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Petrophysical characterization of the Cretaceous-Paleocene succession, Tal- Block, Kohat sub-basin, North West Pakistan.

Byline: Bahar Saddique, Irfan U. Jan, Muhammad Hanif, Nowrad Ali, Syed Anjum Shah and Mohib ur Rehman


The research work deals with the evaluation ofthe reservoir potential through petrophysical analysis ofthe Cretaceous-Paleocene rocks in three wells ofTal block namely, Kahi-01, Sumari deep X-01 and Mamikhel-01 well in the Kohat sub-basin. Two formations namely, Hangu and Lumshiwal formations have been analyzed in detail.

Lumshiwal Formation has a thickness of133 m in Kahi-01 well. A single zone A is marked within the Lumshiwal Formation in Kahi-01 well. The interval display a higher value ofeffective porosity and lesser value ofvolume of shale.

In Sumari deep X-01 well, Lumshiwal Formation has a thickness of122 m. Three zones, C1, C2, and C3, 10, 30 and 35 m thick, respectively, have been marked. Overall, the complete formation proves to be a good reservoir with satisfactory porosities and hydrocarbon saturation values in Sumari deep X-01 well. Lumshiwal Formation is encountered twice in Mamikhel-01 well. The log interpretations show that the formation is clean with lesser volume ofshale, high effective porosity, and high water saturation. The Gas effect approves the reservoir capabilities of the Lumshiwal formation in Mamikhel-01 well.

The thickness of Hangu Formation in Kahi-01 well is 50 m. A single zone B is marked as potential reservoir interval in Hangu Formation which occurs at depth 1705 - 1730 m. The Formation has significant values ofeffective porosity, less volume ofshale and greater hydrocarbon saturation confirms the reservoir potential ofHangu Formation in Kahi-01.

The bulk volume of water data suggests coarser grained rocks for Hangu Formation in Sumari deep X-01 well. The effective porosity and hydrocarbon saturation values determined are unsatisfactory.

Hangu Formation in Mamikhel-01 well is 19 m thick. The water saturation value is high but the Formation has satisfactory values ofeffective porosity and volume of shale.

By correlating the reservoir intervals from the three wells i.e. Kahi-01, Sumari deep X-01 and Mamikhel-01 wells, it is inferred that the overall reservoir capability decreases to the west but increases to the north.

Sequence stratigraphic analysis has showed two types facies association in Lumshiwal Formation and three types offacies association in Hangu formation. The analysis based on GR log determines an inner to middle shelfenvironment for Lumshiwal Formation and deltaic environment for Hangu Formation.

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Publication:Journal of Himalayan Earth Sciences
Date:Dec 31, 2016
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