Reservoir
Canada’s development of large-scale digital drilling core libraries and open geoscience data platforms follows approaches pioneered in Australia, particularly Western Australia, through decades of government investment in geoscience data collection and preservation.
This paper aims to establish a set of best practices for generating particle-size-distribution data from core samples.
This study explores the carbon-capture and mineralization potential of ultramafic rock powders when exposed to flue gases generated from combustion of crude oil and mesquite-derived charcoal.
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Over the past year, despite the naysayers’ comments and predictions, the usual creativity and ingenuity of engineers and scientists in the oil industry were ubiquitous. -
The Pugang gas field, one of the biggest inland gas discoveries of the last decade in China, has hydrogen sulfide (H2S) concentrations as high as 10%, making surface- and downhole-facilities design and execution challenging.
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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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This work presents a real field example in which the integration of well-testing and geological interpretations increased the understanding of a complex, heterogeneous reservoir.
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Although the wellbore is in a nonisothermal environment, heat transfer between the fluid in the wellbore and the formation is often ignored and temperature is usually assumed constant in data interpretation, which will lead to misunderstanding of the pressure profile.
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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.
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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.
