using BTUs, be sure to apply the correct type.FlowCheck supports three of the existing types.


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AGA 8 (1985), Gravity/HV/CO2/N2

This version of the equations requires valid inputs for the heating value,relative density, and CO2 and N2 concentrations. All other compositiondata is ignored. When using BTUs, be sure to apply the correct type.

FlowCheck supports three of the existing types.

AGA 8 (1985), Gravity/CO2/N2

This version of the equations requires valid inputs for the relative densityand CO2 and N2 concentrations. All other composition data is ignored.

AGA 8 (1985), HV/CO2/N2

This version of the equations requires valid inputs for the heating valueand CO2 and N2 concentrations. All other composition data is ignored.

When using BTUs, be sure to apply the correct type. FlowChecksupports three of the existing types.

AGA 8 (1985), Gravity/Methane/CO2/N2

This version of the equations requires valid inputs for real gas relativedensity, methane, and CO2 and N2 concentrations. All othercomposition data is ignored.

NX19 GCN

This calculation, although superseded since 1985 by AGA 8, remains inuse in some parts of the gas industry.

The Gravity, CO2, N2 method of this equation requires valid inputs forreal gas relative density and CO2 and N2 concentrations. All othercomposition data is ignored.

Note: Results are valid over a relatively narrow range of gas compositions.

Redlich-Kwong

This traditional equation remains popular in some fields of engineering.


This method applies to a limited range of pressures, temperatures, andfluid composition types. Calculation uncertainties increase for extremepressures and temperatures.


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Redlich-Kwong with Wichert-Aziz Sour Gas Corrections

This calculation is included for the convenience of users with high acidgas concentrations. For calculations based on Redlich-Kwong,FlowCheck uses fluid property data from the mid-1970s for agreement

with the original publications.

The AGA 8, Detail method is superior in predicting the density of sourgas, but FlowCheck limits the acid gas content to 75 percent.


This method applies to a limited range of pressures, temperatures, andfluid composition types. Calculation uncertainties increase for extremepressures and temperatures.

Velocity of Sound

The velocity of sound calculations are included for natural gas mixtureswhen AGA-8 (1994) Detail is used to calculate compressibility. Thesecalculations include the following engineering and thermodynamic valuesfor the gas composition, pressure and temperature

Engineering and Thermodynamic Values

C* Enthalpy RhoF

Cp (real gas) Fpv Specific enthalpy

Cp (ideal gas) Isentropic exponent Specific entropy

Cp/Cv Molecular weight Velocity of sound

Cv RD (real gas) Zb

Db RD (ideal gas) Zf

Df RhoB

Figure 20 - Engineering and Thermodynamic Values

Liquid Hydrocarbon Settings

The properties of liquids at flowing conditions directly affect volumes atbase conditions. Industry-standard corrections for temperature andpressure are grouped by product and density, as shown in Figure 21,below.


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Figure 21 - Corrections for Temperature and Pressure

Although each type of liquid has a predefined range of densities,FlowCheck allows users to specify unusual densities.

The calculation coefficients for each liquid depend on both thefluid type and observed density. The user must select fluid type carefully.


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Figure 22 - Hydrocarbon Liquid (NGL) Settings

Some users apply spec density to NGLs, as opposed to observed

density. In this case, enter the spec density in the observed density box,and set the observed temperature to the value accompanying the spec

density (usually 15C or 60F).

The density equations for liquid hydrocarbons are as follows:

API 2540 and Chapters 12.2.1M and 12.2.2M

Temperature and pressure corrections for density are performed perguidelines in API literature. FlowCheck uses fluid type and density data

to determine the coefficients for the equations.

API Std 2540 specifies how to predict changes in liquid volume as afunction of temperature. The standard is divided according to producttype. In FlowCheck, Tables 53A, 53B, 54A, and 54B are supported byequations rather than the look-up tables themselves.


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Tables 23E and 24E for light hydrocarbons are also supported by the

equations. These equations use the US customary units (F and SG at

60F) because there are no equivalent metric tables

Tables 53 and 54 (lighter hydrocarbon liquids) are supported by both

equations and tables.

The API-recommended rules for rounding and truncation have beenobserved.

NGL calculations can use Table 53 and 54 equations or lookuptables, or TP25 (API Tables 23E and 24E). TP25 covers a wider rangeof conditions than the old Tables 53 and 54, and are considered to bemore accurate. Calculations for TP25 are done in US units (degrees

Fahrenheit specific gravity at 60

F). TP25 is only valid at this basecondition.

In terms of coverage, FlowChecks look-up tables are wide but notexhaustive.

The figures below show the boundaries of FlowChecks look-up tables.

Note: Some density ranges are restricted by temperature, a limitation of theoriginal data. FlowCheck generates an error message if the user entersa combination outside the table range.

For instance, FlowCheck generates an alarm if the flowing temperaturedoes not fit on Tables 24 or 54 even though the observed data seems tofit corresponding Tables 23 or 53. In this rare type of situation, recheckthe input data, and refer to the API printed tables if necessary.

SG Min SG Max Lower Temp Limit Upper Temp Limit

0.350 0.688 -50 F 200 F

Figure 23 - Table 23E and 24E Coverage

Rho Min Rho Max Lower Temp Limit Upper Temp Limit

480 490 15 C 60 C

490 500 10 C 60 C

500 510 5 C 60 C

510 515 -5 C 60 C

515 525 -10 C 60 C

525 530 -15 C 60 C


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530 540 -20 C 60 C

540 600 -25 C 60 C

600 649 -25 C 50 C

Figure 24 - Table 53 Coverage


500 515 -46 C 55 C

515 600 -46 C 60 C

600 650 -25 C 75 C

Figure 25 - Table 54 Coverage

API Manual of Petroleum Measurement Standards (MPMS) Chapters11.2.1M and 11.2.2M are used to predict how static pressure affectsliquid volume.

The 1994 Addendum to API Chapter 11.2.2M specifies how to estimatethe vapor pressure of hydrocarbon liquids. For fluids whose vaporpressure at base temperature is less than atmospheric pressure, such ascrude oil, vapor pressure is assumed equal to base pressure.

This standard, referred to as TP-15 is only valid down to a density of 490kg/m3.

Where vapor pressure is directly measured or inferred from aspecification, the calculation may be overridden by activating a radiobutton in the dialog box.

For crude oil and refined products, vapor pressure is automatically set to0 kPag. The vapor pressure calculation complains if NGL conditionsapproach the critical point.

No other fluid phase calculations are performed by FlowCheck.

The user is responsible for ensuring the metered fluid is single phase.

The hydrometer adjustment is not applied to NGLs or any other fluidsbelow 600 kg/m3 density. For densities above 600 kg/m3, if ahydrometer was not used to measure the observed density of crude oilor refined products, toggle off the adjustment.


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If observed density measurements were recorded at high pressures, suchas those in a pipeline with an online densitometer, API recommendsapplying pressure corrections during the solution for base density. If anobserved pressure is set in the dialog box and is greater than theequilibrium vapor pressure, FlowCheck includes these corrections in theiterative solution for base density.

The adjustment for Sediment and Water (BS&W) only applies to orificeand liquid turbine calculations. An assumption is implicitly made thatmeter provers are used only on clean product.

Water Settings

FlowCheck implements the Wagenbreth and Kell equations to predictthe density of water at different pressures and temperatures. These

equations are typically used for densitometer calibrations but provide aprecise basis for measuring water through meters as well.

The dialog box for water density is minimal, devoted mainly to outputvalues.

Figure 26 - Water Settings


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Tools

FlowCheck utilities assist in recording results and provide quick answersto common unit conversion questions. The utilities are located under the

Tools menu.

Inspection Form

The Inspection Form utility documents verification activity. Open thisdialog by selecting Inspection Reportfrom theToolsmenu.

Figure 27 - Inspection Form

The Inspection Form utility also contains information for the EFMbeing tested. Manually enter EFM data in the applicable fields, and clickthe Calculate % Differencebutton to show differences in percent.

Because of the large variety of communication protocols and dataformats available, FlowCheck does not support direct connection withflow computers.


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Update Time/Date is a convenient way to stamp the current time on therecord. The stamp is stored with the rest of the information and appearson printed records. Note that the stamp does not automatically update.

Gravity and AtmosphereUse the Gravity and Atmosphere utility to estimate local atmosphericpressure and the force of gravity, based on geographic location.

Figure 28 - Gravity and Atmosphere

To open the Gravity and Atmosphere window, from theToolsmenu,click Local Gravity and Pressure

The equation for atmospheric pressure uses elevation to predict theaverage atmospheric pressure for the users location. When the

calculation is done, FlowCheck solves the equation and immediately usesit for the meter calculations.

The primary purpose of the gravity calculation is to support adjustmentfactors for deadweight-type pressure calibrators. The equation for gravityuses both latitude and elevation. FlowCheck does not compensatecalculations for gravity. The equation is provided only as a support tool.


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The equation for gravity derives from AGA 3, which was taken, in turn,from the Smithsonian Meteorological Tables. The equation for pressureis derived from the Electricity and Gas Inspection Act, a statute ofCanadian law.

Fuel Gas Estimates

When fuel gas measurement data is damaged or absent, the user mayhave to estimate the fuel consumed by engines, line heaters, or treaters.FlowCheck contains utilities to simplify the estimating process for allthree.

FlowChecks fuel gas estimates require current gas compositionsto deliver reliable results.

Estimation data is displayed in the Detail View screen and in theSnapshot Report.

The methods contained here may differ from those specified in theregulations and contracts of the users domain. Remember that these areestimates only and should be treated as such.

Engine Fuel Gas Estimates

The Engine Fuel Gas utility applies Actual Power, Heat Rate (thermal

efficiency), Run Time, and the current gas properties to estimate thevolume and energy of fuel gas required.


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Figure 29 - Engine Fuel Gas Estimates

To open the Engine Fuel Gas Estimates window, from theToolsmenu,click Fuel Gas Estimatesand then click Engine Fuel Gas.

Actual Power is the true power the user expects to generate at the outputshaft of the engine, compensated for elevation, temperature, and frictionlosses.

Thermal efficiency compares the power entering a system with thepower exiting. For engines, fuel combustion supplies the in-boundpower, while out-bound power is typically measured at the output shaft.Heat rate and thermal efficiency are really the same, stated in differentterms. For example, a heat rate of 3600 kJ/kW-hr (or 2544 BTU(it)/hp-hr) represents 100 percent efficiency.

FlowChecks default thermal efficiency for engines is 35 percent, areasonable starting point for jet engines running on natural gas. Forpiston engines, 25 percent is a better choice. The user can consult

vendor specifications for accurate ratings for that application.FlowCheck allows thermal efficiency inputs from 10 to 100 percent.


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Line Heater Fuel Gas Estimates

The Line Heater Fuel Gas utility offers two basic methods of estimatingfuel gas.

Figure 30 - Line Heater Fuel Gas Estimates

To open the Line Heater Fuel Gas Estimates window, from theToolsmenu, click Fuel Gas Estimatesand then click Line Heater

Method 1 uses the Inlet Rating of the vessel and run time. Thecalculation is focused on energy entering the system, based onmanufacturer ratings. If the main burner is in service less than 100

percent of the time, adjust the run time accordingly.Method 2 is more sophisticated, applying data related to heater efficiency(Inlet Temp) and fluid temperature and density.

Note: The user must supply efficiency ratings. This method uses informationabout energy exiting the system to predict fuel consumption.

The ideal thermal efficiency of most indirect line heaters ranges from 75to 80 percent, hence the default value of 80 percent. This implies that 80percent of heat released by fuel gas combustion in the fire tube reachesthe fluid being heated. A heaters ideal efficiency may decrease due to

tube fouling, corrosion, or heat losses to the ambient air.

Method 2 calculates ideal gas heat capacity from current gascompositions and median temperatures to predict the amount of energytransferred to the gas.


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Methods 1 and 2 are linked. If the user enters temperature andthroughput data, Method 1 calculates efficiency, while Method 2estimates Inlet Rate. This format allows the user to estimate efficiencyreductions due to tube fouling, etc. If the heaters performance outputdecreases over time, there will be changes in efficiency.

Treater Fuel Gas Estimates

Treater Fuel Gas estimates are similar to Line Heater Fuel estimates.Supply basic volume, temperature, and density data, and FlowCheckcalculates the fuel required to produce the heat.

Figure 31 - Treater Fuel Gas Estimates

To open the Treater Fuel Gas Estimates window, from theToolsmenu,click Fuel Gas Estimatesand then clickTreater

Oil and water absorb heat at different rates. The user must supply theseparate volumes of each to facilitate accurate calculations.

FlowCheck calculates oil heat capacity using a simple equation listed inthe Chemical Engineers Handbook (Perry & Chilton). Enter the oildensity (standard density) to ensure correct results. Oil density and

volume are used to determine the total mass of heated oil

Cp = (0.388 + 0.00045t) / s^0.5

where Cp is in BTU(it)/lbm-F, t is degrees F, and s is specific gravity(60/60).


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Water heat capacity is fixed at 4.1858 kJ/kg, but the density is calculatedlive at the median temperature. If the users produced water has a highchloride content, these equations may be inadequate for the usersapplication.

The user should not be discouraged by the wide array of units for power,heat capacity, volume, and energy. Engine and vessel manufacturersusually provide their equipment ratings in very clear terms.

Unit Converters

FlowCheck features several unit converters for convenience and as asecond form of program traceability. FlowCheck performs allconversions using the same group of equations and constants.

The unit converters support Energy, Length, Pressure, Temperature, andVolume.

Figure 32 - Unit Converter


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Units and Conversion Factors

Almost everyone has been caught up at some point by a unit conversionproblem. Puzzling variations often exist within the same unit system. Forinstance, the Imperial system expresses density in pounds per Imperial

gallon, in specific gravity at 60F, in API degrees, or in pounds per cubicfoot, to name a few. This section describes how FlowCheck handlesunits of measure and converts one type of unit to another.

Overview

FlowCheck calculations are implemented in SI units, but the programdisplays other units of measure for the users convenience. Display unitscan be individually defined for most physical quantities. Alternatively,install a full slate of display units by choosing Units of Measurefromthe Displaymenu.

Data Sources

The Canadian Metric Practice Guide (CAN/CSA-Z234.1-89)provides the primary source of data for FlowCheck conversions.

Additional data is supplied by the Supplementary Metric Practice Guide,5th Edition 1989 (Canadian Petroleum Association) and the AGAMetric Unit Application Guide (1980) (American Gas Association).

In most cases, unit conversions are performed in long double precisionfloating point arithmetic, using a dimensional analysis approach.

Although FlowCheck supports many types of units, all are derived fromthe set of expressions listed on the succeeding pages.

Note: Some factors appear in fractional format, the traditional way to displaynumbers not well represented by decimals.

Name Description

Time 60 seconds = 1 minute

3600 seconds = 1 hour

86,400 seconds = 1 day

Mass 1 pound mass (lbm) = 45,359,237/100,000,000 kilograms

Length 1 yard = 9144/10,000 meters


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Name Description

1 yard = 3 feet

1 foot = 12 inches

1 mile = 1760 yards

Volume 1 US gallon = 231 cubic inches1 API petroleum barrel = 42 US gallons = 9702 cubic inches

1 Imperial gallon = 454,609/100,000,000 cubic meters

Temperature 5 Kelvins = 9 degrees Rankine

459.67 degrees Rankine = 0 Fahrenheit

273.15 Kelvins = 0 Celsius

Energy 1 calorie (International Table) = 4.1868 Joules

1 calorie (thermochemical) = 4.184 Joules

Specific Heat Capacity of water at 15 C = 4.1858 J/(g.C)

1 Btu/lbm = 5 calories (IT)/9 grams

1 Btu(60 - 61) = 1054.615 Joules

1 therm = 100,000 Btu (IT)

1 dekatherm = 10 therms = 1,000,000 Btu (IT)

Pressure Density of water at 60 F = 999.012 kg/m3

Density of water at 68 F = 998.202 kg/m3

1 inch of Hg at 32 F = 3386.39 Pascals

1 bar = 100 kilopascals

1 horsepower = 550 ft-lbf/s

DynamicViscosity

1 Pascal second = 10 Poise

Constants UsedThroughout

Standard Acceleration Due To Gravity = 9.80665 metres per secondper second

One Standard Atmosphere = 101.325 kilopascals

Universal Gas Constant = 8.314510 J/kg-K (used throughout, exceptby FlowChecks implementation of AGA 8 (1985), which uses10.73164 psia-ft/lb-mol-R for closest agreement with publishedexamples)

Figure 33 - Table of Unit Conversions


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Glossary

Terminology is important, especially to custody transfer measurement.This glossary explains the terms used in FlowCheck.

Absolute Viscosity

Measures the resistance of fluids to flow. In general, the viscosity ofa liquid decreases as temperature increases. Interestingly, the viscosity ofa gas has the opposite relationship with temperature. A closely relatedproperty, kinematic viscosity, equals the absolute viscosity divided bydensity.

Fluid Viscosity

Natural Gas 0.01 cP

NGL 0.3 cP

Water 1 cP

Medium Crude Oil 3 cP

Figure 34 - Table of Typical Values for Absolute Viscosity

Acceleration Due to GravityThe force that pulls objects toward the earths center, which variesslightly from area to area. These variations can be estimated frominformation about geographic position and elevation. FlowCheck usesthe AGA 3 formula, derived from equations published by theSmithsonian Institute.

Air / Fuel Ratio

FlowCheck estimates the air to fuel ratios required for complete

stoichiometric combustion of the measured fuel gas. The ratios areexpressed in terms of mass, volume, and the number of moles.

American Gas Association (AGA)

A national trade association with a long historical involvement in themeasurement standards process, whose primary members are


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distributors of natural gas. AGA and other organizations oftencooperatively support the same standard. For example, ANSI/API 2530,an American National Std, is published by AGA as AGA 3 and by APIas the Manual of Petroleum Measurement Standards (MPMS), Chapter14.3.

Visit AGAs web site at http://www.aga.com.

American Petroleum Institute (API)

A petroleum trade organization whose mandate includes standardizingpetroleum measurement technologies, policies, and procedures. TheManual of Petroleum Measurement Standards (MPMS) is a compendiumof related measurement standards published by API.

Visit APIs web site at http://www.api.org.

Average Flowing Pressure

The mean value of the measured absolute pressure of a fluid over aspecified period of flow (see Flowing Pressure).

Average Flowing Temperature

The mean value of the measured heat intensity of a fluid over a specifiedperiod of flow (see Flowing Temperature).

Base Conditions

It is common practice to report hydrocarbon quantities in terms of thevolume the fluid occupies at a specified pressure and temperature, ratherthan the actual conditions at the meter. For example, Volume at Pb, Tbis the volume a quantity of fluid occupies if its pressure is at basepressure and its temperature at base temperature. This translation to anunchanging, agreed-upon set of conditions simplifies quantity reporting.

In some contracts and documents, standard conditions are specifically

pegged at 14.73 psia and 60 F. In countries using the SI system ofmeasurement, base (or standard or contract) conditions are typically101.325 kPa and 15 C.


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Base Pressure (Pb)

The pressure parameter of a formal definition of volume (see BaseConditions).

Base Pressure Factor (Fpb)

A factor used to translate volumes computed at 14.73 psi to other basepressures. FlowCheck uses Fpb for calculating AGA 7. FlowCheck doesnot use a factor approach for orifice meter applications but doescalculate and report a number of them for user convenience.

Base Temperature (Tb)

The temperature parameter of a formal definition of volume (see BaseConditions).

Base Temperature Factor (Ftb)

A factor used to translate volumes computed at 60 F to other basetemperatures. FlowCheck uses Ftb for calculating AGA 7. FlowCheckdoes not use a factor approach for orifice meter applications but doescalculate and report a number of them for user convenience.

Beta Ratio

In orifice meters, the orifice diameter divided by the pipe diameter. InFlowCheck, temperature-compensated diameter(s) are determinedbefore beta ratio and other quantities are calculated.

British Thermal Unit (Btu)

A traditional unit of energy, originally based on the amount of heatenergy required to increase the temperature of one pound of water byone degree F. However, since the heat capacity of water varies with itstemperature, numerous Btu definitions have evolved. Depending on thestarting point for a temperature increase, the required amount of energydiffers slightly.

FlowCheck supports the following popular variants of the Btu:


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Btu (59 - 60) was standard in the US gas industry until 1992 when theBtu (IT) officially replaced it (see AGA Engineering Technical NoteM-92-2-1)

1 Btu (59 - 60) = 1054.80386 Joules, rounded to nine figures

Btu (60 - 61) was widely used in the Canadian gas industry and stillappears in some documents and contracts

1 Btu (60 - 61) = 1054.615 Joules exactly (by definition)

Btu (IT), or International Table Btu, is formally defined in terms ofthe Joule, the energy unit in the SI system

1 Btu (IT) = 1055.05585262 Joules, exactly

Note: Energy is a very different quantity than volumetric heating value,which depends on base pressure and base temperature. Energy is

independent of volumetric conditions.

Canadian Gas Association (CGA)

The national trade organization for Canadas gas industry. CGAs 320members include Canadas major natural gas transmission companies,distributors, producers, and manufacturers of gas appliances andequipment.

Visit CGAs web site at http://www.cga.ca.

Certified Prover Volume

The volume of a pipe prover determined by calibration, often via awater draw method using special procedures and carefully calibrated

water cans.

Coefficient of Cubical Expansion (Gamma)

A material-specific estimate of volume change resulting fromtemperature change.

Type of Steel Per degree F Per degree C

Mild Steel 1.86E-05 3.35E-05

304 Stainless 2.88E-05 5.18E-05

316 Stainless 2.65E-05 4.77E-05

17-4PH Stainless 1.08E-05 3.24E-05

Figure 35 - Table of Temperature Coeffiecients for Pipe


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Coefficient of Expansion, Pipe

A material-specific estimate of length change resulting from temperaturechange. Typical units are mm/mm/K (SI) and inch/inch/F (Imperial).

Coefficient of Expansion, Plate

A material-specific estimate of length change resulting from temperaturechange. Typical units are mm/mm/K (SI) and inch/inch/F (Imperial).

Combustion Air

The total mass of air required for perfect stoichiometric combustion ofthe metered fuel gas quantity. There is no excess air built intoFlowChecks combustion calculations. If oxygen is present in the fuelgas, FlowCheck rebalances the air requirements to compensate.

Combustion Reference Temperature

Parameter used to fully define the ideal gross volumetric heating valueand used by AGA 8 Gross Compressibility Methods. Refer to thestandard for a full description. If in doubt, configure settings to matchthe other metering pressure and temperature bases, or rely onFlowChecks defaults.

Compressibility at Pb, Tb

The deviation from ideal gas laws that a fluid exhibits at base pressureand base temperature. Compressibility at Pb, Tb is also known as Zb.

Compressibility at Pf, Tf

The deviation from ideal gas laws that a fluid exhibits at flowing pressureand flowing temperature. Compressibility at Pf, Tf is also known as Zf.

Corrected Prover Volume

The volume of a pipe prover, fully compensated for pressure andtemperature effects. This also includes the pressure and temperatureeffects on the fluid inside the vessel.


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(Cpl) Pressure Correction for Liquids

The factor compensating hydrocarbon liquids for the effects of elevatedpressure. FlowCheck uses equations published in API MPMS Chapters11.2.1M and 11.2.2M to estimate Cpl. The addendum to Chapter

11.2.2M prescribes a method for estimating vapor pressure of lighterhydrocarbons, which FlowCheck implements.

(Ctl) Temperature Correction for Liquids

The factor compensating hydrocarbon liquids for the effects oftemperature. FlowCheck uses equations published in API Std 2540 toestimate Ctl, also known as VCF.

(Cps) Pressure Correction for Prover Shells

The factor compensating steel vessels for the effects of elevated internalpressure. FlowCheck uses equations published in API MPMS Chapter12.2 to estimate Cps.

(Cts) Temperature Correction For Prover Shells

The factor compensating steel vessels for the effects of temperature.FlowCheck uses equations published in API MPMS Chapter 12.2 toestimate Cts.

(Csw) Sediment and Water Correction

The volume correction factor compensating for the presence of non-merchantable material in a liquid hydrocarbon delivery.

Differential Pressure (dP)

flowcheck user manual

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