准噶尔盆地玛湖凹陷全油气系统成储机制差异性

doi:10.11743/ogg20250415

Abstract

Abstract:

The Mahu Sag in the Junggar Basin exhibits differential reservoir formation mechanisms across its whole petroleum system （WPS）. In this study， we investigate the petrology， reservoir spaces， and physical properties of representative oil-bearing strata in the WPS， including the Lower Permian Fengcheng Formation， the Upper Permian Urho Formation， and the Lower Triassic Baikouquan Formation to the Upper Triassic BaiJiantan Formation. By combining analyses of major elements and carbon-oxygen isotopes， we examine the mechanisms governing hydrocarbon-water-rock interactions in these formations and analyze the differences in the reservoir formation mechanisms. The results indicate that primary factors controlling the formation of high-quality coarse-grained clastic reservoirs from the Upper Permian Urho Formation to the Triassic strata include sedimentary processes， hydrocarbon-water-rock interactions， and associated mineral dissolution. Different oil-bearing horizons show significantly varying hydrocarbon-water-rock interaction mechanisms and mineral dissolution characteristics. Specifically， the Upper Permian Urho Formation is characterized by extensive laumontite cementation formed by the volcanic material alteration during early diagenesis. Laumontite re-dissolution occurred under the action of organic acids carried by hydrocarbon-bearing fluids， and the resulting dissolution pores act as the primary reservoir spaces in the Upper Permian Urho Formation. In the Baikouquan Formation， high-valent Mn and Fe oxides induced the thermal oxidation of hydrocarbons， generating significant amounts of 13C-deficient CO₂. The resulting dissolution of K-feldspar enhanced reservoir physical properties， especially permeability. In the Middle Triassic Karamay Formation， only limited hydrocarbons were oxidized due to an insufficient supply of oxidizing agents. Instead， organic acids carried by hydrocarbon-bearing fluids induced the partial dissolution of K-feldspar， enhancing reservoir quality locally. In contrast， the Baijiantan Formation experienced minimal hydrocarbon-water-rock interactions， with reservoir quality predominantly dictated by sedimentation and the degree of calcareous cementation. Shale oil reservoirs in the Fengcheng Formation are significantly governed by lithofacies. In this formation， compaction and cementation reduced reservoir physical properties. In contrast， organic acids produced during hydrocarbon generation promoted the dissolution of carbonate minerals and feldspar， improving reservoir physical properties. Generally， the development of high-quality deep coarse-grained clastic reservoirs in the Mahu Sag is intimately associated with hydrocarbon-water-rock interactions. Therefore， the mechanisms behind these interactions merit greater attention. Additionally， research on organic-rich， fine-grained reservoirs should highlight the differences caused by varying lithofacies.

Key words: hydrocarbon oxidation, hydrocarbon-water-rock interaction, whole petroleum system, reservoir genesis, Mahu Sag, Junggar Basin

CLC Number:

TE122.2

Xun KANG, Jingqiang TAN, Wenxuan HU, Jun JIN, Ruipu HU, Jian CAO. Differences in reservoir formation mechanisms across the whole petroleum system in the Mahu Sag， Junggar Basin[J]. Oil & Gas Geology, 2025, 46(4): 1250-1266.

Figures/Tables 11

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Differences in reservoir formation mechanisms across the whole petroleum system in the Mahu Sag， Junggar Basin

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