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<p>The reservoir quality is essential for developing an effective and economically sustainable exploration and production strategy. This study investigates the sandstones of the Neogene Surma Group found in the Begumganj Gas Field (Well-3), situated within the Hatia Trough of the Bengal Basin. The aim is to evaluate the depositional and diagenetic factors that affect the reservoir quality of the Neogene Surma Group by employing techniques such as core analysis, petrography, X-ray diffraction, scanning electron microscopy, and petrophysical analysis. The Surma Group was deposited in a tide-influenced shallow marine shelf and deltaic environment. The petrographic analysis of the Neogene Surma Group reveals that the sandstones are categorized as lithic subarkosic to lithic arkosic, exhibiting an average primary porosity of 8.5% (ranging from 0% to 18%) and a secondary porosity of 2.5%. Core permeability ranges from 12 to 207 mD between depths of 2890–2897&#xa0;m and 0.08-16 mD (avg. 4 mD) at depths of 3178–3186&#xa0;m. Mechanical and ductile grain compaction has significantly reduced primary porosity, with compaction dominating over cementation as revealed by intergranular volume (IGV) analysis. Clay and chlorite cements occur as grain coatings, pore-fillers, and grain linings (rims), while poikilotopic calcite cement severely diminished porosity and permeability. This investigation suggests that the overall reservoir quality is moderate, primarily shaped by the depositional environment (sediment texture, facies, ductile grain supply, and clay content) as well as by diagenetic processes, particularly mechanical compaction followed by clay authigenesis and poikilotopic carbonate cementation. These findings will aid in enhancing petroleum production and refining predictive models for discovering new prospects, thus addressing the persistent energy challenges faced in Bangladesh.</p>

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Depositional and diagenetic controls on the reservoir quality of the Neogene Surma Group in the Begumganj Gas Field, Bengal Basin (Bangladesh)

  • 期刊论文

  • 发表日期：

    2025年12月26日

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  • Padmasree Paul,
  • M. Julleh Jalalur Rahman,
  • Abu Sadat Md. Sayem

摘要

The reservoir quality is essential for developing an effective and economically sustainable exploration and production strategy. This study investigates the sandstones of the Neogene Surma Group found in the Begumganj Gas Field (Well-3), situated within the Hatia Trough of the Bengal Basin. The aim is to evaluate the depositional and diagenetic factors that affect the reservoir quality of the Neogene Surma Group by employing techniques such as core analysis, petrography, X-ray diffraction, scanning electron microscopy, and petrophysical analysis. The Surma Group was deposited in a tide-influenced shallow marine shelf and deltaic environment. The petrographic analysis of the Neogene Surma Group reveals that the sandstones are categorized as lithic subarkosic to lithic arkosic, exhibiting an average primary porosity of 8.5% (ranging from 0% to 18%) and a secondary porosity of 2.5%. Core permeability ranges from 12 to 207 mD between depths of 2890–2897 m and 0.08-16 mD (avg. 4 mD) at depths of 3178–3186 m. Mechanical and ductile grain compaction has significantly reduced primary porosity, with compaction dominating over cementation as revealed by intergranular volume (IGV) analysis. Clay and chlorite cements occur as grain coatings, pore-fillers, and grain linings (rims), while poikilotopic calcite cement severely diminished porosity and permeability. This investigation suggests that the overall reservoir quality is moderate, primarily shaped by the depositional environment (sediment texture, facies, ductile grain supply, and clay content) as well as by diagenetic processes, particularly mechanical compaction followed by clay authigenesis and poikilotopic carbonate cementation. These findings will aid in enhancing petroleum production and refining predictive models for discovering new prospects, thus addressing the persistent energy challenges faced in Bangladesh.