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Agar Multiphase Flow Meter: Oil, Gas, and Water Mixed Stream Diagnostics
Quick Answer: The Agar multiphase flow meter measures oil, gas, and water fractions in one inline device without a test separator. Production teams use it for real time well diagnostics, water cut trends, and gas breakout detection. Silver Automation Instruments supplies compatible flow and pressure instruments and can quote a full measurement loop based on your operating data.
Why This Measurement Is Hard in the Field
Oil, gas, and water rarely arrive as a clean three phase stream. Wells produce slugs of gas, water cut shifts after breakthrough, and emulsion layers form in the pipe. A test separator can do the job, but it takes space, uses operator hours, and gives periodic data only.
Here is the thing. Most field engineers do not need perfect laboratory accuracy. They need a trend that tells them which well is loading up, which pipeline is forming hydrates, and which separator is carrying over water. The Agar meter is used because it gives this trend inline. It sees the mixture at line pressure and temperature and reports phase fractions without removing the well from production.
What the Agar Multiphase Flow Meter Reports
A typical Agar multiphase flow meter reports water cut from 0 to 100 percent, gas volume fraction up to 95 percent or higher depending on the model, mixture mass flow rate, and phase flow rates for oil, water, and gas. Units like kg/h for liquids and Nm3/h for gas are common in operator dashboards. The device also outputs process temperature and pressure from built in sensors.
The Agar meter often combines microwave resonance technology for water cut and a Venturi section for total mass flow. This approach works in oil continuous emulsion and water continuous emulsion. Gas fraction is calculated from density and pressure drop. No separator is required.
In practice, operators look at the water cut curve first. A slow rise from 18 percent to 27 percent over four weeks tells them that water injection is reaching the producer. A sharp gas spike before a pump station suggests slug flow or a valve issue. The diagnostic is not just about allocation. It is about avoiding a shutdown two days later.
We have seen this on a crude gathering station in South Sumatra. The operator replaced a test separator with an inline multiphase meter and reduced well testing time from six hours to forty minutes per well. The meter also caught a water wash injection mismatch that would have taken the export pump offline.
Where This Measurement Is Applied
Oil and gas operators use multiphase flow diagnostics in several locations. On offshore platforms, space is limited and the weight of a test separator is expensive. A compact inline meter reduces deck load and gives continuous data for well allocation.
On FPSO vessels in West Africa, produced fluids from multiple wells arrive in a common manifold. A multiphase meter on each wellhead or test header tracks which well is producing more gas or water without routing each stream to a test separator.
In the Middle East, well test skids with Agar meters are common for remote pads in Oman and Saudi Arabia. In Latin America, heavy oil fields run the meter with injected steam. In high viscosity oil and emulsion layers, manual sampling becomes slow and inaccurate.
Australia and Southeast Asia have also moved toward inline multiphase meters for coal seam gas water handling and produced water reinjection. The same diagnostic principle applies when a water line carries small amounts of oil or gas. The meter detects oil carryover before the water enters a reinjection well or a disposal sump.
What Data You Need to Prepare for a Quote
To specify a multiphase flow meter or a supporting measurement loop, you need to provide basic process data. Line pressure in bar is essential. A wellhead meter at 55 bar behaves differently from a separator outlet at 8 bar. Temperature in Celsius matters because viscosity and gas solubility change with temperature. Pipe size in DN is required for mechanical dimensions and
Water cut range and gas volume fraction are critical for meter configuration. You should also state if the fluid is sweet or sour, and if the installation needs ATEX Zone 1, IECEx, or API 6A compliance. If you have a salinity range for produced water, share it. High salinity shifts the water dielectric and affects electromagnetic and microwave based measurement.
Send us your pressure (bar), temperature (°C), pipe size (DN), flow range, water cut range, gas volume fraction, and certification zone. Silver Automation Instruments will recommend the correct Agar meter configuration where applicable or a supporting measurement package based on our flow instruments.
Supporting Instruments from Silver Automation Instruments
Silver Automation Instruments supplies the instruments around the multiphase flow meter. For liquid only verification lines, our SIL CMF series Coriolis mass flow meter covers DN10 to DN100 with accuracy of 0.1 percent of rate and 4-20 mA HART output. It is a good check meter when a pump station needs independent mass flow data for custody transfer or leak detection.
For produced water and brine disposal, our SIL MAG electromagnetic flow meter in DN15 to DN300 works well with PTFE liners and 316L electrodes. It tolerates conductive water with oil traces and solids if the velocity stays above 0.5 m/s.
For gas breakout lines or flare headers, a SIL USF clamp on ultrasonic flow meter can be installed without cutting the pipe. This is useful when you want a temporary check on a line that already has an Agar meter but shows questionable gas velocity.
Many sites also add a SIL PT pressure transmitter for wellhead pressure and a SIL VPR paperless recorder to store 16 channels of flow, pressure, temperature, and diagnostic flags. These instruments connect to the same RTU or PLC via 4-20 mA, HART, Modbus, or pulse outputs.
We do not push a single meter for every stream. A multiphase meter is the right tool for mixed oil, gas, and water diagnostics. A dedicated Coriolis or electromagnetic meter is better for single phase liquid flow after separation.
FAQ
Can the Agar multiphase flow meter handle high gas volume fraction?
Yes, many models handle gas volume fraction above 90 percent. You need to provide the actual range because high gas volume fraction changes velocity profiles and phase distribution. The meter algorithm usually compensates for slug and annular flow.
What pipe sizes and pressure ratings are common?
Small wellhead installations often use DN50 to DN100. Larger headers may use DN150 or DN200. Pressure ratings of 1500 lb and 2500 lb flanges are common in Middle East and offshore projects. Always state the flange class and line schedule when requesting a quote.
Do I need a separate flow computer?
Some Agar systems include a local display and Modbus output. If you need net oil allocation, a flow computer or PLC can take the Modbus registers and run the allocation logic. Silver Automation Instruments can supply a recorder or integrate with your existing RTU.
How does produced water salinity affect the water cut measurement?
Salinity changes the dielectric constant of water. Microwave based meters include a compensation model for this. You should provide the expected salinity range in µS/cm or ppm so the configuration matches the field brine.
What is the lead time for a complete metering skid?
A complete skid with a multiphase meter, pressure transmitter, recorder, and isolation valves often takes 10 to 16 weeks depending on certification and material class. Standard single instruments from Silver Automation Instruments can ship much faster.
For a quote on an Agar multiphase flow meter or supporting instruments, send us your pressure (bar), temperature (°C), pipe size (DN), and flow range. Contact Silver Automation Instruments by Tel: +86-135-1213-1526, WhatsApp: 86-135-12131526, WeChat: +86 13512131526.
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