Reservoir
Coreflood experiments reveal that alkali significantly reduces viscosity loss in polyacrylamide flooding systems by minimizing adsorption and improving polymer stability under shear stress. The findings position viscosity retention as a key screening criterion for successful alkali-polymer enhanced-oil-recovery applications.
This SPE technical section editorial synthesizes six technical themes shaping CO2 transport and storage and interprets them through a petroleum engineering capability lens.
The UAE project is expected to produce up to 345 MMscf/D by 2029, with expansion potential to 1 Bcf/D.
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This year’s selected papers showcase meaningful advances across condensate‑rich tight gas, tight sandstone, and coalbed methane reservoirs, each contributing new tools for improving predictability and field-development efficiency. -
This paper presents a novel approach to predict reservoir porosity by conditioning seismic data, calibrating seismic impedance inversion, and tailoring rock-physics analysis.
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This study aims to systematically assess casing integrity and corrosion risks associated with CO2 injection in oil-recovery operations.
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This paper presents findings reinforcing the argument that acid fracturing is a strong alternative stimulation method to improve productivity in the Austin Chalk formation.
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The current challenge in reservoir simulation extends beyond developing better models; it entails creating solutions that are faster, more responsive, and genuinely instrumental in guiding decision-making. The papers selected this year clearly represent this evolution.
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This paper aims to assess the effectiveness of using advanced integrated production-data-analysis techniques for condensate-rich tight gas fields.
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This study applies Monte Carlo simulation and an XGBoost regression model to assess the influence of various formations, geologic provinces, tectonic-plate types, and boundary conditions on hydrogen concentrations.
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This case study describes how edge computing and industrial internet of things platforms were deployed to automate and optimize production operations across four distinct basins.
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Output is rising fast in the South American shale play and putting Argentina on a course to soon reach 1 million B/D.
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This case study presents a procedure in which the operator compared production from wells with adjusted wettability to a control group, finding that the adjustments resulted in significant improvements in production and reductions in produced water.
