Organic geochemistry and basin modeling of Late Cretaceous Harshiyat Formation in the onshore and offshore basins in Yemen: Implications for effective source rock potential and hydrocarbon generation

Hakimi, Mohammed Hail; Ahmed, Adeeb; Kahal, Ali Y.; Hersi, Osman Salad; Faifi, Hussain J. Al; Qaysi, Saleh

doi:10.1016/j.marpetgeo.2020.104701

Cited by 25 publications

(14 citation statements)

References 56 publications

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“…Other sample is dominated by C 15 to C 25 carbon number of the normal alkanes in the gas chromatograms (Fig. 8D), suggesting high abundance of aquatic organic matter derived from algal and microbial mats (Hakimi et al 2020;Al-Khafaji et al 2021;Hadad et al 2021;Gharib et al 2021).…”

Section: Normal Alkane and Acyclic Isoprenoid Distributions And Their Interpretation To Organic Matter Input And Environmental Conditionsmentioning

confidence: 99%

The origins of paraffinic oils collected from oilfields in the western Siberian Basin, Russia: implications from geochemical and physical characteristics

Hakimi

Saeed

Al‐Muntaser

et al. 2021

J Petrol Explor Prod Technol

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Four oil samples were collected from oilfields in the western Siberian Basin, and analyzed using conventional geochemical and physical methods. The results of this study were used to evaluate the oil samples, focusing on the characteristics of their source rocks, including the origin of organic matter input; redox depositional conditions and degree of thermal maturity of their probable source rock were studied. The obtained SARA results show that the examined oils are paraffinic oils owing to their high saturated hydrocarbon fraction values of greater than 70% volume. The observed API gravity values (23.55° to 32.57°) and low sulfur content of less than 0.25% wt indicate that the examined oils are sweet oils and were generated from source rock containing Type-II, with low sulfur content. The low sulfur content combined with the vanadium (V) and nickel (Ni) ratios indicates that the examined oils were scoured from a mixture of aquatic and terrestrial organic matter, depositing under generally suboxic environmental conditions. The n-alkane and isoprenoid distributions, with their ratios and parameters further suggest that the examined oil samples were generated from source rock containing a mixed organic matter input and deposited under suboxic to relatively oxic environmental conditions. Bulk compositions and distributions of n-alkane and isoprenoid indicate that the oil samples were generated from mature source rock.

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Section: Normal Alkane and Acyclic Isoprenoid Distributions And Their Interpretation To Organic Matter Input And Environmental Conditionsmentioning

confidence: 99%

The origins of paraffinic oils collected from oilfields in the western Siberian Basin, Russia: implications from geochemical and physical characteristics

Hakimi

Saeed

Al‐Muntaser

et al. 2021

J Petrol Explor Prod Technol

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“…Additionally, the reflectance of the huminite/vitrinite maceral (VR o ) in the studied samples was measured and the maximum, minimum, and mean values are shown in Table . Such values are the most reliable indicator to highlight the maturity and highlight the critical information such as the degree of maturation of organic material and the ability to generate petroleum . The studied samples have mean values of the huminite/vitrinite reflectance (VR o ) between 0.28% and 0.52% (Table ), indicating immature to the very early mature oil-window.…”

Section: Resultsmentioning

confidence: 99%

Geochemical and Petrological Characterization of the Early Eocene Carbonaceous Shales: Implications for Oil and Gas Exploration in the Barmer Basin, Northwest India

et al. 2022

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Carbonaceous shales of the Early Eocene Dharvi/Dunger Formation in the onshore Barmer Basin, northwest India were studied for the first time by integrating geochemical and organic petrological analyses. The carbonaceous shales of the Early Eocene Dharvi/Dunger Formation are characterized by a higher organic carbon content (TOC) of >10 wt % and consist mainly of a mixture of organic matter of types II and III kerogen, with exhibited hydrogen index values ranging between 202 and 292 mg HC/g TOC. The dominance of such kerogen is confirmed by the high amounts of huminite and fluorescent liptinite macerals. Consequently, the carbonaceous shales of the Early Eocene Dharvi/Dunger Formation are promising source rocks for both oil and gas generation potential, with oils of high wax contents, according to pyrolysis–gas chromatography results. The chemical and optical maturity results such as low values huminite/vitrinite reflectance, production index, and T max show that most of the examined carbonaceous shale rocks from the outcrop section of the Kapurdi mine have entered the low maturity stage of oil generation, exhibiting a range of immature to the very early-mature. Therefore, as highlighted in this study, the substantial abundance in hydrocarbon generation potential from these carbonaceous shales in the Dharvi/Dunger Formation may represent future conventional petroleum exploration in the southern part of the Barmer Basin, where the Dharvi/Dunger Formation has reached deeper burial depths.

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“…The HI and OI are helpful in understanding the quality of the OM. These parameters are complementary in investigating kerogen types, quality and hydrocarbon generation potential of source rocks (Hunt 1996;Behar et al 2001;El Diasty et al 2017;Hakimi et al 2020). The Rock-Eval pyrolysis was performed on the selected rock samples from Hangu Formation at HDIP, Islamabad, Pakistan.…”

Section: Rock Eval-pyrolysismentioning

confidence: 99%

“…Generally, the TOC values lie in the range of 1-100 (wt%) and S 2 values lie in the range of 0.1-1000 (mg HC/g rock) for all organic-rich lithologies in sedimentary basins (Hunt 1996; Hakimi and Abdullah 2014), however, in case of the Hangu Formation, the S 2 yield ranges from 0.06 mg HC/g rock (HAM-2C) to 40.71 mg HC/g rock (HKM-4A) showing poor to very good source rock potential (Table 1). Thus, TOC values of 0.09-61.43 (wt%) and S 2 values of 0.06-40.71 mg of HC/g rock are indicating poor to very good and excellent source rock quality, respectively (Hunt 1996;El Diasty et al 2017;Hakimi et al 2020;Khan et al 2021). Relationship between the genetic potential (GP) and TOC shows that the studied formation is considered as poor to excellent source potential (Fig.…”

Section: Source Rock Generative Potentialmentioning

confidence: 99%

“…It reveals the quality or nature of OM to assess the hydrocarbon generating potential of a source rock (Makky et al 2014;Hakimi et al 2020). Different types of kerogen can produce different types of hydrocarbons (Hunt 1996;Hakimi and Abdullah 2014;Hakimi et al 2020). It is therefore necessary to identify the quality of OM encountered within the formation.…”

Section: Kerogen Types and Organic Mattermentioning

confidence: 99%

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Hydrocarbon source rock assessment of the shale and coal bearing horizons of the Early Paleocene Hangu Formation in Kala-Chitta Range, Northwest Pakistan

Khan

Ullah

Siyar

et al. 2022

J Petrol Explor Prod Technol

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The present study aims to investigate the origin, type, thermal maturity and hydrocarbon generation potential of organic matter and paleo-depositional environment of the Early Paleocene (Danian) Hangu Formation outcropped in the Kala-Chitta Range of Northwest Pakistan, Eastern Tethys. Organic-rich shale and coal intervals were utilized for geochemical analyses including TOC (total organic carbon) and Rock–Eval pyrolysis coupled with carbon (δ13Corg) and nitrogen (δ15Norg) stable isotopes. The organic geochemical results showed that the kerogen Type II (oil/gas prone) and Type III (gas prone) dominate the investigated rock units. The TOC (wt%) and S2 yield indicate that the rock unit quantifies sufficient organic matter (OM) to act as potential source rock. However, the thermal maturity Tmax°C marks the over maturation of the OM, which may be possibly linked with the effect attained from nearby tectonically active Himalayan Foreland Fold-and-Thrust Belt system and associated metamorphosed sequences. The organic geochemical analyses deciphered indigenous nature of the OM and resultant hydrocarbons. The δ13Corg and δ15Norg stable isotopic signatures illustrated enrichment of the OM from both marine and terrestrial sources accumulated into the Hangu Formation. The Paleo-depositional model established using organic geochemical and stable isotopic data for the formation supports its deposition in a shallow marine proximal inner shelf environment with prevalence of sub-oxic to anoxic conditions, a scenario that could enhance the OM preservation. Overall, the formation holds promising coal and shale intervals in terms of organic richness, but due to relatively over thermal maturation, it cannot act as an effective source rock for liquid hydrocarbon generation and only minor amount of dry gas can be expected. In implication, the results of this study suggest least prospects of liquid hydrocarbon generation potential within Hangu Formation at studied sections.

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Organic geochemistry and basin modeling of Late Cretaceous Harshiyat Formation in the onshore and offshore basins in Yemen: Implications for effective source rock potential and hydrocarbon generation

Cited by 25 publications

References 56 publications

The origins of paraffinic oils collected from oilfields in the western Siberian Basin, Russia: implications from geochemical and physical characteristics

The origins of paraffinic oils collected from oilfields in the western Siberian Basin, Russia: implications from geochemical and physical characteristics

Geochemical and Petrological Characterization of the Early Eocene Carbonaceous Shales: Implications for Oil and Gas Exploration in the Barmer Basin, Northwest India

Hydrocarbon source rock assessment of the shale and coal bearing horizons of the Early Paleocene Hangu Formation in Kala-Chitta Range, Northwest Pakistan

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