Source rock evaluation of some upper and lower Cretaceous sequences, West Beni Suef Concession, Western Desert, Egypt

Makky, Abubakr F.; Sayed, Mohamed; El-Ata, Ahmed S. Abu; El-Gaied, Ibrahim M. Abd; Fattah, Mohamed Abdel; Abd-Allah, Zakaria M.

doi:10.1016/j.ejpe.2014.02.016

Cited by 35 publications

(26 citation statements)

References 11 publications

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“…The TOC values of the rock samples acquired from organic-rich shale intervals of the Patala Formation at Nammal Gorge Section are mostly >0.5% (table 1), in other words above the minimum limit required for a rock to act as a potential source rock (Hunt 1995;Makky et al 2014;Selley and Sonnenberg 2014). Generally, the dark black carbonaceous shales (PN-5) of Patala Formation have moderate TOC values, while the dark grey shales (PN-14) have poor-to-moderate TOC values (table 1).…”

Section: Toc Resultsmentioning

confidence: 94%

“…More specifically, the TOC values of the shale intervals range from 0.54% to 0.90% with an average value of 0.67% (table 1), which suggests that the Patala Formation has poor-to-moderate TOC values and represents a rock with poor-to-moderate source rock quality at Nammal Gorge Section. Based on TOC results and their comparison with the published source rock standards (Peters 1986;Makky et al 2014), it is assumed that the shale beds of the Patala Formation can act as a source rock for hydrocarbon generation with poor-to-moderate source rock quality. However, the TOC alone seldom evaluates a source rock sufficiently (Selley and Sonnenberg 2014;Khan 2016).…”

Section: Toc Resultsmentioning

confidence: 99%

“…These values reveal that the small amount of the free hydrocarbons is present in the formation to act as a source for free hydrocarbons. More specifically, the S 1 values suggest that the Patala shales are poor source rocks for free hydrocarbons at the current outcrop setting (Peters 1986;Makky et al 2014). Similarly, the S 2 yield (i.e., cracked hydrocarbons) ranges from 0.51 mg/g (PN-7) to 4.19 mg/g (PN-5) with an average value of 1.62 mg/g (table 1), which suggests that inadequate amount of hydrocarbons are present in the Patala carbonaceous shale beds, which can be released by thermal cracking of the kerogen.…”

Section: Rock-eval Pyrolysis Resultsmentioning

confidence: 99%

“…Generally, the TOC and pyrolysis S 2 yield values lie in the range of 1-100 (TOC wt%) and 0.1-1000 mg of HC/g for all organic lithologies in a sedimentary basin (Hakimi and Abdullah 2014; Selley and Sonnenberg 2014). However, in case of the Patala Formation, the S 2 values range from 0.51 to 4.19 mg of HC/mg at the studied section (table 1), which shows that the Patala Formation can generate the least amount of hydrocarbon (Maravelis et al 2013;Makky et al 2014). Thus, keeping in view the TOC and S 2 values of the rock samples and their comparison with the source rock standards, the source rock generative potential of the Patala Formation represents a rock with poor source rock potential (figure 4).…”

Section: Source Rock Generative Potentialmentioning

confidence: 86%

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Hydrocarbon source rock potential evaluation of the Late Paleocene Patala Formation, Salt Range, Pakistan: Organic geochemical and palynofacies approach

et al. 2018

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Organic geochemical and palynofacies analyses were carried out on shale intervals of the Late Paleocene Patala Formation at Nammal Gorge Section, western Salt Range, Pakistan. The total organic carbon content and Rock-Eval pyrolysis results indicated that the formation is dominated by type II and type III kerogens. Rock-Eval T max vs. hydrogen index (HI) and thermal alteration index indicated that the analysed shale intervals present in the formation are thermally mature. S 1 and S 2 yields showed poor source rock potential for the formation. Three palynofacies assemblages including palynofacies-1, palynofacies-2 and palynofacies-3 were identified, which are prone to dry gas, wet gas and oil generation, respectively. The palynofacies assessment revealed the presence of oil/gas and gas prone type II and type III kerogens in the formation and their deposition on proximal shelf with suboxic to anoxic conditions. The kerogen macerals are dominated by vitrinite and amorphinite with minor inertinite and liptinite. The kerogen macerals are of both marine and terrestrial origin, deposited on a shallow shelf. Overall, the dark black carbonaceous shales present within the formation act as a source rock for hydrocarbons with poor-to-moderate source rock quality, while the grey shales act as a poor source rock for hydrocarbon generation.

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Section: Toc Resultsmentioning

confidence: 94%

Section: Toc Resultsmentioning

confidence: 99%

Section: Rock-eval Pyrolysis Resultsmentioning

confidence: 99%

Section: Source Rock Generative Potentialmentioning

confidence: 86%

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Hydrocarbon source rock potential evaluation of the Late Paleocene Patala Formation, Salt Range, Pakistan: Organic geochemical and palynofacies approach

et al. 2018

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“…Moreover, the occurrence of organic matter decreases the bulk density of shale; thus, organic-rich shales have lower bulk density values relative to nonsource shales that have matrix densities range between 2.67 and 2.72 g/cm 3 (Makky et al 2014). However, neutron log values increase in response to the presence of hydrocarbon whereas the interval transmit time increases in mature source rock.…”

Section: Introductionmentioning

confidence: 99%

Total organic carbon content deduced from resistivity-porosity logs overlay: a case study of Abu Roash formation, Southwest Qarun field, Gindi Basin, Egypt

Sarhan

Basal

2020

NRIAG Journal of Astronomy and Geophysics

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The present work evaluates the hydrocarbon potentiality of Abu Roash Formation in SWQ-25 well, Southwest Qarun (SWQ) Field, Gindi Basin, Egypt. The estimation of total organic carbon content (TOC) has been deduced using the overlay between deep resistivity and porosity logs. The results show that Abu Roash A Member is fair to good source rock (TOC ranges from 0.50 to 1.28 wt. %). While, Abu Roash D Member contains fair to very good TOC values (from 0.77 to 2.92 wt. %). In contrast, Abu Roash B and E members display poor to good source rocks, with TOC varies between 0.36 to 1.74 wt. % and 0.32 to 1.42 wt. %, respectively. However, Abu Roash C Member (with TOC varies between 1.50 and 2.19 wt. %) and Abu Roash F Member (with TOC differs from 1.54 to 3.16 wt. %) indicate a good to very good source rock intervals. The neutron porosity-resistivity overlay matches the density-resistivity overlay in carbonate members (A, B, C, D and F members) but a lack of resemblance in clastic units (E and G members).

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Integrated analysis of source rock evaluation and basin modelling in the Abu Gharadig Basin, Western Desert, Egypt: Insights from pyrolysis data, burial history, and trap characteristics

Reda,

Abdel‐Fattah,

Fathy

et al. 2024

Geological Journal

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Source rock evaluation and basin modelling play crucial roles in understanding hydrocarbon potential. In this study, pyrolysis data from 92 shale ditch samples were employed to assess the source rocks in the Abu Gharadig Basin (Western Desert, Egypt). The organic richness ranged from 0.53% to 4.1% by weight, indicating varying hydrocarbon‐generating capabilities. Specifically, kerogen types II and III exhibited the potential to generate hydrocarbons, ranging from fair to good oil sources. The burial history analysis provided insights into the sedimentation and subsidence rates during different geological periods. The Late Jurassic‐Early Cretaceous period witnessed modest rates of sedimentation and subsidence. In contrast, the Oligocene and Late Miocene periods experienced medium burial rates, while the Late Cretaceous‐Early Tertiary period exhibited high burial rates. Specific formations were examined in detail, with the Apollonia Formation standing out as a significant hydrocarbon reservoir. It entered the early oil window at approximately 17.87 Ma and the wet gas window at about 17.41 Ma in the ASSIL‐1X well. However, it didn't reach the GPAA‐4 well. The Abu Roash ‘D’ member also showed promise, entering the early oil window at 38.20 and 47.38 Ma, and the wet gas window at 37.40 and 43.64 Ma. Similarly, the Abu Roash ‘F’ member exhibited favourable hydrocarbon generation, entering the early oil window at 39.90 and 54.86 Ma, and the wet gas window at 39.70 and 51.62 Ma in both the ASSIL‐1X and GPAA‐4 wells. Based on the analysis, the Apollonia, Abu Roash ‘D’ and ‘F’ members were identified as source rocks, while the Kharita, ‘C’, ‘E’ and ‘G’ members were recognized as reservoir rocks. The Abu Roash Shale acted as an effective seal rock. The geological structure of the region revealed the presence of NW‐SE normal faults, forming a three‐way dip closure trap. This research substantially enhances our comprehension of the hydrocarbon system within this basin. It achieves this by thoroughly investigating source rock evaluation, basin modelling and delivering invaluable insights into the mechanisms that govern hydrocarbon generation, expulsion and trap age.

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Source rock evaluation of some upper and lower Cretaceous sequences, West Beni Suef Concession, Western Desert, Egypt

Cited by 35 publications

References 11 publications

Hydrocarbon source rock potential evaluation of the Late Paleocene Patala Formation, Salt Range, Pakistan: Organic geochemical and palynofacies approach

Hydrocarbon source rock potential evaluation of the Late Paleocene Patala Formation, Salt Range, Pakistan: Organic geochemical and palynofacies approach

Total organic carbon content deduced from resistivity-porosity logs overlay: a case study of Abu Roash formation, Southwest Qarun field, Gindi Basin, Egypt

Integrated analysis of source rock evaluation and basin modelling in the Abu Gharadig Basin, Western Desert, Egypt: Insights from pyrolysis data, burial history, and trap characteristics

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