Integrated geophysical and geological study and petroleum appraisal of Cretaceous plays in the Western Gulf of Gabes, Tunisia

Dkhaili, Noomen; Bey, Saloua; Abed, Mahmoud El; Gasmi, Mohamed; Inoubli, Mohamed Hédi

doi:10.1016/j.tecto.2015.06.033

Cited by 7 publications

(3 citation statements)

References 14 publications

(32 reference statements)

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“…1) located in Southeastern Tunisia is separated from the Tunisian Atlas by the North-South Axis and by the Major Gafsa fault. Numerous geological and geophysical studies have been previously conducted in this region (Wildi, 1983;Touati, 1985;Bedir et al, 1992;Buness et al, 1992;Guiraud and Maurin, 1992;Bédir, 1995;Patriat et al, 2003;Gabtni et al, 2011;Khomsi et al, 2012;Dkhaili et al, 2015). The Gabes Gulf is a subsidence domain of the pelagic platform marking the sinking of the Saharian platform towards the central Mediterranean.…”

Section: Geological and Tectonic-magmatic Contextmentioning

confidence: 99%

“…-The pre-middle Cretaceous substratum in the Gulf of Gabes is characterized by a system of extensional oblique-slip faults with NNE-SSW trending formed during an important regional subsidence during the Triassic and the Jurassic. -Throughout the Upper Cretaceous, NNW-SSE trending extensional structures are developed (Philips and Beckett, 2000;Dkhaili et al, 2015). The Santonian-Campanian period is characterized by NW-SE Wrench-normal faulting, probably responsible for the NW trending (Dercourt et al, 1986).…”

Section: Geological and Tectonic-magmatic Contextmentioning

confidence: 99%

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Influence of hydrothermal activity on the mineralogical-petrophysical properties of an atypical doleritic reservoir rock: A case study of the Gabes Gulf (north Africa, Tunisia)

Kort

Hinrichs

Elmola

et al. 2021

Journal of African Earth Sciences

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The Gabes Gulf located in the South Mediterranean Sea (Southeastern part of Tunisia) is a prolific petroleumproducing area with several oil and gas fields and it's the subject of significant discoveries. The area is affected by intense tectonic events and several stages of hydrothermal activities. During drilling at the MX area in NE of the Gabes Gulf, a magmatic intrusion has been encountered within a reservoir rock (i.e., Douleb Formation). The objectives of the present study are (1) to investigate the impact of the hydrothermal activities on this magmatic intrusion and (2) to characterize the potential modifications in its mineralogy and petro-physical properties that can affect the migration/accumulation of hydrocarbons. To do so we combine optical microscopy, X-ray diffraction, scanning electron microscopy, energy dispersive X-ray spectrometry, micro-Raman spectroscopy, electron microprobe analyses, and petro-physical measurements.Our results show that the initial magmatic intrusion (dolerite) is composed mainly of plagioclase, clinopyroxene, and olivine. Based on petrographic observations, this intrusion subjected to several stages of hydrothermal fluid alterations that modified the primary texture and mineralogy. Albite, calcite, ankerite, dolomite, pyrite, quartz, anatase, kaolinite, and chlorite are the main secondary mineral products. During this alteration process, carbonates, pyrite, and quartz precipitated in vesicles, forming amygdules structure with enveloped zones indicating a fluctuation of fluid chemistry during their formation. In addition, petrographic observations indicate an interaction between feldspars exsolution and metasomatic processes in the studied area.The dissolution mechanisms, as well as the textural modifications in the dolerite induced by the hydrothermal activity, are underlined by the presence of spherulites, pores, and micropores. Such modifications significantly improved the porosity of the dolerite body. Conversely, the new mineralization that filled the fractures and micro-fractures, have reduced the inter-pore connections, and thus reduced its permeability. The present work demonstrates the important role of hydrothermal activity on the petro-physical properties of magmatic intrusions and how it could facilitate the migration/accumulation of hydrocarbons. Our results open the door for further investigations to check the potential presence of hydrocarbons within this doleritic intrusion.

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Section: Geological and Tectonic-magmatic Contextmentioning

confidence: 99%

Section: Geological and Tectonic-magmatic Contextmentioning

confidence: 99%

Influence of hydrothermal activity on the mineralogical-petrophysical properties of an atypical doleritic reservoir rock: A case study of the Gabes Gulf (north Africa, Tunisia)

Kort

Hinrichs

Elmola

et al. 2021

Journal of African Earth Sciences

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“…The hydrocarbon potential of the Gulf of Gabes has been the subject of several previous studies (e.g. M'rabet et al, 1991Bedir et al, 1992;Touati and Rodger, 1998;Dey and Inoubli, 2000;Dey et al, 2002;Dkhaili et al, 2015;Baklouti et al, 2017), and an active Cretaceous petroleum system has been proven. The main reservoir units in the study area are the Serdj Formation (Aptian), the Isis Member of the Fahdene Formation (Cenomanian), and the Abiod Formation (Campanian -Maastrichtian) (Fig.…”

Section: Introductionmentioning

confidence: 98%

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Kort

Elmola

Ouazaa

et al. 2021

Journal of Petroleum Geology

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An increase in source rock thermal maturity is in general linked to burial‐related heating according to the regional geothermal gradient, but maturities may also locally be influenced by high‐temperature hydrothermal fluids or igneous intrusions. In the present study of the Isis field located in the Gulf of Gabes (offshore Tunisia), we combine an analysis of organic matter maturity indicators and clay mineral signatures to constrain possible fluid/rock interactions and to define controls on the maturity of potential source rocks. Cuttings samples were collected from source rock intervals in the Cretaceous Bahloul (Cenomanian – Turonian) and underlying Fahdene (Albian – Cenomanian) Formations at the PM borehole, and detailed organic geochemical and clay mineralogical analyses of source rock samples and extracts were carried out. Samples from the Bahloul Formation (2381 m to 2400 m) consist of black to dark grey claystones and globigerinid limestones. Those from the Fahdene Formation (2400 m to 2700 m) comprise alternating claystones and chalky limestones containing globigerinids including Ticinella primula. Both source rock intervals have similar mineralogical compositions consisting of calcite, quartz, albite, anorthite, minor anatase, pyroxene and pyrite. The clay mineralogy of the formations is composed of abundant smectite (two generations), subordinate kaolinite and minor illite and/or mica. The Fahdene source rock contains organic matter consisting of mixed kerogen Types II/III; Type II OM is present in the Bahloul Formation.At the borehole location, the source rock intervals in the Fahdene and Bahloul Formations have been affected by hydrothermal fluids which are derived from an unconformably overlying basalt succession which is >300 m thick. Based on bulk mineral assemblages, the Bahloul Formation has been modified by the hydrothermal fluids more significantly than the underlying Fahdene Formation. Analyses of the clay minerals compositions indicate that interactions between the hydrothermal fluids and the host rocks were very rapid and were localized within fractures and micropores. The Bahloul Formation source rocks have reached an advanced stage of thermal maturity (overmature or end‐ oil window) compared to the thermally immature source rocks in the Fahdene Formation.The results show that the main control on source rock maturation at the studied well was maximum palaeotemperature and this may locally have been influenced by short‐term hydrothermal and magmatic heating as well as by the regional geotherm. Clay minerals were less affected by hydrothermal heating compared to organic matter indices; this may be because mineral components are slower to react to short‐term higher temperature conditions than organic matter.Thus magmatic activity and hydrothermal fluids may locally accelerate the thermal maturation of source rocks even at shallow depths. The study also shows that a combination of clay mineral characterization and organic matter indicators can be useful for the assessment of thermal maturity in potential source rocks.

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Petroleum System Evaluation of Upper Cretaceous and Eocene Plays, Offshore and Onshore Southern Pelagian Basin, Tunisia

Göttlich¹,

Rodríguez

Mnii

et al. 2023

Regional Geology Reviews

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Integrated geophysical and geological study and petroleum appraisal of Cretaceous plays in the Western Gulf of Gabes, Tunisia

Cited by 7 publications

References 14 publications

Influence of hydrothermal activity on the mineralogical-petrophysical properties of an atypical doleritic reservoir rock: A case study of the Gabes Gulf (north Africa, Tunisia)

Influence of hydrothermal activity on the mineralogical-petrophysical properties of an atypical doleritic reservoir rock: A case study of the Gabes Gulf (north Africa, Tunisia)

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Petroleum System Evaluation of Upper Cretaceous and Eocene Plays, Offshore and Onshore Southern Pelagian Basin, Tunisia

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