Petroleum Source Rock Properties of the Neogene Bhuban Shales, Bengal Basin, Bangladesh

Farhaduzzaman, Md.; Abdullah, Wan Hasiah; Islam, Md. Aminul

doi:10.17576/jsm-2015-4404-12

Cited by 4 publications

(1 citation statement)

References 14 publications

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“…Except for the Sylhet limestone, all other formations consist of clastic deposits. The shale units within the Bokabil and Bhuban formations of the Surma group act as the source of rock for Bangladesh's hydrocarbons (Farhaduzzaman, 2013). The upper Bhuban and Bokabil Formation are home to over 80% of the country's gas reserves (Rahman and McCann, 2012).…”

Section: Regional Geologymentioning

confidence: 99%

Evaluation of the Reservoir Characteristics of Exposed Sandstone Facies of the Bhuban Formation in Sitakund Anticline, Chittagong

Uzzal,

Lupin,

Solaiman

2024

Dhaka Univ J Earth Env Sci

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This research concentrates on characterizing the sandstone reservoir features within the Bhuban Formation exposed in the Sitakund Anticline of the Chittagong Hill Tracts. Of the lack of well-qualified reservoirs, the sandstone facies in the Bhuban Formation are considered the primary reservoir source and a significant contributor to Bangladesh's hydrocarbon reserves. The Bhuban Formation showcases a pattern of alternating sandstone and shale layers. To ascertain the existence of reservoir sandstone facies in the Bhuban Formation, the study conducts analyses of exposed structures along various outcrop sections of Bariyadhala, Chandranath, Barabkunda, and Shahasradhara. Through scrutinizing lithology, sedimentary structures, bed configuration, grain size, and reservoir characteristics of rock sequences, three distinct facies types emerge: the alternating sandstone and shale layers, channel sand, and incised valley sand. These facies types signify diverse depositional environments, with the alternating sandstone and shale layers originating from tidal flats, channel sand representing sediment fill within tidal channels, and incised valley sand indicating sediment accumulation within incised valleys. The detailed petrographic analysis underscores that the incised valley fill sand exhibits the most favorable reservoir qualities, boasting an approximate porosity of 25%. The tidal channel fill and the tidal flat deposits display 20% and 8% porosity, respectively. Both channel sand and incised valley sand showcase commendable porosity and permeability. In contrast, the sample featuring the alternation of sandstone and shale has the lowest porosity and contains randomly oriented clay minerals, predominantly Kaolinite. The Dhaka University Journal of Earth and Environmental Sciences, Vol. 12(1), 2023, P 57-68

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Section: Regional Geologymentioning

confidence: 99%