Reservoir attributes of a hydrocarbon-prone sandstone complex: case of the Pab Formation (Late Cretaceous) of Southwest Pakistan

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Reservoir attributes of a hydrocarbon-prone sandstone complex: case of the Pab Formation (Late Cretaceous) of Southwest Pakistan. / Umar, Muhammad; Khan, Abdul Salam; Kelling, Gilbert; Friis, Henrik; Kassi, Akhtar Muhammad.

In: Arabian Journal of Geosciences, Vol. 9, No. 74, 01.2016, p. 1-15.

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Umar, Muhammad ; Khan, Abdul Salam ; Kelling, Gilbert ; Friis, Henrik ; Kassi, Akhtar Muhammad. / Reservoir attributes of a hydrocarbon-prone sandstone complex: case of the Pab Formation (Late Cretaceous) of Southwest Pakistan. In: Arabian Journal of Geosciences. 2016 ; Vol. 9, No. 74. pp. 1-15.

Bibtex

@article{749e6d21d472471097b06d46a11f49bc,
title = "Reservoir attributes of a hydrocarbon-prone sandstone complex: case of the Pab Formation (Late Cretaceous) of Southwest Pakistan",
abstract = "Links between the architectural elements of major sand bodies and reservoir attributes have been explored in a field study of the hydrocarbon-yielding Late Cretaceous Pab Formation of southwest Pakistan. The lithofacies and facies associations represented in the Pab Formation are the main determinants of its reservoir properties. Thus, thick, vertically connected and laterally continuous sand packets have moderate-to-high mean porosities (10–13 {\%}) in fluviodeltaic, shoreface, shelf delta, submarine channel, and fan-lobe facies associations while deeper shelf and basin floor sand bodies yield significantly lower porosities (4–6 {\%}). Overall, in the Pab arenites, porosity values increase with increasing grain size and better sorting. The varying sand-shale ratios encountered in different sectors of the Pab outcrop are also petrophysically important: Sequences displaying high ratios yield higher bulk porosity values than more shale-rich successions. Diagenetic studies of Pab sandstones reveal that intense mechanical compaction and cementation have reduced primary porosity and reservoir quality. Conversely, dissolution of detrital feldspar grains and volcanic fragments during burial and later uplift of these arenites has generated significant secondary porosity.",
keywords = "Porosity, Sandstone, Facies associations, Diagenesis, Stratigraphic Traps, Texture, porosity , Sandstone, Facies associations, Diagenesis, Texture",
author = "Muhammad Umar and Khan, {Abdul Salam} and Gilbert Kelling and Henrik Friis and Kassi, {Akhtar Muhammad}",
year = "2016",
month = "1",
doi = "10.1007/s12517-015-2170-3",
language = "English",
volume = "9",
pages = "1--15",
journal = "Arabian Journal of Geosciences",
issn = "1866-7511",
publisher = "Springer",
number = "74",

}

RIS

TY - JOUR

T1 - Reservoir attributes of a hydrocarbon-prone sandstone complex: case of the Pab Formation (Late Cretaceous) of Southwest Pakistan

AU - Umar, Muhammad

AU - Khan, Abdul Salam

AU - Kelling, Gilbert

AU - Friis, Henrik

AU - Kassi, Akhtar Muhammad

PY - 2016/1

Y1 - 2016/1

N2 - Links between the architectural elements of major sand bodies and reservoir attributes have been explored in a field study of the hydrocarbon-yielding Late Cretaceous Pab Formation of southwest Pakistan. The lithofacies and facies associations represented in the Pab Formation are the main determinants of its reservoir properties. Thus, thick, vertically connected and laterally continuous sand packets have moderate-to-high mean porosities (10–13 %) in fluviodeltaic, shoreface, shelf delta, submarine channel, and fan-lobe facies associations while deeper shelf and basin floor sand bodies yield significantly lower porosities (4–6 %). Overall, in the Pab arenites, porosity values increase with increasing grain size and better sorting. The varying sand-shale ratios encountered in different sectors of the Pab outcrop are also petrophysically important: Sequences displaying high ratios yield higher bulk porosity values than more shale-rich successions. Diagenetic studies of Pab sandstones reveal that intense mechanical compaction and cementation have reduced primary porosity and reservoir quality. Conversely, dissolution of detrital feldspar grains and volcanic fragments during burial and later uplift of these arenites has generated significant secondary porosity.

AB - Links between the architectural elements of major sand bodies and reservoir attributes have been explored in a field study of the hydrocarbon-yielding Late Cretaceous Pab Formation of southwest Pakistan. The lithofacies and facies associations represented in the Pab Formation are the main determinants of its reservoir properties. Thus, thick, vertically connected and laterally continuous sand packets have moderate-to-high mean porosities (10–13 %) in fluviodeltaic, shoreface, shelf delta, submarine channel, and fan-lobe facies associations while deeper shelf and basin floor sand bodies yield significantly lower porosities (4–6 %). Overall, in the Pab arenites, porosity values increase with increasing grain size and better sorting. The varying sand-shale ratios encountered in different sectors of the Pab outcrop are also petrophysically important: Sequences displaying high ratios yield higher bulk porosity values than more shale-rich successions. Diagenetic studies of Pab sandstones reveal that intense mechanical compaction and cementation have reduced primary porosity and reservoir quality. Conversely, dissolution of detrital feldspar grains and volcanic fragments during burial and later uplift of these arenites has generated significant secondary porosity.

KW - Porosity, Sandstone, Facies associations, Diagenesis, Stratigraphic Traps, Texture

KW - porosity

KW - Sandstone

KW - Facies associations

KW - Diagenesis

KW - Texture

U2 - 10.1007/s12517-015-2170-3

DO - 10.1007/s12517-015-2170-3

M3 - Journal article

VL - 9

SP - 1

EP - 15

JO - Arabian Journal of Geosciences

JF - Arabian Journal of Geosciences

SN - 1866-7511

IS - 74

ER -