Petroleum system analysis-conjoined 3D-static reservoir modeling in a 3-way and 4-way dip closure setting: Insights into petroleum geology of fluvio-marine deposits at BED-2 Field (Western Desert, Egypt)

Abdelwahhab, Mohammad A.; Ali, Emad H.; Abdelhafez, Nabil A.

doi:10.1016/j.petlm.2021.06.001

Cited by 18 publications

(5 citation statements)

References 48 publications

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“…Drawing from the integration of seismic interpretation and supportive petrophysical analysis, several high-potential exploration zones warrant further investigation. Especially, improved fluid contact analysis on water saturation model should be performed before further volumetric analysis and exploitation engagements 47 , 48 Priority should be given to channelized reservoirs displaying distinctive Cylinder- and Funnel-shaped facies, while structural traps and fault zones aligning with favourable reservoir properties should be thoroughly examined. Areas exhibiting lateral porosity variation, particularly southwestward, present alluring prospects, along with zones characterized by low shale volume and promising porosity–permeability relationships.…”

Section: Results Of Petrophysical Analysismentioning

confidence: 99%

Focused reservoir characterization: analysis of selected sand units using well log and 3-D seismic data in 'Kukih' field, Onshore Niger Delta, Nigeria

Fagbemi,

Olayinka,

Oladunjoye

et al. 2024

Sci Rep

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This study focuses on the comprehensive reservoir characterization of the ‘Kukih’ Field within the onshore northeastern Niger Delta region, Nigeria. The absence of its detailed description with delineated reservoir properties, lateral continuity, and their use to identify potential reservoir quality and heterogeneity necessitated this study. Integrating well log and 3D seismic data, the investigation aims to elucidate reservoir properties, lithofacies, and depositional environments to unravel hydrocarbon potential. The geological setting, encompassing the Agbada Formation of Early and Middle Miocene age, is scrutinized through detailed geologic analysis. Petrophysical evaluation of four well logs (Kukih-1, Kukih-2, Kukih-3, and Kukih-4) facilitated the determination of key parameters such as shale volume, effective porosity, and water saturation. Seismic interpretation further enriched the structural characterization of the field. Results showcase three predominant reservoir sands (A, B, and C) with distinct lithofacies and thickness variations. Effective porosity ranges from Fair to Excellent, with permeability exhibiting high values for hydrocarbon reservoir potential. Water saturation trends, lithofacies distributions, and structural features were illuminated through iso-parametric maps and seismic analyses. Depositional environments were inferred through facies analysis, revealing the presence of funnel-, cylinder-, and bell-shaped successions that hint at intricate marine sedimentary processes. Challenges owing to limited core data were acknowledged, and the integration of methodologies emerged as a pivotal strategy for enhanced reservoir understanding. This study underscores the ‘Kukih’ Field's hydrocarbon potential, accentuating the significance of multidisciplinary approaches in deciphering complex reservoir systems. In light of the petrophysical analysis derived from the well logs and the identification of structural highs through the structural maps, this study recommends the drilling of unexplored zones exhibiting promising structural characteristics.

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Section: Results Of Petrophysical Analysismentioning

confidence: 99%

Focused reservoir characterization: analysis of selected sand units using well log and 3-D seismic data in 'Kukih' field, Onshore Niger Delta, Nigeria

Fagbemi,

Olayinka,

Oladunjoye

et al. 2024

Sci Rep

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“…The practical implications for future exploration are that the sandstone‐filled point bars and channels act as the primary stratigraphic traps (Abdelwahhab et al, 2021; Galloway & Hobday, 2012; Naseer & Asim, 2017; Radwan et al, 2022; Tayyab et al, 2017; Tayyab & Asim, 2017). The fluvial depositional systems are developed during the rapid rise and relative standstill position of the sea level, which allows the deposition of coarse‐grained sandstones inside the channels and point bars sandstone facies (Naseer et al, 2022).…”

Section: Resultsmentioning

confidence: 99%

Delineating the fluvial sedimentary reservoirs of Cretaceous sedimentation using seismic attributes and seismic‐petrophysical simulations, Southwest Pakistan

et al. 2022

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Channels filled with coarse‐grained sands are one of the hot issues in stratigraphic explorations. However, the sub‐surface uncertainty restricts the prediction of porous channel sandstones using the conventional seismic attributes, which is a concern for the demarcation of stratigraphic plays. The amplitude‐based frequency attributes and seismic‐petrophysical simulation tools were applied to characterize the fluvial channel system from the Indus Basin, Pakistan. The conventional amplitude of the Basal Sand Formation shows limited imaging ability to detect the dimensions of channel‐levee and point bars. The continuous wavelet transforms (CWT) tool distinguishes the whole channel‐levee reservoir system at tuning frequencies of 21, 25, 29, and 34 Hz. The amplitudes extracted along the pseudo‐porosity wells depict the low‐density and low‐velocity profiles within the gas‐bearing zones. The zone between 20% and 30% porosity displays low‐density and low‐velocity compartments within the point bars. Hence, it implicates the zone of deposition for hydrocarbon‐bearing fluvial facies. Based on the porosity constraint, the gas‐bearing fluvial reservoirs have high (>25%) porosity, which implicates the development of aggradational parasequences. The oil‐dominated sandstone facies experience relatively low‐porosity of <12% and negligibly high density and high velocity, which implicates the development of transgressive parasequences. The reservoir system shows an eastward shale‐out zone, where the high‐density and high‐velocity shales mask the channel‐levee systems. Consequently, these stratigraphic configurations are developing into a cost‐effective stratigraphic trap, and hence, this exploration scheme serves as an analogue for global fluvial depositional systems.

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“…High GR values reflect the presence of shale. Therefore, according to the used method by 45 , estimating the GR-Index, IGR is a mandatory to determine the shale volume (Vsh %) using the following Equ. (1):…”

Section: Petrophysical Analysismentioning

confidence: 99%

“…Three-dimensional static reservoir modeling is also a useful technique for locating reservoir boundaries. Numerous logs from wells that have penetrated the investigated reservoirs were used to construct a facies model, which was followed by the construction of the property model (porosity and saturation) for the Matruh Field reservoirs [41][42][43][44][45][46][47] . According to 47,48 , the process of creating a property model is composed of three consecutive phases: (1) geometric; (2) facies; and (3) petrophysical models.…”

Section: Reservoir Modelingmentioning

confidence: 99%

3D geological and petrophysical modeling of Alam El-Bueib Formation using well logs and seismic data in Matruh Field, northwestern Egypt

Ali,

Deaf,

Mostafa

2024

Sci Rep

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There are several productive petroleum fields in the North Western Desert (WD) of Egypt, which received extensive investigations regarding their petroleum potential. However, a few studies tackled the Matruh Oil Field, which contains the oil prolific Early Cretaceous Alam El-Bueib Formation (AEB Fm) reservoir. The reservoir intervals of the AEB Fm show substantial lithological variations across the basin. Therefore, it is necessary to analyze the vertical and lateral distributions in terms of their lithological and petrophysical properties. To achieve this objective, wireline logs of four wells and 20-2D seismic lines were used to construct a depth-structure contour map for the studied part of the field. This map was used to build the field’s structure model and to identify the fault patterns in the basin through several seismic lines. Analyses of well logs data and lithology were used to estimate the petrophysical properties of AEB sandstone units AEB-1, AEB-3A, AEB-3C, and AEB-6. Results show that the AEB-6 Unit is the most promising hydrocarbon-bearing unit. It has a net pay of 20–160 feet, a shale volume of 5–20%, an effective porosity of 14–20%, and a hydrocarbon saturation of 70–88%. The structure-depth maps indicate a number of normal faults with two principal NE-SW and NW–SE trends, which probably act as structural traps in the Matruh Oil Field. The constructed structure-depth maps and calculated petrophysical parameters were used to build a three-dimensional reservoir model. A blind well was used to validate the accuracy and reliability of the facies, porosity, and saturation models for the AEB Fm units, ensuring a good match between log-derived data and built models. The AEB Fm shows regional heterogeneous variations in its petrophysical characteristics. It exhibits unconventional reservoir characteristics in a N–S direction and conventional reservoir characteristics in an E–W direction. This observed heterogeneity shows the need to carry out further investigations to comprehensively assess the hydrocarbon potential of AEB Fm in different areas of the Matruh Basin.

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Petroleum system analysis-conjoined 3D-static reservoir modeling in a 3-way and 4-way dip closure setting: Insights into petroleum geology of fluvio-marine deposits at BED-2 Field (Western Desert, Egypt)

Cited by 18 publications

References 48 publications

Focused reservoir characterization: analysis of selected sand units using well log and 3-D seismic data in 'Kukih' field, Onshore Niger Delta, Nigeria

Focused reservoir characterization: analysis of selected sand units using well log and 3-D seismic data in 'Kukih' field, Onshore Niger Delta, Nigeria

Delineating the fluvial sedimentary reservoirs of Cretaceous sedimentation using seismic attributes and seismic‐petrophysical simulations, Southwest Pakistan

3D geological and petrophysical modeling of Alam El-Bueib Formation using well logs and seismic data in Matruh Field, northwestern Egypt

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