Selma-pmot: a production management optimization tool coupled to multiphase flow simulator

Commingle production nodes are standard practice in the industry to combine multiple segments into one. This practice is adopted at the subsurface or surface to reduce costs, elements (e.g. pipes), and space. However, it leads to one problem: determine the rates of the single elements. This problem is recurrently solved in the platform scenario using the back allocation approach, where the total platform flowrate is used to obtain the individual wells’ flowrates. The wells’ flowrates are crucial to monitor, manage and make operational decisions in order to optimize field production. This work combined outflow (well and flowline) simulation, reservoir inflow, algorithms, and an optimization problem to calculate the wells’ flowrates and give a status about the current well state. Wells stated as unsuited indicates either the input data, the well model, or the well is behaving not as expected. The well status is valuable operational information that can be interpreted, for instance, to indicate the need for a new well testing, or as reliability rate for simulations run. The well flowrates are calculated considering three scenarios the probable, minimum and maximum. Real-time data is used as input data and production well test is used to tune and update well model and parameters routinely. The methodology was applied using a representative offshore oil field with 14 producing wells for two-years production time. The back allocation methodology showed robustness in all cases, labeling the wells properly, calculating the flowrates, and honoring the platform flowrate.

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A Back Allocation Methodology to Estimate the Real-Time Flow and Assist Production Monitoring

Chaves

Monteiro

Ferreira

2021

SPE Annual Technical Conference and Exhibition

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Development of a Virtual Flowmeter as an Enhanced Alternative for Field Production Monitoring

Chaves

Karami

Monteiro

et al. 2021

SPE Annual Technical Conference and Exhibition

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Flowrate is a valuable information for the oil and gas industry. High accuracy on flowrate estimation enhances production operations to control and manage the production. Recognized as a cost-efficient solution, the VFM (virtual flowmeter) is a mathematical-based technology designed to estimate the flowrates using available field instrumentation. The VFM approach developed in this work combines black-box simulations with mixed-integer linear programming (MILP) problem to obtain the flowrates dismissing the tuning process. The methodology included a set of multiphase flow correlations, and the MILP was developed to estimate the flowrate and designate the best fit model. We evaluated the proposed VFM against 649 well test data. The methodology presented 4.1% average percentage error (APE) for percentile 25% and 13.5% APE for percentile 50%. We developed a VFM technology to be used in scenarios with a lack of data, and we believe that our tuning-free method can contribute to the future of VFM technologies.

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Selma-pmot: a production management optimization tool coupled to multiphase flow simulator

Cited by 2 publications

References 25 publications

A Back Allocation Methodology to Estimate the Real-Time Flow and Assist Production Monitoring

A Back Allocation Methodology to Estimate the Real-Time Flow and Assist Production Monitoring

Development of a Virtual Flowmeter as an Enhanced Alternative for Field Production Monitoring

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