Geochemical characteristics of crude oils and basin modelling of the probable source rocks in the Southern Mesopotamian Basin, South Iraq

Al-Khafaji, Amer Jassim; Hakimi, Mohammed Hail; Mohialdeen, Ibrahim M.J.; Idan, Rami M.; Afify, Wafaa E.; Lashin, Aref

doi:10.1016/j.petrol.2020.107641

Cited by 27 publications

(13 citation statements)

References 46 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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“…Subba oilfield lies in southern Iraq and is 72 km from Nasiriya City within the Mesopotamian Basin, as shown in Figure 1. The most significant hydrocarbon reservoir units are located in the Mesopotamian Basin in southern Iraq [17]. Lower Cretaceous succession contains 30% of Iraq's oil and gas reservoirs [18] [19] [20].…”

Section: Location and Geology Settingmentioning

confidence: 99%

Uncertainty Analysis to Assess Depth Conversion Accuracy: A Case Study of Subba Oilfield, Southern Iraq

Al-Khazraji¹,

Al-Qaraghuli²,

Abdulkareem

et al. 2022

eijs

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The depth conversion process is a significant task in seismic interpretation to establish the link between the seismic data in the time domain and the drilled wells in the depth domain. To promote the exploration and development of the Subba oilfield, more accurate depth conversion is required. In this paper, three approaches of depth conversions: Models 1, 2, and 3 are applied from the simplest to the most complex on Nahr Umr Reservoir in Suba oilfield. This is to obtain the best approach, giving less mistakes with the actual depth at well locations and good inter/extrapolation between or away from well controls. The results of these approaches, together with the uncertainty analysis provide a reliable velocity model and more accurate predicted depth that reduced the ambiguity of the subsurface. The uncertainty analysis reveals that Model 3 is considered a more practical and most accurate approach because it gives a minimized standard deviation value of 14 with less residual and error values. The uncertainty of the depth conversion and the standard deviation values is raised towards the eastern part of the field due to an increase in the dipping depth in this region that affects the depth conversion results.

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“…Long chain n-alkanes (more than C 20 ), high boiling point n-alkanes, are commonly attributed to the contribution of terrestrial waxes, especially in the C 25 -C 33 range (Peters and Moldowan, 1993). In this study, the Pr/Ph, Pr/n-C 17 and Ph/n-C 18 outputs are also used for determining the source of organic matter and conditions in the depositional environment (e.g., Shanmugam, 1985;Wang et al, 2010;Al-Khafaji et al, 2020). Biomarker parameters used in this study are presented as follows:…”

Section: Long-chain Saturated Hydrocarbon (N-alkane) Distributionmentioning

confidence: 99%

The Occurrence of Bedding-Parallel Fibrous Calcite Veins in Permian Siliciclastic and Carbonate Rocks in Central Thailand

et al. 2022

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Bedding-parallel fibrous calcite veins crop out at two Permian carbonate localities in the Phetchabun area, central Thailand, within the Nam Duk and Khao Khwang Formations. Samples are studied to determine their petrographic, geochemical and isotopic character, depositional and diagenetic associations and controls on the formation of fibrous calcite across the region. Biomarker and non-biomarker parameters are used to interpret organic matter sources in the vein-hosting units, the depositional environment and levels of source rock maturation in order to evaluate source rock potential in the two Formations. Carbon and oxygen isotope values of the veins and the host are determined to discuss the source of carbonates and diagenetic conditions. The petroleum assessment from the Khao Khwang and Nam Duk Formations suggests that both Formations are a petroleum potential source rock with type II/III kerogen deposited in an estuarine environment or a shallow marine environment and a slope-to-basin marine environment or an open marine environment, respectively. The bedding-parallel fibrous calcite veins from the Khao Khwang and Nam Duk Formations are divided into two types: 1) beef and, 2) cone-in-cone veins. The carbon and oxygen isotope compositions from the fibrous calcite veins suggest that the calcite veins could be precipitated from a carbon source generated in the microbial methanogenic zone. The results in this study provide a better understanding of the interrelationship between the bedding-parallel fibrous calcite veins and petroleum source rock potential.

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Geochemical characteristics of crude oils and basin modelling of the probable source rocks in the Southern Mesopotamian Basin, South Iraq

Cited by 27 publications

References 46 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

Uncertainty Analysis to Assess Depth Conversion Accuracy: A Case Study of Subba Oilfield, Southern Iraq

The Occurrence of Bedding-Parallel Fibrous Calcite Veins in Permian Siliciclastic and Carbonate Rocks in Central Thailand

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