Video: Enhanced Flux Management for Sand Control Completions
- John Cameron (Chevron Energy Technology Company, a division of Chevron U.S.A. Inc.) | Karim Zaki (Chevron Energy Technology Company, a division of Chevron U.S.A. Inc.) | Colin Jones (Chevron Energy Technology Company, a division of Chevron U.S.A. Inc.) | Antonio Lazo (Chevron Energy Technology Company, a division of Chevron U.S.A. Inc.)
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- Society of Petroleum Engineers
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- Document Type
- 2018. Copyright is retained by the author. This presentation is distributed by SPE with the permission of the author. Contact the author for permission to use material from this video.
- 2.4 Sand Control, 3.2.3 Produced Sand / Solids Management and Control, 5 Reservoir Desciption & Dynamics, 2.2 Installation and Completion Operations, 3.2 Well Operations and Optimization, 3.3 Well & Reservoir Surveillance and Monitoring, 3 Production and Well Operations, 5.6.4 Drillstem/Well Testing, 7 Management and Information, 5.5.8 History Matching, 2 Well completion, 7.2 Risk Management and Decision-Making, 7.2.1 Risk, Uncertainty and Risk Assessment, 5.5 Reservoir Simulation, 2.1.3 Completion Equipment, 3.3.1 Production Logging, 5.6 Formation Evaluation & Management
- erosion model, erosion, sand control, screen erosion, flux
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A probabilistic flux and erosion model and workflow has been constructed to estimate the inflow through sand screen on a foot by foot basis along the wellbore using the completion details, production rate, and reservoir and bottom hole flowing pressures. The model is then calibrated & history matched using well data from pressure transient analyses, well test and production logs as available. Extensive laboratory testing coupled with computational flow dynamics modelling provided the algorithms for a number of different screen types to relate flux and sand production to the expected service life for any given future production profile. This allows the well's planned production profile to be optimized by balancing risk, rate and reserves recovery.