Evaluation of source rocks using one dimensional maturity modeling in Lower Indus Basin, Pakistan

Qayyum, Faisal; Hanif, Muhammad; Mujtaba, Muhammad; Wahid, Sohail; Ali, Fahad

doi:10.1007/s12517-015-2244-2

Cited by 9 publications

(3 citation statements)

References 9 publications

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“…Vitrinite reflectance values range from immature (<0.6%) to overmature (>1.35%), and the unit contains mixed type-II and type-III kerogen (Wandrey et al, 2004). One-dimensional maturity modeling of the Sembar Formation suggests that this formation is sufficiently mature to be exploited for its shale gas potential, and it can also charge sand intercalations for a successful petroleum play (Qayyum et al, 2016). Environment of deposition, thermal maturity, mineralogy, and effective reservoir parameters like thickness and porosity proved the Sembar Formation as an ideal prospect for its shale gas potential (Aziz et al, 2018).…”

Section: Introductionmentioning

confidence: 99%

“…Sheikh and Giao (2017) performed a comprehensive study on shale gas potential for the Sembar Formation shale, using primary data for geochemical analysis through rock eval pyrolysis, burial history plots, petroleum system modeling, volumetric estimation, and computation of retained gas in the shale. Qayyum et al (2016) plotted burial history charts and thermal maturity models for the evaluation of source rock potential of the Sembar Formation. Ahmad et al (2013) comprehensively modeled the geochemical parameters and estimated the expelled and retained volume of generated hydrocarbons along with unconventional reservoir characteristics present in the Sembar Formation shale.…”

Section: Introductionmentioning

confidence: 99%

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A novel gas sands characterization and improved depositional modeling of the Cretaceous Sembar Formation, Lower Indus Basin, Pakistan

et al. 2022

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The Lower Indus Basin of Pakistan has substantial hydrocarbon potential with the Cretaceous Sembar Formation as its principal source rock. While studies have identified the shale gas potential of the Sembar Formation, no extensive research has been conducted to evaluate the hydrocarbon potential of thick packages of sands encountered within it. This study is intended to fill this research gap by identifying the hidden-untapped thick packages of sands of the Sembar Formation for the first time in the Khewari and Gambat areas. We use well log and seismic reflection data to define the thickness, depth distribution, and petrophysical properties for reservoir characterization. This integrated modeling identifies favorable zones for gas production and the spatial distribution of sand packages with excellent reservoir properties in thickness (≈200 m), almost continuous sand packages suitable for hydrocarbon exploration. The Suleman-01 well has a very good hydrocarbon reservoir potential with 70% sand volume, approximately 13% effective porosity, 3.57 millidarcys average permeability, and approximately 58–60% hydrocarbon saturation. We suggest that the post-collisional tectonics of the Indian and Eurasian plates affected the depositional geometry of the Sembar Formation in such a way that it trends from shallower to deeper from western to eastern parts of the study area. Similarly, reservoir quality sands follow the positive upward trend from west to east toward the Indian shield. We propose that the approach implemented in this study is applicable to the entire Lower Indus Basin and further toward the Rajasthan Basin in India in the east and Zagros fold-and-thrust belt in Iran in the west. This approach would help assess the undeveloped hydrocarbon potential of the Sembar Formation sands and related formations in South Asia and worldwide.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

A novel gas sands characterization and improved depositional modeling of the Cretaceous Sembar Formation, Lower Indus Basin, Pakistan

et al. 2022

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“…Cretaceous and Paleocene rocks revealed good potential source characteristics in exploratory wells in the periphery of the studied area (Khan and Raza, 1986;Afzal et al, 1997;Qayyum et al, 2016;Ehsan et al, 2018). The shales of the Drazinda Formation, which in places lies conformably above Pirkoh Member, act as a cap/seal rock along with the sealing beds of the Pirkoh Formation (Fig.…”

Section: Stratigraphy and Petroleum System Of Well Zx-01mentioning

confidence: 94%

Reservoir evaluation of the Eastern Tethyan Middle Eocene Larger Benthic Foraminifera dominated carbonates from Pakistan.

Qadir¹,

Shahzad²,

Khan³

et al. 2022

KJS publishes peer-review articles in Mathematics, Computer Sci

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The Eocene Large Benthic Foraminiferal limestones of the Tethyan margins are proven hydrocarbon reservoirs. This study examines the controls on porosity and permeability development of the producing Middle Eocene Pirkoh Member of the Eastern Tethys using well core data from Well Zx-01 from the Punjab Platform area, Central Indus Basin, Pakistan. The standard petrographic and core analysis techniques were adopted to determine these controls. Petrographic studies revealed three microfacies comprising bioclastic packstone to floatstone, bioclastic wackestone and mud-wackestone microfacies. The allochems belong to benthic foraminifera including Nummulites sp., Discocyclinids sp.., Coralline algae, Assilina sp., Lockhartia sp., Coralline algae and Gastropods along with the other bioclastic debris. These allochems were found embedded in the micritic matrix with extensive cementation of calcite. The diagenetic events included cementation, compaction, dolomitization, fracture filling and neomorphism. Based on microfacies, the environment of deposition is interpreted to be a high-energy zone of the middle ramp in shallow marine environment. Subsurface core indicates that the porosity of the reservoir is low to high ranging between 6 to 27.47% and permeability is found low to fair ranging between 0.03 to 7.73 mD, found closely related to microfacies and diagenetic modifications. This study is a first attempt to document the reservoir facies of the non-reefal carbonates of the Pirkoh limestone that would help to exploit the reservoir's potential of the carbonate platforms developed in similar settings worldwide.

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Depositional Architecture of Eocene and Cretaceous Reservoirs (Blending Seismic and Well Data) in Mubarik Area, Central Indus Basin, Pakistan

Toosy

Khan

Shakir

et al. 2021

Pure Appl. Geophys.

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Evaluation of source rocks using one dimensional maturity modeling in Lower Indus Basin, Pakistan

Cited by 9 publications

References 9 publications

A novel gas sands characterization and improved depositional modeling of the Cretaceous Sembar Formation, Lower Indus Basin, Pakistan

A novel gas sands characterization and improved depositional modeling of the Cretaceous Sembar Formation, Lower Indus Basin, Pakistan

Reservoir evaluation of the Eastern Tethyan Middle Eocene Larger Benthic Foraminifera dominated carbonates from Pakistan.

Depositional Architecture of Eocene and Cretaceous Reservoirs (Blending Seismic and Well Data) in Mubarik Area, Central Indus Basin, Pakistan

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