Geochemical characteristics and hydrocarbon generation modeling of the Jurassic source rocks in the Shoushan Basin, north Western Desert, Egypt

Shalaby, Mohamed Ragab; Hakimi, Mohammed Hail; Abdullah, Wan Hasiah

doi:10.1016/j.marpetgeo.2011.07.003

Cited by 133 publications

(53 citation statements)

References 16 publications

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“…The ratio between S 1 and PY makes up the PI, where it is the proportion of the amount of free hydrocarbons already generated to the total amount of hydrocarbon that the organic matter is capable of generating. This parameter can be used to measure source rock thermal maturity (Peters 1986;Shalaby et al 2011Shalaby et al , 2012aEl Nady et al 2015;Qadri et al 2016;Jumat et al 2018;Osli et al 2018). In this study, PI values range from 0.0642 to 0.117.…”

Section: Toc and Rock-eval Pyrolysis Resultsmentioning

confidence: 99%

“…Various techniques of assessing a source rock as performed by Shalaby et al (2011), Qadri et al (2016 and Jumat et al (2017Jumat et al ( , 2018 have been referred to in this research. Following geochemical analysis, this study also constructs a onedimensional basin model using stratigraphic, temperature, and vitrinite reflectance data to investigate the exact timing and depth of hydrocarbon generation windows for the Taratu Formation.…”

Section: Introductionmentioning

confidence: 99%

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Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Osli

Shalaby

Islam

2018

J Petrol Explor Prod Technol

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Hydrocarbon generation modeling and source rock characterization have been carried out on rock samples of the Taratu Formation in the Great South Basin, New Zealand. The Paleocene and Late Cretaceous Taratu Formation samples from Tara-1 well are utilized for geochemical studies. Rock-Eval pyrolysis results show that Taratu formation accommodates organic matter of excellent quantity and quality, with proliferous kerogen type II-III (oil and gas prone) and minor kerogen type III (gas prone). Hydrogen index (HI) of this formation ranges from 165.0 to 327.5 mg HC/g TOC and only Late Cretaceous source rock samples are thermally mature, with maximum pyrolysis temperature (T max ) up to 459 °C and vitrinite reflectance (% R o ) from 0.40 to 1.15% R o . One-dimensional basin modeling shows a best fit in a calibration of measured and modeled temperatures and vitrinite reflectance. The top of oil window was encountered 51 Ma ago at 3100 m and gas generation took place at 4132 m in 8 Ma ago.

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Section: Toc and Rock-eval Pyrolysis Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Osli

Shalaby

Islam

2018

J Petrol Explor Prod Technol

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“…Within the Middle-Late Eocene (38 Ma) and at a depth greater than 2500 m, these source rocks entered the main oil window (0.7-1 %R o ), and during the Late Miocene time (8 Ma), they reached the late oil window (1-1.3 %R o ). The transformation ratio (TR), which is defined as the ratio of generated hydrocarbons to the total generation potential of a source rock (Shalaby et al 2011), reached 96 % for the Kazhdumi Formation and Ahmadi Member (Figs. 13, 14).…”

Section: Burial and Thermal History Modelingmentioning

confidence: 99%

Burial and thermal maturity modeling of the Middle Cretaceous–Early Miocene petroleum system, Iranian sector of the Persian Gulf

Mashhadi

Rabbani

Kamali³

et al. 2015

Pet. Sci.

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The Cretaceous Kazhdumi and Gurpi formations, Ahmadi Member of the Sarvak Formation, and Paleogene Pabdeh Formation are important source rock candidates of the Middle Cretaceous-Early Miocene petroleum system in the Persian Gulf. This study characterizes generation potential, type of organic matter, and thermal maturity of 262 cutting samples (marls and argillaceous limestones) from these rock units taken from 16 fields in the Iranian sector of the Persian Gulf. In addition, the burial and thermal histories of these source rocks were analyzed by one-dimensional basin modeling. Based on the total organic carbon and genetic potential values, fair hydrocarbon generation potential is suggested for the studied samples. Based on T max and vitrinite reflectance values, the studied samples are thermally immature to mature for hydrocarbon generation. The generated models indicate that studied source rocks are immature in central wells. The Gurpi and Pabdeh formations are immature and the Ahmadi Member and Kazhdumi Formation are early mature in the western wells. The Pabdeh Formation is within the main oil window and other source rocks are at the late oil window in the eastern wells. The hydrocarbon expulsion from the source rocks began after deposition of related caprocks which ensures entrapment and preservation of migrated hydrocarbon.

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“…It lies between Latitudes 30° 44' 40" and 30° 46' N and Longitudes 26° 57' 20" and 26° 59' 20" E as shown in Fig.1. The subsurface geologic setting of the northern part of Western Desert has been investigated by many researchers as shown in; [1][2][3][4][5][6][7][8][9][10][11][12][13][14][15][16][17][18].…”

Section: Introductionmentioning

confidence: 99%

Reservoir Evaluation of Bahariya Formation in Tut Oil Field, North Western Desert, Egypt

Aboelhassan¹,

Tarabees²,

Mohamed³

2017

geomate

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Tut Oil Field is located in the northwestern part of the Western Desert, Egypt. This work aims to study the subsurface and reservoir characteristics to evaluate the hydrocarbon potential of Bahariya Formation based on subsurface data available from open-hole well log records of nine wells distributed in the area of study. The subsurface geologic setting, in terms of determining the stratigraphic and structural settings, is gained through the construction of different aligned stratigraphic and structural cross sections, isopach and lithofacies maps. The petrophysical evaluation, in terms of determining the petrophysical characteristics; net pay thickness, effective porosity (∅ eff ), shale content (V sh ), water saturation (S w ) and hydrocarbon saturation ( S h ), is acquired through quantitative computer processed interpretation. The petrophysical characteristics are illustrated laterally in the form of iso-parametric maps and vertically in the form of litho-saturation cross-plots. According to subsurface study and petrophysical evaluation the most productive area is located in central and southern parts of Tut field.

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Geochemical characteristics and hydrocarbon generation modeling of the Jurassic source rocks in the Shoushan Basin, north Western Desert, Egypt

Cited by 133 publications

References 16 publications

Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Hydrocarbon generation modeling and source rock characterization of the Cretaceous–Paleocene Taratu Formation, Great South Basin, New Zealand

Burial and thermal maturity modeling of the Middle Cretaceous–Early Miocene petroleum system, Iranian sector of the Persian Gulf

Reservoir Evaluation of Bahariya Formation in Tut Oil Field, North Western Desert, Egypt

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