Micro Motion Oil and Gas Production Applications-PVR, TBR, TMR Manuals & Guides

Supplement

MMI-20026578, Rev AD

January 2022

Micro Motion™ Multiphase Applications

Production Volume Reconciliation (PVR) | Transient Bubble
Remediation (TBR) | Transient Mist Remediation (TMR)

Safety messages

Safety messages are provided throughout this manual to protect personnel and equipment. Read each safety message carefully
before proceeding to the next step.

Safety and approval information

This Micro Motion product complies with all applicable European directives when properly installed in accordance with the
instructions in this manual. Refer to the EU declaration of conformity for directives that apply to this product. The following are
available: the EU declaration of conformity, with all applicable European directives, and the complete ATEX Installation Drawings
and Instructions. In addition the IECEx Installation Instructions for installations outside of the European Union and the CSA
Installation Instructions for installations in North America are available on the internet at www.emerson.com or through your local
Micro Motion support center.

Information affixed to equipment that complies with the Pressure Equipment Directive, can be found on the internet at

www.emerson.com. For hazardous installations in Europe, refer to standard EN 60079-14 if national standards do not apply.

Other information

Full product specifications can be found in the product data sheet. Troubleshooting information can be found in the configuration
manual. Product data sheets and manuals are available from the Micro Motion web site at www.emerson.com.

Return policy

Follow Micro Motion procedures when returning equipment. These procedures ensure legal compliance with government
transportation agencies and help provide a safe working environment for Micro Motion employees. Micro Motion will not accept
your returned equipment if you fail to follow Micro Motion procedures.

Return procedures and forms are available on our web support site at www.emerson.com, or by phoning the Micro Motion
Customer Service department.

Emerson Flow customer service

Email:

• Worldwide: [e-mail]

• Asia-Pacific: [e-mail]

Telephone:

North and South America

United States 800-522-6277 U.K. and Ireland 0870 240 1978 Australia 800 158 727

Canada [phone] The Netherlands [phone]

Mexico [phone] France [phone]

Argentina [phone] Germany 0800 182 5347 Pakistan 888 550 2682

Brazil [phone] Italy [phone] China [phone]

Chile [phone] Central & Eastern [phone]

Peru [phone] Russia/CIS [phone] South Korea [phone]

Europe and Middle East Asia Pacific

New Zealand 099 128 804

6666

India 800 440 1468

901

Japan [phone]

111

Egypt 0800 000 0015 Singapore [phone]

Oman 800 70101 Thailand 001 800 441 6426

Qatar 431 0044 Malaysia 800 814 008

Kuwait 663 299 01

South Africa 800 991 390

Saudi Arabia 800 844 9564

UAE 800 0444 0684

2

Supplement Contents

MMI-20026578 January 2022

Contents

Chapter 1 Before you begin........................................................................................................5

1.1 About this application manual..................................................................................................... 5

1.2 ProLink III requirements............................................................................................................... 5

1.3 Ordering options......................................................................................................................... 6

1.4 Additional documentation from Micro Motion ............................................................................6

1.5 Terms and definitions.................................................................................................................. 7

1.6 PVR, TBR, and TMR applications...................................................................................................8

Chapter 2 Production Volume Reconciliation (PVR).................................................................. 11

2.1 Understanding the PVR application............................................................................................11

2.2 Density determination...............................................................................................................14

2.3 Configure Production Volume Reconciliation (PVR) using ProLink III ......................................... 18

Chapter 3 Transient Bubble Remediation (TBR)........................................................................ 21

3.1 Understanding the TBR application............................................................................................21

3.2 Configure Transient Bubble Remediation (TBR) using ProLink III ................................................23

Chapter 4 Transient Mist Remediation (TMR)........................................................................... 25

4.1 Understanding the TMR application...........................................................................................25

4.2 Configure Transient Mist Remediation (TMR) using ProLink III ...................................................27

Chapter 5 Display variables...................................................................................................... 29

5.1 Display variables available with PVR, TBR, and TMR....................................................................29

Appendix A Application parameters and data............................................................................. 31

A.1 PVR parameters and data.......................................................................................................... 31

A.2 TBR parameters and data...........................................................................................................37

A.3 TMR parameters and data..........................................................................................................38

Appendix B Best practices for two-phase measurement performance......................................... 41

B.1 Entrained gas performance........................................................................................................41

B.2 Entrained liquid (mist) performance.......................................................................................... 42

B.3 Density determination...............................................................................................................44

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Contents Supplement

January 2022 MMI-20026578

4 Micro Motion Multiphase Applications

Supplement Before you begin

MMI-20026578 January 2022

1 Before you begin

1.1 About this application manual

This application manual explains how to configure the Production Volume Reconciliation
application (PVR), the Transient Bubble Remediation application (TBR), and the Transient
Mist Remediation application (TMR), using ProLink III.

These three applications are available for Micro Motion MVD™ Coriolis meters in an MVD
Direct Connect installation.

PVR, TMR, and TBR are also available for Micro Motion Model 1500, Model 1700,
Model 2500, and Model 2700 transmitters.

This application manual does not provide information on installation of any sensors or
transmitters, or on general configuration. This information can be found in the applicable
sensor installation manual, transmitter installation manual, or transmitter configuration
manual.

Related information

Additional documentation from Micro Motion

1.2 ProLink III requirements

To use this manual, you must have ProLink III Professional v4.0 or later, and you must be
able to connect from ProLink III to the transmitter or core processor.

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Before you begin Supplement

January 2022 MMI-20026578

1.3 Ordering options

For 800 core processor direct connect installations, PVR, TBR, and TMR are available as
Engineering To Order (ETO) applications. PVR and TMR are available individually or in
combination with Smart Meter Verification.

PVR, TMR, and TBR features are now available in the standard product when ordered on
1500, 1700, and 2500 Transmitter Models. The ETO is not required on the 800 core
processor when used with a transmitter.

To order one of these applications, an ETO must be purchased for the core processor (see

Table 1-1). This ETO enables use of the application in an MVD™ Direct Connect installation.

Table 1-1: Core processor ETOs for PVR, TBR, and TMR

Application Direct connect

core processor

PVR Enhanced 22166 22701 Mixture of oil and

TBR Enhanced 13386 25699 Liquid with gas Liquid flow rate and

Standard 12806 Not available. Liquid with gas Liquid flow rate and

TMR Enhanced 18922 22706 Gas with entrained

Individual
application

ETO number Process fluid Desired

Application
with
Smart
Meter
Verification
(SMV)

water

liquid (mist)

measurement

Net oil (dry oil at
reference conditions)
and net water flow

totals

totals

Gas flow rate and
totals

Restriction

Only one ETO can be installed in the transmitter or core processor at a time.

1.4 Additional documentation from Micro Motion

Table 1-2: Additional documentation for PVR, TBR, and TMR installations

Document Use

Micro Motion® MVD™ Direct Connect Meters:
Installation Manual

Sensor installation manual for your sensor Installation and wiring for the sensor

Configuration manual for your transmitter Configuration, operation, maintenance, and

ProLink III User Manual

Modbus Interface Tool

6 Micro Motion Multiphase Applications

Installation and wiring for the MVD Direct
Connect flowmeter

troubleshooting for features that are not related
to PVR, TBR, or TMR

Installation and use of ProLink III

Programming the Modbus host

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MMI-20026578 January 2022

1.5 Terms and definitions

The terms used to describe Multiphase applications vary widely. This manual, and the PVR,
TBR, and TMR applications, use the terms defined here.

Terms used in PVR,
TBR, and TMR

at Reference

At Line

At Reference
density

At Line volume

At Reference
volume

Mixture

Water cut

Entrained,
entrainment

Remediation

Shrinkage

The process of calculating the value of a process variable at
reference temperature, starting from the value of the process
variable at line temperature (the measured value)

The density of the process fluid at line temperature

The density of the process fluid at reference temperature (60 °F)
that is equivalent to its density at line temperature

The volume of the process fluid at line temperature

The volume of the process fluid at reference temperature (60 °F)
that is equivalent to its volume at line temperature

The process fluid before separation, such as a combination of oil
and water, or gas, oil, and water

The volume fraction of water in the liquid mixture, in %

The presence of small amounts of gas in a liquid stream, or liquid
in a gas stream

An adjustment applied to a process variable during periods of
entrained gas or mist when a substitute density value has been
used for volume calculation (PVR and TBR) or the flow rate has
been increased or decreased to compensate for unmeasured flow
(TMR).

The change in liquid volume between the measurement point and
a stock tank due to lighter hydrocarbons evaporating. This is
caused by the stock tank being at a lower pressure, further below
the bubble point of the oil. The shrinkage factor is a user-input
factor, based on a PVT (pressure-volume-temperature) test of the
oil.

Shrinkage Meter
Factor

These terms can be combined in several ways to describe different process variables. The
following table provides several examples, but is not a complete list of possibilities.

Table 1-3: Examples of process variable names

Process variable name Description

Volume Total (unremediated) The total, by volume, of the mixture (oil/water/gas combination),

Volume Total (remediated) The total, by volume, of the oil/water minus the volume

Supplement 7

Used just like the normal Meter Factor, when proving the meter
against liquid measurement at stock tank conditions.

as measured

attributable to gas

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January 2022 MMI-20026578

Table 1-3: Examples of process variable names (continued)

Process variable name Description

Oil Total at Line The total amount of oil measured since the last totalizer reset, at

line temperature, with no adjustment for temperature variation

Water Cut at Reference The percentage of water in the oil, as if the measurement had

been taken at 60 °F

Supplement

1.6 PVR, TBR, and TMR applications

PVR, TBR, and TMR are applications designed to provide more accurate process data in the
presence of multiple phases. For example, if bubbles are present in the process fluid, or the
process fluid is flashing, the volume measurements are often incorrect.

Production Volume Reconciliation (PVR)

• Provides oil and water volumes through density-based calculations for both line and

reference conditions

• Detects bubble entrainment or flashing in the sensor, and can correct volumes

accordingly

• Best for undersized three-phase separators that frequently have intermittent gas or

water contamination in the oil leg

• Offers a simple, low-cost solution for net oil and net water measurement for two-phase

separators

Transient Bubble Remediation (TBR)

• Used with single-component liquid streams that may experience intermittent low

levels of gas entrainment, that is, gas carryunder

• Enables accurate measurement of a single fluid during periods of entrained gas by

providing a substitute density value based on the immediately preceding process
density (standard configuration)

• Tracks total time of aerated flow to assist in diagnosing process issues that may cause

aeration

Transient Mist Remediation (TMR)

• Used with gas streams that may experience intermittent low levels of liquid

entrainment, i.e., liquid carry-over

• Allows gas measurement to continue during periods of entrained liquid (mist) by

providing a substitute flow rate value based on the immediately preceding process
flow rate

• Returns to reporting the measured flow rate when the mist interval is over, increased

or decreased by a maximum of 10%, until flow totals are appropriately adjusted for the
unmeasured flow

• Provides an indication of the amount of time that liquid was present in the stream —

identifying process improvements to reduce gas stream contamination

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1.6.1 Illustrations of PVR, TBR, and TMR installations

PVR, TBR, and TMR can be used with two-phase separators and three-phase separators.

Note

These illustrations do not show all possible combinations.

Figure 1-1: PVR, TBR, or TMR with two-phase separator

A. From wellhead
B. Separator
C. Gas leg

D. Oil/water leg

E. Coriolis sensor with PVR or TBR
F. Coriolis sensor with TMR

G. Modbus host (flow computer)

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Figure 1-2: PVR, TBR, or TMR with three-phase separator

A. From wellhead
B. Separator
C. Water leg

D. Oil leg

E. Gas leg
F. Coriolis sensor with PVR or TBR

G. Coriolis sensor with PVR (optional, used in applications where oil measurement is needed in the water leg to

detect a malfunctioning separator)

H. Coriolis sensor with TMR

I. Modbus host (flow computer)

10 Micro Motion Multiphase Applications

A

B

C

t

ρ

D

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2 Production Volume Reconciliation

(PVR)

2.1 Understanding the PVR application

PVR is used in oil and gas separation applications to compensate for gas and/or water
contamination in the oil leg of a three-phase separator. It is also used to quantify the oil
and water volumes in the liquid leg of a two-phase separator.

PVR uses the meter's drive gain to indicate if there is entrained gas or transient bubbles in
the liquid stream, and adjust the measurement accordingly. Under normal circumstances,
i.e., no entrained gas or bubbles, the application uses the Net Oil Computer (NOC)
algorithm to calculate and quantify the volumes of oil and water in the liquid stream.

Net Oil Computer (NOC)

The Net Oil Computer algorithm calculates the water fraction of the liquid stream so that
the amount of oil and the amount of water can be determined. The algorithm measures
the volume of oil, corrected to a reference temperature, that is contained within the gross
volume of produced fluid.

Compensating for gas in the liquid

Entrained gas, or bubbles in the process fluid, has a negative effect on liquid volume
measurement accuracy. The Coriolis sensor calculates volume based on direct density and
mass measurements. When a bubble is present, mixture density is reduced, causing the
reported volume to be higher than the actual liquid volume. The presence of bubbles is
reflected in the drive gain. The following figure shows how the change in drive gain affects
density measurement.

Figure 2-1: Effect of transient bubbles on drive gain and density measurement

A. Density

B. Drive gain (actual)
C. Transient bubble condition
D. Drive gain (%)

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A transient bubble condition is defined in terms of the sensor's drive gain: If the drive gain
exceeds the configured threshold for more than a specified interval, the selected PVR
action is performed. The transient bubble interval persists until drive gain is below the
configured threshold for the specified interval.

PVR volume calculation during bubble events

If the drive gain threshold is exceeded, the volume calculation for the period of high drive
gain can be handled in one of three ways.

Option Description

Hold Last Value

Use Input Density of
Dry Oil Converted to
Line Conditions

Alert Only

Use an average density value from an earlier point in the process
to calculate volume. If this option is chosen, the water cut from
the point just before the bubble event is effectively held
constant throughout the bubble event.

Convert the density of dry oil at reference temperature (a user­configured value) to density at line temperature, and calculate
volume. This option assumes that all volume during the bubble
event is dry oil.

Post an alert.

12 Micro Motion Multiphase Applications

C

B

E

A

F

D D

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Processing for Hold Last Value

This option directs the application to retrieve measured density data from an earlier point
in the process. The earlier point is identified by the configured PVR Lookback Period. The
density values around this point are averaged, and this average is then used in oil
calculations.

The following figure shows the substitution of average density data during the transient
bubble interval.

Figure 2-2: Hold Last Value in operation

A. Density

B. PVR Drive Gain Threshold
C. Drive gain (actual)
D. PVR Lookback Period

E. Averaged density values

F. Drive gain (%)

Note

If the point defined by PVR Lookback Period happens to fall into a previous transient
bubble interval, the application automatically extends the lookback interval as required so
that the average is calculated from measured density data rather than substituted density
values. In the illustration, the first average is applied to several transient bubble events.

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2.2 Density determination

To configure Production Volume Reconciliation (PVR), you must know the density of dry
oil at reference temperature, and the density of produced water at reference temperature.

Related information

Density determination using the data log from ProLink III
Density determination using a petroleum laboratory

2.2.1 Density determination using the data log from ProLink III

To configure Production Volume Reconciliation (PVR), you must know the density of dry
oil at reference temperature, and the density of produced water at reference temperature.
You can use log data from ProLink III, with the Oil & Water Density Calculator, to obtain
these values.

Note

Even after separation, oil typically contains some amount of interstitial water. The water
cut may be as high as 1% to 3%. For purposes of this application, this is considered dry oil.

This procedure assumes the following:

• The highest density value in the logged data represents produced water.

• The lowest density value in the logged data represents dry oil.

Prerequisites

You must be able to connect to the transmitter or core processor with ProLink III.

You must know how to use the data logging feature in ProLink III.

You must be able to run data logging for the necessary time period, which may be a few
minutes or a few hours, depending on your separator.

You must have the Oil & Water Density Calculator. This is a spreadsheet tool developed by
Micro Motion. You can obtain a copy from your Micro Motion representative.

Procedure

1. Connect to the core processor or transmitter with ProLink III.

• For two-phase separators, connect to the core processor or transmitter on the

oil/water leg. See Figure 1-1.

• For three-phase separators, connect to the core processor or transmitter on the

oil leg. See Figure 1-2.

2. Set up data logging to record the following process variables, with a logging interval
of 1 second:

• Mass flow rate

• Volume flow rate

• Density

• Temperature

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• Drive gain

3. Collect data.

a) Open the level control valve on the separator, and allow the separator to

drop to the lowest safe level, or until gas is first drawn into the liquid leg.

b) Close the level control valve and allow the level to rise to the maximum safe

level.

This will increase the residence time for the liquid in the separator, and may
allow the water to settle to the bottom and the oil to rise to the top.

c) Open the level control valve partially, so that the level drops slowly.

d) Start data logging.

e) Allow the separator to drop to the lowest safe level, or until gas is first drawn

into the liquid leg.

f) Stop data logging.

g) Return the separator to automatic level control.

4. Obtain maximum and minimum density data from the log.

Shortly after the control valve is opened or the dump phase begins, you should see
the temperature stabilizing and the density rising to a maximum value and
stabilizing. This may represent produced water. Just before the lowest safe level, or
before the point where gas is drawn into the liquid leg, you should see the density
falling to a minimum value and stabilizing. This may represent dry oil.

a) Record the maximum density and the corresponding temperature.

b) Record the minimum density and the corresponding temperature.

Important

Never use an unstable density value, or any density value that has an elevated drive
gain.

5. Use the Oil & Water Density Calculator to calculate the density of dry oil at reference
temperature and the density of produced water at reference temperature.

Tip

Unless the oil is light hot condensate, the oil will almost always contain some
interstitial water. This is generally acceptable for allocation measurements.
However, if further accuracy is desired, you can determine the water cut and use it
in the calculation. To determine or estimate the water cut, take a shakeout sample
from one of the following:

• The current flow/dump cycle, at the time of minimum density

• Similar oils produced from the same reservoir

• The tank or tanks that the separator flows into

Enter this water cut into the Oil & Water Density Calculator to calculate the density
of dry oil at reference temperature.

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2.2.2 Density determination using a petroleum laboratory

To configure Production Volume Reconciliation (PVR), you must know the density of dry
oil at reference temperature, and the density of produced water at reference temperature.
You can obtain this values from a petroleum laboratory.

Note

Even after separation, oil typically contains some amount of interstitial water. The water
cut may be as high as 1% to 3%. For purposes of this application, this is considered dry oil.

Important

If you are using a three-phase separator, you can collect the oil sample and the water
sample separately, after separation, or you can collect one sample before separation and
have the laboratory perform the separation.

If you are using a two-phase separator, you should collect one sample before separation
and have the laboratory perform the separation.

Prerequisites

The petroleum laboratory must be able to meet these requirements:

• The laboratory density meter must be able to keep the oil sample pressurized at line

pressure during the density measurement.

• The sample cylinder must be a constant-pressure type, and must be properly rated for

the oil–water composition and for sample pressure.

• The oil density measurement units should be in g/cm³ at reference temperature and/or

°API at reference temperature. The water density measurement should be in g/cm³ at
reference temperature. PVR requires a reference temperature of 60 °F. Be sure to
specify this to the petroleum laboratory, as some countries use other reference
temperatures.

• The laboratory report must include the oil density, water density, and the reference

temperature.

The sample must be collected by a qualified person, using industry-accepted safety
standards.

You must know the minimum required sample size. This varies depending on the water
cut and the volume of the sample cylinder. Consult the petroleum laboratory for specific
values.

You must be able to collect and maintain the oil sample at line pressure, so that the oil will
not lose pressure and outgas.

If you collect the water sample separately, you must be able to protect it from
contamination and evaporation.

Procedure

1. Communicate the handling and measurement requirements to the petroleum

laboratory.

2. If you are collecting one sample that contains both oil and water, identify the point

in the line where the sample will be taken.

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Recommendations:

• Collect the sample upstream from the separator, at a point where the fluid is

well mixed. Fluid in the oil/water leg exiting the separator may not be well
mixed.

• The process fluid at the sample point should be representative of the process

fluid flowing through the sensor on the oil/water leg.

• The line pressure at the sample point should be close to the line pressure at the

sensor.

• Collect the sample from the bottom of the pipe to minimize the amount of gas

in the sample.

3. If you are using a three-phase separator and collecting the oil and water samples
separately, identify the points where the samples will be taken.

Recommendations:

• The sample point for oil must be on the oil leg, as close to the sensor as possible.

See Figure 1-2.

• The line pressure at the oil sample point should be similar to the line pressure at

the sensor.

• The sample point for water must be on the water leg, as close to the sensor as

possible. See Figure 1-2.

Note

If you have a Micro Motion sensor on the water leg, you may be able to use the
data logging procedure described in Density determination using the data log

from ProLink III to determine the water density.

4. If you are using a three-phase separator and collecting the oil and water samples
separately, wait until separation has occurred.

5. Collect the sample or samples, meeting all requirements for pressure and
protection from contamination or evaporation.

6. Mark and tag the sample or samples with the well name or number, time and date,
sample type, and line pressure.

7. Transport the samples to the laboratory safely, as soon as is practical.

Postrequisites

If the laboratory measurements were not corrected to your reference temperature, use
the Oil & Water Density Calculator to calculate density at reference temperature. This is a
spreadsheet tool developed by Micro Motion. You can obtain a copy from your
Micro Motion representative.

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2.3 Configure Production Volume Reconciliation (PVR) using ProLink III

PVR is used with three-phase separators to remove gas and/or water contamination from
oil measurement on the oil leg, and to quantify the net oil and net water in the liquid leg of
a two-phase separator.

Prerequisites

You must know the density of dry oil from this well, at reference temperature and
reference pressure.

You must know the density of water at reference temperature.

Procedure

1. Choose Device Tools → Configuration → Process Measurement → Production
Volume Reconciliation (PVR).

2. Enable the PVR application.

3. Set Reference Temperature to the temperature to be used to calculate standard
density.

In most cases, this is the reference temperature used during density determination.

4. Enter the density of dry oil from this well at the configured reference temperature.

5. Enter the density of produced water at the configured reference temperature.

6. Set PVR Drive Gain Threshold to the value of drive gain, in percent, that indicates
the presence of bubbles in the process fluid.

At drive gain values above this threshold, the transmitter will implement the
configured PVR action.

7. Set PVR Drive Gain Threshold High to the value of drive gain, in percent, that
indicates a significant amount of gas in the process fluid.

At drive gain values above this threshold, the transmitter will post an alert.

8. Set PVR Action to the action that the transmitter will perform when PVR
remediation is active.

Option

Hold Last Value The transmitter will calculate volume using a

Use Input Density of Dry
Oil Converted to Line
Conditions

Description

substitute density value. The substitute value is an
average of the data around a recent point in the
process.

The transmitter will calculate volume using the
configured value for oil density, converted to line
temperature.

Alert Only The transmitter will post an alert.

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As soon as the drive gain drops below PVR Drive Gain Threshold, the transmitter
returns to reporting standard density.

9. If you set PVR Action to Hold Last Value, set PVR Lookback Period to the number of
seconds the transmitter will go back in process history to retrieve and average
process data.

10. Enable or disable PVR Timeout as desired.

Option Description

Enabled If PVR actions are applied for the number of seconds specified in PVR

Timeout Value, the transmitter performs the configured TBR Timeout
Action.

Disabled PVR actions continue until the drive gain drops below PVR Drive Gain

Threshold.

11. If you enabled PVR Timeout:

a) Set PVR Timeout Value to the number of seconds that the transmitter will

perform the PVR action before implementing PVR Timeout Action.

b) Set PVR Timeout Action to the action that the transmitter will perform if the

PVR timeout is reached.

Option

Alert The transmitter posts an alert, and continues PVR

Normal Measurement The transmitter returns to normal measurement, and

Description

actions.

does not post an alert.

Note

For the location of parameters not exclusive to the PVR software, refer to the
transmitter configuration and use manual.

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20 Micro Motion Multiphase Applications

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3 Transient Bubble Remediation (TBR)

3.1 Understanding the TBR application

Transient Bubble Remediation (TBR) is indicated for use with liquid streams that may
experience intermittent low levels of gas entrainment, i.e., gas carry-under. In the
standard configuration, TBR enables accurate oil measurement during periods of
entrained gas by providing a substitute density value based on the immediately preceding
process density.

Liquid with gas measurement process

The presence of entrained gas (or bubbles) can cause significant errors when measuring
the volume flow of liquid through a Coriolis meter. Because bubbles displace some of the
liquid in a flow stream, the measured volume of the mixture may differ from the actual
amount of liquid that emerges from the pipe downstream.

So how can you tell when a liquid contains gas? When bubbles are present in a liquid
stream, Coriolis meters will report an increase in drive gain coinciding with a decrease in
both fluid density
liquid-gas mixture. Therefore, in order to measure only the liquid portion of the stream,
the volume of the bubbles must be ignored or subtracted from the mixture total.
software performs exactly this function, using drive gain as the diagnostic indication that
bubbles or entrained gas is present in the liquid flow stream, and then substituting a
liquid-only density in place of the live measurement until the gaseous event has subsided.
When the gassy portion has passed, indicated by an associated drop in drive gain, the
software returns to reporting the live measured volume flow rate.

(1)

and mass flow rate due to the lower amount of mass contained in the

(2)

TBR

Compensating for gas in the liquid

Entrained gas, or bubbles in the process fluid, has a negative effect on measurement
accuracy, because entrained gas causes abrupt increases in drive gain, and the density
measurement of the mixture is temporarily low. The following figure shows how the
change in drive gain affects density measurement.

(1) High frequency sensors may erroneously report a higher fluid density when entrained gas is present, and therefore are not

recommended for use on liquids with entrained gas. High frequency sensors include F300, H300, and all T-Series sensors.

(2) The unmeasured gases can be (and are often) collected and processed separately downstream if desired (using a separator

for example).

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A

B

C

t

ρ

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Figure 3-1: Effect of transient bubbles on drive gain and density measurement

A. Drive gain (actual)

B. Density
C. Transient bubble condition
D. Drive gain (%)

A transient bubble condition is defined in terms of the sensor's drive gain: If the drive gain
exceeds the configured threshold, the selected TBR action is performed. The transient
bubble interval persists until drive gain is below the configured threshold.

TBR actions

The TBR application can perform either of the following actions if transient bubbles are
detected:

Alert Only

Hold Last Value

Post an alert

Report an average value from an earlier point in the process

Processing for Hold Last Value

This option directs the application to retrieve measured density data from an earlier point
in the process. The earlier point is identified by the configured TBR Lookback Period. The
density values around this point are averaged, and this average is then used in net oil
calculations.

The following figure shows the substitution of average density data during the transient
bubble interval.

22 Micro Motion Multiphase Applications

C

B

E

A

F

D D

Supplement Transient Bubble Remediation (TBR)

MMI-20026578 January 2022

Figure 3-2: Hold Last Value in operation

A. Density

B. TBR Drive Gain Threshold
C. Drive gain (actual)
D. TBR Lookback Period

E. Averaged density values

F. Drive gain (%)

Note

If the point defined by TBR Lookback Period happens to fall into a previous transient
bubble interval, the application automatically extends the lookback interval as required so
that the average is calculated from measured density data rather than substituted density
values.

3.2 Configure Transient Bubble Remediation (TBR) using ProLink III

TBR is used with liquid streams that may experience intermittent low levels of gas
entrainment. TBR allows the system to detect transient bubble conditions, and to take
either of two actions in response.

Procedure

1. Choose Device Tools → Configuration → Process Measurement → Transient
Bubble Remediation (TBR).

2. Set TBR Drive Gain Threshold to the value of drive gain, in percent, that indicates
the presence of bubbles in the process fluid.

Supplement 23

Transient Bubble Remediation (TBR) Supplement

January 2022 MMI-20026578

At drive gain values above this threshold, the transmitter will implement the
configured TBR actions.

3. Set TBR Action to the action that the transmitter will perform when TBR is active.

Option Description

Hold Last Value The transmitter will calculate volume using a substitute density

value. The substitute value is an average of the data around a
recent point in the process.

Alert Only The transmitter will post an alert.

4. If you set TBR Action to Hold Last Value, set Lookback Period to the number of
seconds the transmitter will go back in process history to retrieve and average
process data.

5. Enable or disable TBR Timeout as desired.

Option Description

Enabled If TBR is active for the number of seconds specified in TBR Timeout

Value, the transmitter performs the configured TBR Timeout Action.

Disabled TBR actions continue until the drive gain drops below TBR Drive Gain

Threshold.

6. If you enabled TBR Timeout:

a) Set TBR Timeout Value to the number of seconds that the transmitter will

perform TBR before implementing TBR Timeout Action.

b) Set TBR Timeout Action to the action that the transmitter will perform if the

TBR timeout is reached.

Option

Alert The transmitter returns to normal measurement and

Normal Measurement The transmitter returns to normal measurement, and

Description

an alert is posted..

does not post an alert.

Note

For the location of parameters not exclusive to the TBR software, refer to the
transmitter configuration and use manual.

24 Micro Motion Multiphase Applications

Supplement Transient Mist Remediation (TMR)

MMI-20026578 January 2022

4 Transient Mist Remediation (TMR)

4.1 Understanding the TMR application

TMR is designed for use with gas streams that may experience intermittent low levels of
liquid entrainment, i.e., liquid carry-over.

Entrained liquid, or mist in the process fluid, has a negative effect on measurement
accuracy, because entrained liquid causes abrupt increases in drive gain, and the density
measurement is temporarily low. TMR allows gas measurement to continue during
periods of entrained liquid (mist) by providing a substitute flow rate value based on the
immediately preceding process flow rate. When the mist interval is over, TMR returns to
reporting the measured flow rate, increased or decreased by a maximum of 10%, until flow
totals are appropriately adjusted for the unmeasured flow.

A transient mist condition is defined in terms of the sensor's drive gain: If the drive gain
exceeds the configured threshold, the transmitter automatically performs transient mist
remediation. The transient mist interval persists until drive gain is below the configured
threshold.

The following figure illustrates TMR processing.

Supplement 25

A

H

H

G G

E

E

F F

B

C

D D

Transient Mist Remediation (TMR) Supplement

January 2022 MMI-20026578

Figure 4-1: TMR in operation

A. Flow rate

B. TMR Drive Gain Threshold
C. Drive gain (actual)
D. Pre-Mist Averaging Period and source of M1

E. Averaged flow rate values

F. Post-Mist Adjustment Delay and source of M2
G. Adjustment period
H. Adjusted flow rate values

When TMR is detected, the transmitter substitutes an average flow rate value, M1, for the
measured flow rate, for the entire transient mist interval. The substitute flow rate is
calculated from the actual flow rate data for the previous n seconds, where n is
determined by the setting of Pre-Mist Averaging Period.

When the transient mist interval is over, the transmitter waits for the number of seconds
specified by Post-Mist Adjustment Delay. During that period, the transmitter calculates a
second average flow rate, M2. M1 and M2 are then averaged, producing an approximate
value for the actual flow rate during the transient mist interval. The measured flow rate is
then increased or decreased by a maximum of 10% until the flow total has been
compensated for all of the unmeasured flow.

26 Micro Motion Multiphase Applications

Supplement Transient Mist Remediation (TMR)

MMI-20026578 January 2022

4.2 Configure Transient Mist Remediation (TMR) using ProLink III

TMR is designed for use with gas streams that may experience intermittent low levels of
liquid entrainment.

Procedure

1. Choose Device Tools → Configuration → Process Measurement → Transient Mist
Remediation (TMR).

2. Enable the TMR application.

3. Set TMR Drive Gain Threshold to the value of drive gain, in percent, that indicates
the presence of mist in the process fluid.

At drive gain values above this threshold, the transmitter will initiate TMR.

4. Set Pre-Mist Averaging Period to the number of seconds over which flow rate will
be averaged to produce a substitute flow rate.

When mist is detected, the transmitter retrieves the most recent flow rate data for
the specified number of seconds, averages the data, and reports the result rather
than the measured flow rate.

5. Set Post-Mist Adjustment Delay to the number of seconds that the transmitter will
wait, after mist is detected, before beginning TMR adjustment.

During TMR adjustment, the transmitter increases or decreases the measured flow
rate by a maximum of 10%. The TMR adjustment continues until the flow total has
been completely compensated for the unmeasured flow.

Note

For the location of parameters not exclusive to the TMR software, refer to the
transmitter configuration and use manual.

Supplement 27

Transient Mist Remediation (TMR) Supplement

January 2022 MMI-20026578

28 Micro Motion Multiphase Applications

Supplement Display variables

MMI-20026578 January 2022

5 Display variables

5.1 Display variables available with PVR, TBR, and TMR

When PVR, TBR, or TMR is implemented on your transmitter, additional application­specific process variables are available to configure as display variables.

The following table lists the process variables that are available for configuration as display
variables. For instructions on configuring display variables, see the configuration manual
for your transmitter.

Table 5-1: Process variables available as display variables

Process variable Application

PVR TBR TMR

Oil Total At Line ✓

Water Total At Line ✓

Water Cut At Line ✓

Accumulated TBR Time ✓ ✓

Mass Flow (unremediated) ✓ ✓ ✓

Mass Total (unremediated) ✓ ✓ ✓

Mass Inventory (unremediated) ✓ ✓ ✓

Mass Flow (remediated) ✓

Mass Total (remediated) ✓

Mass Inventory (remediated) ✓

Meastured Oil Density At Reference
(Fixed API Units)

Meastured Oil Density At Reference
(Fixed SGU Units)

Oil Flow Rate At Line ✓

Oil Flow Rate At Reference ✓

Oil Total At Reference ✓

Unremediated Density At Line ✓ ✓

Unremediated Volume Flow At Line ✓ ✓

✓

✓

Unremediated Volune Total At Line ✓ ✓

Volume Flow (remediated) ✓ ✓ ✓

Volume Total (remediated) ✓ ✓ ✓

Volume Inventory (remediated) ✓ ✓ ✓

Supplement 29

Display variables Supplement

January 2022 MMI-20026578

Table 5-1: Process variables available as display variables (continued)

Process variable Application

PVR TBR TMR

Water Cut At Reference ✓

Water Flow Rate At Line ✓

Water Flow Rate At Reference ✓

Water Total At Reference ✓

30 Micro Motion Multiphase Applications

Supplement Application parameters and data

MMI-20026578 January 2022

A Application parameters and data

To use Modbus to configure other parameters, see the Micro Motion Modbus Interface Tool.

This information is provided for completeness.

A.1 PVR parameters and data

Table A-1: PVR configuration parameters

Parameter Description Modbus location and data type

Application Status Enabled/disabled Coil 75, coil 246 (write to both coils)

• 0=Disabled

• 1=Enabled

Density of Dry Oil at
Reference Temperature

Density of Water at
Reference Temperature

PVR Drive Gain Threshold The drive gain, in %, that

PVR Drive Gain Threshold
High

PVR Action The remediation action to

Density of dry oil from this
well, in g/cm³, at 60 °F

Density of produced
water from this well, in
g/cm³, at 60 °F

triggers the configured
PVR remediation action

The drive gain, in %, that
represents a significant
amount of gas in the
liquid stream. The
transmitter sets a flag.

be implemented

1959–1960, Float

1831–1832, Float

617–618, Float

343–344, Float

ETO ≤ v3.95 624 Bit 0, U16

• 0=Calculate volume from a substitute

density value, derived from averaged
density values from an earlier point in
the process

• 1=Alert only

ETO > v3.95 4450, U16

• 0=Calculate volume from a substitute

density value, derived from averaged
density values from an earlier point in
the process

• 1=Alert only

• 2=Calculate volume using the

configured value for oil density,
converted to line temperature

PVR Lookback Period The number of seconds to

go back to determine a
substitute density value

Supplement 31

620, U16

Application parameters and data Supplement

January 2022 MMI-20026578

Table A-1: PVR configuration parameters (continued)

Parameter Description Modbus location and data type

PVR Timeout Enable or disable a

timeout on the PVR
remediation action

PVR Timeout Value The number of seconds

that PVR remediation will
be performed before
timing out

PVR Timeout Action The action to be

performed if PVR
remediation times out

Enable Shrinkage Factor
Adjusted Volume Flow
Outputs

Shrinkage Factor User-defined oil shrinkage

Shrinkage Meter Factor User-defiined oil

Enables a set of variables
that are adjusted for user­defined oil shrinkage

value, using a no-flow
computer.

shrinkage value using the
meter/transmitter. Users
can restrict the meter
factor to the shrinkage
factor level for easier
record keeping.

624 Bit 6, U16

• 0=Disabled

• 1=Enabled

619, U16

624 Bit 1, U16

• 0=Normal Measurement

• 1-Alert

Coil 376

1689-1960, Float

3992-3993, Float

Sales Density Enables comparison of

produced density to sales
density to determine the
shrinkage factor.

Table A-2: PVR application status

Modbus location and
data type

52–55,
8–byte ASCII

Value Description

DENSHI The calculated uncorrected water cut is greater than 100%. Water

DENSLO The calculated uncorrected water cut is less than 0%. Water cut is

GVF_HI The GVF is high; drive gain is higher than PVR Drive Gain Threshold

GVF_LO The GVF is low; drive gain is between PVR Drive Gain Threshold and

(eight space
characters)

4465-4466, Float

cut is reported as 100%.

reported as 0%.

High.

PVR Drive Gain Threshold High.

No condition is active.

32 Micro Motion Multiphase Applications

Supplement Application parameters and data

MMI-20026578 January 2022

Table A-3: PVR process variables

Process variable Value Modbus location

No entrained
gas detected

Entrained gas detected

and data type

Water Cut At Line Calculated water cut at line

conditions

Water Cut At Reference

Water Flow Rate At Line

(1)

Calculated water cut at 60 °F Core Processor ETO < v4.13:01557–1558, Float

(1)

Net volume flow rate of the
water at line conditions

Core Processor ETO < v4.13:01555–1556, Float

Core Processor ETO ≥ v4.13:

• PVR Action=0 or 1:

Calculated water cut at
line conditions

• PVR Action=2: 0

Core Processor ETO ≥ v4.13:

• PVR Action=0 or 1:

Calculated water cut at
60 °F

• PVR Action=2: 0

Core Processor ETO < v4.13:01561–1562, Float

Core Processor ETO ≥ v4.13:

• PVR Action=0 or 1: Net

volume flow rate at line
conditions

• PVR Action=2: 0

Water Total At Reference

(1)

Net volume flow rate of the

0 1549–1550, Float

water at 60 °F

Water Total At Line Net volume total of the

water at line conditions,
incrementing

Core Processor ETO < v4.13:
Net volume total of the
water at line conditions held

1667–1668, Float

at previous value; total does
not increment

Core Processor ETO ≥ v4.13:

• PVR Action=0 or 1: Net

volume flow rate at line
conditions,
incrementing

• PVR Action=2: Net

volume total of the
water at line conditions
held at previous value;
total does not increment

Supplement 33

Application parameters and data Supplement

January 2022 MMI-20026578

Table A-3: PVR process variables (continued)

Process variable Value Modbus location

and data type

1663–1664, Float

Water Total At Reference

No entrained
gas detected

(1)

Net volume total of the
water at 60 °F, incrementing

Entrained gas detected

Core Processor ETO < v4.13:
Net volume total of the
water at 60 °F held at
previous value; total does
not increment

Core Processor ETO ≥ v4.13:

• PVR Action=0 or 1: Net

volume flow rate at
60 °F, incrementing

• PVR Action=2: Net

volume total of the
water at 60 °F held at
previous value; total
does not increment

Oil Density At Line (Fixed
SGU Units)

(1)

Density of the oil at 60 °F
(user-specified), converted
to line conditions using line
temperature and API Even
Table Correction for “A
Tables” (Temp
DensityOil

@60F

,

@Line

), then

reported in SGU units

Oil Density At Line (Fixed API

(1)

Units)

Density of the oil at 60 °F
(user-specified), converted
to line conditions using line
temperature and API Even
Table Correction for “A
Tables” (Temp
DensityOil

@60F

,

@Line

), reported in

°API

Oil Flow Rate At Line

(1)

Volume flow rate of oil at
line conditions

Oil Flow Rate At
Reference

(1)

Volume flow rate of oil at
60 °F

Oil Total Rate At Line Net volume total of the oil at

line conditions

Oil Total At Reference

(1)

Net volume total of the oil at
60 °F

Density of the oil at 60 °F
(user-specified), converted
to line conditions using line
temperature and API Even
Table Correction for “A
Tables” (Temp
DensityOil

@60F

,

@Line

), then

reported in SGU units

Density of the oil at 60 °F
(user-specified), converted
to line conditions using line
temperature and API Even
Table Correction for “A
Tables” (Temp
DensityOil

@60F

,

@Line

), reported in

°API

Volume flow rate of oil at
line conditions

Volume flow rate of oil at
60 °F

Net volume total of the oil at
line conditions

Net volume total of the oil at
60 °F

345–346, Float

347–348, Float

1553–1554, Float

1547–1548, Float

1665–1666, Float

1661–1662, Float

Density Density of the oil and water

mixture, at line conditions

Core Processor ETO < v4.13:
Remediated density of the

249–250, Float

mixture at line conditions,
with the configured TBR
action applied

34 Micro Motion Multiphase Applications

Supplement Application parameters and data

MMI-20026578 January 2022

Table A-3: PVR process variables (continued)

Process variable Value Modbus location

No entrained
gas detected

Entrained gas detected

Core Processor ETO ≥ v4.13:

• PVR Action=0 or 1:

Remediated density of
the mixture at line
conditions, with the
configured TBR action
applied

• PVR Action=2: User-

specified density of oil at
60 °F, converted to line
conditions

and data type

Mass Flow Rate Mass flow rate of the liquid

mixture, unremediated for
PVR

Mass Total Mass total of the liquid

mixture, unremediated for
PVR

Mass Inventory Mass inventory of the

mixture, unremediated for
PVR

Volume Flow Rate Volume flow rate of the

mixture, remediated for PVR

Volume Total Total volume of the mixture

at line conditions,
remediated

Volume Inventory Volume inventory of the

mixture, remediated for PVR

Unremediated Volume Flow
Rate At Line

(1)

Volume flow rate of the
mixture at line conditions,
with TBR correction
(unremediated)

Volume Total At Line

(1)

Total volume of the mixture
at line conditions, without
TBR correction
(unremediated)

Accumulated TBR Time

(2)

Total number of seconds
that TBR correction has
been active, since the last
master reset

Mass flow rate of the liquid
mixture, unremediated for
PVR

Mass total of the liquid
mixture, unremediated for
PVR

Mass inventory of the
mixture, unremediated for
PVR

Volume flow rate of the
mixture, remediated for PVR

Total volume of the mixture
at line conditions,
remediated

Volume inventory of the
mixture, remediated for PVR

Volume flow rate of the
mixture at line conditions,
with TBR correction
(unremediated).

Total volume of the mixture
at line conditions, without
TBR correction
(unremediated)

Total number of seconds
that TBR correction has
been active, since the last
master reset

247–248, Float

259–260, Float

263–264, Float

253–254, Float

261–262, Float

265–266, Float

2265–2266, Float

349-350, Float

2267–2268, INT32

Shrinkage Factor Oil Flow
Rate At Line

(3)

Volume flow of oil at line
conditions, adjusted by
shrinkage factor and
shrinkage meter factor

Volume flow of oil at line
conditions, adjusted by
shrinkage factor and
shrinkage meter factor

1733–1734, Float

Supplement 35

Application parameters and data Supplement

January 2022 MMI-20026578

Table A-3: PVR process variables (continued)

Process variable Value Modbus location

No entrained
gas detected

Entrained gas detected

and data type

Shrinkage Factor Oil Flow
Rate At Reference

(3)

Shrinkage Factor Volume
Flow Rate At Reference

Shrinkage Factor Oil Total at

(3)

Line

Shrinkage Factor Oil Total at
Reference

Shrinkage Factor Volume
Total At Reference

(3)

(3)

Measured Oil Density At
Reference (Fixed SGU

(3)

Units)

Measured Oil Density At
Reference (Fixed API

(3)

Units)

Unremediated Density

Volume flow of oil at
reference conditions,
adjusted by shrinkage factor
and shrinkage meter factor

Volume flow of the mix at

(3)

reference conditions

Volume Total of the mix at
line conditions

Oil Total of the mix at
reference conditions

Volume Total of the mix at
reference conditions

Density of the mixture at 60
°F, assuming the mixture is
all oil. reported in SGU Units

Density of the mixture at 60
°F, assuming the mixture is
all oil. reported in °API.

(4)

Density of the mixture at

Volume flow of oil at
reference conditions,
adjusted by shrinkage factor
and shrinkage meter factor

Volume flow of the mix at
reference conditions

Volume Total of the mix at
line conditions

Oil Total of the mix at
reference conditions

Volume Total of the mix at
reference conditions

1735–1736, Float

1737–1738, Float

4616–4617, Float

4618–4619, Float

4796–4797, Float

1655–1666, Float

4465–4466, Float

1539–1540, Float
line conditions
(unremediated for PVR)

(1) Not available when connected to a transmitter.
(2) Requires the enhanced core processor v4.11 or later with ETO 22166 or ETO 22701.
(3) Requires the enhanced core processor v4.31 or later with ETO 22166 or ETO 22701.
(4) Requires the enhanced core processor v4.40 or later with ETO 22166 or ETO 22701. If for direct connect, use ETO

13386 or the standard 800 v4.42 or greater if connected to a Model 2700 Transmitter.

36 Micro Motion Multiphase Applications

Supplement Application parameters and data

MMI-20026578 January 2022

A.2 TBR parameters and data

Table A-4: TBR configuration parameters

Parameter Description Modbus location and data type

Drive Gain Threshold The drive gain, in %, that triggers TBR 617–618, Float

TBR Action The remediation action to be implemented 624, U16

• Bit #0: Initial Action
— 0=Hold Last Value

— 1=Alert Only

• Bit #2: Drive Gain Averaging
— 0=1 second

— 1=4 seconds

• Bit #3: Apply to Mass Flow (affects volume

flow)

— 0=Yes

— 1=No

• Bit #4: Apply to Density (affects volume

flow)

— 0=Yes

— 1=No

• Bit #5: Timeout Alert Type
— 0=Two-Phase Flow

— 1=Density Out of Range

TBR Lookback Period

TBR Timeout Enable or disable a timeout on the TBR

TBR Timeout Value The number of seconds that TBR remediation

TBR Timeout Action The action to be performed if TBR remediation

The time period (seconds) that the application
goes back in time to determine the substitute
density to use in calculations

remediation action

will be performed before timing out

times out

620, U16

624 Bit #6, U16

• 0=Disabled

• 1=Enabled

619, U16

624 Bit #1, U16

• 0=Normal Measurement

• 1=Alert

Table A-5: TBR application status parameters

Application status Description Modbus location and data type

TBR Active Indicates whether TBR is active or inactive 433 Bit #10, U16

TBR Total Time The duration of the TBR interval, in seconds 989, U32

Supplement 37

Application parameters and data Supplement

January 2022 MMI-20026578

Table A-6: TBR process variables

Process variable Description Modbus location and

data type

Mixture Mass Flow Rate (unremediated) Mass flow rate of the mixture, unremediated 247–248, Float

Mixture Mass Total (unremediated) Mass total of the mixture, unremediated 259–260, Float

Mixture Mass Inventory (unremediated) Mass inventory of the mixture, unremediated 263–264, Float

Mixture Uncorrected Volume Flow Rate
(remediated)

Mixture Uncorrected Volume Total
(remediated)

Mixture Uncorrected Volume Inventory
(remediated)

Unremediated Density

(1) Requires the enhanced core processor v4.40 or later with ETO 13386 for direct connect, or the standard 800 v4.42 or

greater if connected to a Model 2700 Transmitter.

(1)

Volume flow rate of the mixture, remediated 253–254, Float

Total volume of the mixture at line conditions,
remediated

Volume inventory of the mixture at line
conditions, remediated

Volume inventory of the mixture at line
conditions, remediated

261–262, Float

265–266, Float

1539-1540, Float

A.3 TMR parameters and data

Table A-7: TMR configuration parameters

Parameter Description Modbus location and data type

Application Status Enabled/disabled Coil 75 (Core processor version less than

v4.40)
Coil 473 (Core processor version 4.40 or

greater.)

• 0=Disabled

• 1=Enabled

Drive Gain Threshold The drive gain, in %, that triggers TMR 617–618, Float

Pre–Mist Averaging
Period

Post–Mist Adjustment
Delay

TMR Action The remediation action to be implemented 624, U16

The time period (seconds) that the application
goes back in time to determine the density to
use in TMR remediation

The time period (seconds) that the transmitter
waits before beginning density adjustment

619, U16

620, U16

• Bit #5: Timeout Alert Type
— 0=Two–Phase Flow

— 1=Density Out of Range

Table A-8: TMR application status parameters

Application status Description Modbus location and data type

TMR Active Indicates whether TMR is active or inactive 433 Bit #12, U16

38 Micro Motion Multiphase Applications

Supplement Application parameters and data

MMI-20026578 January 2022

Table A-8: TMR application status parameters (continued)

Application status Description Modbus location and data type

TMR Total Time The duration of the TMR interval, in seconds 989, U32

Table A-9: TMR process variables

Process variable Description Modbus location and

data type

Mass Flow Rate (remediated) Mass flow rate of the process fluid, remediated 973–974, Float

Mass Total (remediated) Mass total of the process fluid, remediated 975–976, Float

Mass Inventory (remediated) Mass inventory of the process fluid,

977–978, Float

remediated

Mass Flow Rate (unremediated) Mass flow rate of the process fluid,

247–248, Float

unremediated

Mass Total (unremediated) Mass total of the process fluid, unremediated 259–260, Float

Mass Inventory (unremediated) Mass inventory of the process fluid,

263–264, Float

unremediated

Uncorrected Liquid Volume Flow Rate
(remediated)

Uncorrected Liquid Volume Total
(remediated)

Uncorrected Liquid Volume Inventory
(remediated)

(1)

(1)

(1)

Corrected GSV Flow Rate (remediated)

(2)

Volume flow rate of the process fluid,
remediated

Total volume of the process fluid at line
conditions, remediated

Volume inventory of the process fluid at line
conditions, remediated

Corrected GSV flow rate of the process fluid,

253–254, Float

261–262, Float

265–266, Float

455–456, Float

remediated

Corrected GSV Total (remediated)

(2)

Corrected GSV total of the process fluid,

457–458, Float

remediated

Corrected GSV Inventory (remediated)

(2)

Corrected GSV inventory of the process fluid,

459–460, Float

remediated

(1) Applicable if Volume Flow Type = Liquid.
(2) Applicable if Volume Flow Type = Gas Standard Volume. GSV is available with TMR for transmitters v6.62 and later.

Supplement 39

Application parameters and data Supplement

January 2022 MMI-20026578

40 Micro Motion Multiphase Applications

Supplement Best practices for two-phase measurement performance

MMI-20026578 January 2022

B Best practices for two-phase

measurement performance

B.1 Entrained gas performance

Measurement accuracy for liquids with entrained gas is a complex function of GVF,
viscosity, velocity, sensor geometry, drive frequency, and orientation. The best
measurement performance will always be achieved if fluid can be measured in single­phase. Add a free-gas knockout upstream if possible. The following guidelines apply
regardless if APM options are licensed or not. When gas entrainment is inevitable, APM will
improve the measurement performance.

Common sources for unintentional gas entrainment

• Long drops from fill point to liquid level in tanks

• Agitators and mixers

• Leaks in seals or pumps

• Pumping out of nearly empty tanks

• Pressure loss (flashing) for volatile liquids

• Pumping through nearly empty piping

Ways to minimize flow errors

• Use ELITE® (low frequency) sensors whenever possible. F-Series and H-Series sensors

are also acceptable, but less accurate.

• Do not use T-Series sensors or Models F300/H300 compact because they have a high

operating frequency.

• Use the enhanced core processor (Model 800) either as direct connect or with the

1000-2000 Transmitter family: they perform best in applications with entrained gas.

• Orient the meter properly:

Table B-1: Preferred sensor orientation for liquids with entrained gas

Process Preferred orientation

Delta-shaped sensors (CMF010, CMF025,
CMF050, CMF100)

Supplement 41

Best practices for two-phase measurement performance Supplement

January 2022 MMI-20026578

Table B-1: Preferred sensor orientation for liquids with entrained gas (continued)

Process Preferred orientation

Any F-Series or CMFS sensor, and CMF200 or
larger (flow should go up)

• Ensure sensor is filled as quickly as possible, and stays full during measurement:
— For horizontal pipes, maintain a minimum flow velocity of 1 m/s to purge air from

an empty pipe and keep it full.

— For vertical pipes, flow upward and maintain minimum velocity of 1 m/s to prevent

solids from settling out of the fluid.

• Add back pressure, or increase line pressure, to minimize size of bubbles in flow

stream.

• Size the meter appropriately to operate normally as close to the sensor nominal flow

rate as is practical. Higher velocity leads to better performance, as long as pressure
drop does not cause liquids flash.

• Ensure fluid is well mixed. If needed, you can install a blind “T” and/or static mixer just

upstream of the sensor to evenly distribute bubbles through both sensor tubes. If using
a blind “T”, install it in the same plane as the sensor tubes.

• If re-zeroing in the field is necessary, zeroing must be done on a pure liquid without

bubbles in order to avoid error. If this cannot be done, use the factory zero.

• Minimize damping on outputs to minimize processing delay from electronics.

• Do not stop the totalizer immediately after batch; allow the totalizer to stabilize for

approximately 1 second.

• Set Flow Cutoff as high as is practical to avoid totalizing at no flow condition if bubbles

remain in the sensor.

B.2 Entrained liquid (mist) performance

Measurement accuracy for gases with entrained liquids (mist) is mostly related to the
amount of mass contained in liquid droplets compared to an equivalent volume of gas
containing the same mass. It is important to choose the correct sensor. Otherwise, sensor
geometry, drive frequency, and orientation can cause errors that reduce performance. The
best measurement performance will always be achieved if fluid can be measured in single­phase. Add a liquid trap upstream if possible. The following guidelines apply regardless if
APM options are licensed or not. When liquid entrainment is inevitable, APM will improve
the measurement performance.

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Common sources for unintentional liquid entrainment

• Temperature loss (condensation)

• Pressure increase

• Poorly managed level control in separators or GLCCs

• Malfunctioning or over-filled liquid traps

Ways to minimize measurement errors

• Use ELITE® (low frequency) sensors whenever possible. F-Series and H-Series sensors

are also acceptable, but less accurate.

• Size the meter appropriately for gas flow. Avoid high turndowns where sensor

sensitivity may be reduced.

• Do not use T-Series sensors or compact Models F300/H300 because they have a high

operating frequency.

• Use the enhanced core processor (Model 800) or the 1000-2000 transmitter family:

they perform best in applications with entrained liquid.

• Use the enhanced core processor (Model 800) either as direct connect or with the

1000-2000 transmitter family: they perform best in applications with entrained liquid.

• Orient the meter properly:

Table B-2: Preferred sensor orientation when there could be entrained liquid

Process Preferred orientation

Delta-shaped sensors (CMF010, CMF025,
CMF050, CMF100)

Any F-Series or CMFS sensor, and CMF200 or
larger (flow should go down)

• Ensure sensor is dried (blown-out) as quickly as possible, and stays dry during

measurement.

• Avoid temperature losses; insulation is highly recommended if condensate is caused by

cooling temperatures.

• Avoid pressure increases in the system; Ensure that pressure regulators are functioning

properly.

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Best practices for two-phase measurement performance Supplement

January 2022 MMI-20026578

• If entrained liquid is unavoidable, try to ensure that the process is well mixed.

• Avoid elbows, valves, or other components that may introduce a flow profile affecting

one tube (for example, a swirling motion entering the flow tubes)

• If re-zeroing in the field is necessary, zeroing must be done on a pure gas without liquid

in order to avoid error. If this cannot be done, use the factory zero.

• Minimize damping on outputs to minimize processing delay from electronics.

• Do not stop the totalizer immediately after batch; allow the totalizer to stabilize for

approximately 1 second.

• Set Flow Cutoff as high as is practical to avoid totalizing at no flow condition if droplets

remain in the sensor.

B.3 Density determination

If you are using either the PVR application or the , you must know the density of water
from the well, corrected to reference temperature, and the density of dry oil from the well,
corrected to reference temperature.

B.3.1

Important

Micro Motion recommends working with a laboratory to obtain the most accurate values.
The accuracy of the PVR data depends upon the accuracy of these two density values.

Density determination using a petroleum laboratory

To configure PVR for net oil measurement, you must know the density of oil at reference
temperature, and the density of produced water at reference temperature. You can obtain
these values from a petroleum laboratory.

Note

Even after separation, oil typically contains some amount of interstitial water. The water
cut may be as high as 1% to 3%.

Important

If you are using a three-phase separator, you can collect the oil sample and the water
sample separately, after separation, or you can collect one sample before separation and
have the laboratory perform the separation.

If you are using a two-phase separator, you should collect one sample before separation
and have the laboratory perform the separation.

Prerequisites

Sample collection must meet these requirements:

• You must be able to collect a sample that is representative of your process.

• The sample must be collected by a qualified person, using industry-accepted safety

standards.

• You must know the minimum required sample size. This varies depending on the water

cut and the volume of the sample cylinder. Consult the petroleum laboratory for
specific values.

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• If the sample contains oil, you must be able to collect and maintain the sample at line

pressure, so that the oil will not lose pressure and outgas. This will change the
laboratory-measured density.

• If you collect the water sample separately, you must be able to protect it from

contamination and evaporation.

You must know the reference temperature that you plan to use.

The petroleum laboratory must be able to meet these requirements:

• The laboratory density meter must be able to keep the oil sample pressurized at line

pressure during the density measurement.

• The sample cylinder must be a constant-pressure type, and must be properly rated for

the oil–water composition and for sample pressure.

• The oil and water density measurement units must be entered into the PVR software in

g/cm³ at reference temperature (always 60 °F with an enhanced core processor direct
connect or with the 1000-2000 transmitter family).

• The laboratory report must include the oil density, water density, and the reference

temperature.

Procedure

1. Communicate the handling and measurement requirements and the reference

temperature to the petroleum laboratory.

2. If you are collecting one sample that contains both oil and water, identify the point

in the line where the sample will be taken.

Recommendations:

• Collect the sample at a point where the fluid is well mixed.

• The line pressure at the sample point should be close to the line pressure at the

sensor.

• The line temperature at the sample point should be close to the line

temperature at the sensor.

3. If you are using a three-phase separator and collecting the oil and water samples
separately:

a) Identify the points where the samples will be taken.

Recommendations:

• The sample point for oil must be on the oil leg, as close to the sensor as

possible.

• The line pressure at the oil sample point should be similar to the line

pressure at the sensor.

• The sample point for water must be on the water leg, as close to the

sensor as possible.

• The line temperature at the water sample point should be similar to the

line temperature at the sensor.

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Best practices for two-phase measurement performance Supplement

January 2022 MMI-20026578

b) Wait until separation has occurred.

4. Collect the sample or samples, meeting all requirements for pressure and
protection from contamination or evaporation.

5. Mark and tag the sample or samples with the well name or number, time and date,
sample type, line pressure, and line temperature.

6. Transport the samples to the laboratory safely, as soon as is practical.

Postrequisites

If the laboratory measurements were not corrected to your reference temperature, use
the Oil & Water Density Calculator to calculate density at reference temperature. This is a
spreadsheet tool developed by Micro Motion. You can obtain a copy by visiting https://

www.emersonflowsolutions.com/oildensityref or from your Micro Motion representative.

B.3.2

Density determination using a three-phase separator

To configure net oil measurement, you must know the density of dry oil at reference
temperature, and the density of produced water at reference temperature. If you have a
three-phase separator, you can use density data and the Oil & Water Density Calculator to
obtain these values.

Note

Even after separation, oil typically contains some amount of interstitial water. The water
cut may be as high as 1% to 3%. For purposes of this application, this is considered dry oil.

Prerequisites

You must have a three-phase separator in the process. You can use a mobile three-phase
test separator.

You must have a sensor and transmitter installed on the oil leg, and a sensor and
transmitter installed on the water leg or determine the water density separately by manual
sampling.

You must know the reference temperature that you plan to use (always 60 °F (15.6 °C)
with an enhanced core processor direct connect or with the 1000-2000 transmitter
family).

You must have the Oil & Water Density Calculator. This is a spreadsheet tool developed by
Micro Motion. You can obtain a copy from your Micro Motion representative or by visiting

https://www.emersonflowsolutions.com/oildensityref.

Important

The accuracy of net oil data depends on the accuracy of the density data. Never use an
unstable density value, or any density value that has an elevated drive gain.

Procedure

1. Wait until separation has occurred.

2. At the transmitter on the oil leg, do one of the following options:

• Read and record the density value and the temperature value

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• If logging the live variable data, monitor the live density at line conditions, or the

corrected density at 60 °F (15.6 °C) (modbus register 1655)

3. At the transmitter on the water leg, read and record the density value and the
temperature value. Alternatively, enter the density of the water obtained by
another method, such as sampling.

4. Use the Oil & Water Density Calculator to calculate the density of dry oil at reference
temperature and the density of produced water at reference temperature. You can
obtain a copy from your Micro Motion representative or by visiting https://

www.emersonflowsolutions.com/oildensityref.

Tip

Unless the oil is light hot condensate, the oil will almost always contain some
interstitial water. This is generally acceptable for allocation measurements.
However, if further accuracy is desired, you can determine the water cut and use it
in the calculation. To determine or estimate the water cut, take a shakeout sample
from one of the following:

• The current flow/dump cycle, at the time of minimum density

• Similar oils produced from the same reservoir

• The tank or tanks that the separator flows into

Enter this water cut into the Oil & Water Density Calculator to calculate the density
of dry oil at reference temperature.

Supplement 47

MMI-20026578

Rev. AD

2022

For more information:

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