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Flow, level & control


Achieving in-situ flow meter calibration utopia


Dr Bruno Pinguet, Multiphase Domain senior advisor at TÜV SÜD National Engineering Laboratory, discusses how multiphase and wet gas flow meters (MFMs) are particularly impacted by pressure-volume-temperature (PVT) effects and how establishing a test protocol for intercomparing in field conditions can accurately identify if meter performance is as it should be.


F


or the oil and gas industry, accurately measuring a mixture of oil, water and gas in field conditions is a major


challenge. Multiphase flow meters (MFMs) have opened the door to the development of marginal assets and promote more efficient exploitation of larger fields. As a multiphase meter can eliminate the need for a test separator, which are big and difficult to maintain, smaller platforms are possible. Existing facilities can also be upgraded to take subsea tie-backs without having to add an extra test separator. Indeed, the test separator may be reused as an additional production separator to cope with the extra production. MFMs also give continuous measurements, allowing better reservoir management, well optimisation, and a quick response to water break-through and similar events. Also, having a subsea multiphase meter on each wellhead facilitates the production and flow assurance issues and better reservoir recovery factor. The ability to provide real-time flow


measurement will lead to a greater uptake in MFMs worldwide. However, due to the costs


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required to send them back to facilities for calibration, the challenges of validating them in- situ throughout their time in service must be addressed. This is becoming an even more significant issue as the oil and gas industry continues to exploit deeper and more remote fields. Additionally, accurate flow measurement near the wellhead enables users to make informed decisions about critical operational procedures, such as optimisation, obtaining reservoir characteristics, enhanced recovery techniques, and the mitigation of pipeline flow assurance challenges. However, the use of multiphase flow meters


in oil and gas applications, particularly when installed for remote or subsea application, is fraught with challenges. Whilst ensuring the ongoing performance of multiphase flow meters is critical to avoid the financial exposure and risks associated with their mismeasurement, so far little has been done to address the challenges associated with their ongoing verification or calibration in-situ, for both topside and subsea installations. All metering devices monitoring oil and gas flows provide information at the in-situ


April 2021 Instrumentation Monthly


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