Enhanced recovery
This paper presents an autonomous, data-driven solution designed specifically for intermittent well optimization.
This work evaluates CO2-based fracturing as a sustainable development approach for shale gas reservoirs in the Burgos Basin of Mexico.
This paper describes an autonomous inflow-control technology for gas wells developed to detect and choke unwanted water production autonomously while allowing gas and condensate production.
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With the recent drop in oil prices, operators are shifting to optimization of existing assets with minimal costs. For mature floods (water, chemical, and CO2), one low-cost optimization strategy is the intelligent adjustment of well-rate targets. -
Thermal steam stimulation is considered the most effective of current methods for heavy-oil production. However, the method has problems with low coverage by steam injection and decreased efficiency.
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The addition of a hydrocarbon condensate to steam operations in heavy-oil and bitumen reservoirs has emerged as a potential technology to improve not only oil recovery but also energy efficiency.
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Chemical enhanced-oil-recovery methods such as polymer and alkaline/surfactant/polymer (ASP) flooding are generally not considered suitable for oil viscosities greater than 100 or 200 cp.
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This article describes how the use of a biological EOR technique that applied produced water for reservoir flooding in a mature field led to rapid and substantial increases in oil production.
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The authors present a method to reduce uncertainty in EOR performance adaptively while identifying an optimal operational strategy for a given tolerance to risk.
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Conventional miscible- or near-miscible-gasflood simulation often overestimates oil recovery, mostly because it does not capture a series of physical effects tending to limit interphase compositional exchanges.
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The Bakken’s ultratight, largely oil-wet nature limits the potential of waterflooding. As an alternative, an optimally spaced well-to-well surfactant-flooding technology is proposed.
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Limited design capability, few number of field tests, and lack of monitoring and control were the reasons most EOR projects did not perform in the past. All those are history now.
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This study provides technical analysis of the viability of enhanced-oil-recovery (EOR) processes; the results indicate the potential for significant improvement in recovery efficiency over continued waterflooding.
