Integrated sedimentological and petrophysical rock-typing of the Messinian Abu Madi formation in South Batra gas field, onshore Nile Delta, Egypt

Adl, Hanaa El; Leila, Mahmoud; Ahmed, Mohammed A.; Anan, Tarek; El‐Shahat, Adam

doi:10.1016/j.marpetgeo.2020.104835

Cited by 28 publications

(6 citation statements)

References 41 publications

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“…The very high sand/mud ratio, abundant cross‐stratifications, general absence of either mud interbeds or parallel laminations are indicatives of high‐energy environmental conditions (e.g., Miall, 1978; Tucker, 2001). A sharp base suggests in‐channel deposition; multiple scour surfaces and stacked sand beds in coarsening‐upward patterns suggest amalgamation of the fluvial channel sand bars (e.g., Bridge, 2006; El Adl et al, 2021; Leila, Ali, Abu El‐Magd, AlWaan, & Elgendy, 2021; Leila & Moscariello, 2019; Miall, 1996). Unlike the ideal succession of Abu Madi Formation in the main canyon system of the central Nile Delta which constitutes a transgressive sequence of fluvial, estuarine, and marine‐influenced facies (Dalla et al, 1997; Dolson et al, 2001; Leila & Moscariello, 2018), the sedimentary succession in the study region is mainly fluvial.…”

Section: Results and Interpretationsmentioning

confidence: 99%

“…In the Abu Madi Formation, the fluvial channel‐fill sandstones are interpreted as the result of a high sedimentation rate (~0.3 m/k.y.) (Abdel Aal et al, 2001; El Adl et al, 2021; Leila & Moscariello, 2019). However, overpressure with SSDS is observed within the heterolithic intervals above and below the fluvial channel sandstones.…”

Section: Discussionmentioning

confidence: 99%

“…Subsequently, the entire Mediterranean shelf and slope systems were subaerially exposed, deeply eroded and large‐scale fluvial canyons were incised along the entire Mediterranean margins (e.g., Barber, 1981; Bertoni & Cartwright, 2007; Clauzon, 1982; Leila & Moscariello, 2019; Lofi et al, 2005; Madof et al, 2019; Ryan & Cita, 1978). In the Nile Delta, this event is marked by the incision of the Eonile canyon which was infilled during the Late Messinian transgression (~5.45 Ma, Popescu et al, 2021) by the backstepping Abu Madi fluvial‐estuarine facies (Dalla et al, 1997; Dolson et al, 2005; El Adl, Leila, Ahmed, Anan, & El‐Shahat, 2021; Keheila, 1990; Leila & Moscariello, 2019; Leila, Sen, Abioui, & Moscariello, 2021; Rubino et al, 2015). On the basis of the quantitative modelling analysis of Gargani et al (2010), the Nile Delta has been significantly modified due to the isostatic rebound inherited from the Mediterranean sea‐level fall, sediment loading, and river incision.…”

Section: Geologic Settingmentioning

confidence: 99%

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Soft‐sediment deformation structures in the Late Messinian Abu Madi Formation, onshore Nile Delta, Egypt: Triggers and tectonostratigraphic implications

et al. 2022

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The Upper Messinian Abu Madi Formation of the Nile Delta constitutes sediments deposited during the final stage of the Messinian salinity crisis (MSC). Several levels of soft‐sediment deformation structures (SSDS) were observed in the transgressive heterolithic fluvial facies deposited adjacent to the deep‐seated faults. The most common deformation features include diapiric structures, intraformational lithoclastic breccia, small‐scale normal faults, slump folds, and liquefied beds. Such association of SSDS typically resembles those described elsewhere as generated by a complex interplay of gravity‐driven and seismically induced liquefaction processes. The pore pressure measurements revealed high pore fluid density ~ 9.1 ppg equivalent density values which reflect a mild pressure disequilibrium in Abu Madi sediments. Pressure disequilibration is observed all over the studied section of the Abu Madi Formation and is not only restricted to the fluvial channel sandstones deposited during rapid loading. Therefore, allogenic seismic activity has been proposed as the main trigger for pressure disequilibrium and the development of SSDS in the Abu Madi Formation. The heterolithic nature of the Abu Madi sediments as well as the scarcity of bioturbation provides the favourable conditions for the preservation of the seismically induced deformation. The lateral variation in thickness suggests deposition of the Abu Madi Formation during periods of active subsidence which promotes the generation of the SSDS. Late MSC tectonism likely controlled the evolution and sedimentary facies variability of the Abu Madi canyon‐infill system, and therefore the distribution of Abu Madi facies varies significantly over very short distances. Abu Madi SSDS follows the spatial distribution observed in other “lago‐mare” deposits (e.g., Foes Formation and SE Spain), characterized by spatial variability and vertical rhythmic alternation between deformed and non‐deformed layers. Accordingly, regional tectonic instability in the circum‐Mediterranean margins during the late stage of the MSC is proposed.

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Section: Results and Interpretationsmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

Section: Geologic Settingmentioning

confidence: 99%

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Soft‐sediment deformation structures in the Late Messinian Abu Madi Formation, onshore Nile Delta, Egypt: Triggers and tectonostratigraphic implications

et al. 2022

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“…Permeability and porosity of reservoir rocks have a vital role in the evaluation of the fluid flow in these porous media. The discrimination of reservoir rock types is a function of the hydraulic flow units (HFUs), according to their flow zone indicator (FZI), normalized porosity index (NPI) and reservoir quality index (RQI) (Ahmad & Gingras, 2022; Al‐Jawad & Saleh, 2020; Amaefule et al, 1993; Dou et al, 2018; El Adl et al, 2021; Farshi et al, 2019; Radwan et al, 2021b; Shalaby et al, 2020; Yin et al, 2020). The components of a reservoir with harmonic lateral continuity in the geological characteristics that control fluid flow in reservoirs are known as HFUs (Abu‐Hashish et al, 2022; Amaefule et al, 1993; Rezaee et al, 2007).…”

Section: Introductionmentioning

confidence: 99%

Rock typing of the Miocene Hammam Faraun alluvial fan delta sandstone reservoir using well logs, nuclear magnetic resonance, artificial neural networks, and core analysis, Gulf of Suez, Egypt

Ahmed¹,

el‐Din

Radwan

et al. 2023

Geological Journal

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The application of integrated methods to evaluate the quality of reservoir rocks is becoming crucial in petroleum geoscience. The Miocene reservoirs in the El Morgan Oil Field consist mainly of sandstones with interbedded dolomitic silts and shales. Based on the pore scale, the sandstone reservoir of Hammam Faraun Member is a heterogeneous reservoir, and this is the main challenge in this oil field that affects both production and exploration activities. In this article, we have integrated the well logs, nuclear magnetic resonance (NMR), artificial neural networks (ANN) and core analysis to better understand these alluvial fan sandstone reservoirs. The petrographic description indicates arkosic sandstone with varied pore types, texture, cement, and sorting. The studied flow and storage capacity for well#1, indicate four rock types with 24 flow units and eleven barriers, which indicates a high degree of heterogeneity. The artificial neural networks (ANN), that is, the K.mod module, were used to enhance the prediction quality and forecast of FZI in the uncored intervals, where the NMR‐calculated permeability acts as a calibration point for the FZI model validation. This study reveals that the FZI is controlled by permeability, which is mostly influenced by pore throat size. The NMR log showed varied free fluid volume with varied capillaries, clay‐bound volumes and minor streaks of tar along the studied unit. The reservoir pores in the study area are residual pores that have undergone mechanical compaction and cementation that reduce porosities, while dissolution enhances the sandstone porosities. Porosity and permeability were significantly reduced in the presence of clays and carbonate minerals, which indicates poor reservoir quality zones in some parts. The primary factor influencing permeability is pore throat size, which is heavily influenced by the depositional environment and subsequent diagenetic processes. The findings of this study could lead to the development of accurate reservoir static models for future exploration and development plans in the studied area and elsewhere in similar depositional settings.

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“…Reservoir classification techniques that include combined core analysis and well log data can also be used to characterize reservoir flow unit parameters [7][8][9]. Advanced rock typing techniques, which are based on flow zone indicators (FZI), can be used to calculate flow unit identification and characterization [10][11][12]. Reservoir parameters such as porosity and permeability have been used to define reservoir hydraulic flow units during the construction of reservoir models [13,14].…”

Section: Introductionmentioning

confidence: 99%

An Integrated Approach for Saturation Modeling Using Hydraulic Flow Units: Examples from the Upper Messinian Reservoir

El-Gendy,

Mabrouk,

Waziry

et al. 2023

Water

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The Upper Messinian reservoirs located in the Salma Field of the Nile Delta area contain variable facies. The key reservoir interval of the Abu Madi Formation was deposited in fluvial to deltaic environments. These fine-grained facies form significant reservoir heterogeneity within the reservoir intervals. The main challenges in this study are reservoir characterizing and predicting the change in reservoir water saturation (SW) with time, while reservoir production life based on the change in reservoir capillary pressure (Pc). This work applies petrophysical analysis to enable the definition and calculation of the hydrocarbon reserves within the key reservoir units. Mapping of SW away from the wellbores within geo-models represents a significant challenge. The rock types and flow unit analysis indicate that the reservoir is dominated by four hydraulic flow units. HFU#1 represents the highest flow zone indicator (FZI) value. Core analysis has been completed to better understand the relationship between SW and the reservoir capillary pressure above the fluid contact and free water level (FWL), which is used to perform saturation height function (SHF) analysis. The calculated SW values that are obtained from logs are affected by formation water resistivity (Rw) and log true resistivity (RT), which are influenced by the volume of clay content and mud salinity. This study introduces an integrated approach, including evaluation of core measurements, well log analysis covering cored and non-cored intervals, neural analysis techniques (K-mode algorithm), and permeability prediction in non-cored intervals. The empirical formula was predicted for direct calculation of dynamic SW profiles and predicted within the reservoir above the FWL based on the change in reservoir pressure.

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Integrated sedimentological and petrophysical rock-typing of the Messinian Abu Madi formation in South Batra gas field, onshore Nile Delta, Egypt

Cited by 28 publications

References 41 publications

Soft‐sediment deformation structures in the Late Messinian Abu Madi Formation, onshore Nile Delta, Egypt: Triggers and tectonostratigraphic implications

Soft‐sediment deformation structures in the Late Messinian Abu Madi Formation, onshore Nile Delta, Egypt: Triggers and tectonostratigraphic implications

Rock typing of the Miocene Hammam Faraun alluvial fan delta sandstone reservoir using well logs, nuclear magnetic resonance, artificial neural networks, and core analysis, Gulf of Suez, Egypt

An Integrated Approach for Saturation Modeling Using Hydraulic Flow Units: Examples from the Upper Messinian Reservoir

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