Micro Motion Micro Motion Model 5700 Transmitter Net Oil CalculationsMicro Motion Model 5700 Transmitter Net Oil Calculations Manuals & Guides

Multiwell Supplement
MMI-20052554, Rev AA
March 2019
Micro Motion Model 5700 Transmitter Net Oil Calculations
Multiwell Supplement
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.
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.
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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.
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2
Multiwell Supplement Contents
MMI-20052554 March 2019

Contents

Chapter 1 Before you begin............................................................................................................5
1.1 About this manual............................................................................................................................ 5
1.2 Related documentation....................................................................................................................5
1.3 Overview of Model 5700 NOC tasks..................................................................................................5
Chapter 2 Planning........................................................................................................................ 7
2.1 NOC overview...................................................................................................................................7
2.2 NOC terminology............................................................................................................................. 7
2.3 NOC system components.................................................................................................................8
2.4 Installation architecture....................................................................................................................8
2.5 Operation modes............................................................................................................................. 9
2.6 Required well data..........................................................................................................................11
2.7 Water cut determination................................................................................................................11
2.8 NOC features and options...............................................................................................................12
2.9 Configuration checklist...................................................................................................................15
Chapter 3 Configure the NOC application..................................................................................... 17
3.1 Basic configuration procedure........................................................................................................17
3.2 Set up a water cut monitor............................................................................................................. 20
3.3 Set up Transient Bubble Remediation............................................................................................. 21
3.4 Density determination....................................................................................................................21
Chapter 4 Perform a well test.......................................................................................................25
4.1 Run a well test................................................................................................................................ 25
4.2 View well test data..........................................................................................................................25
4.3 Well test time periods.....................................................................................................................27
4.4 Manage other activity during a well test......................................................................................... 28
Chapter 5 Perform continuous measurement...............................................................................29
5.1 About continuous mode measurement.......................................................................................... 29
5.2 View continuous mode measurement data.................................................................................... 29
5.3 Pause and resume continuous mode measurement....................................................................... 30
5.4 Access view data from continuous measurement screen................................................................ 31
5.5 Access configuration screens from continuous measurement........................................................ 31
5.6 Continuous mode time periods...................................................................................................... 31
5.7 Manage other activity during continuous mode measurement.......................................................33
Chapter 6 Change modes............................................................................................................. 35
6.1 Change to continuous mode.......................................................................................................... 35
6.2 Change to well test mode...............................................................................................................35
Chapter 7 NOC alerts....................................................................................................................37
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Appendix A Differences between Series 3000 and Model 5700 NOC Modbus registers.....................39
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1 Before you begin

1.1 About this manual

This manual explains how to understand, plan, configure, and use the Net Oil Calculations (NOC) application on a Model 5700 transmitter.
The information in this document assumes that users understand all corporate, local government, and national government safety standards and requirements that guard against injuries and death.

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:
Micro Motion Advanced Phase Measurement Application Manual
Micro Motion Model 5700 Transmitters with Configurable Outputs: Configuration and Use Manual
Micro Motion Model 5700 Transmitters with Configurable Outputs: Installation Manual
Modbus Interface Tool
Micro Motion ProLink III User Manual
Sensor installation manual

1.3 Overview of Model 5700 NOC tasks

Step
1 Install the Model 5700
2 Set up digital commmunications
3 Start up the system
3 Configure security and language
4 Configure system data
5 Configure inputs
6 Configure digital communications
Task
Model 5700
NOC (multiwell)
supplement
(this manual)
Model 5700
installation
manual
Model 5700
configuration
and use manual
7 Configure the NOC application
8 Configure outputs
9 Configure NOC status alert severity
10 Perform optional configuration
11 Run an NOC well test
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Step Task
12 Perform NOC continuous measurement
13 Perform calibrations and meter verification
14 Troubleshoot alerts
Model 5700
NOC (multiwell)
supplement
(this manual)
Model 5700
installation
manual
Model 5700
configuration
and use manual
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2 Planning

2.1 NOC overview

NOC is a software option that customers can purchase for the Model 5700 transmitter.
The NOC application can provide real-time measurements of water cut when paired with a Micro Motion sensor installed on either of the following options:
The oil or water leg of a two-phase separator
The oil leg of a three-phase separator
Alternatively, the NOC application can receive water cut data from an external water cut monitor. When the water cut value is known, net oil volume flow and net water volume flow can be calculated.
Net oil volume flow and net water volume flow can also be calculated by the Advanced Phase Measurement software from current density data.
All volume rates and totals are at line conditions, uncorrected, unless stated otherwise.

2.2 NOC terminology

Term Definition
Actual The flow rate as measured at the time of viewing.
Average The flow-weighted average, calculated from the beginning of the applicable
time period.
Back flow Uncorrected volume flow that is moving backward through the sensor.
Density or density @ line The density of the mixture, with no corrections applied.
Gross or gross @ ref The sum of the oil volume and the water volume, as measured by the NOC
application.
Net oil or net oil @ ref Oil that is measured by volume, corrected to reference temperature, with the
oil shrinkage factor applied.
Net water or net water @ ref Water that is corrected to reference temperature, with the water shrinkage
factor applied.
PV Process Variable
Total The rolling total, calculated from the beginning of the applicable time period.
Uncorrected gross or gross @ line The raw volume flow measurement from the oil or oil and water leg.
Uncorrected oil or net oil @ line Oil moving through the oil or oil and water leg that is measured by volume,
with no corrections applied. Temperature correction and shrinkage factors are not applied.
Uncorrected water cut or water cut @ line
Uncorrected water or net water @ line Water moving through the oil or oil and water leg, measured by volume, with
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The percentage of water in a production stream that is at operating conditions.
no corrections applied. Temperature correction and shrinkage factors are not applied.
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Term Definition
Water cut or water cut @ ref The percentage of water in a production stream, corrected to reference
temperature, with the water shrinkage factor applied.
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2.3 NOC system components

The Model 5700 NOC system requires:
One Model 5700 transmitter with the NOC software option
One Micro Motion sensor installed on the oil and water, or oil leg
(Optional) A water cut monitor on the oil and water, or oil leg

2.4 Installation architecture

You can install the Model 5700 NOC system with a two-phase separator, or a three-phase separator.
Note
The following examples do not illustrate all possible combinations.
NOC system with a two-phase separator
With a two-phase separator, the NOC system uses density-based water cut data.
A. Model 5700 transmitter
B. Separator C. Oil/water leg D. Sensor
NOC system with a three-phase separator
With a three-phase separator:
A meter is installed on the water leg, but the Model 5700 transmitter does not monitor or record flow data
from this source.
A water cut monitor is installed on the oil leg. The NOC system can be configured to use either density-
based water cut data, or data from the water cut monitor.
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A. Model 5700 transmitter
B. Separator C. Oil leg D. Sensor
E. (Optional) Water cut monitor
F. Water leg
G. Flowmeter for water

2.5 Operation modes

The NOC system operates in either well test mode or continuous mode.
You can change modes after initial configuration. However, changing modes affects current measurement and data collection.
Well test mode
Well tests can be performed on up to 48 wells. A manifold system is used to ensure that output from a single well is routed through the test separator and the NOC system. The system can save data for a total of three well tests. If more than three tests are run, older tests are overwritten as required.
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A. Model 5700 transmitter
B. Manifold C. One well to test separator D. Separator
E. Liquid leg
F. Sensor G. To production separator H. Other wells to production separator
Continuous mode
One well is measured continuously. The NOC system supplies current flow data, plus running averages and totals.
A. Model 5700 transmitter
B. From a single well C. Separator D. Liquid leg
E. Sensor
F. To production separator
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2.6 Required well data

The following information is required for each well tested or measured by the NOC system:
Density of dry oil from this well at reference temperature and reference pressure. To ensure the most
accurate net oil data, the density should be based on live oil rather than dead oil. “Live oil” refers to crude oil at line pressure.
Density of the water from this well, at reference temperature and reference pressure.
If you do not know the density values, do any of the following tasks:
Take samples of produced oil and produced water, perform laboratory analysis, and enter the results into
the well configuration.
Perform an in-line density determination for oil, water, or both. During in-line density determination, the
appropriate process fluid (water or live oil) is routed through the sensor, density values are averaged over a user-specified time period, and these values are converted to reference temperature. The water cut calculation uses these average values for DO and DW.
Enter approximate values at initial configuration, begin measurement, and recalculate NOC data at a later
time when well-specific density values are known.

2.7 Water cut determination

There are two options for determining water cut, density-based and water cut monitoring.
Density-based
The NOC application derives the water cut by applying the following equation:
D
− D
Watercut=
D
Mix
D
O
D
W
Water cut monitoring (external water cut)
A water cut monitor is used to measure the process stream directly. The Model 5700 transmitter retrieves the water cut data via a HART connection. A HART connection between the primary mA output on the NOC platform and the water cut monitor is required.
The Model 5700 can also use external water cut using an mA Input.
Density of the oil, water, and gas mixture
Density of produced oil (user-supplied value)
Density of produced water (user-supplied value)
Mix
DW− D
O
O
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2.8 NOC features and options

This section describes several features and options of the NOC application.

2.8.1 Temperature correction

Temperature correction refers to the conversion of data collected at the observed process temperature to the equivalent values at reference temperature. The NOC application automatically applies temperature correction to NOC data, using the temperature data from the RTD built into the sensor.

2.8.2 Shrinkage factors

Shrinkage is a reduction in mass and volume of crude oil due to the vaporization and evaporation of the volatile components in the oil. By estimating the shrinkage during oil storage or transport, you can estimate sellable oil based on upstream volume measurement.
Note
The contraction of the volume due to cooling is not a mass loss. It is the thermal contraction of the oil accounted for by “temperature correction” via the Volume Correction Factors in API Ch 11.1.
The NOC application includes one shrinkage factor for oil. The net oil flow rate measured by the NOC application is automatically multiplied by the corresponding shrinkage factor and output on a separate PV. By default, the shrinkage factors are set to 1.0, resulting in no compensation for shrinkage.
Use your standard methods to determine the appropriate shrinkage factors, taking into consideration the location of the sensor in your process.

2.8.3 Liquid with gas

This measurement option improves flow measurement in liquid processes with intermittent entrained gas.
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 due to the lower amount of mass contained in 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.
(1)
and mass flow rate
(2)
(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%.
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The Advanced Phase Measurement software with NOC 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.
Figure 2-1: How entrained gas affects drive gain and density measurement
Planning
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 Advanced Phase Measurement software with NOC 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.
The drive gain threshold can also be entered manually. For details about drive gain thresholds, see B-4 or B-5.
Production type options
Continuous Flow
Select this option only when flow rates are expected to be stable under normal operating conditions. The Advanced Phase Measurement software with NOC assumes the liquid properties and flow velocity through
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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, or other variable processes. When variable flow is selected, APM will remediate only density and volume variables.
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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.
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.
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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.

2.9 Configuration checklist

This section contains questions that you should answer before beginning basic configuration of the Net Oil Computer Software and the NOC system.
Note
These questions are specific to implementing the NOC system and do not address basic system configuration (for example, configuring the clock, passwords, events, communications, etc.).
Will this system be used to test multiple wells or to perform continuous measurement of a single well?
If it will be used for well testing, what wells will be tested? in what order?
Will you use density-based water cut data or a water cut monitor? If you are using a water cut monitor,
what is its range?
For all wells that will be measured:What is the oil density at reference temperature? If not known, will you perform a density
determination?
What is the water density at reference temperature? If not known, will you perform a density
determination?
(For Well Test mode only) What is each well’s purge time?
Will you use HART communications for water cut data? If yes:What are the HART tags of the external devices?
Is the primary mA Output wired to support HART communications with the external devices?
If you will configure shrinkage factors, what values will you use?
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3 Configure the NOC application

This section explains how to configure the NOC application and perform density determination procedures.
CAUTION
Failure to perform configuration tasks in the proper sequence could result in an incomplete
configuration. For the sequence, see Overview of Model 5700 NOC tasks.
Do not change configuration during data collection. Changes made to the NOC configuration will affect
NOC measurement. Changes made to other configuration parameters may affect NOC measurement.
To ensure accurate NOC data, follow the instructions in Manage other activity during a well test or
Manage other activity during continuous mode measurement to change configuration.

3.1 Basic configuration procedure

Use the following general steps to configure the NOC application.
Prerequisites
You must have a valid NOC license on your transmitter.
Go to Menu > Service Tools > License Manager.
Make sure that API Referral is disabled.
Go to Menu > Configuration > Process Measurement > API Referral.
Procedure
1. Go to Menu > Configuration > Process Measurement > Adv Phase Measurement > Application Setup
> Net Oil (NOC) and save.
2. Go to Menu > Configuration > Process Measurement > Well Perf Measurement.
3. Set Mode of Operation to Continuous or Well Test.
Option
Continuous One well, separator, or pipeline is monitored continuously.
Well Test A well test is performed on any of the wells on a manifold, up to 48 wells. Each well is
4. Set Reference Temperature to the reference temperature to be used by the NOC application.
5. If you are using continuous mode, go to Well Data-Densities and set the well parameters for the well
being measured.
6. If you are using well test mode, go to Well Data-Densities and perform the following steps:
a) Specify the well to configure.
Description
configured independently and well test data is stored separately.
b) Assign a name to the well.
c) Set the well parameters for the well being measured.
See Well parameters.
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7. Go to Menu > Configuration > Process Measurement > Well Perf Measurement > External Inputs to
enable or disable use of a water cut monitor. If Water Cut Monitor is enabled, additional setup is required.
See Set up a water cut monitor.
8. Go to Menu > Configuration > Process Measurement > Well Perf Measurement > Compensations to
set the parameters.
Option Description
APM Remediation See Remediation options (APM Action).
Shrinkage Factors See Shrinkage factors
To disable shrinkage factors, set them to 1.0.
Contract Reset If enabled, the NOC totals are reset when the contract time has ended. See the
Micro Motion Advanced Phase Measurement Application Manual.
9. Optional: Configure mA Outputs, Discrete Outputs, or Frequency Outputs to report NOC data.
For these procedures, see the Micro Motion Model 5700 Transmitters with Configurable Outputs: Configuration and Use Manual.
Assign the required process variable to the output. Available NOC process variables are listed in
NOC process variable (PV) to output assignments.
Configure other output parameters as required.
10. Optional: Configure the severity level of the NOC status alerts.
For these procedures, see the Micro Motion Model 5700 Transmitters with Configurable Outputs:
Configuration and Use Manual.
For a list of NOC status alerts, see Alerts.
11. Optional: Configure the process variables. For the procedures, see the Micro Motion Model 5700 Transmitters with Configurable Outputs:
Configuration and Use Manual.

3.1.1 Well parameters

Parameter
Well Name Well xx (where xx is the well
Oil Density @ Ref 0.8000 g/cm³
Default Description
A name that identifies this well. A name can contain a
number) For example, Well 05
(800.000 kg/m³)
maximum of 16 characters, including spaces.
The oil density from this well at reference temperature. This parameter is required only if density-based water cut is used.
Water Density @ Ref 1.0000 g/cm³
(1,000.000 kg/m³)
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The water density from this well at reference temperature. This parameter is required only if density-based water cut is used.
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Parameter Default Description
Purge time 0 sec (Well Test mode only) The measurement delay period after
a well test has been started. Purge time allows the separator to displace any contents from the previous test.
Drive Deviation Limit 8% The maximum acceptable Drive Gain during a water or oil
density determination. If the drive gain is greater than the limit, the density determination may need to be rerun.
Oil Duration Ave 30 sec The sample time, in seconds, for an oil density
determination procedure.
Water Duration Ave 30 sec The sample time, in seconds, for a water density
determination procedure.
Mass Hold Value 0.0 g/cm³ (0 kg/m³) Held mass flow value used during remediation.
Density Hold Value 0.0 g/cm³ (0 kg/m³) Held density value used during remediation.
Vol Flow Hold Value 0.0 l/s Held volume flow value used during remediation.
Current DG Threshold 30% Above the threshold value, the measurement will be
remediated in accordance with the configured Advanced Phase Measurement software settings.

3.1.2 NOC process variable (PV) to output assignments

NOC PV
APM event
Average back flow rate
Average gross rate
Average net oil flow rate
Average net water cut
Average net water rate
Average uncorrected gross rate
Average uncorrected oil rate
Average uncorrected water cut
Average uncorrected water rate
Back flow rate
External water cut
Gross volume rate
Net oil flow rate
(1)
Assignable outputs
DOs mAs FOs
Net water cut
Net water flow rate
Uncorrected oil volume rate
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NOC PV Assignable outputs
DOs mAs FOs
Uncorrected water cut
Uncorrected water volume rate
(1) ON = Remediation active; OFF = Remediation inactive

3.2 Set up a water cut monitor

Use this procedure to configure a water cut monitor.
Procedure
1. Ensure that the water cut monitor is correctly installed, tested, and configured to report water cut data in %.
2. Enable the water cut monitor as an external input if you have not already done so. See Basic configuration procedure, Step 7.
3. Optional: To specify a value for an external water cut limit, go to Menu > Configuration > Process Measurement > Well Perf Measurement > External Inputs.
When the measured water cut exceeds this value, an alert is posted.
Set this parameter to the highest value in your water cut monitor's range.
Disable this alert by setting the value to 100%.
4. Set up a HART polling connection between the Model 5700 device and the water cut monitor.
a) Ensure that the primary mA Output has been wired to support HART protocol, and that the mAO
has a HART connection to the water cut monitor. You can also use the mA Input.
b) Go to Menu > Configuration > Process Measurement > Well Perf Measurement > External
Inputs > Temperature > External Temperature.
c) Select Polling Variable 1 or Polling Variable 2.
d) Set Polling Control to Poll as Primary or Poll as Secondary.
e) Go to Menu > Configuration > Inputs/Outputs > Channel A > HART Settings > Poll External
Device.
f) Specify the device to be polled in Watercut @ Line.
5. Verify that water cut data is being received by viewing the current water cut value in either well test mode or continuous mode. Ensure that the displayed value matches the value sent by the water cut monitor.
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3.3 Set up Transient Bubble Remediation

Procedure
1. Go to Menu > Configuration > Process Measurement > Well Performance Meas > Compensations.
2. Set Remediation Action to Hold Last Value.
The transmitter will calculate volume using a substitute density value. The substitute value is an average of the data around a recent point in the process.
3. Optional: Configure a Discrete Output to report APM status. See Basic configuration procedure.

3.4 Density determination

If you are performing a density determination for oil and for water, it is more convenient to perform density determination for water first.
At any point during the procedures in this section, you can discard the data and stop the density determination process by selecting Cancel or by navigating left to return to other functions.

3.4.1 Density determination for water

There are two density determination methods for water: in-line and manual. This section provides instructions for both methods.
The in-line method requires enough water in the separator to supply a stable flowing density for the density determination period.
If there is not enough water, use the manual method.
Perform in-line density determination for water
Procedure
1. Stop all well tests currently running.
2. Make sure that water is flowing through the sensor. You might need to close the outlet valve and the inlet valve from the separator and wait for the phases
to settle, then open the outlet valve.
3. Go to Menu > Service Tools > Verification & Calibration > Density Determination > Water Density > Measure and Save.
4. You are prompted to select a well. The current values for water density, water temperature, volume total, flow rate, drive deviation, pressure (if enabled), and water duration are displayed.
Note
The Drive Deviation and Water Duration values are read-only. To change them, reconfigure the well data. See Basic configuration procedure.
5. Monitor the density and temperature values, watching for the density and temperature readings to stabilize.
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6. Optional: Highlight Volume Total Reset and navigate to the right to reset the volume total to 0. Select Continue to confirm resetting the volume total.
This enables you to monitor the amount of fluid that remains in the separator, if the separator liquid volume is known.
7. When the density and temperature readings have stabilized, select Start. The NOC application will average the density and temperature of the process fluid for the duration set by the Water Duration value for the well. When a water density determination (DD) is running, the averaging screen shows the DD progress indicating percentage complete, drive gain, density, volume, and temperature. After 100%, the screen will show one of the following screens:
Deviation Limit Exceeded The deviation was exceeded. This screen displays the
maximum drive deviation during the averaging process and the current drive deviation limit.
If the Deviation Limit Exceeded screen displays, you might need to stabilize the process fluid or increase the
Drive Deviation value.
Averaging Complete Save The density and temperature averaging is complete.
8. When the averaging process is complete, you can can save or discard the data (cancel). A save will replace the stored value with the new value.
Manual density determination for water
Procedure
1. Stop all well tests currently running.
2. Fill the separator with production fluid from the well that will be tested, and let the phases settle.
3. Take a water sample from the bottom of the water layer or from the water trap.
4. Cover the sample container and allow the sample to cool to near-ambient temperature.
5. Measure the density and temperature of the sample using a hygrometer and a thermometer.
6. Go to Menu > Service Tools > Verification & Calibration > Density Determination
7. In well test mode, select the appropriate well.
8. From the last density determination timestamp screen, navigate right, then select Water Density > Manually Enter.
9. Enter the density of the water sample in the units shown on the Entry screen.
10. Enter the temperature of the water sample in the units shown on the screen.
11. Select Calculate at Ref, then navigate right. The NOC application converts the observed water density to water density at reference temperature. The stored value for water density at reference temperature displays, as well as the date and time at which this value was stored.
12. You can can save or discard the data (cancel). A save will replace the stored value with the new value.
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3.4.2 Perform in-line density determination for oil

Procedure
1. Stop all well tests currently running.
2. Ensure that oil is flowing through the sensor. You might need to drain water from the separator.
3. Go to Menu > Service Tools > Verification & Calibration > Density Determination
4. In well test mode, select the appropriate well.
5. After the last density determination timestamp screen, select Oil Density. The current values for oil density, oil temperature, pressure (if enabled), water cut (if enabled), volume total, flow rate, drive deviation, and oil duration are displayed.
Note
The Drive Deviation and Oil Duration values are read-only. To change them, reconfigure the well data. See Basic configuration procedure.
6. Monitor the density and temperature values, watching for the density and temperature readings to stabilize.
7. Optional: Highlight Volume Total Reset and navigate to the right. If you reset this total when the separator first started to flow, i.e. when you were doing the water density determination, you can monitor the amount of fluid to reset the volume total to 0. Select Continue to confirm resetting the volume total.This enables you to monitor the amount of fluid that remains in the separator, if the separator volume is known.
8. When the density and temperature readings have stabilized, highlight Start and navigate to the right. The NOC application will now average the density and temperature of the process fluid for the specified oil averaging duration. If the drive gain exceeds the limit, then the Oil Deviation Limit Exceeded screen displays. From this screen, you have the option to continue the save process or discard the data and restart the density determination process.
Note
If the Oil Deviation Limit Exceeded displays, you might need to stabilize your process fluid or increase the Drive Deviation value.
9. If you are using the density-based water cut, take a sample of the fluid in the pipe during this averaging period, then measure the sample water cut. You can use any standard procedure, such as centrifuge, distillation, Karl-Fischer, etc., to measure the water cut. Measure in % volume.
If you are using a water cut monitor, this sampling procedure is optional. You can use either the water cut data measured by the monitor or water cut data from the sample.
Important
The accuracy of the water cut value directly affects the accuracy of the NOC data. Use a representative sample and measure carefully. Some medium and light oil samples may have negligible entrained water.
10. When the averaging process is complete, you can can save or discard the data (cancel). Select Continue to confirm resetting the volume total.
A save will replace the stored value with the new value.
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11. Is water cut monitor enabled or disabled?
Option Description
If enabled Water cut data from the averaging period displays.
a. Select Continue.
The reference density of dry oil from the density determination will be computed and displayed along with the current values.
b. Select Save to replace the stored value with the new value.
If you are using a water cut monitor and you saved the average water cut and the reference density of oil, the density determination procedure is complete.
However, you can still enter a manual water cut value and apply it as described in the following steps.
If disabled Enter the water cut manually, select OK and go to Step 12
12. Select Enter Watercut. The date and time of the current density determination procedure displays.
13. Enter the water cut you measured in Step 9, then select Hold to Save.
14. Highlight Calculate at Ref and navigate to the right. The NOC application uses this water cut data to convert the observed oil density to dry oil density at reference temperature. The stored value for oil density at reference temperature displays, as well as the date and time at which this value was stored.
15. You can save or discard the data (cancel).
24 Micro Motion® Model 5700 Transmitter
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4 Perform a well test

This section explains how to use the NOC application to run a well test.
A well test must be started and stopped manually or through a Modbus command.
Well tests are identified by the well name and by the start date and time. You can save up to three well tests. If you run additional well tests, each new well test will overwrite the oldest well test.

4.1 Run a well test

Prerequisites
Ensure that the NOC application is set for well test mode, and that all necessary data for the well has been configured.
Procedure
1. Go to Menu > Operations > Well Performance Meas > Well Test Mode.
2. Select Start Well Test.
3. Navigate to the well you want tested.
4. Highlight Start Well Test and navigate right to begin the test.
During the well test you can:
Select Actual to see current test data.
Select View Production Meas to view more detailed data on the current test.
The well test screen displays, showing the test start time and the elapsed time.
5. Select Stop Test to end the well test. The final well test values are automatically written to memory.
6. To run another test, return to Step 2.

4.2 View well test data

You can view well test data at several points from the display.
You can also read well test data through the Modbus interface, or report actual and average process variables by assigning them to an mA Output or Frequency Output.
Procedure
Choose one of the following options:
Option
To access basic data for the current well test
To access more detailed data for either the current test or a stored test
Description
If running, select Actual or View Production Meas.
To view stored tests, choose Operations > Well Performance
Meas > Well Test Mode
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Option Description
To view archives, choose View Well Tests from the View Well
Tests screen.

4.2.1 Well test mode display values

Process variable Definition
Actual density The current density of the production fluid.
Actual gross rate The current flow rate of the production fluid (all process fluid through the NOC
sensor).
Actual net oil rate The current net oil flow rate.
Actual temperature The current temperature of the production fluid.
Actual water cut The current water cut used in net oil calculations that may be either density-
based or from the water cut monitor, depending on the water cut configuration.
Average density The average density, calculated from the beginning of the well test.
Average gross rate The average flow rate of the production fluid (all process fluid through the NOC
sensor).
Average gross rate The average flow rate of production fluid, calculated from the beginning of the
well test. This rate:
May or may not include TMR carry-over data, depending on the TMR
configuration
Does not include gas data
Average net oil rate The average net oil flow rate, calculated from the beginning of the well test.
Average net oil rate The average net oil flow rate, calculated from the beginning of the test. The
current net oil flow rate may or may not include oil carry-over, depending on TMR configuration.
Average temperature The average temperature, calculated from the beginning of the well test.
Average water cut The average water cut value, calculated from the beginning of the well test.
Average water cut The average water cut value, calculated from the beginning of the well test.
Gross total Total production fluid, by volume, calculated from the beginning of the well
test.
Net oil total The total net oil, by volume, calculated from the beginning of the well test.
Remediation The hours and minutes that remediation has been active
Test started The date and time that the well test was started.
Test time elapsed The hours and minutes that the well test has been running.
Water cut overrange (Water cut monitor only) The hours and minutes that the water cut has been
above the configured External Water Cut Limit.
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4.2.2 Well test mode: production data

For the current test, running average, minimum, maximum, and total values for each process variable are calculated from the beginning of the test. When the well test stops, the final values are stored with the test data.
Process variable Actual Avg Min Min
time/ date
Net oil
Water cut
Gross flow
Net water
Drive gain
Density
Temperature
Back flow
Mass flow
Uncorrected oil flow
Uncorrected water flow
Uncorrected water cut
Uncorrected gross
Time test started
Time test elapsed
Timestamp
Hours and minutes
Max Max
time/ date
Total
Time of TBR
Time of water cut overrange
Hours and minutes
Hours and minutes

4.3 Well test time periods

For the current test, running average, minimum, maximum, and total values for each process variable are calculated from the beginning of the test. When the well test is stopped, the final values will be stored with the test data.
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4.4 Manage other activity during a well test

Certain actions, such as reconfiguring well data, will cause discontinuities in the well test data and will interfere with data collection. If you need to change system configuration or perform a maintenance procedure, perform this procedure before doing so.
Procedure
1. Stop the well test.
2. Make the required configuration changes or perform the required procedures.
3. Start a new well test.
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5 Perform continuous measurement

5.1 About continuous mode measurement

In continuous mode, measurement begins as soon as the system is up and running, or as soon as the system is configured for continuous mode measurement.
You cannot start and stop continuous mode measurement. However, you can:
Pause and resume measurement
View current data
Reset the start time for summary variables
Write archive records that summarize well production from the beginning of the continuous mode time
period up to the point the record is written
View archive records

5.2 View continuous mode measurement data

Use this procedure to view continuous mode measurement data from the Model 5700 display. As an alternative, you can read continuous mode measurement data from the Modbus interface, or report actual and average process variables (PVs) by assigning them to an mA Output or Frequency Output.
Procedure
Choose one of the following options:
Option
To access basic data for the current well test
To access more detailed data for either the current test or a stored test

5.2.1 Continuous mode: quick view

Process variable
Average/total since Timestamp for the beginning of continuous mode measurement or the last
Average gross rate Average flow rate of production fluid, calculated from the beginning of the
Definition
Reset All.
continuous mode measurement or from the last reset.
Description
Menu > Operations > Well Performance Meas > Continuous > Quick View
Menu > Operations > Well Performance Meas > Continuous > View Production Measures
Average net oil rate Average net oil flow rate, calculated from the beginning of continuous mode
measurement or from the last reset.
Average water cut Average water cut value, calculated from the beginning of the continuous
mode measurement or from the last reset.
Gross total Total production fluid, by volume, calculated from the beginning of the
continuous mode measurement or from the last reset.
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Process variable Definition
Net oil total Total net oil, by volume, calculated from the beginning of the continuous mode
measurement or from the last reset.
Remediation Hours and minutes that remediation has been active.
Test time elapsed Hous and minutes since this continuous mode measurement period was
started.
Total paused time Hours and minutes that measurement has been paused.
Water cut overrange (Water cut monitor only) Hours and minutes that the water cut has been above
the configured External Water Cut Limit.

5.2.2 Continuous mode: production data

Process variable Actual Avg Min Min
time/ date
Net oil
Water cut
Gross flow
Net water
Drive gain
Density
Temperature
Back flow
Mass flow
Uncorrected oil flow
Uncorrected water flow
Uncorrected water cut
Uncorrected gross
Max Max
time/ date
Total Reset
time/ date
Inv

5.3 Pause and resume continuous mode measurement

While measurement is paused, no data is collected, displayed, or stored. Average, minimum, maximum, total, and inventory values are not updated.
You can pause and resume measurement as often as you like.
Procedure
Go to Menu > Operations > Well Performance Meas > Continuous Mode > Pause/Resume.
30 Micro Motion® Model 5700 Transmitter
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Multiwell Supplement Perform continuous measurement
MMI-20052554 March 2019
5.4 Access view data from continuous measurement
screen
Procedure
From the Continuous Mode screen, select View Production Meas or Quick View.
5.5 Access configuration screens from continuous
measurement
To prevent data discontinuities, use this procedure to access configuration screens from the continuous measurement screens.
At any point from the continuous measurement screens, you can access the configuration and maintenance menus. The system will not prevent configuration changes, calibrations, or other procedures during continuous measurement. However, many actions can cause discontinuities in the data, and many procedures will interfere with data collection.
Procedure
1. Pause measurement.
2. If required, save an archive record.
3. Make the required configuration changes or perform the required procedures.
4. Reset all process variables (PVs).
5. Resume measurement.

5.6 Continuous mode time periods

You can view, reset, save, and archive continuous mode time periods.
Running average, minimum, maximum, and total values are calculated from the beginning of continuous mode measurement.
The following figure explains the relationship between Save, Reset, snapshots, and archive records.
Figure 5-1: Continuous mode timeline and time periods
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5.6.1 Reset continuous mode time periods

Procedure
Choose one of the following options:
Option Description
Set a new start time for one PV
Set a new start time for all PVs
a. Go to Menu > Operations > Well Performance Meas > Continuous Mode >
View Production Meas.
b. Select the PV.
c. Press Reset.
d. Navigate right, then select Yes on the reset confirmation screen.
Not all PVs can be reset individually. If Reset does not display, the system does not allow an individual reset for that PV.
a. Go to Menu > Operations > Well Performance Meas > Continuous Mode >
Reset.
b. Follow the prompts.

5.6.2 Archive records

At any time during continuous mode measurement, you can save the current values of the summary variables to an archive record. The archive record is then available for viewing.
Archive records:
Are identified by a timestamp
Can be saved for up to three archives

5.6.3 View archive records

Procedure
1. Go to Menu > Operations > Well Performance Meas > Continuous > View Archive.
2. Specify the archive record you want to view.
3. Select the specific PV you want to view.

5.6.4 Save to an archive record

Use this procedure to save the current values of the summary variables to an archive record.
Procedure
1. Go to Menu > Operations > Well Performance Meas > Continuous Mode.
2. Select SAVE.
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5.7 Manage other activity during continuous mode
measurement
Certain actions, such as reconfiguring well data, will cause discontinuities in the data and will interfere with data collection. If you need to change system configuration or perform a maintenance procedure, perform this procedure before doing so.
Procedure
1. Go to Menu > Operations > Well Performance Meas > Continuous Mode.
2. Pause measurement.
3. Optional: Save an archive record.
4. Make the required configuration changes or perform the required procedures.
5. Reset all process variables.
6. Resume measurement.
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6 Change modes

Changing from well test mode to continuous mode, or from continuous mode to well test mode, affects current measurement and data collection. To change modes, follow the instructions in this section.

6.1 Change to continuous mode

Use this procedure to change from well test mode to continuous mode.
If a well test is running, it will be stopped automatically when the mode is changed.
Procedure
1. Record all required well test data to an external system.
Well test data will be unavailable from the display while the system is in continuous mode.
2. Go to Menu > Configuration > Process Measurement > Well Perf Measurement.
3. Change Mode of Operation to Continuous Mode.

6.2 Change to well test mode

Use this procedure to change from continuous mode to well test mode.
Procedure
1. If required, save an archive record.
See Save to an archive record.
2. Record all required well test data to an external system.
Continuous mode data will be unavailable from the display while the system is in well test mode.
3. Go to Menu > Configuration > Process Measurement > Well Perf Measurement.
4. Change Mode of Operation to Well Test Mode.
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36 Micro Motion® Model 5700 Transmitter
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MMI-20052554 March 2019

7 NOC alerts

This section provides information on the status alerts associated with the NOC application. For information on all other Model 5700 alerts, see the Micro Motion Model 5700 Transmitters with Configurable Outputs: Configuration and Use Manual.
Alert Cause
A136 NOC Power Off
A137 Measurements Paused
A138 APM Remediation
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 alerts default to Info
No alerts are affected by fault timeout
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38 Micro Motion® Model 5700 Transmitter
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MMI-20052554 March 2019

A Differences between Series 3000 and Model 5700 NOC Modbus registers

Register Name Series 3000 Model 5700
1657 Gross Volume Total Total Inventory
1659 Mass Total Total Inventory
1661 Net Oil Volume Total Total Inventory
1663 Net Water Volume Total Total Inventory
1665 Uncorrected Oil Volume Total Total Inventory
1667 Back Flow Volume Total Total Inventory
1669 Back Flow Volume Total Total Inventory
1671 Uncorrected Gross Volume Total Total Inventory
1673 Gas Volume Total Total Inventory
2327 Gross Volume Inventory Inventory Total
2329 NOC Mass Inventory Inventory Total
2331 Net Oil Volume Inventory Inventory Total
2333 Net Water Volume Inventory Inventory Total
2335 Uncorrected Oil Volume Inventory Inventory Total
2337 Uncorrected Water Volume Inventory Inventory Total
2339 Back Flow Volume Inventory
(uncorrected)
2341 Uncorrected Gross Volume Inventory Inventory Total
2343 Gas Volume Inventory (Gas Meter) Inventory Total
Inventory Total
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* MMI-20052554*
MMI-20052554
Rev. AA
2019
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