Foreword — Oil-sands and heavy-oil deposits: Local to global multidisciplinary collaboration

Hein, Frances J.; Parks, Kevin P.; Leckie, Dale A.; Seibel, Chris

doi:10.2113/gscpgbull.64.2.99

Cited by 6 publications

(2 citation statements)

References 5 publications

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“…The bitumen bearing formations in Athabasca were developed in Alberta subbasin of Western Canadian Basin [20]. The McMurray Formation is a member of the Manville Group that was deposited as fluvial-estuarine-marginal successions due to the Boreal sea level rising during the middle to late Cretaceous.…”

Section: Geologic Backgroundmentioning

confidence: 99%

Quantitative Characterization of Tidal Couplets in Oil Sands Reservoir, the Upper McMurray Formation, Northeastern Alberta, Canada

et al. 2021

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The McMurray Formation, NE Alberta, Canada, is one of the most significant bitumen bearing deposits worldwide. This formation deposited and reworked in fluvial, tidal, or estuarine environments results in a huge number of tidal couplets (TCs) which is consisted of mm-cm scale sandy and muddy interlayers. These couplets not only increase the geologic heterogeneity of the oil sand reservoir but also make it hard to predict the performance of in situ thermal processes. In this paper, based on literatures, lab analysis, core photos, logging, and drilling data, a quantitative characterization procedure for mm-cm scale tidal couplets was proposed. This procedure, which includes identification, classification, quantitative description, and spatial distribution prediction, was presented. Five parameters, thickness, mud volume, laminae frequency, spatial scale, and effective petrophysical properties, were selected to describe the TCs quantitatively. To show the procedure practically, TCs in the oil sand reservoir of McMurray Formation, Mackay River Project, and CNPC, were selected to demonstrate this procedure. The results indicate that the TCs are in mm-cm thickness, densely clustered, and in a variety of geometries. Based on geologic origins, these couplets were divided into four types: tidal bar couplets (TBCs), sand bar couplets (SBCs), mix flat couplets (MFCs), and tidal channel couplets (TCCs). The thickness, mud volume, and frequency were calculated by mathematical morphological processed core photos. The spatial scale of TCs was estimated by high-density well correlations. The effective petrophysical properties were estimated by bedding scale modeling and property modeling via REV. Finally, the spatial distribution of TCs was predicted by object-based modeling.

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Section: Geologic Backgroundmentioning

confidence: 99%

Quantitative Characterization of Tidal Couplets in Oil Sands Reservoir, the Upper McMurray Formation, Northeastern Alberta, Canada

et al. 2021

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“…This subject is also very important for the petroleum industry due to the fact that several oil basins are composed of high viscosity oils. These types of oils have become economically attractive due to recent discoveries of oil reservoirs in Canada, Venezuela, and Brazil, such as Campos Basin (Hein et al, 2017). Thus, it is essential to know how high fluid viscosities impact pressure losses of the flow in an ESP stage, as well as on ESP performance.…”

Section: Introductionmentioning

confidence: 99%

Effects of High Fluid Viscosity on Pressure Losses of the Single-Phase Flow Inside an Esp Stage

Siqueira

Steiner

Bueno

2019

BJPG

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The Electrical Submersible Pump (ESP) system is among the most widely used artificial lift methods in the world. This work studies the effects of high fluid viscosity on pressure losses of the flow in an ESP stage. A theoretical model was applied to four different flow cases. First, curves for head and pressure losses at the pump stage were generated and, based on literature formulations available in the model, as well as on adjusted empirical coefficients (for highly viscous fluids), implemented in the model. Subsequently, the heads were estimated and evaluated using experimental data and statistical analyses based on mean square error. The results showed that high fluid viscosity impacted considerably pressure losses and pump performance. In 50% of the cases studied, statistical analyses alone could estimate the head in the pump stage with good accuracy. However, in the remaining cases, it was also necessary to consider the physical behavior of the highly viscous fluids studied. The variability of the selected formulations from the literature (for pump head and pressure losses) with pump rotation, and especially with high fluid viscosity, was considerably larger than the ones found in previous studies for less viscous fluids.

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Research on Molecular Dynamics Simulation of Oil Sands Pyrolysis

Liu

Zhu

Liu

et al. 2022

Proceedings of the International Field Exploration and Development Conference 2021

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Foreword — Oil-sands and heavy-oil deposits: Local to global multidisciplinary collaboration

Cited by 6 publications

References 5 publications

Quantitative Characterization of Tidal Couplets in Oil Sands Reservoir, the Upper McMurray Formation, Northeastern Alberta, Canada

Quantitative Characterization of Tidal Couplets in Oil Sands Reservoir, the Upper McMurray Formation, Northeastern Alberta, Canada

Effects of High Fluid Viscosity on Pressure Losses of the Single-Phase Flow Inside an Esp Stage

Research on Molecular Dynamics Simulation of Oil Sands Pyrolysis

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