Sequence stratigraphic controls on reservoir characterization and architecture: case study of the Messinian Abu Madi incised-valley fill, Egypt

Fattah, Mohamed Abdel; Slatt, Roger M.

doi:10.2478/s13533-012-0144-5

Cited by 16 publications

(9 citation statements)

References 24 publications

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“…Reference 12 showed that the incised-valley filling pattern of Abu Madi Formation is consistent with an abrupt relative sea-level fall followed by a still stand, then a progressive rise. For Abu Madi Formation reservoirs, the sections in the lower parts and upper parts consist of thick, porous sandstone, with some shale intercalations 13 .…”

Section: Geologic Settingsmentioning

confidence: 95%

Formation evaluation of Abu Madi reservoir in Baltim gas field, Nile Delta, using well logs, core analysis and pressure data

Metwally,

Mabrouk,

Mahmoud

et al. 2023

Sci Rep

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Baltim Eastern and Northern gas fields in the offshore Nile Delta have very high gas condensate accumulations. Therefore, the present research evaluates Abu Madi and Qawasim Formations and defines the petrophysical parameters for them using various data from five wells composed of wireline logs (gamma-ray, density, neutron, sonic, resistivity), core data, pressure data, and cross-plots. In the current study, the formations of the main reservoirs were evaluated qualitatively and quantitatively based on the petrophysical analysis to assess the production potential. Based on the lithological identification, the two main reservoirs (Abu Madi and Qawasim Formations) are composed of sandstone, calcareous shale, and siltstone. The main petrophysical parameters (Shale volume, effective porosity, net thickness, and fluid saturations) were mapped to track the areal petrophysical variations in the field. The results of the petrophysical analysis reveal that the main reservoirs are promising for the hydrocarbon potential with effective porosity of 18%, low shale content with an average value of about 21%, higher gas saturation of average value of nearly 58%, net reservoir thickness ranges from 25.5 to 131.5 m, net pay thickness (effective thickness) ranges from 6 to 61 m. Also, the conventional core analysis affirms that the main reservoirs are of good effective porosity with high horizontal and vertical permeability values. There is a good match between the well-log results and the pressure data with the production data (DST “perforation tests”). Baltim East (BE3) well has the most desired petrophysical characteristics in the Baltim East gas field, while, the Baltim North-1 (BN1) well showed the most favorable petrophysical parameters in the Baltim North gas field. Different fluid contacts (gas water contact GWC) were detected by integrating all reservoir pressures. The integration of different data in our present work (well logs, core measurements, and pressure data) could reduce the drilling risks and help to determine the best locations for future exploration and development, which is considered a big challenge in the petroleum industry.

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Section: Geologic Settingsmentioning

confidence: 95%

Formation evaluation of Abu Madi reservoir in Baltim gas field, Nile Delta, using well logs, core analysis and pressure data

Metwally,

Mabrouk,

Mahmoud

et al. 2023

Sci Rep

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show abstract

“…It is difficult to identify the unconformity surface and ascertain the sequence boundary only by seismic reflections due to the relatively homogeneous property of the shale reservoir. Previous studies suggest that well-log data, geochemical parameters, lithofacies are of key significance for determining shale sequence boundaries [21,[53][54][55]. In this study, sequence boundaries are determined by a combination of redox indicator (U/Th ratio), well logs (Natural gamma ray, Uranium, Compensated neutron logging, Acoustic, Density), lithofacies.…”

Section: Identification Of Second-order Sequence Boundarymentioning

confidence: 97%

Division of shale sequences and prediction of the favorable shale gas intervals: an example of the Lower Cambrian of Yangtze Region in Xiuwu Basin

Zhang

Song

et al. 2019

Open Geosciences

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It is a common method to use sequence stratigraphic theory to identify favourable intervals in hydrocarbon exploration. The Lower Cambrian shale of Well Jiangye-1 in Yangtze Region in Xiuwu Basin was chosen as the research object. The content of excess silicon of siliceous minerals in shale was calculated quantitatively, and the concentration distribution of Al, Fe, Mn showed that the excess silicon is of hydrothermally origin and the shale deposited in an environment with hydrothermal activity. Using U/Th values in the study, combined with lithology and logging data, in order to divide sequences of the Lower Cambrian shale in Yangtze Region in Xiuwu Basin. The result shows that the shale of the Lower Cambrian shale is recognized as 1 2nd sequence (TST-RST, TST = Transgressive systems tract; RST = Regressive systems tract) and then further subdivided into 5 3rd sequences (SQ1-SQ5). During the deposition of SQ2 and SQ3, hydrothermal activity was active, and their excess silicon content was generally above 20%-30%. Rising sea level and active hydrothermal activity were beneficial for the enrichment of siliceous minerals and organic matter. Based on the comparison of the reservoir parameters, it tells that SQ2 and SQ3 have relatively higher content of TOC, higher content of brittle minerals (such as siliceous minerals, carbonate minerals and so on), larger effective porosity and higher content of gas, which make it as the most favourable intervals of the Lower Cambrian in Xiuwu Basin.

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“…The regional tectonic setting of the area is characterized by an initial, syndepositional extensional rift phase, during which the Abu Roash F was deposited, followed by a phase of transtension and subsequently by a phase of transpression (Bayoumi & Lofty, 1989;Keeley & Wallis, 1991;Abd El Aziz et al 1998;El Toukhy et al 1998;Abdel-Fattah & Slatt, 2013;Sarhan, 2017;Abdel-Fattah et al 2021). During the entire tectonic history up to the present day, the maximum horizontal stress has been oriented NW-SE (Bayoumi & Lofty, 1989;Sarhan, 2017).…”

Section: B Regional Settingmentioning

confidence: 99%

Scale discrepancy paradox between observation and modelling in fractured reservoir models in oil and gas industry

et al. 2022

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The appraisal and development of fractured reservoirs are challenging tasks because of the combined variations in reservoir quality and natural fracture distribution. Fracture models are built routinely to support both appraisal and development decisions for such reservoirs. One of the key objectives of these models is to generate three-dimensional (3D) fracture properties for dynamic flow simulations. In this paper, we illustrate the discrepancy between the scale of observation required to build a thorough geological understanding of the subsurface and the simplification imposed by modelling. We use a case study carried out in the context of an exploration campaign of a Cretaceous carbonate reservoir in Egypt. After describing the regional geological setting of the area, we share a series of detailed observations on open-hole logs, cores, thin-sections and borehole images. These observations are focused on reservoir architecture, fracture typology and fracture connectivity. Observations are then integrated with the regional geological context to build a conceptual fracture model and to characterize the uncertainty affecting the essential parameters of this model. The conceptual model, combined with 3D seismic data, is used to define a fracture modelling strategy. This strategy includes a drastic simplification of the conceptual model to generate 3D discrete fracture network scenarios that are calibrated using pressure communication data from the exploration wells. Another extreme simplification is then necessary to populate 3D simulation grids. In the case study presented, the key tuning parameters to obtain a dynamic match are the grid cell orientation and the width of the modelled fault damage zone.

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Sequence stratigraphic controls on reservoir characterization and architecture: case study of the Messinian Abu Madi incised-valley fill, Egypt

Cited by 16 publications

References 24 publications

Formation evaluation of Abu Madi reservoir in Baltim gas field, Nile Delta, using well logs, core analysis and pressure data

Formation evaluation of Abu Madi reservoir in Baltim gas field, Nile Delta, using well logs, core analysis and pressure data

Division of shale sequences and prediction of the favorable shale gas intervals: an example of the Lower Cambrian of Yangtze Region in Xiuwu Basin

Scale discrepancy paradox between observation and modelling in fractured reservoir models in oil and gas industry

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