Enhanced recovery
Operators are turning to new gas-lift and nanoparticle-fluid technologies to drive up production rates.
This paper addresses the difficulty in adjusting late-stage production in waterflooded reservoirs and proposes an integrated well-network-design mode for carbon-dioxide enhanced oil recovery and storage.
This work presents the development of fast predictive models and optimization methodologies to evaluate the potential of carbon-dioxide EOR and storage operations quickly in mature oil fields.
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The First Eocene is a multibillion-barrel heavy-oil carbonate reservoir in the Wafra field, located in the Partitioned Zone between Saudi Arabia and Kuwait. After more than 60 years of primary production, expected recovery is low and provides a good target for enhanced-oil-recovery processes. -
This paper studies the technical and economic viability of this EOR technique in Eagle Ford shale reservoirs using natural gas injection, generally after some period of primary depletion, typically through long, hydraulically fractured horizontal-reach wells.
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This paper presents technologies and best practices to improve oil recovery in mature fields through waterflooding optimization. These technologies have proved practical and cost-effective.
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This paper provides a robust methodology for miscible CO2 WAG experimental-data acquisition and history matching.
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To the best of the authors’ knowledge, this is the first surface-complexation-based model that describes fully ionic compositional dependence observed in ionically treated waterfloods in both sandstones and carbonates.
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As operators and asset owners worked continually to increase efficiency in oil production, they all realized that part of efficiency improvement is increasing recovery factors. Everybody now is extremely focused on recovering more from the reservoirs they have.
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This paper presents the implementation of an approach for improving oil recovery by water-injection optimization using injection-control devices (ICDs) in unconventional reservoirs.
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The Eagle Ford formation has produced approximately 2 billion bbl of oil during the last 7 years, yet its potential may be even greater. Using improved oil-recovery (IOR) methods could result in billions of additional barrels of production.
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This paper evaluates the incremental benefit of water injection in a conventional gas reservoir when compared with gas compression.
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This paper evaluates the ability of different groups of surfactants to improve oil recovery in unconventional liquid reservoirs (ULRs) by experimentally simulating the fracture treatment to represent surfactant imbibition in a ULR core fracture during a soaking flowback.
