3D Seismic Structural Analysis and Basin Modeling of the Matruh Basin, Western Desert, Egypt

Abstract

In order to evaluate the hydrocarbon potential of the Matruh Basin, North Western Desert of Egypt, the tectonic history, basin analysis, and maturity modeling of the Albian-Cenomanian Formations of the Matruh Basin were investigated using well logs and 3D seismic data. Structural analysis of the tops of the Bahariya, Kharita, and Alamein Dolomite Formations reveals them to dip to the southeast. Burial history and subsidence curves show that the basin experienced a tectonic subsidence through the Middle-Late Jurassic and Early Cretaceous times. Thermal maturity models indicated that Cenomanian clastics of the Bahariya Formation are in the early mature stage in the east portions of the area, increasing to the mid maturity level in the southwestern parts. On the other hand, the Albian Kharita Formation exhibits a mid maturation level in the most parts of the area. The petroleum system of the Matruh Basin includes a generative (charge) subsystem with Middle Jurassic and Cenomanian sources (for oil/gas) and Turonian sources (for oil), with peak generation from Turonian to Eocene, and a migration-entrapment subsystem including expulsion and migration during Early Tertiary to Miocene into structures formed from Late Cretaceous to Eocene.

Organic geochemical, palynofacies, and petrographic analyses examining the hydrocarbon potential of the Kharita Formation (Albian) in the Matruh Basin, northwestern Egypt

“…Despite this difference in measured and calculated values, the general increase in maturity in an eastward direction consistent with maturation we record at Siqeifa 1X. The Kharita Formation in the Mideiwar 1X, Matruh 1-1, Matruh 2-1, and Matruh 3-1 wells in Matruh Basin show shale contents of 21.7 %, 22.1 %, 21.4 %, and 23.2 % similar to that recoded from the Abu Tunis 1X (23 %), but with a relatively higher maturity level (Metwalli et al, 2018; see Fig. 21).…”

“…19). It can therefore be anticipated that intervals of the Kharita Formation present deeper in the Matruh Basin will have higher thermal maturity and have evolved further into the oil-window (Metwalli et al, 2018). These data are in good agreement with the TAI (2 to 2+) obtained from TWL petrography of smooth pteridophyte spores.…”

“…21). The burial and thermal history modelling of Metwalli et al (2018) on the Kharita Formation indicates the presence of more mature (late mature, oil-window and main gas generation, 1-1.3 %Rv) potential gas-producing zones to the east and southeast of our studied area of the basin. This is specifically shown in the Darduma 1A, Matruh 1-1 and Ras Kanayes wells (Fig.…”

“…Against this, recent seismic structural analysis and basin modelling of the sedimentary sequence in the Matruh Basin revealed more mature potential gas-prone source rocks of the Kharita Formation to the southeast of the Abu Tunis 1X and Siqeifa 1X wells (Metwalli et al, 2018).…”

“…1). The Matruh Basin holds about 23 BBOE of known oil (Shahin, 1992) and about 3 TCF of gas reserves (Metwalli et al, 2018), and the main Mesozoic hydrocarbon source rocks are the Middle Jurassic upper Khatatba, the Lower Cretaceous (Berriasian-kerogen Types III and II. Thermal maturation indices indicated immature to early mature (early oilwindow) stage of maturity for these sample, with values for Tmax of 416-428 °C (avg.…”