Hydrocarbon potential of the Middle Jurassic Sargelu Formation, Zagros Fold Belt, northern Iraq

Al-Ameri, Thamer K.; Al-Ahmed, Ahmed A.; Zumberge, John E.; Pitman, and Janet

doi:10.3997/2214-4609-pdb.246.28

Cited by 5 publications

(6 citation statements)

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“…Suitable source rocks have TOC (total organic content) ranges from 3 to 10% [8]. The organic matters of Sargelu Formation are comparable with the biomarker of the oil accumulated in the Cretaceous oil reservoirs inclusions and seeps in North Iraq [9].…”

Section: Discussionmentioning

confidence: 99%

Fluid Inclusions Usage for Assessing Oil Migration in Duhok, North Iraq

Awadh¹,

Al-Ameri²,

Jassim³

et al. 2010

POS

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Studies of primary and secondary fluid inclusions were done on epigenetic barite samples collected from carbonates of Lower part of Sarmord Formation (Lower Cretaceous) and Aqra-Bekhme Formations (Upper Cretaceous) in Duhok, north Iraq. Lead isotopes composition in galena which associated barite that contained fluid inclusions helped the identification two events of fluid inclusions. These fluid inclusions contain brine water and hydrocarbons. Primary and secondary fluid inclusions in barite as well as lead isotopes composition in galena helped the interpretation of oil migration history and the pathway of oil migration. Ages of galena are syngronous with the events of oil and water trapping as inclusions within barite, and hence the interpreted galena generation could be assigned to the fluid inclusions age. Accordingly, the events are two phases of early and late generations that correspond to 120 m.y. and 30 m.y. respectively. Correlation with 10 PetroMod basin modeling of the generated oil from the Jurassic and Lower Cretaceous Formations fitted with the event of early galena generation, whereas the oil migration started before 70 m.y. and continued to 30 m.y. ago. Palynomorphs study confirmed that the oil in source rocks is similar with the migrated oil

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Section: Discussionmentioning

confidence: 99%

Fluid Inclusions Usage for Assessing Oil Migration in Duhok, North Iraq

Awadh¹,

Al-Ameri²,

Jassim³

et al. 2010

POS

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show abstract

“…Suitable source rocks have TOC (total organic content) ranging from 3 to 10% [9]. The organic matters of Sargelu Formation are comparable with the biomarker of the oil accumulated in the Cretaceous oil reservoirs inclusions and seeps in North of Iraq [9]. The extracted palynomorphs from Upper Jurassic-Lower cretaceous source rocks appeared as similar as with the extracted palynomorphs from the migrated oil.…”

Section: -The Sargelu Formation Of Middlementioning

confidence: 71%

“…Jurassic (167 m.y) appear to be the main source rocks which has TOC of 1 to 17 wt%. Suitable source rocks have TOC (total organic content) ranging from 3 to 10% [9]. The organic matters of Sargelu Formation are comparable with the biomarker of the oil accumulated in the Cretaceous oil reservoirs inclusions and seeps in North of Iraq [9].…”

Section: -The Sargelu Formation Of Middlementioning

confidence: 91%

Fluid Inclusions Usage for Assessing Oil Migration in Duhok, North of Iraq

Awadh¹,

Al-Ameri²,

Jassim³

et al. 2009

JUAPS

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Studies of primary and secondary fluid inclusions were done on epigenetic barite samples which collected from carbonates in Lower part of Sarmord Formation (Lower Cretaceous and Aqra-Bekhme Formations (Upper Cretaceous) in Duhok localities of North of Iraq.Lead isotopes composition in galena which associated barite that contained fluid inclusions helped the identification two events of fluid inclusions. These fluid inclusions contain brine water and hydrocarbons. Primary and secondary fluid inclusions in barite as well as lead isotopes composition in galena helped the interpretation of oil migration history and the pathway of oil migration. Ages of galena are syngronous with the events of oil and water trapping as inclusions within barite, and hence the interpreted galena generation could be assigned to the fluid inclusions age. Accordingly, the events are two phases of early and late generations that correspond to 120 m.y. and 30 m.y. respectively.Correlation with 10 PetroMod basin modeling of the generated oil from the Jurassic and Lower Cretaceous Formations fitted with the event of early galena generation, whereas the oil migration started before 70 m.y and continued to 30 m.y ago.Palynomorphs study confirms that the oil in source rocks is similar with the migrated oil.

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“…8,14 The types I and II kerogens and mixed type II/III kerogens in the Sargelu organic-rich carbonates, which were deposited in a marine environment, make primarily oil-prone source rocks. 6,13 Good geochemical relationships between the reservoir oils and the mature Sargelu rocks in the basin support this discovery. 8 The Sargelu Formation is the main oil-source rock and is directly related to the main petroleum-producing regions recognized to date, acting as a conventional petroleum resource, according to Hakimi and Najaf 8 analysis of the biomarker fingerprints of reservoir oils from oilfields in the ZFB.…”

Section: Introductionmentioning

confidence: 72%

Organic Geochemistry and 1-D Basin Modeling of the Late Triassic Baluti Formation: Implication of Shale Oil Potential in the Kurdistan Region of Iraq

Mohialdeen,

Hakimi,

Fatah

et al. 2024

ACS Omega

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This investigation looks at the Late Triassic Baluti Formation's organic geochemical, mineralogical, and petrographical characteristics from a single exploration well (TT-22) near the Taq Taq oilfield in northern Iraq. The Baluti Formation shale samples that were studied in the studied well have high total organic carbon (TOC %) values up to 4.92 wt % and mostly hydrogen-rich types I and II kerogen with a minor gradient to types II/III and III kerogen, indicating a good oil-source rock. The hydrogen-rich kerogen was also confirmed by various organic matter (OM) origins and depositional environment-related biomarkers. The biomarker indicators demonstrate that the Baluti shale was deposited under anoxic conditions and contains a variety of OM generated mostly from algae marine and other aqueous organic materials, along with some terrigenous land plants. The geochemical and optical maturity indicators show that most of the examined Baluti shale samples, with a deep burial depth of more than 4000 m, are thermally mature, thus defining peak-mature to late-mature stages of the oil generation window. According to the basin models, from the late Miocene to the present, between 10 and 59% of the kerogen in the Baluti shale source rock has been transformed into oil, which is consistent with the VR values between 0.77 and 1.08%. The presence of the oil crossover in these shale rocks with an oil saturation index of more than 100 mg HC/g rock supports the maximal oil generation from the Baluti source rock system. Additionally, there was little oil expulsion from the Baluti source rock system at the end of the late Miocene, with transformation ratio values below 60% (59%). Considering the more significant oil generation and little expulsion, a high pressure was generated and forced the brittle minerals of the Baluti shales (mainly quartz), creating a natural fracture system as recognized and observed in the thin section. This natural fracture system enhances the porosity system of tight shale rocks of the Baluti Formation, giving rise to a high probability of oil production using hydraulic fracturing stimulation.

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Hydrocarbon potential of the Middle Jurassic Sargelu Formation, Zagros Fold Belt, northern Iraq

Cited by 5 publications

References 0 publications

Fluid Inclusions Usage for Assessing Oil Migration in Duhok, North Iraq

Fluid Inclusions Usage for Assessing Oil Migration in Duhok, North Iraq

Fluid Inclusions Usage for Assessing Oil Migration in Duhok, North of Iraq

Organic Geochemistry and 1-D Basin Modeling of the Late Triassic Baluti Formation: Implication of Shale Oil Potential in the Kurdistan Region of Iraq

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