Geochemistry and detrital zircon U–Pb dating of Pliocene-Pleistocene sandstones of the Chittagong Tripura Fold Belt (Bangladesh): Implications for provenance

Rahman, M. Julleh Jalalur; Xiao, Wenjiao; Hossain, Md. Sakawat; Yeasmin, Rumana; Sayem, Abu Sadat Md.; Ao, Songjian; Yang, Lei; Abdullah, Rashed; Dina, Nafisa Tamanaya

doi:10.1016/j.gr.2019.07.018

Cited by 28 publications

(18 citation statements)

References 59 publications

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“…Detrital zircon‐Pb ages and the probability density plot of the IBR foreland basin sediments from the present study with the possible provenance, Gangdese batholith (Ji, Wu, Chung, Li, & Liu, 2009), Himalayan unit (Gehrels et al, 2011), Indo‐Burma Range (IBR) sediments (Allen et al, 2008; Rahman et al, 2020), Lohit Batholith (Lin et al, 2013), western Myanmar magmatic arc (J.‐G. Wang et al, 2014)…”

Section: Discussionmentioning

confidence: 65%

Detrital zircon U–Pb ages of Tertiary sequences (Palaeocene‐Miocene): Inner Fold Belt and Belt of Schuppen, Indo‐Myanmar Ranges, India

et al. 2022

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The along‐strike heterogeneity in the tectonics of Himalaya is well recognized; however, the eastern segment of Himalaya is less studied compared to the other segments. This study combines the comprehensive field data, as well as the U–Pb geochronology of sandstone samples from the Indo‐Burma Range (east India). The study shows that the Lower Disang Formation was deposited in an open marine environment with a steep gradient during the Late Cretaceous to Mid‐Eocene, accommodating the detritus solely from an Indian source. Furthermore, during the Early to Late Eocene interval, the sedimentary basin changed to a shallow marine shelf when the sediments from Himalayan as well as trans‐Himalaya were deposited. The Upper Disang Formation must have been deposited just before or during the collision process between the Indian and Asian plates. After the India‐Asian collision, there was a remnant ocean, in which the sediments of the Barail and Surma groups were deposited in the shallow marine to deltaic environments. The Tethys Ocean completely dried out in the Late Miocene resulting in a change from marine to fluvial environments, which facilitated the deposition of the sandstones of the Tipam Formation. Based on the U–Pb ages, the Palaeogene basin history in the Indo‐Burma Range was unlike the central Himalaya, that is, the detritus were mainly sourced from the Burmese Plate and adjoining magmatic rocks.

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Section: Discussionmentioning

confidence: 65%

Detrital zircon U–Pb ages of Tertiary sequences (Palaeocene‐Miocene): Inner Fold Belt and Belt of Schuppen, Indo‐Myanmar Ranges, India

et al. 2022

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“…The Hatiya Trough and most of the Bengal Foredeep is underlain by oceanic crust formed following the break-away of India from Australia and Antarctica during the Early Cretaceous. Late Neogene -Recent sediments in the Hatiya Trough were in general derived from provenance areas in the Himalayan mountain belt (Najman et al, 2016), although minor amounts of arc-derived sediments from the Trans-Himalaya or Paleogene Indo-Burman Ranges have also been reported (Rahman et al, 2017;Yang et al, 2019;Rahman et al, 2020;Yang et al, 2020).…”

Section: Geological Settingmentioning

confidence: 99%

Geophysical Characterization of the Sangu Gas Field, Offshore, Bangladesh: Constraints on Reservoirs

Shahriar

Hossain

et al. 2020

Journal of Petroleum Geology

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The only produced offshore gas field in Bangladesh, known as the Sangu field, is located in the Hatiya Trough in the east of the Bay of Bengal, and has estimated total reserves of about 1055 BCF GIIP. The early shut‐down of the field in October 2013 may have resulted in significant volumes of recoverable gas being left in the subsurface over a depth range of 1893 m to 3640 m. In this paper, seismic and well log data were analyzed and interpreted in order to investigate the structure and stratigraphy of the Sangu field, together with the lithology, extent and petrophysical properties of the reservoir. The general lithostratigraphy at Sangu has some similarity to that of the Surma Basin of the Bengal Foredeep. Reservoir rocks consist of Miocene and Pliocene deltaic sandstones and deep‐water clastics. The source rock is the Miocene Bhuban Shale which is mature for gas generation in the Hatiya Trough. Three Neogene seismic stratigraphic megasequences were recognised at Sangu and are interpreted to have been deposited respectively in fluvial, delta front and shelf slope or marginal marine settings. Based on an analysis of wireline logs from wells Sangu‐1 and Sangu‐5 and on seismic‐to‐well ties, a series of reservoir units referred to (from the base up) as the T1 (E, D, C, A&B), Supra‐T1, T2 and T3 have been identified. Petrophysical analyses showed that the average total porosity of these reservoir units is >13%, the permeability is in general less than10 mD, and the gas saturation ranges from 24% to 80%. Mapping of the reservoirs shows that the structure at Sangu is an asymmetric anticline with a NNW‐SSE axial trend. Amplitude data have allowed the delineation of two other potential reservoir zones in the field at depths of 2900‐3000 m and 3550‐3750 m. The study will contribute to future offshore gas exploration and development in the Bay of Bengal region based on the geological and geophysical characteristics of the reservoirs delineated.

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“…According to Najman et al (2016), the Himalayan Mountain belts act as the dominant source for the Late Neogene‐Recent sediments in the Hatiya Trough. However, a small amount of arc‐derived sediments from the Trans‐Himalaya or Palaeogene Indo‐Burman Ranges are also reported (Rahman et al, 2017, 2020; Yang et al, 2020).…”

Section: Geological Settingmentioning

confidence: 99%

Diagenetic controls on the reservoir quality of Neogene sandstones in the offshore area of the Bengal Basin, Bangladesh

Rahman

Mutti²,

et al. 2022

Geological Journal

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The Neogene sandstones offer hydrocarbon reservoirs in the offshore area of the Bay of Bengal (Bangladesh), but their reservoir quality is not well known. Understanding the impact of depositional and diagenetic controls on reservoir quality is crucial to hydrocarbon exploration and production in reservoir sandstones. This study aims to investigate the depositional and diagenetic controls on reservoir quality of the Neogene Surma Group from the Sangu Gas Field (the only offshore gas field), in the Bay of Bengal, Bangladesh using a combination of petrographical, petrophysical, X-ray diffraction, scanning electron microscope fitted with energy dispersive spectra and core analysis data. Diagenetic modifications to the sandstones include mechanical and ductile grain compaction followed by clay cementation (dominantly chlorite, illite-smectite and minor kaolinite), poikilotopic calcite cement and subordinate amounts of quartz cement, as well as partial dissolution of feldspars and lithic fragments. Sandstones with primary porosities ≥20% have average intergranular volume value of 33%, although permeability in most sections of the reservoir falls below 8-10 mD. There has also been localized creation of secondary porosity due to dissolution. The average intergranular porosity lost by compaction is 14% (ranges from 3% to 37%), and the average porosity lost by cementation is 10% (ranges from 3% to 37%). This study shows that the reservoir quality is predominantly controlled by depositional environment (ductile grain supply, clay content), a diagenetic processes (compaction followed by clay cement and early to intermediate poikilotopic calcite cement) and will provide insights into the reservoir quality evaluation in the offshore areas of the Bengal Basin.

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Geochemistry and detrital zircon U–Pb dating of Pliocene-Pleistocene sandstones of the Chittagong Tripura Fold Belt (Bangladesh): Implications for provenance

Cited by 28 publications

References 59 publications

Detrital zircon U–Pb ages of Tertiary sequences (Palaeocene‐Miocene): Inner Fold Belt and Belt of Schuppen, Indo‐Myanmar Ranges, India

Detrital zircon U–Pb ages of Tertiary sequences (Palaeocene‐Miocene): Inner Fold Belt and Belt of Schuppen, Indo‐Myanmar Ranges, India

Geophysical Characterization of the Sangu Gas Field, Offshore, Bangladesh: Constraints on Reservoirs

Diagenetic controls on the reservoir quality of Neogene sandstones in the offshore area of the Bengal Basin, Bangladesh

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