Evaluation of Organic Matter Richness of Eocene Strata Based on Calcareous Nannofossils and Rock-Eval Analysis in North Dezful, Iran

Parandavar, Mohammad; Sadouni, Jalil

doi:10.1007/s12583-020-1091-6

Cited by 6 publications

(7 citation statements)

References 53 publications

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“…This is based on the fact that the plain is located in an area of tectonic extension, with a history of faulting and sedimentary deposition that has created an extensional structure. Additionally, areas of the plain have also experienced recent volcanic activity, which further reinforces the assumption that the plain has an extensional structure (Parandavar and Sadouni, 2021). This extension has caused the rocks to be folded, creating a series of ridges and valleys.…”

Section: Geological Settingsupporting

confidence: 62%

Integrating watershed segmentation algorithm and supervised Bayesian classification for the assessment of petrophysical parameters, pore properties, and lithofacies: a case study from Abadan Plain, SW Iran

Ghanbarnejad Moghanloo,

Riahi

2023

Earth Sci Inform

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In this paper, an integrated workflow based on recent geoscience data is presented for assessing the reservoir characterization and structural interpretation of the Burgan formation, a highly productive formation in the Abadan plain, SW Iran. Utilizing newly acquired high-resolution SEM images, we evaluated the pore size, pore distribution, and pore aspect ratio of Burgan formation. The watershed segmentation algorithm is also capable of detecting throats and closed pores. The porosity fractions from SEM images are used for calibration of the porosity log at several well locations in order to perform petrophysical modeling. Since the facies behavior is complex in the study area, we utilized supervised Bayesian classifier using P-wave velocity, density, and facies log dataset. The confusing matrix and machine learning metrics including Accuracy (97.01%), Precision (93.88%), F1 Score (94.16%), and False Positive Rate (2.52%), indicate that the classifier has been properly trained at well locations. A reasonable match is evident between the modeled petrophysical parameters and the true (core) porosity and water saturation at the location of the test well. Furthermore, we have demonstrated the validity of assumptions concerning the dominance of extensional structure in the Abadan plain by using interpreted seismic data. The presented workflow can be used to optimize drilling operations and reduce risks in similar geological settings in the studied formation.

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Section: Geological Settingsupporting

confidence: 62%

Integrating watershed segmentation algorithm and supervised Bayesian classification for the assessment of petrophysical parameters, pore properties, and lithofacies: a case study from Abadan Plain, SW Iran

Ghanbarnejad Moghanloo,

Riahi

2023

Earth Sci Inform

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“…Increasingly, calcareous nannofossil data is being used to improve biostratigraphic resolution (e.g. Senemari and Jalili, 2021;Senemari and Mahanipour, 2022;Parandavar and Sadouni, 2021).…”

Section: Sbzmentioning

confidence: 99%

Petroleum Geology of the Cenozoic Succession in the Zagros of Sw Iran: A Sequence Stratigraphic Approach

Piryaei,

Davies

2024

Journal of Petroleum Geology

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The Cenozoic stratigraphy of the Zagros records the ongoing collision between the Arabian and Eurasian Plates and the closure of NeoTethys. A Paleogene NW‐SE trending foreland basin was inherited from a Late Cretaceous precursor. Widespread progradation into the foredeep was a feature of both margins which, allied to ongoing tectonism, had by the late Eocene led to the narrowing and subsequent division of the foredeep into the Lurestan – Khuzestan and Lengeh Troughs, separated by the northward continuation of the rejuvenated Qatar‐Fars Arch. This sub‐division strongly influenced subsequent deposition and the petroleum geology of the area. In addition, the diachronous nature of the Arabian – Eurasian collision led to strong diachroneity in lithostratigraphic units along the length of the Zagros. Hence its petroleum geology is best understood within a regional sequence stratigraphic framework. This study identifies three tectono‐megasequences (TMS 10, TMS 11a, TMS 11b) and multiple depositional sequences.The Cenozoic contains a world class hydrocarbon province with prolific oil reservoirs in the Oligo‐Miocene Asmari Formation sealed by the evaporite‐dominated Gachsaran Formation, mostly contained within giant NW‐SE trending “whaleback” anticlines concentrated in the Dezful Embayment. Reservoirs in the SW are dominantly siliciclastic or comprise mixed siliciclastics and carbonates, whereas those to the east and NE are dominated by fractured carbonates. There remains untested potential in stratigraphic traps, especially in deeperwater sandstone reservoirs deposited along the SW margin of the foredeep.Late Miocene to Pliocene charge to the Asmari reservoirs was mostly from Aptian – Albian Kazhdumi Formation source rocks. In some fields, an additional component was from organic‐rich late Eocene to earliest Oligocene Pabdeh Formation source rocks confined to the narrowing Lurestan – Khuzestan Trough. Where mature, the latter source rock is also a potential unconventional reservoir target, although the prospective area is limited due to recent uplift and erosion. Deeper Jurassic source rocks contributed to the Cheshmeh Khush field in Dezful North. Silurian source rocks charged gas‐bearing structures in the Bandar Abbas region.

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“…In the past decade, shale oil and gas reservoirs have attracted extensive attention from researchers from academic institutions and oil companies around the world. − Shale gas production in China exceeded 200 × 10 8 m 3 in 2020 and has been successfully exploited at the commercial level in the marine Ordovician Wufeng and Silurian Longmaxi shale reservoirs of the Sichuan Basin and its adjacent areas. , Many studies have noted that natural gas in shale reservoirs mainly occurs in three states: (1) free gas in nano- to micro-scale pore networks and microfractures; (2) adsorbed gas on the surface of OM and clay minerals (CM); and (3) dissolved gas in formation water or liquid hydrocarbons. ,, For postmature Longmaxi shale reservoirs (thermal maturity above 2.0%), free and adsorbed gas are generally regarded as the dominant components of shale gas accumulations, while dissolved gases could be considered negligible since almost no liquid hydrocarbons are present in these reservoirs, that is, the primary sites where dissolved gas occurs. In the two main components above, the proportion of adsorbed gas varies widely, typically accounting for 20–85 and 20–50% of the total shale gas capacity for typical shale gas reservoirs from North America and South China, respectively. ,, Thus, studies related to the adsorption of natural gas, that is, primarily methane, in shale reservoirs are extremely significant for reasonably estimating the economic efficiency of shale gas accumulations.…”

Section: Introductionmentioning

confidence: 99%

Investigations on Supercritical Methane Adsorption and Storage in the Lower Longmaxi Shale of Nanchuan Area, Southeast Sichuan Basin

Zhang

Xiao

et al. 2023

Energy Fuels

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A series of high-pressure methane adsorption measurements were performed at various temperatures on whole shale and kerogen samples collected from the Lower Longmaxi shale in the Nanchuan area, southeast Sichuan Basin, to investigate supercritical methane adsorption properties and evaluate in-place methane storage capacity as a function of burial depth. The results show that the supercritical Dubinin−Radushkevich (SDR) model fits the excess adsorption isotherms marginally better than the supercritical Langmuir model. However, the fitted adsorbed methane density of kerogens obtained from the SDR model may be greater than the liquid methane density at the atmospheric boiling point (0.423 g/cm 3 ). The proposed multiple regression fitting carried out in this work illustrates that approximately 57.59% (34.51−85.45%) and 37.60% (10.74−59.52%) of the methane adsorption capacity at 333.15 K can be attributed to organic matter (OM) and clay minerals (CMs), respectively, for whole shales investigated. According to thermodynamic analyses, the significant contribution of OM to the methane adsorption capacity can be attributed to the stronger affinity between kerogens and methane molecules in contrast to that between CMs and whole shales. The methane storage capacity estimated as a function of burial depth showed that the adsorbed gas storage capacity declines with increasing burial depth between 2000 and 5000 m, while the free gas storage capacity shows the opposite trends. Gas accumulation pressure primarily exerts a significant effect on the free gas storage capacity rather than adsorbed gas storage capacity, and adsorbed gas storage capacity begins to exceed free gas storage capacity at shallow burial depths for normally pressured gas accumulations. Normally pressured shale gas accumulations at shallow burial depths, which are widely distributed in the residual syncline of the study area, should be given more attention due to their relatively low development costs and relatively high storage capacity for adsorbed gas.

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Evaluation of Organic Matter Richness of Eocene Strata Based on Calcareous Nannofossils and Rock-Eval Analysis in North Dezful, Iran

Cited by 6 publications

References 53 publications

Integrating watershed segmentation algorithm and supervised Bayesian classification for the assessment of petrophysical parameters, pore properties, and lithofacies: a case study from Abadan Plain, SW Iran

Integrating watershed segmentation algorithm and supervised Bayesian classification for the assessment of petrophysical parameters, pore properties, and lithofacies: a case study from Abadan Plain, SW Iran

Petroleum Geology of the Cenozoic Succession in the Zagros of Sw Iran: A Sequence Stratigraphic Approach

Investigations on Supercritical Methane Adsorption and Storage in the Lower Longmaxi Shale of Nanchuan Area, Southeast Sichuan Basin

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