Multi-proxy approach to screen the hydrocarbon potential of the Jurassic succession in the Matruh Basin, North Western Desert, Egypt

Gentzis, Thomas; Carvajal‐Ortiz, Humberto; Deaf, Amr S.; Tahoun, Sameh S.

doi:10.1016/j.coal.2017.12.001

Cited by 26 publications

(8 citation statements)

References 42 publications

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“…Using the geophysical logs that were provided for the given wells in the research area, the effective porosity and oil saturation were estimated, and their values were scaled up and dispersed on the wells. The features that were used in constructing the effective porosity and oil saturation models were guided by the structural and facies models [55][56][57][58][59][60] .…”

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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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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“…El Nady et al, (2016) studied the dark gray shales and carbonates of the upper Khatatba Formation in the Salam-3X and fair mature gas-prone source rocks in the Shushan Basin. Gentzis et al, (2018) found a thick carbonate section (390 m) with only a few shale horizons of the Khatatba Formation in northeast Matruh Basin through the Abu Tunis-1X well as a reservoir rock containing migrated hydrocarbons and NSO compounds.…”

Section: Introductionmentioning

confidence: 97%

The Reservoir potential of Middle Jurassic sedimentary deposits in the Imhotep Field, Matruh Basin, North-Western Egypt

Ali

2024

Frontiers in Scientific Research and Technology

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This study examines the reservoir potential of the Middle Jurassic Khatatba Formation in the significant gas producer Imhotep Field, Matruh Basin, northwestern Egypt. The Upper Safa member sandstones of Khatatba Fm are characterized by low-quality, confined sandstone reservoirs. Yet, the Lower Safa member sandstones show better gas reservoir quality and exhibit remarkable decreases in shale volumes, including kaolinite. There is about a 30 m gross thickness, a 10 m net effective pay, about 6 % average effective porosity, 21% mD permeability, 12% shale volume, 24% water saturation and ~77% average hydrocarbon saturation. The deeply seated Lower Safa sandstone reservoirs in the Imhotep W-1X well are not suitable for gas production because they show a high decline in production and pressure tests. Therefore, they require high pressure to produce gas and condensates, which is probably not economically feasible. Moreover, geomechanical results indicate that the Lower Safa member is a brittle reservoir with better drilling capabilities than the more ductile Upper Safa member. Because of the vertical facies change and sandstone low-permeability in the Khatatba Fm, the quality of the reservoir is seen as the biggest risk that was tested in the field. In general, the Khatatba Fm in the Imhotep Field is a better reservoir because it is mostly made up of coarse, organically poor clastic deposits in the Imhotep W-1X well area. More studies based on multi-approach analysis are needed to fully examine the regional reservoir potential of the Khataba Fm in the Matruh Basin.

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“…Several studies have been conducted on the Middle Jurassic Khatatba Formation to assess the organic matter and source rock characteristics based on the organic geochemistry of total organic carbon and Rock-Eval pyrolysis [9,10], biomarker analysis [11], palynofacies analysis and palynomorph composition [9,12], and paleoenvironmental changes in relative sea level [8]. However, previous studies on the Khatatba Formation from the Shushan Basin based on detailed elemental geochemical data and their investigation in terms of paleoenvironmental redox and weathering conditions and terrigenous sediment influx, are still lacking.…”

Section: Introductionmentioning

confidence: 99%

Weathering Intensity, Paleoclimatic, and Progressive Expansion of Bottom-Water Anoxia in the Middle Jurassic Khatatba Formation, Southern Tethys: Geochemical Perspectives

Mansour,

Martizzi,

Ahmed

et al. 2024

Minerals

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The Jurassic Period was a significant phase of variable organic matter accumulation in paleo-shelf areas of the southern Tethys (Egypt). Reconstructing the paleoredox conditions, paleoclimate, and weathering intensity, along with the role of terrigenous sediment flux and mineralogical maturity, is important for understanding basin infill history and prevalent paleoenvironmental conditions. Here, inorganic geochemical data are presented from the Middle Jurassic Khatatba Formation and two samples from the underlying Ras Qattara and the overlying Masajid formations in the Jana-1x well, Shushan Basin, Western Desert. Twenty-four (24) whole-rock samples were analyzed for their major and trace element composition and carbonate content. The Khatatba Formation represents one of the major hydrocarbon source rocks in the North Western Desert, Egypt. Redox conditions were assessed based on enrichment factors of redox-sensitive elements Mo, V, U, and Co. Results revealed that the Khatatba Formation was deposited under predominant anoxic bottom and pore water conditions, in contrast to the oxic settings that were prevalent during the deposition of the Ras Qattara and Masajid formations. Continental weathering intensity and paleoclimate were reconstructed based on several proxies, such as the chemical index of alteration (CIA), K2O/Rb, Rb/Sr, Ln(Al2O3/Na2O), and Al/K ratios, indicating that the studied succession was deposited during alternating phases between weak and moderate weathering intensity under arid and warm-humid climates, respectively. Periods of enhanced continental weathering were associated with high values of clastic ratios such as Si/Al, Ti/Al, and Zr/Al, suggesting increased terrigenous sediment supply during intensified hydrological cycling. These ratios further provided inferences about the changes in sediment grain size, such as a change from shale to coarse silt- and sand-size fractions.

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Multi-proxy approach to screen the hydrocarbon potential of the Jurassic succession in the Matruh Basin, North Western Desert, Egypt

Cited by 26 publications

References 42 publications

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

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

The Reservoir potential of Middle Jurassic sedimentary deposits in the Imhotep Field, Matruh Basin, North-Western Egypt

Weathering Intensity, Paleoclimatic, and Progressive Expansion of Bottom-Water Anoxia in the Middle Jurassic Khatatba Formation, Southern Tethys: Geochemical Perspectives

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