Early-Oil Generation Potential of Type II-S Kerogen in the Upper Cretaceous (Cenomanian–Turonian) Organic-Rich Carbonate Succession from Ajloun Region in Northern Jordan

Hakimi, Mohammed Hail; Alqudah, Mohammad; Mustapha, Khairul Azlan; Varfolomeev, Mikhail A.; Lashin, Aref; Hatem, Baleid Ali; Rahim, Abdul; Sen, Souvik; Radwan, Ahmed E.; Yelwa, Nura Abdulmumini

doi:10.1007/s13369-022-07242-1

Cited by 5 publications

(14 citation statements)

References 43 publications

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“…The bulk kinetic results obtained from the three oil-asphaltenes are presented in Figure . According to the bulk kinetic models (Figure a), activation energy ( E a ) distributions are broad, ranging between 38 and 62 kcal/mol while the frequency factor ( A ) is 1.47 × 10 13 s and 1.52 × 10 13 /1 s. However, the ‘ E a ’ and ‘ A ’ values refer to the oil-sourcing kerogen types. − Type I oil-sourcing kerogens exhibit a narrow range of E a between 47 and 56 kcal/mol , while the oil-rich type II and II–S kerogens display a wide range of activation energies varying from 44 to 66 kcal/mol. ,,, In this regard, the relatively broad activation energy distributions observed in the studied oil-asphaltenes are typical for oils generated by type II kerogen that is deposited in a marine environmental setting.…”

Section: Resultsmentioning

confidence: 99%

“…29−31 Type I oilsourcing kerogens exhibit a narrow range of E a between 47 and 56 kcal/mol 32,33 while the oil-rich type II and II−S kerogens display a wide range of activation energies varying from 44 to 66 kcal/mol. 29,30,34,35 In this regard, the relatively broad activation energy distributions observed in the studied oil-asphaltenes are typical for oils generated by type II kerogen that is deposited in a marine environmental setting. In order to compare the effect of the calculated kinetics on the asphaltene degradation behavior, the geological heating was estimated using a consistent rate at a 3.3 °C/My rate.…”

Section: Kinetic Studies Of the Oil-asphaltenementioning

confidence: 85%

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Molecular Compositions of Oil-Bearing Sandstones and Oil-Asphaltenes from the Kharir Oilfields in the Western Central Masila Basin, Yemen

Al-Matary,

Hakimi,

Mustapha

et al. 2024

ACS Omega

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Oil-bearing sandstone samples were collected from the Lower Cretaceous sequence in the Kharir-2 exploration well, Kharir oilfields (Eastern Yemen). The current study integrates biomarker of the aliphatic hydrocarbon fraction of the extracted oil with a new finding from the molecular structure of the oilasphaltene, in order to learn more about their properties, including organic matter (OM) input, depositional environment, and thermal maturity. The overall oil composition results show that the extracted oils have a high saturated hydrocarbon of up to 50% and significant levels of aromatic hydrocarbon and polar components, indicating generally paraffinic to naphthenic oil. This claim agrees with the molecular structure of the kerogen derived from the pyrolysis−gas chromatography result of the oilasphaltene, which suggests that the extracted oils from the Lower Cretaceous sandstone reservoirs are mainly paraffinic-naphthenicaromatic oils, exhibiting low wax content and originated from marine type II kerogen. The type II kerogen of the marine-source rock is also demonstrated by the bulk kinetic model of the oil-asphaltene for the extracted oils, with a broad range of E a between 38 and 62 kcal/mol and a frequency factor (A) of 1.52−1.47 × 10 13 /1 s. The biomarker characteristics of the aliphatic fraction show that the extracted oils from the Lower Cretaceous sandstone reservoirs were generated from clay-rich source rock, containing OM origin of mainly marine and terrestrial OM input and deposited under suboxic environmental conditions. Furthermore, the maturity-sensitive aliphatic biomarker parameters indicate that the extracted oils were generated from mature source rock in the range of the peakmature stage of the oil generation window. Oil−source rock correlation of various established biomarker proxies for OM origin, depositional environment, and lithology suggests that these extracted oils were possibly generated from a single source rock, and the Madbi clay-rich formation contributed to most of the extracted oil from the Lower Cretaceous sandstone reservoir rocks.

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Section: Resultsmentioning

confidence: 99%

Section: Kinetic Studies Of the Oil-asphaltenementioning

confidence: 85%

Molecular Compositions of Oil-Bearing Sandstones and Oil-Asphaltenes from the Kharir Oilfields in the Western Central Masila Basin, Yemen

Al-Matary,

Hakimi,

Mustapha

et al. 2024

ACS Omega

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“…The studied MCM Formation samples were part of a larger system of similar facies and age that has been found in many localities, not only in Jordan but also throughout the region. ,,− A direct comparison was made with previous work on samples from nearby Upper Cretaceous oil shales of the MCM Formation that had similar TOC enrichment (average ∼10 wt %), HI values (600–700 mg HC/g TOC), and petrographic observations (predominant AOM). This study supports what they found in the similar-age oil shales, but also points to the kerogen being of Type IIS. ,, Based on bulk kinetic models, the main phase of the HC formation from the thermally immature Upper Cretaceous oil shales of the MCM Formation was determined and occurred between 122 and 148 °C, with a suggested equivalent vitrinite reflectance of between ∼0.56 and 0.65 (Hakimi et al (2018)).…”

Section: Discussionmentioning

confidence: 95%

Section: Discussionmentioning

confidence: 99%

Impact of Thermal Maturation of the Upper Cretaceous Bituminous Limestone of Attarat Um Ghudran Central Jordan on Calcareous Nannofossil Preservation

Alqudah,

Al Alaween,

Fermor

et al. 2023

ACS Omega

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Oil shale deposits of the Late Cretaceous from three boreholes in central Jordan were examined to assess the impact of thermal maturation on the content of nannofossils. Thermal activity has been shown to have a strong effect on organic matter content and composition but its effect on calcareous nannofossil assemblages remains inconclusive. This study aims to determine the impact of thermal maturation on nannofossil assemblages and to compare this to an estimated maturity level based on bulk geochemical analysis. Micropaleontological and geochemical analyses were conducted on 31 samples from three oil shale wells drilled in Attarat Um Ghudran central Jordan. Several types of nannofossil preservation have been recorded, including dissolution, overgrowth, and breakage. In the Jordan oil shale sections, nannofossils exhibit a variety of preservation types, with intense dissolution in the middle part of the study sections. The vast majority of the samples had high TOC enrichment, with 29 samples exceeding values of >10%. Kerogen recovery and quality from the oil shale are very good, with a predominance of fluorescent amorphous organic matter (AOM) and minor algal components. The low fluorescence preservation index (FPI), which is 1 in most of the samples, indicates that alteration occurred due to intense thermal activities in the study interval. The palynomorph and AOM fluorescence, ranging from a spore coloration index (SCI) of 3 to 5, suggest that the studied samples were approaching the oil window. A correlation between the nannofossil preservation and geochemical parameters shows a predominance of poorly preserved nannofossils along with high total organic carbon contents and an elevated hydrogen index (HI). We show that low FPI values and a higher level of maturity are associated with poor nannofossil preservation, suggesting that nannofossils, in conjunction with petrographic analysis of kerogen, could be used as a rapid screening technique for estimating levels of oil-shale maturity. The nature of the tectonism in the study area, including faulting and a metamorphosed zone, enhanced the maturity, which might explain why the nannofossils were so significantly affected.

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“…19 The Shu'ayb organic-rich carbonate sediments are enriched in sapropelic OM and belong to one of the high-quality oil-source rocks in Northern Jordan's basins. 19 A preliminary study proposed that the bituminous carbonates mainly contain Types I and II kerogen, which can generate profitable amounts of sulfur-rich oil during the early mature stage of the oil window. 19 Although previous works have focused on the geochemical assessment of the bituminous carbonate facies in the Shu'ayb Formation and its ability for oil generation potential, 19 little is known about the depositional environment factors and their implication for understanding the organic carbon accumulation in the Upper Cretaceous sequence in Northern Jordan.…”

Section: Introductionmentioning

confidence: 99%

Geochemical and Organic Petrological Characteristics of the Bituminous Carbonate Succession (Upper Cretaceous Shu’ayb Formation) in Northern Jordan: Implications for Organic Matter Input and Paleosalinity, Paleoredox, and Paleoclimatic Conditions

Hakimi,

Alqudah,

Momani

et al. 2024

ACS Omega

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Early-Oil Generation Potential of Type II-S Kerogen in the Upper Cretaceous (Cenomanian–Turonian) Organic-Rich Carbonate Succession from Ajloun Region in Northern Jordan

Cited by 5 publications

References 43 publications

Molecular Compositions of Oil-Bearing Sandstones and Oil-Asphaltenes from the Kharir Oilfields in the Western Central Masila Basin, Yemen

Molecular Compositions of Oil-Bearing Sandstones and Oil-Asphaltenes from the Kharir Oilfields in the Western Central Masila Basin, Yemen

Impact of Thermal Maturation of the Upper Cretaceous Bituminous Limestone of Attarat Um Ghudran Central Jordan on Calcareous Nannofossil Preservation

Geochemical and Organic Petrological Characteristics of the Bituminous Carbonate Succession (Upper Cretaceous Shu’ayb Formation) in Northern Jordan: Implications for Organic Matter Input and Paleosalinity, Paleoredox, and Paleoclimatic Conditions

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