Sequence Stratigraphic Model of Middle Permian Barakar Formation from a Marginal Gondwana Basin, India

Dey, Joyjit; Sen, Souvik

doi:10.1007/s12583-018-0791-7

Cited by 13 publications

(1 citation statement)

References 22 publications

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“…This is a typical characteristic of fan deposits (alluvial fans, basin floor fans etc.) (Sen et al 2016;Dey and Sen 2018;Sen and Dey 2020). Kaolinite, the dominant clay mineral phase in the studied samples, infers their sedimentary origin under continental conditions (Keller 1970;Tsuzuki and Kawabe 1983;De et al 2020;De and Sengupta 2021;Farouk et al 2022).…”

Section: Petrophysical Investigationmentioning

confidence: 61%

Reservoir characterization of the middle Miocene Kareem sandstones, Southern Gulf of Suez Basin, Egypt

Farouk

Sen²,

Pigott

et al. 2022

Geomech. Geophys. Geo-energ. Geo-resour.

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In this study, we have assessed the petrographical and petrophysical characteristics of the progradational, syn-rift Middle Miocene Rahmi sandstone gas reservoir (Lower Kareem Formation) from the East Matr and Amal hydrocarbon fields, southern Gulf of Suez by integrating sidewall cores and wireline logs. We interpreted a reservoir gas gradient of around 0.09 psi/ft from the downhole pressure measurements. Based on well log-based petrophysical analyses, we interpreted that the Rahmi reservoir in the East Matr field has a 0.10–0.18 v/v total porosity, 0.08–0.14 v/v effective porosity, 0.08–0.17 v/v shale volume along with water saturation ranging between 0.09 and 0.32 v/v. The correlated reservoir in the Amal field is observed to have higher porosities (0.17–0.22 v/v total porosity and 0.15–0.19 v/v effective porosity), although it exhibits higher water saturation (0.38–0.54 v/v). The reservoir consists of very fine to coarse grained, poorly to moderately sorted, subangular to subrounded, poorly cemented and moderately compacted sublithic, subarkosic and arkosic arenites with moderate to good intergranular porosity. Abundant lithic fragments and poor textural maturity of the Rahimi sandstones imply a high energy shoreface depositional environment in close proximity to the hinterland. Porosity reduction is attributed to dolomite cementation, kaolinite, formation of pseudomatrix by mechanical compaction of argillaceous lithics, and quartz overgrowth. Long and concavo-convex intergranular contacts indicate that silica needed for quartz cementation was derived by moderate degree of chemical compaction of the quartz grains. Partial to near-complete dissolution of the labile grains (feldspar and lithics) and dolomite attributed to the reservoir quality improvement. Scattered dolomite cements prevented more severe mechanical and chemical compaction.

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Section: Petrophysical Investigationmentioning

confidence: 61%

Reservoir characterization of the middle Miocene Kareem sandstones, Southern Gulf of Suez Basin, Egypt

Farouk

Sen²,

Pigott

et al. 2022

Geomech. Geophys. Geo-energ. Geo-resour.

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Formation evaluation and reservoir potential of the Middle Miocene syn-rift Hammam Faraun Member from the offshore Esh El Mellaha area, southern Gulf of Suez, Egypt

Farouk,

Sen,

El-Behery

et al. 2024

Mar Geophys Res

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This study presents an integrated formation evaluation of the Middle Miocene syn-rift sandstones of the Hammam Faraun Member from southern Gulf of Suez. Core data, XRD, wireline logs and gas chromatography data have been utilized to assess the reservoir characteristics. Three lithofacies are identi ed from the cored intervals: i) ne to medium-grained massive sandstone (F-1), ii) low-angle cross-bedded ne-grained sandstone (F-2) and iii) coarse to very coarse-grained massive sandstone (F-3). The dominantly massive nature of the sand units with sharp erosive base and bottom rip-up clasts strongly indicates a high energy channel or fan deposit. XRD analysis exhibits quartz and feldspar to be the dominant constituents of these calcareous arkose. Montmorillonite and kaolinite are the major clay phases along with minor illite. Routine core analysis of a total of 168 core plugs indicates meso-to megaporous sandstones with porosity up to 28% and Kh up to 1171 mD. Permeability anisotropy analysis exhibit the dominance of primary depositional fabric and isotropic pores. Wireline log analysis yielded shale volume < 0.2 v/v, porosity ~ 0.18-0.24 v/v, and water saturation ~ 0.33-0.49 v/v. Various gas ratios (wetness, balance, character, and oil indicator ratio) estimated from the chromatograph data indicates the presence of liquid hydrocarbon within the studied reservoirs. The study concludes excellent reservoir properties in the Hammam Faraun clastic intervals of the Esh Elmallha area. HighlightsHammam Faraun reservoirs consist of meso-megaporous calcareous arkose.Massive sands with sharp erosive base and bottom rip-up clasts indicates a high energy channel or fan deposit.Wireline logs indicate poor shale volume and considerable hydrocarbon saturation.Gas chromatography data con rms the presence of liquid hydrocarbon.

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Petrophysical Characterization of the Turonian and Cenomanian Intervals in the Abu Gharadig Field, Western Desert, Egypt: Inferences on Reservoir Quality and Resource Development

Farouk

Sen²,

Abuseda

et al. 2022

Nat Resour Res

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Sequence Stratigraphic Model of Middle Permian Barakar Formation from a Marginal Gondwana Basin, India

Cited by 13 publications

References 22 publications

Reservoir characterization of the middle Miocene Kareem sandstones, Southern Gulf of Suez Basin, Egypt

Reservoir characterization of the middle Miocene Kareem sandstones, Southern Gulf of Suez Basin, Egypt

Formation evaluation and reservoir potential of the Middle Miocene syn-rift Hammam Faraun Member from the offshore Esh El Mellaha area, southern Gulf of Suez, Egypt

Petrophysical Characterization of the Turonian and Cenomanian Intervals in the Abu Gharadig Field, Western Desert, Egypt: Inferences on Reservoir Quality and Resource Development

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