3D Structural, Facies and Petrophysical Modeling of C Member of Six Hills Formation, Komombo Basin, Upper Egypt

Ali, Mohamed; Abdelmaksoud, Ahmed; Essa, Mahmoud A.; Abdelhady, Ahmed Awad; Darwish, M.

doi:10.1007/s11053-019-09583-5

Cited by 33 publications

(6 citation statements)

References 19 publications

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“…Seismic reflection data allow the imaging of subsurface structures down to 7 s two‐way time (TWT). The seismic interpretation process includes the recognition and picking of the principal seismo‐stratigraphic features and faults (carried out using the Schlumberger Petrel TM package) in order to define boundaries of the main seismo‐stratigraphic units in the study area, and in particular, in the vicinity of the structural high (Ali, 2020; Ali et al., 2018; Ali, Abdelhady, et al., 2020; Ali, Abdelmaksoud, et al., 2020). Accordingly, six crosslines, three inlines, and three composite lines were interpreted to study the break out of the studied feature (Figures 2b, 3, 4, and 6).…”

Section: Data Sets and Methodologymentioning

confidence: 99%

Geophysical Evidence for Magmatism Southwest of the Brothers Islands, Northern Red Sea (Offshore Quseir, Egypt)

et al. 2022

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The Red Sea formed due to the separation of Arabia from Nubia during the Late Oligocene-Early Miocene, involving a counter-clockwise rotation of the Arabian plate. Although the southern and central sectors of the Red Sea reached the oceanic stage and display a prominent NW-SE oriented axial ridge, the nature of the crust in its northward termination is still controversial (e.g., Augustin et al., 2021). Onshore observations in the present-day margins of the northern Red Sea (NRS) indicate a "classic" rifted margin dynamic dominated by normal fault and half-graben geometries and provide constraints on the timing and evolution of rifting (Figure 1a; Bosworth & Burke, 2005;Cochran, 1983Cochran, , 2005. Omar and Steckler (1995) concluded that the early stage of rifting was accompanied by two uplift and erosion phases of the shoulders. The first stage started ∼34 Ma in the Early Oligocene, while the second uplift and erosion phase occurred during the latest Oligocene to Early Miocene. However, geological and thermochronometric evidence from the Quseir area on the Red Sea coast indicates that only the second uplift and erosion phase at 23 Ma exists (

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Section: Data Sets and Methodologymentioning

confidence: 99%

Geophysical Evidence for Magmatism Southwest of the Brothers Islands, Northern Red Sea (Offshore Quseir, Egypt)

et al. 2022

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“…During the Pliocene, the Nile River separated these Cretaceous rift basins into the Western Desert (Komombo) and the Eastern Desert (Nuqra and Kharit) basins (Figure 2). The Komombo Basin has Early Cretaceous mature source and reservoir rocks with excellent porosity and permeability values (Ali, Abdelhady, et al, 2020; Ali, Abdelmaksoud, et al, 2020; Ali, Darwish, et al, 2018).…”

Section: Introductionmentioning

confidence: 99%

“…Several attempts have been made at comprehending the depositional environments and geochemical characteristics of the Cretaceous sediments of the Komombo Basin using well and seismic data (Abdeen et al, 2021; Abdelhady, 2016; Abdelhady et al, 2016; Ali, 2017, 2020; Ali, Abdelhady, et al, 2020; Ali, Abdelmaksoud, et al, 2020; Ali et al, 2017a, 2017b, 2019; Ali, Darwish, et al, 2018; Dolson et al, 2014; Fathy et al, 2010; Said & Sakran, 2020; Selim, 2016). These studies improved our understanding of the hydrocarbon potential and stratigraphic heterogeneities of the Komombo Basin.…”

Section: Introductionmentioning

confidence: 99%

Tectonic evolution and subsidence history of the Cretaceous basins in southern Egypt: The Komombo Basin

Ali

Abdelhady³

et al. 2022

Basin Research

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The structure and tectonic evolution of the Cretaceous rift basins of southern Egypt are poorly understood. In this study, the tectonostratigraphy of the Komombo Basin has been determined using seismic, well and biostratigraphic data. The tectonostratigraphy of the basin is compared to the Kharit, Nuqra and Beni Suef basins in Egypt as well as Muglad Basin in Sudan. The Komombo Basin is a 58 km long, 28 km wide NW–SE trending half‐graben infilled with 2200 m of Berriasian‐Maastrichtian sediments and overlain by 400 m of Pliocene sediments. Four Berriasian to Maastrichtian syn‐rift and post‐rift sequences and three Pliocene channel systems of Nile sediments have been identified. Moreover, a series of normal faults, negative flower structures, reverse faults and folds are mapped in the basin. Backstripping reveals two rift phases during the Berriasian‐Barremian and Turonian‐Santonian, respectively. Additionally, the tectonic subsidence curves indicate that two major unconformities have occurred during the Aptian‐Albian and Maastrichtian‐Pliocene, which are correlated with a basement uplift during the Albian‐Cenomanian and the Oligocene‐Miocene flank uplift related to the opening of the Red Sea, respectively. The rift episodes are attributed to far‐field stress changes resulting from the initial opening of the South Atlantic and followed by the NW part of the African plate colliding and anticlockwise rotating into Europe. The highest β factors (1.20–1.11) for both rift phases are found at the centre of the basin. The rift phases thinned the crust from 32.5 to 28.2 km and 31.9 km in the depocenter and the western flank of the basin. The Komombo Basin has a similar rift history, stratigraphy and structural style to the Kharit, Nuqra and Mugland basins. All of these basins witnessed two major rift phases in the Early and Late Cretaceous, whereas the Beni Suef Basin encountered strike‐slip tectonic events in the Late Cretaceous.

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“…Its use allows expanding the analysis of conventional geological data by visualizing continuities, groupings, and spatial trends, as well as geometries of geological bodies or units, structural geological framework, and variation of geochemical contents or any other numerical or categorical parameters in geosciences. Recent 3D modeling examples in the oil and gas sector can be seen in Qadri et al (2019), , Ali et al (2020), and Islam et al (2021). Examples of 3D geological modeling focusing on CO 2 storage are scarce, such as Kaufmann and Martin (2008), Douglass and Kelly (2010), Monaghan et al (2012), Alcalde et al (2014), Lech et al (2016), Mediato et al (2017), Shogenov et al (2017), Vo Thanh et al (2019, and Zhong and Carr (2019).…”

Section: Introductionmentioning

confidence: 99%

3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

et al. 2021

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The Paris Agreement established global ambitious targets for reducing carbon dioxide (CO 2 ) emissions, requiring the rapid and extensive development of low carbon technologies, and one of the most efficient is CO 2 geological storage. Among the deep geological formations used for CO 2 storage, the shale layers have been a new emerging field with higher efficiency because they are abundant and have a high content of organic matter that is favorable for CO 2 retention. However, one of the challenges in evaluating a location for potentials reservoirs is the adequate geological characterization and storage volume estimation. The study evaluates the Irati Formation of the Paraná Basin based on wireline logs information within Southeastern Brazil, where most stationary sources of carbon emissions are located. Three-dimensional (3D) implicit modeling techniques were applied not only for volume calculation purpose, but also in the site selection stage, generating thematic 3D models indicating thickness, depth, structures, and distance to aquifer systems. The limestones, shales, and black shales of the Irati Formation were locally grouped into six units considering the geological composition and spatial continuity. Based on the 3D model and reservoir parameters, the organic-rich shale Unit E with a theoretical capacity of 1.85 Gt is considerable for CO 2 storage. The estimated CO 2 storage capacity is promising because it is higher than the total CO 2 locally produced, and it could support the implantation of new projects in this region.

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3D Structural, Facies and Petrophysical Modeling of C Member of Six Hills Formation, Komombo Basin, Upper Egypt

Cited by 33 publications

References 19 publications

Geophysical Evidence for Magmatism Southwest of the Brothers Islands, Northern Red Sea (Offshore Quseir, Egypt)

Geophysical Evidence for Magmatism Southwest of the Brothers Islands, Northern Red Sea (Offshore Quseir, Egypt)

Tectonic evolution and subsidence history of the Cretaceous basins in southern Egypt: The Komombo Basin

3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

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3D Structural, Facies and Petrophysical Modeling of C Member of Six Hills Formation, Komombo Basin, Upper Egypt

Cited by 33 publications

References 19 publications

Geophysical Evidence for Magmatism Southwest of the Brothers Islands, Northern Red Sea (Offshore Quseir, Egypt)

Geophysical Evidence for Magmatism Southwest of the Brothers Islands, Northern Red Sea (Offshore Quseir, Egypt)

Tectonic evolution and subsidence history of the Cretaceous basins in southern Egypt: The Komombo Basin

3D implicit modeling applied to the evaluation of CO2 geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil

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Product

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3D implicit modeling applied to the evaluation of CO₂ geological storage in the shales of the Irati Formation, Paraná Basin, Southeastern Brazil