Application Manual
MMI-20030076, Rev AA
October 2015
Micro Motion® Advanced Phase Measurement
Application Manual
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.
Emerson Flow customer service
Email:
•
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•
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Contents
Contents
Chapter 1
Before you begin ............................................................................................................ 1
1.1
1.2
1.3
1.4
1.5
Chapter 2
APM measurement ........................................................................................................ 5
2.1
2.2
2.3
2.4
Chapter 3
Configure APM to measure liquid with gas, using ProLink III .......................................................25
Configure APM to measure net oil with gas, using ProLink III ......................................................26
Configure APM to measure gas with entrained liquid (mist), using ProLink III .............................34
Additional configuration for APM ................................................................................. 37
5.1
5.2
5.3
Chapter 6
Configure APM to measure liquid with gas, using the display ..................................................... 15
Configure APM to measure net oil with gas, using the display .................................................... 16
Configure APM to measure gas with entrained liquid (mist), using the display ........................... 22
Configure APM using ProLink III ....................................................................................25
4.1
4.2
4.3
Chapter 5
APM installations ......................................................................................................................... 5
APM measurement option: Liquid with gas .................................................................................. 7
APM measurement option: Net oil with gas ................................................................................. 9
APM measurement option: Gas with liquid ................................................................................ 12
Configure APM using the display .................................................................................. 15
3.1
3.2
3.3
Chapter 4
About this application manual ..................................................................................................... 1
About the Advanced Phase Measurement (APM) application ....................................................... 1
APM requirements ....................................................................................................................... 2
Terms and definitions .................................................................................................................. 3
Additional documentation from Micro Motion .............................................................................4
Configure viewing and reporting for APM process variables ....................................................... 37
Configure the totalizer history log to include APM contract totals ..............................................39
Configure events ....................................................................................................................... 39
Transmitter operation ..................................................................................................41
6.1
6.2
Read APM process variables ....................................................................................................... 41
Read APM contract totals ...........................................................................................................41
Appendices and reference
Appendix A
Application parameters and data ................................................................................. 43
A.1
A.2
Modbus interface to APM configuration parameters ..................................................................43
Modbus interface to APM process data ...................................................................................... 44
Application Manual
i
Contents
ii
Micro Motion® Advanced Phase Measurement
Before you begin
1
Before you begin
Topics covered in this chapter:
1.1
•
•
•
•
About this application manual
About the Advanced Phase Measurement (APM) application
APM requirements
Terms and definitions
•
Additional documentation from Micro Motion
About this application manual
This application manual explains how to configure and use the Advanced Phase
Measurement application.
This application manual does not provide information on installation of the Model 5700
transmitter, or installation of any sensors. It does not provide general configuration and
operation information. This information can be found in the applicable installation manual
or the transmitter configuration manual.
Related information
Additional documentation from Micro Motion
1.2
About the Advanced Phase Measurement
(APM) application
Advanced Phase Measurement (APM) provides accurate measurement of fluid streams
during periods of two-phase flow: either gas in a liquid stream or liquid in a gas stream.
APM also supports measurement of net oil.
There are three license options for APM. The options are described in the following table.
Table 1-1: APM license options
Application Manual
APM license option
Process fluid
Desired measurement
Liquid with gas
Liquid with entrained gas
Liquid flow rate and totals, gas
void fraction (GVF)
NOC with gas
Mixture of oil, gas, and water
from a wellhead
Net oil(1) and net water flow
rates and totals, GVF
1
Before you begin
Table 1-1: APM license options (continued)
APM license option
Process fluid
Desired measurement
Gas with liquid
Gas with entrained liquid (mist) Gas flow rate and totals
(1) Dry oil at reference conditions
For purchasing information, see the product data sheet for the Model 5700 transmitter.
1.3
APM requirements
Ensure that your installation meets these requirements.
Transmitter requirements
APM is available only on the Model 5700 transmitter.
Sensor requirements
APM does not require a specific sensor. You can use any sensor that is supported by the
Model 5700 transmitter and that meets your application requirements.
Core processor requirements
APM requires the enhanced core processor. The standard core processor does not support
APM.
Installation and wiring requirements
There are no specific installation requirements.
On the transmitter, Channel E must be enabled and must be wired to a Modbus host.
If you plan to use the NOC measurement option with an external water cut monitor,
Channel D on the transmitter must be enabled, and must be configured as an mA input,
wired to the water cut monitor, and configured appropriately.
I/O requirements
To configure APM, you can use either of the following:
•
Transmitter display
•
ProLink III v3.2 or later
For operation, APM process data is available over a Modbus connection. The following are
required:
2
•
A Modbus/RS-485 connection from your Modbus host to the transmitter
•
A Modbus program that reads APM process data on the appropriate schedule
Micro Motion® Advanced Phase Measurement
Before you begin
1.4
Terms and definitions
The terms used to describe oil and gas vary widely. The APM application and this manual
use the terms defined here.
Terms used in APM
Correction
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)
Uncorrected density
The density of the process fluid at line temperature
Corrected density
The density of the process fluid at reference temperature that
is equivalent to its density at line temperature
Uncorrected volume
The volume of the process fluid at line temperature
Corrected volume
The volume of the process fluid at reference temperature that
is equivalent to its volume at line temperature
Mixture
The process fluid before separation, e.g., a combination of oil
and water, or gas, oil, and water
Water cut (Net oil with
gas only)
The amount of water in the oil, in %
External water cut (Net A water cut value measured by an external device and
oil with gas only)
supplied to APM via the mA input
Density-based water
cut (Net oil with gas
only)
A water cut value calculated by APM based on current process
density, the density of produced oil (user-supplied value), and
the density of produced water (user-supplied value)
Density determination
(Net oil with gas only)
The procedure used to obtain two required values: The
density of dry oil at reference temperature, and the density of
water and reference temperature
Net
A measurement of a single component of the process fluid,
e.g., oil only, water only
Entrained, entrainment The presence of small amounts of gas in a liquid stream, or
liquid in a gas stream
Application Manual
Remediation
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 (liquid flows) or the flow
rate has been increased or decreased to compensate for
unmeasured flow (gas flows).
Contract total
Up to four user-specified inventories that are used to measure
production
Contract period
The 24-hour period over which contract totals are
incremented. Contract totals are reset at the beginning of
each contract period.
3
Before you begin
1.5
Additional documentation from Micro Motion
Table 1-2: Additional documentation for APM installations
4
Document
Use
Sensor installation manual for your sensor
Installation and wiring for the sensor
Transmitter installation manual for the
Model 5700 transmitter
Installation and wiring for the Model 5700 transmitter
Configuration manual for the Model 5700 transmitter
Configuration, operation, maintenance, and
troubleshooting for features that are not related
to APM
ProLink III user manual
Installation and use of ProLink III
Modbus Interface Tool
Programming the Modbus host
Micro Motion® Advanced Phase Measurement
APM measurement
2
APM measurement
Topics covered in this chapter:
•
•
•
•
2.1
APM installations
APM measurement option: Liquid with gas
APM measurement option: Net oil with gas
APM measurement option: Gas with liquid
APM installations
The APM device can be installed directly at the wellhead, on the oil leg and/or gas leg of a
three-phase separator, or on the oil/water and/or gas leg of a two-phase separator. If the
APM device is installed at the wellhead, the need for a test separator may be eliminated.
APM at the wellhead
Figure 2-1: APM at the wellhead
A.
B.
C.
D.
Application Manual
Wellhead
Coriolis sensor
Transmitter with APM (NOC with gas)
Modbus host (flow computer)
5
APM measurement
APM with a three-phase separator
Figure 2-2: APM with a three-phase separator
A.
B.
C.
D.
E.
F.
G.
H.
I.
6
From wellhead
Separator
Water leg
Oil leg
Gas leg
Coriolis sensor and transmitter with APM (Liquid with gas, variable flow)
Coriolis sensor and transmitter with APM (Liquid with gas, variable flow) (optional, used in applications where oil
measurement is needed in the water leg to detect a malfunctioning separator)
Coriolis sensor and transmitter with APM (Gas with liquid)
Modbus host (flow computer)
Micro Motion® Advanced Phase Measurement
APM measurement
APM with a two-phase separator
Figure 2-3: APM with a two-phase separator
A.
B.
C.
D.
E.
F.
G.
From wellhead
Separator
Gas leg
Oil/water leg
Coriolis sensor and transmitter with APM (NOC with gas)
Coriolis sensor and transmitter with APM (Gas with liquid)
Modbus host (flow computer)
2.2
APM measurement option: Liquid with gas
This measurement option reports liquid data from a process fluid that is liquid with
intermittent entrained gas.
APM Liquid with gas: Measurement process
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.
Because volume is calculated from mass and density, all volume measurements are also
affected.
Application Manual
7
APM measurement
Drive gain (%)
Figure 2-4: Effect of entrained gas on drive gain and density measurement
A
B
A.
B.
Density
Drive gain (actual)
The drive gain threshold is calculated automatically upon startup. After startup, APM
updates the drive gain threshold every 60 seconds. This eliminates the need for the user to
guess at the value of drive gain that indicates two-phase flow.
APM volume calculation during entrained gas events
If the drive gain threshold is exceeded, the volume calculation for the period of high drive
gain can be handled in either of two ways.
Option
Description
Hold Last Value
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 entrained gas event is effectively held
constant throughout the event.
Use Input Density of Convert the density of dry oil at reference temperature (a userDry Oil Converted to configured value) to density at line temperature, and calculate
Line Conditions
volume. This option assumes that all volume during the
entrained gas event is dry oil.
Hold Last Value in operation
The following figure illustrates Hold Last Value in operation
8
Micro Motion® Advanced Phase Measurement
APM measurement
Figure 2-5: Hold Last Value in operation
Drive gain (%)
E
A
B
C
D
A.
B.
C.
D.
E.
2.3
D
Density
Drive gain threshold
Drive gain (actual)
Earlier point in process
Averaged density values
APM measurement option: Net oil with gas
This measurement option reports net oil data from a process fluid that is a mixture of oil
and water with intermittent entrained gas.
This measurement option has two components:
2.3.1
•
Net oil measurement (NOC)
•
Entrained gas remediation
APM Net oil measurement
The Net Oil Computer (NOC) 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, that is contained within the gross volume of produced fluid.
This algorithm requires four types of data:
Application Manual
•
Current flow rate
•
Density of dry oil from this well at reference conditions
•
Density of water from this well at reference conditions
9
APM measurement
•
Current water cut
The current flow rate is always available from the device.
The user is responsible for determining the density of dry oil and the density of water,
correcting to reference conditions, and supplying the values during configuration.
The current water cut can be measured by a water cut monitor and supplied to APM via the
mA input, or it can be calculated by APM from current density data via the density-based
net oil calculation. If density-based water cut is chosen, APM uses the following equation
to calculate the water cut.
Equation 2-1: Calculation of density-based water cut
ρL-ρO
WaterCut= ρ
2.3.2
W-ρO
ρL
Density of the liquid (oil/gas mixture) as measured by the sensor
ρO
Density of produced oil (calculated from user-supplied value)
ρW
Density of produced water (calculated from user-supplied value)
Entrained gas remediation
Entrained gas remediation uses the meter's extended drive gain to indicate if there is
entrained gas in the liquid stream, and adjust the measurement accordingly.
The following figure shows how the change in drive gain affects density measurement.
Because volume is calculated from mass and density, all volume measurements are also
affected.
Drive gain (%)
Figure 2-6: Effect of entrained gas on drive gain and density measurement
A
B
A.
B.
10
Density
Drive gain (actual)
Micro Motion® Advanced Phase Measurement
APM measurement
The drive gain threshold is calculated automatically upon startup. After startup, APM
updates the drive gain threshold every 60 seconds. This eliminates the need for the user to
guess at the value of drive gain that indicates two-phase flow.
APM volume calculation during entrained gas
If the drive gain threshold is exceeded, the volume calculation for the period of high drive
gain can be handled in either of two ways.
Option
Description
Hold Last Value
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 entrained gas event is effectively held
constant throughout the event.
Use Input Density of Convert the density of dry oil at reference temperature (a userDry Oil Converted to configured value) to density at line temperature, and calculate
Line Conditions
volume. This option assumes that all volume during the
entrained gas event is dry oil.
The following figure illustrates Hold Last Value in operation
Figure 2-7: Hold Last Value in operation
Drive gain (%)
E
A
B
C
D
A.
B.
C.
D.
E.
Application Manual
D
Density
Drive gain threshold
Drive gain (actual)
Earlier point in process
Averaged density values
11
APM measurement
2.4
APM measurement option: Gas with liquid
This measurement option reports gas data from a process fluid that is gas with
intermittent entrained liquid (mist).
APM Gas with liquid: Measurement process
Mist in the process fluid has a negative effect on measurement accuracy, because liquid
has a significantly higher density than gas. Therefore, small amounts of liquid can
significantly impact the mass totals.
The following figure shows how the change in drive gain affects density measurement.
Drive gain (%)
Figure 2-8: Effect of transient mist on drive gain and density measurement
A
B
A transient mist condition is defined in terms of the sensor's extended drive gain: If the drive
gain exceeds the drive gain threshold, the transmitter automatically performs transient
mist remediation. The transient mist interval persists until drive gain is below the
threshold.
The drive gain threshold is calculated automatically upon startup. After startup, APM
updates the drive gain threshold every 60 seconds. This eliminates the need for the user to
guess at the value of drive gain that indicates two-phase flow.
APM: Gas with liquid remediation
The following figure illustrates APM processing when mist is detected in the gas stream.
12
Micro Motion® Advanced Phase Measurement
APM measurement
Figure 2-9: APM: Gas with liquid remediation
G
G
E
H
E
H
A
B
C
D
A.
B.
C.
D.
E.
F.
G.
H.
F
D
F
Flow rate
Drive gain threshold
Extended drive gain
Pre-mist averaging period and source of M1
Averaged flow rate values
Post-mist adjustment delay and source of M2
Adjustment period
Adjusted flow rate values
When mist 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 by a maximum of 10% until the flow total has been compensated for all of
the unmeasured flow.
Application Manual
13
APM measurement
14
Micro Motion® Advanced Phase Measurement
Configure APM using the display
3
Configure APM using the display
Topics covered in this chapter:
•
•
•
3.1
Configure APM to measure liquid with gas, using the display
Configure APM to measure net oil with gas, using the display
Configure APM to measure gas with entrained liquid (mist), using the display
Configure APM to measure liquid with gas,
using the display
This measurement option is appropriate for liquids with intermittent entrained gas.
Prerequisites
Ensure that Mass Flow Cutoff is set to a non-zero value. This ensures that totalizing stops
when remediation is active. In most installations, the default value is satisfactory. See the
transmitter configuration manual for instructions on setting or verifying Mass Flow Cutoff.
Ensure that the two-phase flow limits are set to the default values: Two-Phase Flow Low Limit
= 0 g/cm³, Two-Phase Flow High Limit = 5 g/cm³. In a typical application, these limits will never
be reached, so the transmitter will never initiate standard two-phase flow processing. APM
processing will be implemented instead.
Procedure
1.
Choose Menu > Configuration > Process Measurement > Adv Phase Measurement > Application
Setup.
2.
Select Single Liq.
3.
Set Production Type to the option that best describes the majority of flow in your
system.
Option
Description
Continuous Flow Relatively constant flow rate, e.g., natural production, ESP
Variable Flow
4.
Flow that stops and starts, or fluctuates frequently between high and low
flow rates, e.g., pump jack, test separator
Enter the density of the entrained gas.
• If line pressure is less than 250 psi absolute, set Gas @ Line to Standard.
• If line pressure is greater than 250 psi absolute, set Gas @ Line to the density of
the entrained gas at typical line conditions.
5.
Application Manual
Choose Menu > Configuration > Process Measurement > Adv Phase Measurement > Reporting
Interval and enter the time period, in minutes, over which process variables will be
averaged.
15
Configure APM using the display
The averages are written to the Modbus registers, and are available for retrieval by a
Modbus host.
6.
Configure the contract period.
a. Choose Menu > Configuration > Process Measurement > Adv Phase Measurement >
Contract Period.
b. Set Time Zone to the time zone that you are using for the contract period.
If necessary, set Special Time Zone to the number of hours to add or subtract from
UTC.
Note
The time zone displayed here is the time zone setting for the transmitter. If you change
the time zone here, you are changing the setting of the transmitter clock.
c. Set Contract Start Hour to the time of day at which the contract starts.
Enter the time in a 24-hour HH:MM format, where 00:00 = midnight.
Example:
18:30
Restriction
You cannot configure contract totals using the display. If you want to configure contract
totals, you must use ProLink III. See Chapter 4.
3.2
Configure APM to measure net oil with gas,
using the display
This measurement option is used to measure the oil content of an oil/liquid mixture with
intermittent entrained gas.
1.
2.
3.
3.2.1
Determine the density of dry oil and water (Section 3.2.1)
Configure APM to measure net oil with gas, using the display (Section 3.2)
Configure APM to measure gas with entrained liquid (mist), using the display
(Section 3.3)
Determine the density of dry oil and water
Before configuring the application, 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.
Important
Micro Motion recommends working with a laboratory to obtain the most accurate values. The
accuracy of the net oil data depends upon the accuracy of these two density values.
16
Micro Motion® Advanced Phase Measurement
Configure APM using the display
•
•
Density determination using a petroleum laboratory
Density determination using the display and a three-phase separator
Density determination using a petroleum laboratory
To configure APM for net oil measurement, you must know the density of dry 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%. 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
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.
•
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.
•
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:
Application Manual
•
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.
•
The laboratory report must include the oil density, water density, and the reference
temperature.
17
Configure APM using the display
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. See Figure 2-2.
• 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 2-2.
• 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 temeprature.
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 from your
Micro Motion representative.
Density determination using the display and a three-phase
separator
To configure APM for 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.
18
Micro Motion® Advanced Phase Measurement
Configure APM using the display
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. See Figure 2-2.
You must know the reference temperature that you plan to use.
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.
Wait until separation has occurred.
2.
At the transmitter on the oil leg, read and record the density value and the
temperature value.
Tip
If density and temperature are not configured as display variables, you can read them from
this location: Menu > Operations > Process Variable Values.
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.
3.
At the transmitter on the water leg, read and record the density value and the
temperature value.
Tip
If density and temperature are not configured as display variables, you can read them from
this location: Menu > Operations > Process Variable Values.
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.
4.
Application Manual
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.
19
Configure APM using the display
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.
3.2.2
Configure NOC parameters using the display
You must configure the transmitter with site-specific values for net oil measurement.
Prerequisites
Ensure that Mass Flow Cutoff is set to a non-zero value. This ensures that totalizing stops
when remediation is active. In most installations, the default value is satisfactory. See the
transmitter configuration manual for instructions on setting or verifying Mass Flow Cutoff.
Ensure that the two-phase flow limits are set to the default values: Two-Phase Flow Low Limit
= 0 g/cm³, Two-Phase Flow High Limit = 5 g/cm³. In a typical application, these limits will never
be reached, so the transmitter will never initiate standard two-phase flow processing. APM
processing will be implemented instead.
If you plan to use a water cut monitor:
•
Channel D must be available to use as a mA input.
•
The water cut monitor must be installed and wired to Channel D.
Procedure
1.
Choose Menu > Configuration > Process Measurement > Adv Phase Measurement > Application
Setup.
2.
Select Net Oil (NOC).
3.
Enter the values obtained from density determination.
a. Set Oil Density @ Ref to the density of dry oil, corrected to reference temperature.
b. Set Water Density @ Ref to the density of water, corrected to reference
temperature.
4.
Set Production Type to the option that best describes the majority of flow in your
system.
Option
Description
Continuous Flow Relatively constant flow rate, e.g., natural production, ESP
Variable Flow
20
Flow that stops and starts, or fluctuates frequently between high and low
flow rates, e.g., pump jack, test separator
Micro Motion® Advanced Phase Measurement
Configure APM using the display
5.
Enter the density of the entrained gas.
• If line pressure is less than 250 psi absolute, set Gas @ Line to Standard.
• If line pressure is greater than 250 psi absolute, set Gas @ Line to the density of
the entrained gas at typical line conditions.
6.
Set Reference Temp to the temperature to which net oil and net water measurements
will be corrected.
7.
Set View Production Meas to the type of net oil data that will be shown on the display.
Option
Description
Corrected to Standard
The display will show Watercut @ Ref, Net Oil Flow @ Ref, etc.
Uncorrected
The display will show Watercut @ Line, Net Oil Flow @ Line, etc.
This parameter is applicable only if a net oil process variable is configured as a
display variable.
8.
Choose Menu > Configuration > Process Measurement > Adv Phase Measurement > Reporting
Interval and enter the time period, in minutes, over which process variables will be
averaged.
The averages are written to the Modbus registers, and are available for retrieval by a
Modbus host.
9.
Configure the contract period.
a. Choose Menu > Configuration > Process Measurement > Adv Phase Measurement >
Contract Period.
b. Set Time Zone to the time zone that you are using for the contract period.
If necessary, set Special Time Zone to the number of hours to add or subtract from
UTC.
Note
The time zone displayed here is the time zone setting for the transmitter. If you change
the time zone here, you are changing the setting of the transmitter clock.
c. Set Contract Start Hour to the time of day at which the contract starts.
Enter the time in a 24-hour HH:MM format, where 00:00 = midnight.
Example:
18:30
Restriction
You cannot configure contract totals using the display. If you want to configure contract
totals, you must use ProLink III. See Chapter 4.
10.
Application Manual
If you want to use a water cut monitor, set up the mA input to receive the water cut
data.
21
Configure APM using the display
a. Choose Menu > Configuration > Inputs/Outputs > Channels and configure Channel D to
operate as an mA input.
b. Choose Device Tools > Configuration > I/O > Inputs > mA Input.
c. Verify that Assignment is set to Watercut @ Line.
This is the default assignment. Do not change it; if you do, you will have to use
ProLink III to change it back.
d. Verify the settings of Lower Range Value and Upper Range Value.
Default values:
• Lower Range Value = 0%
• Upper Range Value = 100%
In most cases, these values are not changed.
e. Set mA Input Damping as desired.
Postrequisites
If you set Production Type to Variable Flow, there is an additional parameter that controls the
action to be taken when gas is detected. This parameter is called Density Corrective Action,
and can be set to either Hold Last Value or Density Oil @ Line. This parameter is not available
from the display. The default setting is Hold Last Value. If you want to change it, you must
use ProLink III.
3.3
Configure APM to measure gas with entrained
liquid (mist), using the display
This measurement option is appropriate for gas process fluids with intermittent entrained
liquid (mist).
Prerequisites
Ensure that Mass Flow Cutoff is set to a non-zero value. This ensures that totalizing stops
when remediation is active. In most installations, the default value is satisfactory. See the
transmitter configuration manual for instructions on setting or verifying Mass Flow Cutoff.
Ensure that the two-phase flow limits are set to the default values: Two-Phase Flow Low Limit
= 0 g/cm³, Two-Phase Flow High Limit = 5 g/cm³. In a typical application, these limits will never
be reached, so the transmitter will never initiate standard two-phase flow processing. APM
processing will be implemented instead.
Procedure
22
1.
Choose Menu > Configuration > Process Measurement > Adv Phase Measurement > Application
Setup.
2.
Select Gas with Liquid.
3.
Set Pre-Mist Ave Period to the number of seconds over which density data will be
averaged, to produce the substitute density value.
Micro Motion® Advanced Phase Measurement
Configure APM using the display
4.
Set Post-Mist Adj Delay to the number of seconds that the system will wait before
beginning measurement remediation.
5.
Choose Menu > Configuration > Process Measurement > Adv Phase Measurement > Reporting
Interval and enter the time period, in minutes, over which process variables will be
averaged.
The averages are written to the Modbus registers, and are available for retrieval by a
Modbus host.
6.
Configure the contract period.
a. Choose Menu > Configuration > Process Measurement > Adv Phase Measurement >
Contract Period.
b. Set Time Zone to the time zone that you are using for the contract period.
If necessary, set Special Time Zone to the number of hours to add or subtract from
UTC.
Note
The time zone displayed here is the time zone setting for the transmitter. If you change
the time zone here, you are changing the setting of the transmitter clock.
c. Set Contract Start Hour to the time of day at which the contract starts.
Enter the time in a 24-hour HH:MM format, where 00:00 = midnight.
Example:
18:30
Restriction
You cannot configure contract totals using the display. If you want to configure contract
totals, you must use ProLink III. See Chapter 4.
Application Manual
23
Configure APM using the display
24
Micro Motion® Advanced Phase Measurement
Configure APM using ProLink III
4
Configure APM using ProLink III
Topics covered in this chapter:
•
•
•
4.1
Configure APM to measure liquid with gas, using ProLink III
Configure APM to measure net oil with gas, using ProLink III
Configure APM to measure gas with entrained liquid (mist), using ProLink III
Configure APM to measure liquid with gas,
using ProLink III
This measurement option is appropriate for liquids with intermittent entrained gas.
Prerequisites
Ensure that Mass Flow Cutoff is set to a non-zero value. This ensures that totalizing stops
when remediation is active. In most installations, the default value is satisfactory. See the
transmitter configuration manual for instructions on setting or verifying Mass Flow Cutoff.
Ensure that the two-phase flow limits are set to the default values: Two-Phase Flow Low Limit
= 0 g/cm³, Two-Phase Flow High Limit = 5 g/cm³. In a typical application, these limits will never
be reached, so the transmitter will never initiate standard two-phase flow processing. APM
processing will be implemented instead.
Procedure
1.
Choose Device Tools > Configuration > Process Measurement > Advanced Phase Measurement.
2.
If necessary, set Fluid Type to Liquid with Gas and click Apply.
3.
Set Production Type to the option that best describes the majority of flow in your
system and click Apply.
Option
Description
Continuous Flow Relatively constant flow rate, e.g., natural production, ESP
Variable Flow
4.
Flow that stops and starts, or fluctuates frequently between high and low
flow rates, e.g., pump jack, test separator
If line pressure is greater than 250 psi absolute, enter the density of the entrained
gas at typical line conditions.
Tip
If you need help determining this value, use the Gas Wizard provided in the ProLink III
window.
5.
Application Manual
Set Average Reporting Interval to the time period, in minutes, over which process
variables will be averaged.
25
Configure APM using ProLink III
The averages are written to the Modbus registers, and are available for retrieval by a
Modbus host.
6.
Set Contract Start Time to the time of day at which the contract starts.
The contract time is based on the transmitter clock. You can change the setting of
the transmitter clock if necessary. See the transmitter configuration manual for
more information.
Enter the time in a 24-hour HH:MM format, where 00:00 = midnight.
Example:
18:30
7.
Select up to four inventory values to use as contract totals, to be tracked for each
contract period.
Each contract total is set to 0 every 24 hours, at the configured Contract Start Time.
Tip
You can configure custom inventories and use them for contract totals. See the transmitter
configuration manual for more information.
4.2
Configure APM to measure net oil with gas,
using ProLink III
This measurement option is used to measure the oil content of an oil/liquid mixture with
intermittent entrained gas.
1.
2.
4.2.1
Determine the density of dry oil and water (Section 4.2.1)
Configure NOC parameters using ProLink III (Section 4.2.2)
Determine the density of dry oil and water
Before configuring the application, 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.
Important
Micro Motion recommends working with a laboratory to obtain the most accurate values. The
accuracy of the net oil data depends upon the accuracy of these two density values.
•
•
•
26
Density determination using a petroleum laboratory
Density determination using ProLink III and a two-phase separator
Density determination using ProLink III and a three-phase separator
Micro Motion® Advanced Phase Measurement
Configure APM using ProLink III
Density determination using a petroleum laboratory
To configure APM for net oil measurement, you must know the density of dry 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%. 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
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.
•
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.
•
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:
Application Manual
•
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.
•
The laboratory report must include the oil density, water density, and the reference
temperature.
27
Configure APM using ProLink III
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. See Figure 2-2.
• 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 2-2.
• 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 temeprature.
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 from your
Micro Motion representative.
Density determination using ProLink III and a two-phase
separator
To configure APM for net oil measurement, 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.
28
Micro Motion® Advanced Phase Measurement
Configure APM using ProLink III
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 have a two-phase separator in the process. You can use a mobile two-phase test
separator.
You must know the reference temperature that you plan to use.
You must have a sensor and transmitter installed on the oil/water leg. See Figure 2-3
You must be able to connect to the transmitter 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 transmitter with ProLink III.
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
• 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.
Application Manual
29
Configure APM using ProLink III
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.
Density determination using ProLink III and a three-phase
separator
To configure APM for 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.
30
Micro Motion® Advanced Phase Measurement
Configure APM using ProLink III
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. See Figure 2-2.
You must be able to connect to both transmitters from ProLink III.
You must know the reference temperature that you plan to use.
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.
Wait until separation has occurred.
2.
Collect data from the oil leg.
a. Make a connection to the transmitter on the oil leg.
b. Read and record the density value.
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.
c. Read and record the temperature value.
3.
Collect data from the water leg.
a. Make a connection to the transmitter on the water leg.
b. Read and record the density value.
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.
c. Read and record the temperature value.
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.
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
Application Manual
31
Configure APM using ProLink III
• 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.
4.2.2
Configure NOC parameters using ProLink III
You must configure the transmitter with site-specific values for net oil measurement.
Prerequisites
Ensure that Mass Flow Cutoff is set to a non-zero value. This ensures that totalizing stops
when remediation is active. In most installations, the default value is satisfactory. See the
transmitter configuration manual for instructions on setting or verifying Mass Flow Cutoff.
Ensure that the two-phase flow limits are set to the default values: Two-Phase Flow Low Limit
= 0 g/cm³, Two-Phase Flow High Limit = 5 g/cm³. In a typical application, these limits will never
be reached, so the transmitter will never initiate standard two-phase flow processing. APM
processing will be implemented instead.
If you plan to use a water cut monitor:
•
Channel D must be available to use as a mA input.
•
The water cut monitor must be installed and wired to Channel D.
Procedure
1.
Choose Device Tools > Configuration > Process Measurement > Advanced Phase Measurement.
2.
If necessary, set Fluid Type to Net Oil (NOC) and click Apply.
3.
Set Production Type to the option that best describes the majority of flow in your
system and click Apply.
Option
Description
Continuous Flow Relatively constant flow rate, e.g., natural production, ESP
Variable Flow
4.
Flow that stops and starts, or fluctuates frequently between high and low
flow rates, e.g., pump jack, test separator
If you set Production Type to Variable Flow, set Density Corrective Action to the action to be
taken when gas is detected.
Option
Description
Hold Last Value
Volume is calculated using an average density value from an earlier point
in the process.
Density Oil @ Line Volume is calculated using the density of dry oil at line conditions.
5.
32
If line pressure is greater than 250 psi absolute, enter the density of the entrained
gas at typical line conditions.
Micro Motion® Advanced Phase Measurement
Configure APM using ProLink III
Tip
If you need help determining this value, use the Gas Wizard provided in the ProLink III
window.
6.
Enter the values obtained from density determination.
a. Set Dry Oil Density at Reference to the density of dry oil, corrected to reference
temperature.
b. Set Water Density at Reference to the density of water, corrected to reference
temperature.
7.
Set Reference Temperature to the temperature to which net oil and net water
measurements will be corrected.
8.
If you want to use a water cut monitor, set up the mA input to receive the water cut
data.
a. Choose Device Tools > Configuration > I/O > Channels and configure Channel D to
operate as an mA input.
b. Choose Device Tools > Configuration > I/O > Inputs > mA Input.
c. Set Assignment to Watercut @ Line.
d. Verify the settings of Lower Range Value and Upper Range Value.
Default values:
• Lower Range Value = 0%
• Upper Range Value = 100%
In most cases, these values are not changed.
e. Set mA Input Damping as desired.
9.
Set Average Reporting Interval to the time period, in minutes, over which process
variables will be averaged.
The averages are written to the Modbus registers, and are available for retrieval by a
Modbus host.
10.
Set Contract Start Time to the time of day at which the contract starts.
The contract time is based on the transmitter clock. You can change the setting of
the transmitter clock if necessary. See the transmitter configuration manual for
more information.
Enter the time in a 24-hour HH:MM format, where 00:00 = midnight.
Example:
18:30
11.
Select up to four inventory values to use as contract totals, to be tracked for each
contract period.
Each contract total is set to 0 every 24 hours, at the configured Contract Start Time.
Application Manual
33
Configure APM using ProLink III
Tip
You can configure custom inventories and use them for contract totals. See the transmitter
configuration manual for more information.
4.3
Configure APM to measure gas with entrained
liquid (mist), using ProLink III
This measurement option is appropriate for gas process fluids with intermittent entrained
liquid (mist).
Prerequisites
Ensure that Mass Flow Cutoff is set to a non-zero value. This ensures that totalizing stops
when remediation is active. In most installations, the default value is satisfactory. See the
transmitter configuration manual for instructions on setting or verifying Mass Flow Cutoff.
Ensure that the two-phase flow limits are set to the default values: Two-Phase Flow Low Limit
= 0 g/cm³, Two-Phase Flow High Limit = 5 g/cm³. In a typical application, these limits will never
be reached, so the transmitter will never initiate standard two-phase flow processing. APM
processing will be implemented instead.
Procedure
1.
Choose Device Tools > Configuration > Process Measurement > Advanced Phase Measurement.
2.
If necessary, set Fluid Type to Gas with Liquid and click Apply.
3.
Set Pre-Mist Averaging Period to the number of seconds over which density data will be
averaged, to produce the substitute density value.
4.
Set Post-Mist Adjustment Delay to the number of seconds that the system will wait
before beginning measurement remediation.
5.
Set Average Reporting Interval to the time period, in minutes, over which process
variables will be averaged.
The averages are written to the Modbus registers, and are available for retrieval by a
Modbus host.
6.
Set Contract Start Time to the time of day at which the contract starts.
The contract time is based on the transmitter clock. You can change the setting of
the transmitter clock if necessary. See the transmitter configuration manual for
more information.
Enter the time in a 24-hour HH:MM format, where 00:00 = midnight.
Example:
18:30
7.
34
Select up to four inventory values to use as contract totals, to be tracked for each
contract period.
Micro Motion® Advanced Phase Measurement
Configure APM using ProLink III
Each contract total is set to 0 every 24 hours, at the configured Contract Start Time.
Tip
You can configure custom inventories and use them for contract totals. See the transmitter
configuration manual for more information.
Application Manual
35
Configure APM using ProLink III
36
Micro Motion® Advanced Phase Measurement
Additional configuration for APM
5
Additional configuration for APM
Topics covered in this chapter:
•
•
•
5.1
Configure viewing and reporting for APM process variables
Configure the totalizer history log to include APM contract totals
Configure events
Configure viewing and reporting for APM
process variables
When APM is enabled, additional process variables are available.
5.1.1
•
To configure a process variable as a display variable, see the manual entitled .
•
To report a process variable over an output, see the manual entitled .
•
To query a process variable using Modbus, follow standard Modbus programming
techniques.
APM-specific process variables
The process variables listed here are available only when APM is enabled.
The following table lists the APM-specific process variables by measurement option, and
provides information on reporting.
Table 5-1: APM-specific process variables
APM measurement option
Viewing and reporting
MAO1,
MAO2,
MAO3
Process variable
Liquid
with gas
Net Oil
with gas
Gas with
liquid
Display
Modbus
Extended Drive Gain
✓
✓
✓
✓
✓
Gas Void Fraction
✓
✓
✓
✓
DensityOil@Line
✓
✓
✓
DensityOil@Ref
✓
✓
✓
NetFlowOil@Line
✓
✓
✓
✓
✓
NetFlowOil@Ref
✓
✓
✓
✓
✓
NetTotalOil@Line
✓
✓
✓
NetTotalOil@Ref
✓
✓
✓
NetFlowWater@Line
✓
✓
✓
✓
✓
NetFlowWater@Ref
✓
✓
✓
✓
✓
Application Manual
FO1, FO2
✓
37
Additional configuration for APM
Table 5-1: APM-specific process variables (continued)
APM measurement option
Liquid
with gas
Process variable
Net Oil
with gas
Gas with
liquid
Viewing and reporting
Display
Modbus
MAO1,
MAO2,
MAO3
NetTotalWater@Line
✓
✓
✓
NetTotalWater@Ref
✓
✓
✓
Watercut@Line
✓
✓
✓
✓
Watercut@Ref
✓
✓
✓
✓
FO1, FO2
APM contract period
Today's total
✓
✓
✓
✓
Yesterday's total
✓
✓
✓
✓
5.1.2
Default display variables
The following table lists the default display variables for APM. In all cases, the two-line
display option is enabled. All APM process variables can be configured as display variables.
Table 5-2: Default display variables
APM measurement option
Display variable
38
Liquid with gas
NOC with gas
Gas with liquid
Two-line display, Varia- Volume Flow Rate
ble 1
Volume Flow Rate
Mass Flow Rate
Two-line display, Varia- Volume Total
ble 2
Water Cut@Line
Mass Total
Display Variable 1
Density
Net Oil Flow Rate@Line
Temperature
Display Variable 2
Temperature
Net Oil Total@Line
Density
Display Variable 3
GVF
Net Water Total@Line
Empty
Display Variable 4
Empty
Temperature
Empty
Display Variable 5
Empty
GVF
Empty
Display Variable 6–15
Empty
Empty
Empty
Micro Motion® Advanced Phase Measurement
Additional configuration for APM
5.2
Configure the totalizer history log to include
APM contract totals
The transmitter can store APM 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).
1.
Ensure that you have configured the APM contract totals as desired.
2.
Choose Device Tools > Configuration > Totalizer History Log.
3.
Do not change the settings of Start Logging Date, Start Logging Time, or Log Interval.
These parameters are set automatically by the APM application.
4.
Set Log Total 1, Log Total 2, Log Total 3, and/or Log Total 4 to the desired APM contract
total.
You can configure the totalizer history log to include both APM and non-APM totals.
5.3
Configure events
When APM is enabled, additional process variables are available to use in event
configuration.
See the transmitter configuration manual for instructions on configuring events.
Application Manual
39
Additional configuration for APM
40
Micro Motion® Advanced Phase Measurement
Transmitter operation
6
Transmitter operation
Topics covered in this chapter:
•
•
6.1
Read APM process variables
Read APM contract totals
Read APM process variables
You can use any standard method to read APM process variables.
APM 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 write a Modbus program to read APM process variables.
6.2
Read APM contract totals
APM operates on a 24-hour contract period. You can read APM contract totals for the
current contract period and for the previous contract period. Depending on the
configuration of the totalizer history log, you may be able to read contract totals for earlier
periods.
The APM contract totals are derived from existing inventories. However, the APM contract
totals are reset automatically at the beginning of each contract period. Therefore, the
values shown for APM contract totals 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 24-hour period. Data for earlier
contract periods is not affected.
Procedure
•
•
Application Manual
To read APM contract totals for the current contract period:
-
Using the display: Menu > Operations > Totalizers > See APM Totals > Current Totals
-
Using ProLink III: Device Tools > Totalizer Control > APM Contract Totals
To read APM contract totals for the previous contract period:
-
Using the display: Menu > Operations > Totalizers > See APM Totals > Yesterday's Totals
-
Using ProLink III: Device Tools > Totalizer Control > APM Contract Totals
41
Transmitter operation
•
To read APM contract totals from earlier contract periods, you must read the
totalizer history log. See the transmitter configuration manual for more information.
Related information
Configure the totalizer history log to include APM contract totals
42
Micro Motion® Advanced Phase Measurement
Application parameters and data
Appendix A
Application parameters and data
Topics covered in this appendix:
•
•
A.1
Modbus interface to APM configuration parameters
Modbus interface to APM process data
Modbus interface to APM configuration
parameters
You can use a Modbus tool to configure APM or to modify the existing configuration. This
section provides information on the Modbus registers that are used in APM configuration.
Tip
Typically, APM configuration is performed using either ProLink III or the display. This information is
provided for completeness.
Restriction
This section includes only Modbus registers that are specific to APM configuration, or that have been
redefined for APM configuration. To use Modbus to configure other parameters, see the Modbus
Interface Tool.
Table A-1: APM-specific configuration parameters
APM measurement option
Modbus
Parameter
Liquid
with gas
Net Oil
with gas
Gas with
liquid
Address
Data type
Integer codes / Unit
(Range)
Output Type
✓
✓
✓
3940
U16
• 0 = No remediation
• 1 = Liquid with gas,
consistent flow
• 2 = NOC with gas,
consistent flow
• 3 = Liquid with gas,
variable flow
• 4 = NOC with gas,
variable flow
• 5 = Gas with liquid
Gas Density(1)
✓
✓
✓
3935
Float
Configured unit
Density Corrective Action
✓
4450
U16
• 0 = Hold Last Value
• 1 = Density Oil @ Line
Reference Temperature
✓
319
Float
Configured unit
Application Manual
43
Application parameters and data
Table A-1: APM-specific configuration parameters (continued)
APM measurement option
Liquid
with gas
Parameter
Net Oil
with gas
Gas with
liquid
Modbus
Address
Data type
Integer codes / Unit
(Range)
Dry Oil Density @ Ref
✓
1959
Float
g/cm³ (0.2–1.5)
Water Density @ Ref
✓
1831
Float
g/cm³ (0.5–1.5)
Pre-Mist Averaging Period
✓
619
U16
seconds (2–128)
Post-Mist Averaging Period
✓
620
U16
seconds (2–128)
Average Reporting Inter- ✓
val
✓
✓
3900
U16
minutes (1–1440)
Contract Start Time
✓
✓
✓
3966
U16
hours (0–23)
Contract Total 1
✓
✓
✓
3967
U16
Contract Total 2
✓
✓
✓
3968
U16
Contract Total 3
✓
✓
✓
3969
U16
Contract Total 4
✓
✓
✓
3970
U16
•
•
•
•
•
•
•
4 = Inventory 1
7 = Inventory 2
18 = Inventory 3
64 = Inventory 4
25 = Inventory 5
28 = Inventory 6
31 = Inventory 7
(1) At line conditions
A.2
Modbus interface to APM process data
In typical operation, a Modbus interface is used to read process data. This section provides
information on the Modbus registers that contain APM process data.
Restriction
This section includes only process data that is specific to APM. To use Modbus to read other process
data, see the Modbus Interface Tool.
Table A-2: APM-specific process variables
APM measurement option
Process variable
Liquid
with gas
Net Oil
with gas
Gas Void Fraction
✓
Gas with
liquid
Modbus
Address
Data type
Unit
✓
3907
Float
%
Density Oil @ Line
✓
345
Float
SGU
Density Oil @ Line
✓
347
Float
°API
Net Oil Flow @ Line
✓
1553
Float
Configured unit
Net Oil Flow @ Ref
✓
1547
Float
Configured unit
44
Micro Motion® Advanced Phase Measurement
Application parameters and data
Table A-2: APM-specific process variables (continued)
APM measurement option
Liquid
with gas
Net Oil
with gas
Gas with
liquid
Modbus
Address
Data type
Unit
✓
1665
Float
Automatically derived
from configured unit
Net Oil Total @ Line(2)
✓
4240
Double
Automatically derived
from configured unit
Net Oil Total @ Ref(1)
✓
1661
Float
Automatically derived
from configured unit
Net Oil Total @ Ref(3)
✓
4236
Double
Automatically derived
from configured unit
Net Water Flow @ Line
✓
1561
Float
Configured unit
Net Water Flow @ Ref
✓
1549
Float
Configured unit
Net Water Total @
Line (1)
✓
1667
Float
Automatically derived
from configured unit
Net Water Total @ Line(4)
✓
4248
Double
Automatically derived
from configured unit
Net Water Total @ Ref(1)
✓
1663
Float
Automatically derived
from configured unit
Net Water Total @ Ref(5)
✓
4244
Double
Automatically derived
from configured unit
Watercut @ Line
✓
1555
Float
%
Watercut @ Ref
✓
1557
Float
%
989
U32
Seconds
433, Bit
#12
U16
• 0 = Inactive
• 1 = Active
Process variable
Net Oil Total @ Line(1)
✓
Total Mist Time(6)
TMR remediation status
Current period data (Period Averaged Outputs)
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
✓
3955
Float
Configured unit
PAO Net Oil Flow @ Ref
✓
3957
Float
Configured unit
PAO Watercut @ Line
✓
3959
Float
Configured unit
3961
Float
Configured unit
PAO Gas Void Fraction
✓
✓
PAO Temperature
✓
✓
✓
3963
Float
Configured unit
✓
✓
✓
3972
Float
Automatically derived
from configured unit
APM contract period
Today's total 1
Application Manual
45
Application parameters and data
Table A-2: APM-specific process variables (continued)
APM measurement option
Modbus
Process variable
Liquid
with gas
Net Oil
with gas
Gas with
liquid
Address
Data type
Unit
Today's total 2
✓
✓
✓
3974
Float
Automatically derived
from configured unit
Today's total 3
✓
✓
✓
3976
Float
Automatically derived
from configured unit
Today's total 4
✓
✓
✓
3978
Float
Automatically derived
from configured unit
Yesterday's total 1
✓
✓
✓
3980
Float
Automatically derived
from configured unit
Yesterday's total 2
✓
✓
✓
3982
Float
Automatically derived
from configured unit
Yesterday's total 3
✓
✓
✓
3984
Float
Automatically derived
from configured unit
Yesterday's total 4
✓
✓
✓
3986
Float
Automatically derived
from configured unit
(1)
(2)
(3)
(4)
(5)
(6)
46
Legacy NOC register
Inventory 4 (only if you are using the default configuration)
Inventory 3 (only if you are using the default configuration)
Inventory 6 (only if you are using the default configuration)
Inventory 5 (only if you are using the default configuration)
Automatically set to 0 on a power cycle
Micro Motion® Advanced Phase Measurement
Application parameters and data
Application Manual
47
*MMI-20030076*
MMI-20030076
Rev AA
2015
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