Micro Motion Application Manual: 5700 Micro Motion Advanced Phase Measurement Manuals & Guides

Micro Motion™ Advanced Phase
Measurement

Application Manual

Application Manual

MMI-20030076, Rev AD

September 2020

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.

or through your local Micro Motion support center.

Emerson Flow customer service

Email:

• Worldwide: [e-mail]

• Asia-Pacific: [e-mail]

Telephone:

North and South America Europe and Middle East Asia Pacific

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

Canada [phone] The Netherlands [phone]

6666

Mexico [phone] France [phone]

901

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

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

Chile [phone] Central & Eastern [phone]

111

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New Zealand 099 128 804

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Japan [phone]

2

Application Manual Contents

MMI-20030076 September 2020

Contents

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

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

1.2 Related documentation............................................................................................................... 5

1.3 About the software...................................................................................................................... 6

1.4 APM software requirements.........................................................................................................7

1.5 Terms and definitions.................................................................................................................. 9

Chapter 2 Measurement options and configuration................................................................. 11

2.1 Liquid with gas...........................................................................................................................11

2.2 Net oil........................................................................................................................................17

2.3 Gas with liquid........................................................................................................................... 21

Chapter 3 Additional configuration.......................................................................................... 27

3.1 Configure viewing and reporting for process variables............................................................... 27

3.2 Configure APM contract totals into the totalizer history log....................................................... 30

3.3 Configure events....................................................................................................................... 31

Chapter 4 Transmitter operation..............................................................................................33

4.1 Read process variables...............................................................................................................33

4.2 Read contract totals...................................................................................................................33

Chapter 5 APM alerts............................................................................................................... 35

Appendix A Application parameters and data............................................................................. 37

A.1 Advanced Phase Measurement Modbus configuration parameters............................................37

A.2 Advanced Phase Measurement default totalizer and inventory values....................................... 38

A.3 Advanced Phase Measurement Modbus process variables......................................................... 39

A.4 Period Averaged Options current period data............................................................................40

Appendix B Typical oil and gas applications and other information............................................. 43

B.1 Advanced Phase Measurement with a two-phase separator.......................................................43

B.2 Advanced Phase Measurement with a three-phase separator.................................................... 44

B.3 Advanced Phase Measurement at the wellhead......................................................................... 45

B.4 Automatic Drive Gain Threshold determination.........................................................................46

B.5 Manual Drive Gain Threshold..................................................................................................... 47

Appendix C Best practices for two-phase measurement performance......................................... 49

C.1 Entrained gas performance........................................................................................................49

C.2 Entrained liquid (mist) performance.......................................................................................... 50

C.3 Density determination...............................................................................................................52

Application Manual 3

Contents Application Manual

September 2020 MMI-20030076

4 Micro Motion Advanced Phase Measurement

Application Manual Before you begin

MMI-20030076 September 2020

1 Before you begin

1.1 About this application manual

This application manual explains how to configure and use the Advanced Phase
Measurement licensed software option on select Model 5700 transmitters. It also contains
limited, supplemental installation and configuration information specifically related to the
Advanced Phase Measurement software. Refer to the sensor and transmitter installation
manuals and the transmitter configuration and use manual for complete information.

Important

This manual assumes that:

• The transmitter has been installed correctly and completely according to the

instructions in the transmitter installation manual

• Users understand basic transmitter and sensor installation, configuration, and

maintenance concepts and procedures

1.2 Related documentation

You can find all product documentation on the product documentation DVD shipped with
the product or at www.emerson.com.

See any of the following documents for more information:

• Model 5700 installation manual
— Micro Motion 5700 Transmitters with Configurable Inputs and Outputs: Installation

Manual

— Micro Motion 5700 with Ethernet Transmitters: Installation Manual

— Micro Motion 5700 Transmitters for FOUNDATION™ Fieldbus: Installation Manual

— Micro Motion 5700 Transmitters with Intrinsically Safe Outputs: Installation Manual

— Micro Motion 5700 Transmitters for PROFIBUS-PA: Installation Manual

• Model 5700 configuration and use manual
— Micro Motion 5700 Transmitters with Configurable Inputs and Outputs: Configuration

and Use Manual

— Micro Motion 5700 with Ethernet Transmitters: Configuration and Use Manual

— Micro Motion 5700 Transmitters for FOUNDATION™ Fieldbus: Configuration and Use

Manual

— Micro Motion 5700 Transmitters with Intrinsically Safe Outputs: Configuration and Use

Manual

— Micro Motion 5700 Transmitters for PROFIBUS-PA: Configuration and Use Manual

• Micro Motion Enhanced Density Application Manual

• Micro Motion Modbus Map

Application Manual 5

Before you begin Application Manual

September 2020 MMI-20030076

• Micro Motion ProLink III with ProcessViz Software User Manual

• Micro Motion Ethernet PROFINET Siemens Integration Guide

• Sensor installation manual

1.3 About the software

Micro Motion Advanced Phase Measurement software improves long-term flow reporting
and measurement performance in processes with intermittent periods of two-phase flow,
including liquids with entrained gas or gas with entrained liquid. And if it is combined with
the Net Oil or Concentration Measurement software options, the software can also report
liquid concentration, Net Oil, and/or Gas Void Fraction (GVF) during the same two-phase
conditions.

There are three measurement options for the Advanced Phase Measurement software:
Net Oil, Liquid with Gas, and Gas with Liquid.

Note

Each option is licensed separately in the transmitter. Field upgrades are permitted.

Table 1-1: Net oil options (choose one)

License option (ordering
code)

MA - Manual Advanced Phase
Measurement configuration

MW - Net Oil Computer (NOC)
software - multiple wells

Description Availability

Suitable for a mixture of oil and
water under predictable flow
conditions.
Includes manual drive gain
threshold only. See Manual

Drive Gain Threshold.

This option is the Model 5700
upgrade for Production Volume
Reconciliation (PVR).

Ideal for test separators shared
by multiple wells.

The transmitter stores a total of
three well tests in memory. The
transmitter can be set up for
testing up to 48 independently­configured wells; however, only
the most recent three tests
that have been completed
remain in storage at a time.

Suitable for mixtures of oil and
water, with remediation for
gas.

• Not available on a

transmitter with
intrinsically safe or non­intrinsically safe
FOUNDATION™ Fieldbus H1
outputs

• Not available on a

transmitter with
intrinsically safe outputs

• Do not combine with APM

liquid with gas (option PL) ­basic remediation for gas is
included.

• Do not combine with APM

liquid with gas (option PL) ­already included.

• Only available on a

transmitter with
configurable outputs

6 Micro Motion Advanced Phase Measurement

Application Manual Before you begin

MMI-20030076 September 2020

Table 1-1: Net oil options (choose one) (continued)

License option (ordering
code)

PO - Net Oil Suitable for mixtures of oil and

Description Availability

water. Add PL option to
remediate for gas.

Table 1-2: Liquid with gas

License option (ordering
code)

PL - Advanced Phase
Measurement Liquid with Gas

Description Availability

Suitable for any liquid with
entrained gas.

Table 1-3: Gas with liquid

License option (ordering
code)

PG - Advanced Phase
Measurement Gas with Liquid

Description Availability

Suitable for any gas that may
contain entrained liquids
(mist).

Can be combined with APM
license code PL. PL is
recommended since most net
oil applications contain gas.

• Can be combined with APM

license code PO.

• Can be combined with

license code concentration
measurement (CM).

Cannot be activated with any
other license code.

1.4 APM software requirements

Ensure that your installation meets the requirements in this section.

Transmitter

Advanced Phase Measurement software is available only on the Model 5700 transmitter,
either integrally mounted, in a 9-wire remote configuration, or in combination with any
800 Enhanced Core Processor.

Not available with:

• Weights & Measures -NTEP (option NT)

• Safety certification of 4-20 mA outputs per IEC 61508 (option SI)

Sensor

Advanced Phase Measurement software is compatible with any sensor that is supported
by the Model 5700 transmitter except for the T-Series and R-Series sensors due to limited
performance with two-phase fluids. The software is not compatible with the 700 Standard
Core processor.

Installation and wiring

• Follow the installation and wiring instructions in the sensor and transmitter installation

manuals.

Application Manual 7

Before you begin Application Manual

September 2020 MMI-20030076

• Identify and follow any application-specific installation needs as identified in this

manual for your application type.

• For the entrained gas/mist/empty-full-empty best installation practices, refer to Best

practices for two-phase measurement performance.

• If you plan to use the net oil measurement option with an external water cut monitor:
— For the 5700 configurable transmitter, Channel D on the transmitter must be

enabled, and must be configured as a mA Input, wired to the water cut monitor,
and configured appropriately. HART integration is supported on Channel A by
polling.

— For the 5700 Ethernet transmitter, an external host system is required to accept the

water cut monitor input and feed it to the transmitter.

— For the 5700 intrinsically safe transmitter, HART integration is supported on

Channel A by polling.

Note

Water cut cannot be input into the 5700 transmitter with FOUNDATION fieldbus output if
the software revision of the transmitter is 1.x.

Configuration and operation

The Advanced Phase Measurement software can be configured using the interface option
already being used to configure the transmitter:

• Transmitter display

• ProLink III v4.2 or later

• Field communicator (Model 5700 configurable and Model 5700 fieldbus transmitters

only).

• A fieldbus host (Model 5700 fieldbus transmitter only)

• A web browser (Model 5700 Ethernet transmitter only)

Because much of the Advanced Phase Measurement software process data is not
assignable to an output (for example, contract totals), use one of the following external
host systems, depending upon the transmitter output type:

• For the Model 5700 configurable transmitter, a Modbus/RS-485 connection to

Channel E, that must be enabled and wired to a Modbus host to collect and process
data.

• For the Model 5700 Ethernet transmitter, an Ethernet/IP connection to the transmitter,

and an appropriate host program to collect the Advanced Phase Measurement
software process data.

• For the Model 5700 FOUNDATION fieldbus transmitter, a fieldbus H1 connection to the

transmitter and a fieldbus host that reads Advanced Phase Measurement software
process data.

• For the Model 5700 intrinsically safe transmitter, HART integration by polling.

8 Micro Motion Advanced Phase Measurement

Application Manual Before you begin

MMI-20030076 September 2020

1.5 Terms and definitions

The Advanced Phase Measurement software application and this manual use the terms
defined here.

Contract hour

Contract period

Contract total

Corrected density

Corrected volume

Correction

Density-based
water cut

Density
determination

Drive gain
threshold

Contract totals are recorded and then reset at the beginning of the
contract hour.

The 24-hour period that monitors how much fluid the well has
delivered. Contract totals are reset at the beginning of each
contract period.

Up to four user-specified totals that are used to measure
production.

The density of the process fluid at reference temperature.

The volume of the process fluid at reference temperature.

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 or observed
value).

The water cut value calculated by Advanced Phase Measurement
software using the measured line density referenced to a density/
water cut curve based on user-entered dry oil and water densities
at reference temperature.

The procedure for obtaining the density of dry oil and water at
reference temperature—both are required for use with the Net Oil
software option.

Maximum drive gain value expected for single-phase fluid under
typical operating conditions. Above the threshold value, the
measurement will be remediated in accordance with the
configured Advanced Phase Measurement software settings. See

Automatic Drive Gain Threshold determination or Manual Drive
Gain Threshold for more information.

Entrained,
entrainment

External water cut

Gas void fraction

Meter factor for
shrinkage

Mixture

Application Manual 9

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

A water cut value measured by an external device and supplied to
the Advanced Phase Measurement software via the mA Input or
any compatible digital protocol; such as HART, EtherNet/IP, etc.

The ratio of gas volume to total mixture volume at line conditions.
Also called Gas Volume Fraction.

A meter factor, established by proving, that acts as a multiplier to
shrinkage-factored (SF) variables. Not commonly used.

The process fluid before separation - for example, a combination
of a two-phase system; two liquids (oil and water), or a three­phase system (gas, oil, and water).

Before you begin Application Manual

September 2020 MMI-20030076

Multiwell

Net

Period averaged
output (PAO)

Post-mist
adjustment delay

Pre-mist averaging
period

Remediated

An installation where well tests can be performed on up to 48
wells. A manifold system is used to ensure that the output from a
single well is routed through the test separator and the NOC
system.

A measurement of a single component of the process fluid - for
example, oil only, water only.

Rolling averages, with adjustable averaging period, that help
identify trends in noisy data. Available PAOs are: mass flow rate,
density, volume flow rate, net oil flow rate and water cut at line
and reference conditions, gas void fraction, and temperature. The
Average Reporting Interval is used to adjust the averaging period.

Period of stable gas flow conditions after a liquid entrainment
event. After this delay, the average flow rate during Post-Mist
Adjustment Delay is averaged with the Pre-Mist Averaging Period
and the flow rate is adjusted a maximum of +/-10% of reading until
any difference has been appropriately corrected in the totalizers.
Default = 15 seconds.

Period of stable gas flow conditions prior to a liquid entrainment
event. Averaging period is user configurable with units = n
seconds. The average flow rate during this period will be reported
until the entrained liquid event has passed. Default = 15 seconds.

An adjustment applied to a measured process variable by the
Advanced Phase Measurement algorithm to correct for errors
associated with two-phase fluid conditions.

Shrinkage

Shrinkage factor

Uncorrected
density

Uncorrected
volume

Unremediated

Water cut

The change in liquid volume between the measurement point and
a stock tank due to lighter hydrocarbons.

User input multiplier used to account for shrinkage between
measurement point and stock tank. Only affects shrinkage­factored (SF) variables. You can estimate your shrinkage factor by
dividing the temperature-corrected metered density by the
temperature-corrected oil sales density.

The density of the process fluid at line temperature and pressure.

The volume of the process fluid at line temperature and pressure.

Measured variables that are not adjusted by the Advanced Phase
Measurement algorithm. In two-phase conditions, these process
variables represent the whole mixture, or bulk fluid (e.g. water, oil,
and gas).

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

10 Micro Motion Advanced Phase Measurement

Application Manual Measurement options and configuration

MMI-20030076 September 2020

2 Measurement options and

configuration

2.1 Liquid with gas

This measurement option improves flow measurement in liquid processes with
intermittent entrained gas, or with known-density liquids under continuous entrained gas
conditions.

Note

The liquid with gas measurement option can also be combined with the net oil
measurement option or concentration measurement. See the Micro Motion Enhanced
Density Application Manual to configure concentration measurement.

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
the 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.
The APM 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) 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 the F300/H300 compact, and all T­Series sensors.

(2) The accuracy and repeatability of the mass flow and density measurements for liquids with entrained gas is dependent on

the sensor-fluid decoupling ratio, which is a complex function of fluid velocity, fluid viscosity, fluid density, the difference
between the liquid and gas densities, the operating sensor frequency, and the Gas Volume Fraction (GVF) of gas. For best
measurement performance, GVF should be kept below 15%.

(1)

and mass flow rate

(2)

due to the lower amount of mass contained in

Application Manual 11

Measurement options and configuration Application Manual

September 2020 MMI-20030076

Figure 2-1: How entrained gas affects drive gain and density measurement

C

B

A

ρ

D

DG%

t

• DG% = drive gain percentage

• t = Time

• ρ = Density

A. Drive gain indication

B. Measured density
C. Entrained gas ocurring during these intervals
D. Drive gain threshold

Entrained gas in liquids affects drive gain and density measurement. The green line (A)
shows the drive gain indication which is stable under most single-phase conditions.
However, if gas is entrained in the liquid, the density reading (B) will drop and the drive
gain reading will increase. When the entrained gas bubbles go away, the drive gain will
return to its normal indication and the density measurement will reflect the density of the
liquid.

The APM software identifies entrained gas in liquid flow by detecting the sharp increases in
drive gain and corresponding decreases in density measurement. The software
continuously monitors the most recent drive gain data (up to 60 minutes) to determine
drive gain threshold. If the measurement exceeds the drive gain threshold, the fluid is
deemed to contain entrained gas, and remediation occurs.

2.1.1

12 Micro Motion Advanced Phase Measurement

Production type options

Continuous Flow

Select this option only when flow rates are expected to be stable under normal operating
conditions. The APM software assumes the liquid properties and flow velocity through the
pipe is constant, and hence is able to remediate the mass flow values in addition to density
and volume values.

Variable Flow (default)

Select this option when flow rates are not stable, for applications such as batching, dump
valve control, beam pumps, production separators, or other variable processes.

Application Manual Measurement options and configuration

MMI-20030076 September 2020

When variable flow is selected, APM will remediate only density and volume variables.

2.1.2 Drive gain threshold mode

There are two ways to determine when remediation occurs, either Automatic or Manual.

Automatic

The APM software will determine when flow conditions are stable or when multiphase flow
is present in order to perform remediation. This mode is not available with a manual
Advanced Phase Measurement configuration (option MA). See Manual Drive Gain

Threshold.

Manual

At drive gain values above the user-entered threshold, the transmitter will perform the
configured remediation option. As soon as the drive gain drops below the manual drive
gain threshold value, the transmitter returns to reporting unremediated values. See

Manual Drive Gain Threshold.

2.1.3

Remediation options (APM Action)

If the drive gain threshold is exceeded, you must select one of the following methods to
handle the volume calculation for the period of high drive gain.

Hold Last Value (default)

APM will use a held density value from an earlier point in the process to report density,
calculate volume, and calculate any other density-influenced variables during
remediation. If this option is chosen, the density from the point just before the entrained
gas event is held constant throughout the event.

Application Manual 13

Measurement options and configuration Application Manual

September 2020 MMI-20030076

Figure 2-2: Hold Last Value in operation

C

B

A

ρ

D

DG%

t

• DG% = drive gain percentage

• t = Time

• ρ = Density

A. Drive gain

B. Measured density
C. Held density value during entrained gas intervals
D. Drive gain threshold

This figure shows how the Hold Last Value feature works in APM. The green line (A) shows
the drive gain value and the blue line (B) shows the density reading. If the liquid gets
entrained with gas bubbles, the drive gain increases above the drive gain threshold (D).
Then the software determines a density value from recent process data that does not have
a high drive gain. It then substutes that value for the measured density until the drive gain
goes back below the threshold value (D). This substituted density is also referred to as the
remediated density.

Density Hold Override

APM will use a user-input density value from an earlier point in the process to report
density, calculate volume, and calculate any other density-influenced variables during
remediation. This value should reflect the density of the liquid at line conditions.

2.1.4

14 Micro Motion Advanced Phase Measurement

Configure liquid with gas measurement

Configuring liquid with gas measurement is one part of the following required
configuration for APM functionality.

Application Manual Measurement options and configuration

MMI-20030076 September 2020

Start

End

Configure units

See configuration

and use manual

Configure totalizers

and inventories

See configuration

and use manual

Configure liquid

with gas

(this procedure)

Configure channels

and outputs

See configuration

and use manual

Procedure

1. Set the mass flow cutoff and the volume flow cutoff to a non-zero value. This

ensures that totalizing stops when flow is stopped. In most installations, the default
value is satisfactory.

Option Description

Display Menu → Configuration → Process Measurement → Flow

Variables → Mass Flow Settings

ProLink III Menu → Configuration → Process Measurement → Flow

Web browser Configuration → Process Measurement → Flow Variables

2. Navigate to one of the following paths based on the tool you are using.

Option

Description

Display Menu → Configuration → Process Measurement

→ Adv Phase Measurement

ProLink III Device Tools → Configuration → Process

Measurement → Advanced Phase Measurement

Field Communicator or
enhanced FF host

Basic FF host (fieldbus

Configure → Manual Setup → Advanced Phase
Measurement

The APM transducer block

transmitters only)

Web browser (Ethernet
transmitters only)

Configuration → Process Measurement →
Advanced Phase Measurement

3. Depending on your configuration tool, configure liquid with gas measurement:

• From the display, navigate to Single Liquid and Save.

• From ProLink III, set Fluid Type to Liquid with Gas.

4. Verify or make changes to the following settings:

Application Manual 15

Measurement options and configuration Application Manual

September 2020 MMI-20030076

Depending on which tool you are using, the parameter name or order may be
different.

Parameter Description

Production Type Choose one of the following options:

• Continuous flow if the flow in your system is generally

constant. Continuous flow assumes a constant flow rate
that enables mass flow to also be remediated by
subtracting GVF.

• Variable flow if the flow in your system frequently starts

and stops or fluctuates between high and low flow rates.

See Production type options.

Density Hold Override Density will report this value when in remediation. This

value should reflect the density of the liquid at line
conditions.

Drive Gain Threshold

• From the display, enable or disable the automatic

threshold. Disabling automatic threshold defaults to
manual. You must configure a manual threshold value.

• From ProLink III, select automatic or manual drive gain

threshold.

See Drive gain threshold mode.

User Input DG Threshold For use with manual threshold only, this is the drive gain

value above which APM will remediate.

Gas Density @ Line The density of entrained gas. Default = 0.

• Use Default (zero) if the line pressure is less than 250 psi

(17.24 bar) absolute.

• If the typical line pressure is greater than 250 psi

(17.24 bar) absolute, set this parameter to the density of
the entrained gas at typical line conditions. This setting
will affect the GVF output (and mass flow remediation if

Process Type is set to Continuous).

Average Reporting Interval

If using the display, navigate
left to select.

Transmitter Date

Not available in the display.

Transmitter Time

The time period, in minutes, over which process variables
will be averaged. The averages are available for retrieval by
the host system.

Displays the currently-set date.

• From the display, choose Menu → Configuration →

Time/Date/Tag.

• From ProLink III, choose Device Tools → Configuration

→ Process Measurement → Advanced Phase
Measurement in the Transmitter Date field.

• From the display, set the time zone.

• From ProLink III, set the time zone, time zone offset,

date, and time.

16 Micro Motion Advanced Phase Measurement

Application Manual Measurement options and configuration

MMI-20030076 September 2020

2.2 Net oil

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

Note

The PO measurement option should also be combined with the standalone liquid with gas
remediation function that gives it the added capability to mediate against intermittent
entrained gas. The MA and MW options are not compatible with PL.

This algorithm requires the following data:

• Flow rate and temperature, that are measured by the meter.

• Density of both dry oil and water from this well at reference conditions. These are

determined by the operator and entered during configuration. See Density

determination for more information about density determination.

• Current water cut is either:
— Measured by a water cut monitor and supplied to the Advanced Phase

Measurement software via the mA Input or host system

(3)

2.2.1

— Calculated by the Advanced Phase Measurement software from current density

data via the density-based net oil calculation (polled via HART). If density-based
water cut is chosen, the software uses the following equation to calculate the water
cut.

Equation 2-1: Calculation of density-based water cut

ρ

–ρ

mix

WaterCut=

• ρ

• ρ

• ρ

= Density of the oil and water mixture as measured by the sensor

mix

= Density of produced oil calculated from user-supplied value

oil

= Density of produced water calculated from user-supplied value

water

ρ

water

–ρ

oil

oil

Configure net oil measurement

Configuring net oil measurement is one part of the following required configuration for
APM functionality.

(3) Not available for the Model 5700 fieldbus version 1.x.

Application Manual 17

Measurement options and configuration Application Manual

September 2020 MMI-20030076

Start

End

Configure units

See configuration

and use manual

Configure totalizers

and inventories

See configuration

and use manual

Configure net oil

measurement

(this procedure)

Configure channels

and outputs

See configuration

and use manual

Prerequisites

If you plan to use a water cut monitor:

• For the 5700 configurable transmitter, Channel D on the transmitter must be enabled,

and must be configured as a mA Input, wired to the water cut monitor, and configured
appropriately. HART integration is supported on Channel A by polling.

• For the 5700 Ethernet transmitter, an external host system is required to accept the

water cut monitor input and feed it to the transmitter.

• For the 5700 intrinsically safe transmitter, HART integration is supported on Channel A

by polling.

Note

Water cut cannot be input into the 5700 transmitter with FOUNDATION fieldbus output if
the software revision of the transmitter is 1.x.

Procedure

1. Set the mass flow cutoff and the volume flow cutoff to a non-zero value. This

ensures that totalizing stops when flow is stopped. In most installations, the default
value is satisfactory.

Option

Description

Display Menu → Configuration → Process Measurement → Flow

Variables → Mass Flow Settings

ProLink III Menu → Configuration → Process Measurement → Flow

Web browser Configuration → Process Measurement → Flow Variables

2. Navigate to one of the following paths based on the tool you are using.

Option

Description

Display Menu → Configuration → Process Measurement →

Adv Phase Measurement

ProLink III Device Tools → Configuration → Process

Measurement → Advanced Phase Measurement

18 Micro Motion Advanced Phase Measurement

Application Manual Measurement options and configuration

MMI-20030076 September 2020

Option Description

Field Communicator Configure → Manual Setup → Advanced Phase

Measurement

Web browser (Ethernet
transmitters only)

Configuration → Process Measurement → Advanced
Phase Measurement

3. Depending on your configuration tool, configure net oil measurement:

• From the display, navigate to Net Oil (NOC) and Save.

• From ProLink III, set Fluid Type to Net Oil (NOC) or Net Oil (NOC) and Liquid with

Gas if both are licensed.

4. Verify or make changes to the following settings:

Depending on which tool you are using, the parameter name or order may be
different.

Parameter Description

Production Type

APM Action If you are using variable flow, when the drive gain threshold

• Continuous flow if the flow in your system is generally

constant. Continuous flow assumes a constant flow rate
that enables mass flow to also be remediated by
subtracting GVF.

• Variable flow if the flow in your system frequently starts

and stops or fluctuates between high and low flow rates.

See Production type options.

is exceeded, you can configure your transmitter to hold the
last value, use density oil @ line, or a density hold override,
to handle the volume calculation for the period of high drive
gain.

See Remediation options (APM Action).

Density Hold Override If the Density Hold Override is used, then density will report

this value when in remediation. This value should represent
the liquid mixture density at line conditions.

Drive Gain Threshold

User Input DG Threshold For use with manual threshold only, this is the drive gain

Density Oil @ Line The NOC algorithm converts the density of dry oil at

Application Manual 19

• From the display, enable or disable the automatic

threshold. Disabling automatic threshold defaults to
manual. You must configure a manual threshold value.

• From ProLink III, select automatic or manual drive gain

threshold.

See Drive gain threshold mode.

value above which APM will remediate.

reference conditions (a user-configured value) to density at
line conditions, and calculates volume. This option assumes
that all volume during the entrained gas event is dry oil.

Measurement options and configuration Application Manual

September 2020 MMI-20030076

Parameter Description

Gas Density @ Line The density of entrained gas. Default = 0.

• Use Default (zero) if the line pressure is less than 250 psi

(17.24 bar) absolute.

• If the typical line pressure is greater than 250 psi

(17.24 bar) absolute, set this parameter to the density of
the entrained gas at typical line conditions. This setting
will affect the GVF output (and mass flow remediation if
Process Type is set to Continuous).

This setting is needed only when Net Oil is combined with
Liquid with Gas to more accurately determine GVF at
conditions where gases have more mass - such as at high
pressure.

Water Density @ Ref The density of water, corrected to the reference

temperature obtained from density determination.

Dry Oil Density @ Ref The density of dry oil at reference conditions obtained from

a density determination.

Reference Temp The temperature to which net oil and net water

measurements will be corrected. The default is 60 °F.

View Production Meas

(display only)

The type of net oil data that will be shown on the display.

• If you select Corrected to Standard, the display shows

Watercut @ Ref, Net Oil Flow @ Ref, etc.

• If you select Uncorrected, the display shows Watercut

@ Line, Net Oil Flow @ Line, etc.

This parameter is applicable only if a net oil process variable
is configured as a display variable.

Average Reporting Interval

If using the display, navigate
left to select.

Transmitter Date and Time

Not available in the display.

The time period, in minutes, over which process variables
will be averaged. The averages are available for retrieval by
the host system.

Displays the currently-set date.

• From the display, choose Menu → Configuration →

Time/Date/Tag.

• From ProLink III, choose Device Tools → Configuration

→ Process Measurement → Advanced Phase
Measurement in the Transmitter Date field.

• From the display, set the time zone.

• From ProLink III, set the time zone, time zone offset,

date, and time.

Contract Start Time

If using the display, navigate
left until you can select

Contract Period to see
Contract Start Hour.

20 Micro Motion Advanced Phase Measurement

The time of day at which the contract starts. Enter the time
in a 24-hour HH:MM format, where 00:00 = midnight and
18:30 = 6:30 pm.

Application Manual Measurement options and configuration

MMI-20030076 September 2020

Parameter Description

Contract Total [1 - 4]

Not available from the
display.

Shrinkage Factor-Adjusted
Volume Flow Outputs

Shrinkage Factor A user-input value, multiplied by the measured volume to

Meter Factor for Shrinkage A meter factor, established by proving, that acts as a

2.3 Gas with liquid

This measurement option improves mass flow measurement in gaseous processes with
intermittent entrained liquids (mist).

Gas with liquid measurement process

The presence of entrained liquids (or mist) can cause significant errors when measuring
the mass flow of gas through a Coriolis meter. Because droplets contribute a relatively
large amount of mass to a gas mixture, but do not always move uniformly through the
pipe with the gas, even a small amount of condensate can cause measurement
discrepancies between what is measured by the meter and what emerges from the pipe
downstream.

Up to four user-specified totals that are used to measure
production.

See Read contract totals.

Enable or disable shrinkage-factored variable calculations.

match the expected volumes after shrinkage.

multiplier to shrinkage-factored (SF) variables. Not
commonly used.

So how can you tell when a gas contains mist or condensate? When liquids are present in a
gas stream, Coriolis meters will report an increase in both drive gain and fluid density

(4)

in
combination with an increase in mass flow rate – due to the higher mass of the combined
gas-liquid mixture. Therefore, in order to measure only the gaseous portion of the stream,
the mass of the liquids must be ignored or subtracted from the mixture total.

(5)

The
Advanced Phase Measurement software performs exactly this function, using drive gain as
the diagnostic indication that mist or entrained liquids are present in the gas flow stream,
and then substituting a gas-only flow rate in place of the live measurement until the liquid
event has subsided. When the mist event is over, indicated by an associated drop in drive
gain, the software returns to reporting the live measured mass flow rate. If the flow rate
after the event differs significantly from the rate prior to the event, the software will apply
an adjustment to the mass flow output until the totalizers accurately represent the flow
rate change that occurred during the mist event.

(6)

The following figure shows how the change in density and drive gain are affected by mist.

(4) Coriolis meters do not measure the density of gases accurately, but the density reading can be combined with drive gain as

a useful diagnostic to detect changes in fluid properties.

(5) The unmeasured liquids can be (and are often) collected and processed separately downstream if desired.
(6) The outputs are adjusted by a maximum of ±10% of live reading.

Application Manual 21

Measurement options and configuration Application Manual

September 2020 MMI-20030076

Figure 2-3: Effect of transient mist on drive gain and flow measurement

B

D

A

C C

DG%

FLOW

t

• FLOW = mass flow rate

• DG% = drive gain percentage

• t = Time

A. Drive gain indication

B. Measured mass flow rate
C. Entrained liquid (mist) occurring during these intervals
D. Drive gain threshold

The green line (A) shows the drive gain indication during flow. If mist gets entrained into
the gas, the drive gain and the mass flow rate (B) will both increase. The red line (D) shows
a drive gain threshold above which mist is entrained in the gas. APM will automatically
choose an appropriate drive gain threshold (D) or you can opt to set the threshold
manually.

The Advanced Phase Measurement software identifies entrained mist in gas flow by
detecting the sharp increases in drive gain and corresponding increases in mass flow
measurement. When automatic drive gain threshold is enabled, the software continuously
monitors the most recent drive gain data (up to 60 minutes) to determine the drive gain
threshold. If the measurement exceeds the drive gain threshold, the fluid is deemed to
contain entrained liquid, and remediation occurs.

Gas with liquid remediation

The following figure illustrates Advanced Phase Measurement software processing when
mist is detected in the gas stream.

22 Micro Motion Advanced Phase Measurement

Application Manual Measurement options and configuration

MMI-20030076 September 2020

Figure 2-4: Advanced Phase Measurement software: Gas with liquid remediation

E

C

B

F

E

G

C

F

G

D

A

DG%

FLOW

t

• FLOW = mass flow rate

• DG% = drive gain percentage

• t = Time

A. Drive gain indication

B. Measured mass flow rate
C. Pre-mist averaging period and source of average flow rate during this period
D. Drive gain threshold

E. Post-mist adjustment delay and source of average flow rate during this period

F. Held flow rate during entrained mist intervals

G. Post-mist adjustment applied to measured flow rate (if applicable)

The Advanced Phase Measurement software uses the drive gain and mass flow readings to
correct for the presence of entrained mist in gas. The green line (A) shows the drive gain
during flow. The blue line (B) shows the measured mass flow reading both with, and
without entrained gas. When mist is present, the drive gain will go above the drive gain
threshold (D). This threshold value is automatically determined by APM or manually
adjustable. When the drive gain exceeds this threshold, APM will look back in time (C)
seconds, and determine an average, pre-mist, mass flow rate. It will then substitute mass
flow rate (F) until the drive gain goes back below the threshold. Then during time period
(E), a post-mist, mass flow rate average is determined. If the post- and pre-mist averages
are different, a mass flow adjustment (G) is made to the mass rate after time period (E)
until the total mass difference is reconciled.

The first mist event had equal mass flow rates before and after the mist event, so (G) is
equal to (F). In the second mist event, the post-mist flow rate was greater than the pre-

Application Manual 23

Measurement options and configuration Application Manual

September 2020 MMI-20030076

mist rate, so a (G) was applied that was greater than (F). This held flow rate (F) is also
known as the remediated mass flow rate.

2.3.1 Configure gas with liquid measurement

Configuring gas with liquid measurement is one part of the following required
configuration for APM functionality.

Start

End

Configure units

See configuration

and use manual

Configure totalizers

and inventories

See configuration

and use manual

Configure gas with

liquid measurement

(this procedure)

Configure channels

and outputs

See configuration

and use manual

Procedure

1. Set the mass flow cutoff and the volume flow cutoff to a non-zero value. This

ensures that totalizing stops when flow is stopped. In most installations, the default
value is satisfactory.

Option

Description

Display Menu → Configuration → Process Measurement → Flow

Variables → Mass Flow Settings

ProLink III Menu → Configuration → Process Measurement → Flow

Web browser Configuration → Process Measurement → Flow Variables

2. Navigate to one of the following paths based on the tool you are using.

Option

Description

Display Menu → Configuration → Process Measurement

→ Adv Phase Measurement

ProLink III Device Tools → Configuration → Process

Measurement → Advanced Phase Measurement

Field Communicator or
enhanced FF host

Basic FF host (fieldbus

Configure → Manual Setup → Advanced Phase
Measurement

The APM transducer block

transmitters only)

24 Micro Motion Advanced Phase Measurement

Application Manual Measurement options and configuration

MMI-20030076 September 2020

Option Description

Web browser (Ethernet
transmitters only)

Configuration → Process Measurement →
Advanced Phase Measurement

3. Depending on your configuration tool, configure net oil measurement:

• From the display, navigate to Gas with Liquid and Save.

• From ProLink III, set Fluid Type to Gas with Liquid.

4. Verify or make changes to the following settings:

Depending on which tool you are using, the parameter name or order may be
different.

ProLink III Description

Drive Gain Threshold

User Input DG Threshold For use with manual threshold only, this is the drive gain

Pre-Mist Ave Period Period of stable gas flow conditions prior to a liquid

• From the display, enable or disable the automatic

threshold. Disabling automatic threshold defaults to
manual. You must configure a manual threshold value.

• From ProLink III, select automatic or manual drive gain

threshold.

See Drive gain threshold mode.

value above which APM will remediate.

entrainment event. Averaging period is user configurable
with units = n seconds. The average flow rate during this
period will be reported until the entrained liquid event has
passed. Default = 15 seconds.

Post-Mist Adj Delay Period of stable gas flow conditions after a liquid

entrainment event. After this delay, the average flow rate
during Post-Mist Adjustment Delay is averaged with the Pre­Mist Averaging Period and the flow rate is adjusted a
maximum of +/-10% of reading until any difference has been
appropriately corrected in the totalizers. Default = 15
seconds.

Average Reporting Interval

If using the display, navigate
left to select.

Transmitter Date and Time

Not available in the display.

Application Manual 25

The time period, in minutes, over which process variables
will be averaged. The averages are available for retrieval by
the host system.

Displays the currently-set date.

• From the display, choose Menu → Configuration →

Time/Date/Tag.

• From ProLink III, choose Device Tools → Configuration

→ Process Measurement → Advanced Phase
Measurement in the Transmitter Date field.

• From the display, set the time zone.

• From ProLink III, set the time zone, time zone offset,

date, and time.

Measurement options and configuration Application Manual

September 2020 MMI-20030076

ProLink III Description

Contract Start Time

If using the display, navigate
left until you can select

Contract Period to see
Contract Start Hour.

Contract Total [1 - 4]

Not available from the
display.

The time of day at which the contract starts. Enter the time
in a 24-hour HH:MM format, where 00:00 = midnight and
18:30 = 6:30 pm.

Up to four user-specified totals that are used to measure
production.

See Read contract totals.

26 Micro Motion Advanced Phase Measurement

Application Manual Additional configuration

MMI-20030076 September 2020

3 Additional configuration

3.1 Configure viewing and reporting for process variables

When Advanced Phase Measurement software is enabled, additional process variables are
available.

Procedure

• To configure a process variable as a display variable, or to report a process variable over

an output, see the transmitter configuration and use manual.

• To query a process variable using Modbus, follow standard Modbus programming

techniques.

3.1.1

Advanced Phase Measurement specific process variables

The process variables listed here are available only when Advanced Phase Measurement
software is enabled.

The following table lists the process variables by measurement option, and provides
information on reporting.

Process variable

Gas Void Fraction ✓ ✓ ✓ ✓ ✓

DensityOil

DensityOil

NetFlowOil

NetFlowOil

NetTotalOil

NetTotalOil

NetFlowWater

NetFlowWater

NetTotalWater

NetTotalWater

Watercut

Watercut

@Line

@Ref

@Line

@Ref

@Line

@Ref

@Line

@Ref

@Line

@Ref

@Line

@Ref

Advanced Phase Measurement

option

Liquid

with gas

Net Oil Gas with

liquid

✓ ✓ ✓ ✓

✓ ✓ ✓ ✓

✓ ✓ ✓ ✓ ✓ ✓

✓ ✓ ✓ ✓ ✓ ✓

✓ ✓ ✓ ✓

✓ ✓ ✓ ✓

✓ ✓ ✓ ✓ ✓ ✓

✓ ✓ ✓ ✓ ✓ ✓

✓ ✓ ✓ ✓

✓ ✓ ✓ ✓

✓ ✓ ✓ ✓ ✓

✓ ✓ ✓ ✓ ✓

Viewing and reporting

Display Modbus

and

Ethernet

Fieldbus

1)

(

mAO1,
mAO2,

mAO3

FO1, FO2

Application Manual 27

Additional configuration Application Manual

September 2020 MMI-20030076

Process variable Advanced Phase Measurement

option

Liquid

with gas

APM contract period

Today's total ✓ ✓ ✓ ✓ ✓

Yesterday's total ✓ ✓ ✓ ✓ ✓

(1) For fieldbus version 1.x transmitters, you can only publish through the AI Blocks four process variables and two

totalizers/inventories.

3.1.2

Default display variables

Net Oil Gas with

liquid

Display Modbus

Viewing and reporting

Fieldbus

and

Ethernet

1)

(

mAO1,
mAO2,

mAO3

The following table lists the default display variables for Advanced Phase Measurement
software. In all cases, the two-line display option is enabled. All of these process variables
can be configured as display variables.

Display variable Advanced Phase Measurement option

Liquid with gas NOC with gas Gas with liquid

Two-line display,
Variable 1

Volume Flow Rate Volume Flow Rate Mass Flow Rate

FO1, FO2

Two-line display,
Variable 2

Display Variable 1 Density Net Oil Flow Rate

Display Variable 2 Temperature Net Oil Total

Display Variable 3 GVF Net Water Total

Display Variable 4 Empty Temperature Empty

Display Variable 5 Empty GVF Empty

Display Variable 6–15 Empty Empty Empty

Volume Total Water Cut

@Line

@Line

@Line

@Line

Mass Total

Temperature

Density

Empty

3.1.3 Period averaged output (PAO) configuration

Period averaged outputs provide an easy and reliable way to prevent data collection
systems from recording outliers in erratic data. This is included with Advanced Phase
Measurement software since two-phase conditions cause more volatile measurement
outputs. The period over which the PAOs are averaged can be adjusted using the Average
Reporting Interval parameter.

28 Micro Motion Advanced Phase Measurement

Application Manual Additional configuration

MMI-20030076 September 2020

Figure 3-1: Example density measurement without averaged outputs and with
average outputs

ρ

ρ

0.9

0.8

0.7

0.6

0.9

0.8

0.7

0.6

A

t

1

2

3

B

t

1

2

3

• ρ = Density

• t = Time

A. Density measurement without averaged outputs

B. Density measurement with averaged outputs

3.1.4

Application Manual 29

Configure PAO

Procedure

Navigate to one of the following paths to set the interval.

Option

Display Configuration → Adv Phase Measurement → Reporting Interval

ProLink III Device Tools → Configuration → Process Measurement → Advanced Phase

Description

Measurement → Average Reporting Interval

Additional configuration Application Manual

September 2020 MMI-20030076

3.2 Configure APM contract totals into the totalizer history log

The transmitter can be configured to store Advanced Phase Measurement contract totals
to the totalizer history log. This allows you to access totals from earlier contract periods.
Otherwise, the transmitter maintains data for only the current contract period (today) and
the immediately preceding contract period (yesterday).

Procedure

1. Ensure that you have configured the Advanced Phase Measurement contract totals
as desired.

Option Description

Display Menu → Configuration → Process Measurement → Adv Phase

Measurement → Contract Period

ProLink III Device Tools → Contract Period Totals

3.2.1

2. Navigate to the Totalizer Log.

Option Description

Display Menu → Configuration → Totalizer Log

ProLink III Device Tools → Configuration → Totalizer Log

Field Communicator Not available

3. Set Log Total 1, Log Total 2, Log Total 3, and/or Log Total 4 to the desired
Advanced Phase Measurement contract total.

You can configure the totalizer history log to include both Advanced Phase
Measurement and standard totals.

Related information

Read contract totals

(7)

History log variables

The following variables are added to the history log when APM is enabled. The output type
is not equal to zero.

Liquid with gas

• Gas Void Fraction

• Unremediated Density

For fieldbus version 1.x transmitters, any two of the publishable totalizers and inventories can be used, but only two at a

(7)

time.

30 Micro Motion Advanced Phase Measurement

Application Manual Additional configuration

MMI-20030076 September 2020

• Unremediated Mass Flow

• External Temperature

• Velocity

Net oil with gas and NOC multiple wells

• Net Flow Oil @ Ref

• Watercut @ Ref

• Density of Oil @ line

• Unremediated Density

• Unremediated Mass Flow

Gas with liquid

• Unremediated Mass Flow

• GSV Volume Flow

• TMR Time

• Liquid mass flow estimate

• Extended drive gain

Net oil without gas

• Net Flow Oil @ Ref

• Watercut @ Ref

3.3 Configure events

When Advanced Phase Measurement software is enabled, additional process variables are
available to use in event configuration.

Procedure

See the transmitter configuration manual for instructions on configuring events.

Application Manual 31

Additional configuration Application Manual

September 2020 MMI-20030076

32 Micro Motion Advanced Phase Measurement

Application Manual Transmitter operation

MMI-20030076 September 2020

4 Transmitter operation

4.1 Read process variables

Advanced Phase Measurement process variables can be configured as display variables or
assigned to outputs. See the transmitter configuration manual for information on using
the display to read process variables. You can also use the host system for your Modbus,
fieldbus, or Ethernet/IP network to read the variables.

4.2 Read contract totals

You can read contract totals for the current 24-hour contract period and for the previous
24-hour contract period. Depending on the configuration of the totalizer log, you may be
able to read contract totals for earlier periods.

The contract totals are derived from existing inventories. However, they are reset
automatically at the beginning of each contract period. Therefore, the values shown will
probably not match the values shown for the inventories.

Important

You can reset inventories manually, and you can stop and start inventories manually.
However, if you do this, data for the current contract period will not reflect the entire 24­hour period. Data for earlier contract periods is not affected.

• The contract totals for the current contract period are stored in the Today's Total [1-4]

parameters.

• The contract totals for the previous contract period are stored in the Yesterday's Total

[1-4] parameters.

• The contract totals from earlier contract periods can be read in the totalizer log.

Related information

Configure APM contract totals into the totalizer history log

Application Manual 33

Transmitter operation Application Manual

September 2020 MMI-20030076

34 Micro Motion Advanced Phase Measurement

Application Manual APM alerts

MMI-20030076 September 2020

5 APM alerts

This section provides information on the status alerts associated with the APM application.
For information on all other Model 5700 alerts, see the appropriate Micro Motion Model
5700 configuration and use manual.

Alert Cause

A138 APM Remediation Remediation is active.

Watercut limited to 0% Watercut has exceeded the upper limit. Check base oil density.

Watercut limited to 100% Watercut has exceeded the lower limit. Check base water

density.

Watercut Unavailable Watercut unavailable due to high gas. Consider using external

watercut meter.

• All alerts are configurable

• All alert severities default to Out of Specification

• No alerts are affected by fault timeout

Application Manual 35

APM alerts Application Manual

September 2020 MMI-20030076

36 Micro Motion Advanced Phase Measurement

Application Manual Application parameters and data

MMI-20030076 September 2020

A Application parameters and data

This section includes only Modbus registers that are specific to or redefined for the
Advanced Phase Measurement software configuration. To use Modbus to configure other
parameters, see the Micro Motion Modbus Map.

Typically, Advanced Phase Measurement configuration is performed using either ProLink
III or the display. This information is provided for completeness.

A.1 Advanced Phase Measurement Modbus

configuration parameters

Parameter APM option Modbus

Liquid

with gas

Average Reporting
Interval

Contract Start Time ✓ ✓ ✓ 3966 U16 hours (0–23)

Contract Total [1-4] ✓ ✓ ✓ 3967-3970U16 • 4 = Inventory 1

Density Corrective
Action

Drive Gain
Threshold Override

✓ ✓ ✓ 3900 U16 minutes (1–1440)

✓ ✓ ✓ 3971 U16 • 0 = manual

Net Oil

with gas

Gas with

liquid

✓ 4450 U16 • 0 = Hold Last

Address Data

type

Integer codes /
Unit (Range)

• 7 = Inventory 2

• 18 = Inventory 3

• 64 = Inventory 4

• 25 = Inventory 5

• 28 = Inventory 6

• 31 = Inventory 7

Value

• 1 = Density Oil @

Line

• 1 = auto

Drive Gain
Threshold Override
Value

Dry Oil Density @
Ref

Gas Density

Application Manual 37

(1)

✓ ✓ ✓ 3998-39

99

✓ 1959 Float g/cm³ (0.2–1.5)

✓ ✓ ✓ 3935 Float Configured unit

Application parameters and data Application Manual

September 2020 MMI-20030076

Parameter APM option Modbus

Liquid

with gas

Output Type ✓ ✓ ✓ 3940 U16 • 0 = No

Post-Mist Averaging
Period

Pre-Mist Averaging
Period

Net Oil

with gas

Gas with

liquid

Address Data

type

✓ 620 U16 seconds (2–128)

✓ 619 U16 seconds (2–128)

Integer codes /
Unit (Range)

remediation

• 1 = Liquid with

gas, continuous
flow

• 2 = NOC with

gas, continuous
flow

• 3 = Liquid with

gas, variable
flow

• 4 = NOC with

gas, variable
flow

• 5 = Gas with

liquid

• 6 = NOC only

Reference
Temperature

Water Density @ Ref ✓ 1831 Float g/cm³ (0.5–1.5)

(1) At line conditions

✓ 319 Float Configured unit

A.2 Advanced Phase Measurement default totalizer

and inventory values

Totalizer/Inventory Liquid with Gas Gas with Liquid Net Oil

1 Mass Flow

(Remediated)

2 Volume Flow

(Remediated)

3 Temperature

Corrected Volume

4 Gas Standard Volume Gas Standard Volume Net Oil @ Line

5 Standard Volume Standard Volume Net Water @ Ref

6 Net Mass Net Mass Net Water @ Line

Mass Flow
(Remediated)

Volume Flow
(Remediated)

Temperature
Corrected Volume

Mass Flow
(Remediated)

Volume Flow

Net Oil @ Ref

38 Micro Motion Advanced Phase Measurement

Application Manual Application parameters and data

MMI-20030076 September 2020

Totalizer/Inventory Liquid with Gas Gas with Liquid Net Oil

7 Net Volume Net Volume Net Volume

A.3 Advanced Phase Measurement Modbus

process variables

Process variable

Gas Void Fraction ✓ 3907 Float %

Density Oil @ Line ✓ 345 Float SGU

Density Oil @ Line ✓ 347 Float °API

Density Oil @ 60F ✓ 1665 Float °API

Net Oil Flow @ Line ✓ 1553 Float Configured unit

Net Oil Flow @ Ref ✓ 1547 Float Configured unit

Net Oil Inventory @

(2)

Line

Net Oil Inventory @

(3)

Line

Net Oil Total @

(2)

Ref

Net Oil Total @

(4)

Ref

(1)

Advanced Phase

Measurement option

Liquid

with gas

Net Oil

with gas

✓ 1665 Float Automatically

✓ 4240 Double Automatically

✓ 1661 Float Automatically

✓ 4236 Double Automatically

Gas with

liquid

Address Data

type

Modbus

Unit

derived from
configured unit

derived from
configured unit

derived from
configured unit

derived from
configured unit

Net Water Flow @
Line

Net Water Flow @
Ref

Net Water Total @

(2)

Line

Net Water Total @

(5)

Line

Net Water Total @
Ref

Application Manual 39

✓ 1561 Float Configured unit

✓ 1549 Float Configured unit

✓ 1667 Float Automatically

derived from
configured unit

✓ 4248 Double Automatically

derived from
configured unit

✓ 1663 Float Automatically

derived from
configured unit

Application parameters and data Application Manual

September 2020 MMI-20030076

(7)

(1)

Advanced Phase

Measurement option

Liquid

with gas

Net Oil

with gas

✓ 4244 Double Automatically

Modbus

Gas with

liquid

Address Data

type

✓ 989 U32 Seconds

✓ 433, Bit

#12

U16 • 0 = Inactive

Unit

derived from
configured unit

• 1 = Active

Process variable

Net Water Total @

(6)

Ref

Watercut @ Line ✓ 1555 Float %

Watercut @ Ref ✓ 1557 Float %

Total Mist Time

APM Liquid with Gas
remediation status

(1) For fieldbus version 1.x transmitters, you can only publish through the AI Blocks four process

variables and two totalizers/inventories.

(2) Legacy NOC register
(3) Inventory 4 (only if you are using the default configuration)
(4) Inventory 3 (only if you are using the default configuration)
(5) Inventory 6 (only if you are using the default configuration)
(6) Inventory 5 (only if you are using the default configuration)
(7) Automatically set to 0 on a power cycle

A.4 Period Averaged Options current period data

Process variable

PAO Mass Flow ✓ ✓ ✓ 3949 Float Configured unit

PAO Density ✓ ✓ ✓ 3951 Float Configured unit

PAO Volume Flow ✓ ✓ ✓ 3953 Float Configured unit

PAO Net Oil Flow @
Line

PAO Net Oil Flow @
Ref

PAO Watercut @
Line

PAO Gas Void
Fraction

PAO Temperature ✓ ✓ ✓ 3963 Float Configured unit

Unremediated Mass
Flow

(1)

Advanced Phase

Measurement option

Liquid

with gas

✓ 3961 Float Configured unit

✓ ✓ ✓ 3943 Float Automatically

Net Oil

with gas

Gas with

liquid

✓ 3955 Float Configured unit

✓ 3957 Float Configured unit

✓ 3959 Float Configured unit

Address Data

Modbus

Unit

type

derived from
configured uni

40 Micro Motion Advanced Phase Measurement

Application Manual Application parameters and data

MMI-20030076 September 2020

Process variable

(1)

Advanced Phase

Modbus

Measurement option

Unremediated
Density

Liquid

with gas

✓ ✓ ✓ 3945 Float Automatically

Net Oil

with gas

Gas with

liquid

Address Data

type

Unit

derived from
configured uni

Unremediated
Volume Flow

✓ ✓ ✓ 3947 Float Automatically

derived from
configured uni

(1) For fieldbus version 1.x transmitters, you can only publish through the AI Blocks four process

variables and two totalizers/inventories.

Application Manual 41

Application parameters and data Application Manual

September 2020 MMI-20030076

42 Micro Motion Advanced Phase Measurement

Application Manual Typical oil and gas applications and other information

MMI-20030076 September 2020

B Typical oil and gas applications and

other information

B.1 Advanced Phase Measurement with a two-

phase separator

A. From wellhead

B. Separator
C. Gas leg
D. Oil/water leg

E. Coriolis sensor and transmitter with Advanced Phase Measurement (NOC with gas)

F. Coriolis sensor and transmitter with Advanced Phase Measurement (Gas with liquid)

G. Modbus host (flow computer)

Related information

Best practices for two-phase measurement performance

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B.2 Advanced Phase Measurement with a three-

phase separator

A. From wellhead

B. Separator
C. Water leg
D. Oil leg

E. Gas leg

F. Coriolis sensor and transmitter with Advanced Phase Measurement (NOC with gas,

variable flow)

G. Coriolis sensor and transmitter with Advanced Phase Measurement (Liquid with gas,

variable flow)

H. Coriolis sensor and transmitter with Advanced Phase Measurement (Gas with liquid)

I. Modbus host (flow computer)

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B.3 Advanced Phase Measurement at the wellhead

A. Wellhead

B. Coriolis sensor
C. Transmitter with Advanced Phase Measurement (NOC with gas)
D. Modbus host (flow computer)

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B.4 Automatic Drive Gain Threshold determination

An essential function of the Advanced Phase Measurement software is to monitor drive
gain, and then use drive gain data to define and adjust the Drive Gain Threshold, which
ultimately determines when and how measurement remediation is needed.

E

A

B

D

C

A

B

C

D

DG%

t

1

t

2

• DG% = Drive Gain Percentage

• t1 = Drive Gain Threshold interval 1

• t2 = Drive Gain Threshold interval 2

A. Drive Gain Threshold (measurement will be remediated if drive gain exceeds this

threshold)

B. Drive gain indication
C. Minimum drive gain detected at the beginning of each drive gain threshold interval.
D. Drive Gain Threshold Addition. This value is added to the minimum drive gain (C) to

establish a small buffer so the software only remediates values that exceed the typical
drive gain fluctuations for each unique process.

E. Advanced Phase Measurement software remediates density during these intervals.

This figure illustrates how the software determines the Drive Gain Threshold (A) under live
conditions if automatic drive gain threshold is configured. The green dotted line shows the
Coriolis sensor’s live drive gain indication (B) over time (t). The software continuously
analyzes the live drive gain using the most recent data (duration set by the Drive Gain
Threshold Interval) to determine the lowest drive gain that is typical for the process.

(8)

The
live drive gain indication for most applications fluctuates a bit under normal operating
conditions, typically within a small range that is not attributable to two-phase flow or
other process upsets. To avoid remediating during this typical process noise, a small Drive
Gain Threshold Addition (D) is added to the lowest sample point (C). The newly
established Drive Gain Threshold (A) represents the sampled minimum drive gain plus the
drive gain threshold addition. During the remainder of the threshold Interval, if the
indicated drive gain (B) exceeds the established Drive Gain Threshold (A), the transmitter
will appropriately remediate the measured flow rate and/or the fluid density.

(9)

After the

threshold interval is over, the process starts again.

The factory default for Drive Gain Threshold Interval is 60 minutes, which is suitable for most continuous processes, but it

(8)

may be shortened or lengthened as required for each application. Contact customer support for assistance.

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B.5 Manual Drive Gain Threshold

When using the manual drive gain threshold option, select a value above the typical
variation in the drive gain under normal flowing conditions. Remediation will occur when
the drive gain exceeds this threshold limit. If the threshold is set too high, it is possible that
some gas entrainment may occur without exceeding the established threshold, and hence
no remediation will occur. Alternatively, if the threshold is too low, the process may be
remediated even under normal flowing conditions.

If you are using ProLink III, view variations and maximum values during normal operation
by using trends or data logs on the drive gain data. If your process is batched or cyclical,
you should observe and/or record several cycles to establish normal drive gain levels.

If data collection is not available, view the drive gain on the 5700 display by configuring
the display variables. For more information, see the Model 5700 configuration and use
manual.

• DG% = Drive Gain Percentage

• t = Time

A. Drive gain indication

B. Drive gain threshold

C. Remediation occurring during these intervals

(9) The measurement variables remediated by APM are configurable per license type and software and output configuration.

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C Best practices for two-phase

measurement performance

Related information

Advanced Phase Measurement with a two-phase separator

C.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.

• Orient the meter properly:

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

Process Preferred orientation

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

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Table C-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.

C.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 : they perform best in applications

with entrained liquid.

• Orient the meter properly:

Table C-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.

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

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• 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.

C.3 Density determination

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

Important

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

the PVR application or the Net Oil application, you must know

C.3.1 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 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.

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

• Read and record the density value and the temperature value

• 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:

C.3.2

• 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.

Density determination using a petroleum laboratory

To configure APM 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.

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• 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.

• 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 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.

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

line temperature at the sensor.

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.

Application Manual 55

*MMI-20030076*

MMI-20030076

Rev. AD

2020

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