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Abstract: The reservoir quality of unconventional resources is highly variable due to the complex nature of the depositional settings and physical processes. Multidisciplinary integration of sedimentology, ichnology, and geochemistry on extensive set of long cores allowed us to construct a detailed depositional model and sequence stratigraphic framework for the Horn River Shales; the third largest gas reservoir in Canada. Detailed analysis of cores indicated that depositional conditions range between low-energy anoxic conditions to higher-energy oxygenated conditions. Utilizing major changes in the sedimentological, ichnological, and geochemical characters, I identified eight major surfaces and nine systems tracts including highstand, transgressive, lowstand, and falling-stage systems tracts. Our results show that high resolution sequence stratigraphy is applicable in unconventional basins, and major surfaces and systems tracts can be delineated in as much detail as in shallow-water siliciclastic settings. I also applied a forward stratigraphic modelling approach in order to numerically simulate a 3D stratigraphic model for the Horn River Basin that I compared to the observed stratigraphic patterns, enabling us to test importance of parameters such as basin bathymetry, timing and magnitude of sea level cycles, and the volume of extra- and intra-basinal input. Forward stratigraphic modelling is a powerful tool to predict reservoir potential in sedimentary basins, although it has rarely been applied to unconventional basins. The results presented herein show that forward modelling can be applied to unravelling sequence stratigraphic units in unconventional reservoirs.

Biography:Dr. Ayranci completed his B.Sc. and M.Sc. degrees at the Geological Eng. Dept., Akdeniz University, Turkey. He obtained his Ph.D. degree from the Earth Science Dept., Simon Fraser University, Canada. Following his Ph.D. he join the research group of Dr. Nick Harris at the University of Alberta, Canada, as a Post-doctoral research fellow and later became a Research Associate at the same department. He is currently an assistant professor at the College of Petroleum Engineering and Geosciences, King Fahd University of Petroleum and Minerals. He has a diverse background in sedimentology, marine geology, stratigraphy, ichnology, and forward stratigraphic modelling. The overarching theme of his research is modern and ancient marine settings, and unconventional reservoirs. Under this umbrella, his research can be divided into four sub-categories:

1. Sedimentological and ichnological characterization of deep- and shallow-water deltaic settings
2. Sediment transport mechanisms in marine environments.
3. Depositional characterization and sequence stratigraphy of unconventional reservoirs
4. Applications of forward stratigraphic modelling in shale basins and deltaic settings
   

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• CONTACTProf. Thomas Finkbeiner
• EMAILthomas.finkbeiner@kaust.edu.sa

​Abstract: Drilling is crucial to many industries, including hydrocarbon extraction, CO₂ sequestration, geothermal energy, and others. During penetrating the subsurface rocks, drilling fluid (mud) is used for drilling bit cooling, lubrication, removing rock cuttings, and providing wellbore mechanical stability. Significant mud loss from the wellbore into the surrounding formation causes fluid lost-circulation incidents. This phenomenon leads to cost overrun, environmental pollution, delays project time, and causes safety issues. Although lost-circulation exacerbates wellbore conditions, prediction of the characteristics of subsurface formations can be obtained. Generally, four formation types cause lost-circulation: natural fractures, and induced fractures, vugs and caves, and porous/permeable medium. The focus of this work is on naturally fractured formations, which is the most common cause of lost circulation. In this work, a novel prediction tool is developed based on analytical solutions and type-curves (TC). Type-curves are derived from the Cauchy equation of motion and mass conservation for non-Newtonian fluid model, corresponding to Herschel-Bulkley model (HB). Experimental setup from literature mimicking a deformed fracture supports the establishment of the tool. Upscaling the model of a natural fracture at subsurface conditions is implemented into the equations to achieve a group of modified type-curves (MTC) alongside another set of derivative-based type-curves (DMTC). The developed approach is verified with numerical simulations. Further, verification is performed with other analytical solutions. This proposed tool serves various functionalities; It predicts the volume loss as a function of time, based on wellbore operating conditions. The time-dependent fluid loss penetration from the wellbore into the surrounding formation can be computed. Additionally, the hydraulic aperture of the fracture in the surrounding formation can be estimated. Due to the non-Newtonian behavior of the drilling mud, the tool can be used to assess the fluid loss stopping time. Validation of the tool is performed by using actual field datasets and published experimental measurements. Machine-Learning is finally investigated as a complementary approach to determine the flow behavior of mud loss and the corresponding fracture properties.

Zoom Meeting https://kaust.zoom.us/j/99757086778

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• CONTACT Rami Albattat
• EMAIL Rami.Albattat@kaust.edu.sa