Palynofacies and Source Rock Evaluation of Late Triassic Baluti Formation, from two selected wells, in the Northwestern Kurdistan Region, Iraq

Akram, Revan

doi:10.25156/ptj.2018.8.2.148

Cited by 3 publications

(4 citation statements)

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“…The geochemical results in this study from Atrush-1 and Shaikan-5B are similar to the analytical results for the Baluti Formation in Atrush-1 and Shaikan-1B presented by Akram and Naqshabandi (2018) (Fig. 6).…”

Section: Discussionsupporting

confidence: 89%

“…At least some of the reservoired oils are interpreted to be sourced from within the Triassic (Al-Ameri and Zumberge, 2012; English et al, 2015), suggesting the presence of an effective Triassic petroleum system. However, the identity of the Triassic source rocks remains poorly understood and relatively few published studies have attempted to assess the source rock potential or maturity of the Triassic succession in Kurdistan (Abeed, 2006;Al-Ameri et al, 2009;Naqishbandi et al, 2015;English et al, 2015;Akram and Naqshabandi, 2018;Edilbi et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

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Stratigraphic Correlation and Source Rock Characteristics of the Baluti Formation From Selected Wells in the Zagros Fold Belt, Kurdistan Region, Northern Iraq

Mohialdeen

Fatah

Abdula

et al. 2021

Journal of Petroleum Geology

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The Upper Triassic Baluti Formation has been identified and mapped based on its log response in selected wells from the Zagros foldbelt in the Kurdistan Region of northern Iraq. A preliminary evaluation of the formation's source rock potential was made by Rock‐Eval screening analysis in four wells along a NW‐SE profile (Atrush‐1, Shaikan‐5B, Taq Taq‐22 and Miran‐2) with maturity determined from reflectance measurements in samples from well Taq Taq‐22. The Baluti Formation consists of thinly interbedded shales, carbonates and anhydrite ranging in thickness from 48 m in well Atrush‐1 to 118 m in well Miran‐2. The Rock‐Eval screening was conducted primarily on bulk cuttings samples plus selected picked cuttings. The TOC content is low to moderate (0.23 to 1.14 wt%). However, the shale content in many of the analysed bulk samples was relatively low, making assessment of the source potential problematic. The highest TOCs are recorded from the thickest analysed sections from wells Miran‐2 and Taq Taq‐22, where high‐gamma bituminous shales are present. Rock‐Eval Tmax values ranging from 295 to 438°C are not consistent with estimates of pre‐Zagros burial to depths of between 4600 m (Atrush‐1) and 6900 m (Miran‐2). The relatively low Tmax values suggest that the S2 response does not reflect kerogen pyrolysis in these samples and may be due to the presence of solid bitumen, which is observed in the Baluti Formation in at least three of the study wells (Taq Taq‐22, Miran‐2 and Shaikan‐5B). Little pyrolysable organic matter remains in the formation due to the interpreted deep pre‐Zagros burial and the consequent high maturity in Taq Taq‐22 (VR = 1.51%Ro) and Miran‐2 (estimated VR >2%Ro), and the poor source character in Atrush‐1 and Shaikan‐5B. Organic petrography suggests the presence of vestiges of Types I and II kerogen in Taq Taq‐22, with bitumen observed as stains in the matrix of the shales and also in the pores and fractures of interbedded dolostones. However, bitumen reflectance determinations for Taq Taq‐22 indicate an equivalent vitrinite reflectance maturity of no more than 0.93%Ro, which is significantly less than that of the indigenous vitrinite, implying the solid bitumen in this well is derived primarily from migrated hydrocarbons. Further detailed analysis is required, but the results suggest that the Baluti Formation may have sourced hydrocarbons in its depocentre which is identified in this study as covering a NW‐SE trending area between Bekhme and Sangaw.

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Section: Discussionsupporting

confidence: 89%

Section: Introductionmentioning

confidence: 99%

Stratigraphic Correlation and Source Rock Characteristics of the Baluti Formation From Selected Wells in the Zagros Fold Belt, Kurdistan Region, Northern Iraq

Mohialdeen

Fatah

Abdula

et al. 2021

Journal of Petroleum Geology

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“…2b), the maximum value of HI reached to 200 mg HC/g TOC (ranging between 100-200 mg HC/g TOC) in both parts, while OI values were greater than HI and ranged from 159-318 mg CO2/g TOC suggesting the type III variety and capable of producing gas in an acceptable situation. The same conclusion has been reached by Akram and Naqshabandi (2018) in well Atrush-1. Thermal maturity is evaluated using Vitrinite reflectance and Tmax pyrolysis results (Fig.…”

Section: Source Rock Characterization From Pyrolysis Resultssupporting

confidence: 82%

“…Because of its economic significance, the Baluti Formation has been described in numerous papers (Tobia and Mustafa, 2019;Asaad and Omer, 2020;Hussain et al, 2021;Edilbi et al, 2021), the majority of which focus on lithofacies, depositional environments, mineralogy and inorganic geochemistry. However, palynology and source rock potential for the Baluti Formation in other locations have been also studied (Hanna, 2007;Edilbi, 2016;Akram and Naqshabandi, 2018). Petrophysics evaluation is a major application in studying reservoirs for the hydrocarbon industry, whereas, source rocks potentiality is able to estimate the total volume and quality of exploitable hydrocarbons in a sedimentary basin.…”

Section: Introductionmentioning

confidence: 99%

Petroleum Potentiality and Petrophysical Evaluation of Late Triassic Baluti Formation, Northern Iraq

Mamaseni

Al-Juboury

Omar

et al. 2022

IGJ

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Source rock potentiality and reservoir characteristics of the Baluti Formation (Late Triassic), Northern Iraq were examined in order to determine the hydrocarbon generation potential and reservoir properties. A combination of geochemical analyses, stable carbon isotope, 1D-basin modeling and digital log data were used to evaluate the formation. The Total Organic Carbon ratios range from 0.39 to 0.61 wt%, while the quantity of free hydrocarbon and residual hydrocarbon are low (0.05-0.11, 0.40-0.90 mg/g respectively). The average of oxygen index is 318 mg CO2/g TOC, while the hydrogen index is less than 200 mg HC/g TOC, which indicates type III kerogen. The outcomes of the pristane/phytane and Pr/n-C17 with Ph/n-C18 ratios suggest that the formation was deposited under oxic environment. This conclusion is also supported by trace elemental data. According to the average of Ro% of 0.58 and Tmax of 430.1oC, the formation is in immature to early mature stage. From a plot of 1D-modeled Ro% versus time, it is inferred that the organic matter of the formation had reached early maturation in the Early Paleocene (63Ma). The Baluti is waxier formation and the degree of waxiness ranges from 1.99-2.55. Regarding to, Triterpanes (Tm/Ts) and regular sterane C27-C29 the studied formation has deposited in terrestrial environment with high terrigenous input with hot and arid to semiarid climates. This result is supported by stable carbon isotopic data and clay mineralogy. Porosity of the dolomite beds is 10-15%. Based on the cutoff results, the Baluti Formation has only 1.13m net pay of 72m thickness, which means that the formation has poor porosity and permeability in the reservoir beds.

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Mineralogy and geochemistry of the Late Triassic Baluti Formation, Northern Iraq

Hussain

Al-Juboury

Al-Haj

et al. 2021

Journal of African Earth Sciences

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Palynofacies and Source Rock Evaluation of Late Triassic Baluti Formation, from two selected wells, in the Northwestern Kurdistan Region, Iraq

Cited by 3 publications

References 0 publications

Stratigraphic Correlation and Source Rock Characteristics of the Baluti Formation From Selected Wells in the Zagros Fold Belt, Kurdistan Region, Northern Iraq

Stratigraphic Correlation and Source Rock Characteristics of the Baluti Formation From Selected Wells in the Zagros Fold Belt, Kurdistan Region, Northern Iraq

Petroleum Potentiality and Petrophysical Evaluation of Late Triassic Baluti Formation, Northern Iraq

Mineralogy and geochemistry of the Late Triassic Baluti Formation, Northern Iraq

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