Diagenesis and reservoir quality of overpressured deep-water sandstone following inorganic carbon dioxide accumulation: Upper Miocene Huangliu Formation, Yinggehai Basin, South China Sea

Fu, Meiyan; Song, Rongcai; Xie, Yuyuan; Zhang, Shao-nan; Gluyas, Jon; Zhang, Ying-zhao; Zhang, Ya

doi:10.1016/j.marpetgeo.2016.08.005

Cited by 26 publications

(18 citation statements)

References 36 publications

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“…Chlorite was not observed in the samples considered in this study. Its presence in the rocks of the LDX system was reported by Fu et al (2016). Moreover, the presence of chlorite within and below the CO2 gas reservoirs is inferred as a potential source of the iron leading to ankerite precipitation (see below).…”

Section: Clay Mineralsmentioning

confidence: 74%

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Dawsonite and ankerite formation in the LDX-1 structure, Yinggehai basin, South China sea: An analogy for carbon mineralization in subsurface sandstone aquifers

Lei

Liu

et al. 2020

Applied Geochemistry

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The geochemistry and petrology of the LDX-1 structure of the Yinggehai basin, a natural analog of a sedimentary carbon storage site, was investigated to understand the consequences of the charging of CO2 gas in this system. The rocks in this structure are dominated by subarkose and sublitharenite sandstones. The authigenic minerals formed after CO2 injection are dawsonite, microcrystalline quartz, kaolinite and ankerite.Dawsonite and ankerite are formed just beneath a CO2 bearing anticlinal structure due to the reactions between silicate minerals (feldspars and clay minerals) and the fluid phase. Carbon and oxygen isotopic analyses indicate that the main carbon source for dawsonite and ankerite formation was mantle magmatic CO2. The aqueous activities of sodium and calcium, the partial pressure of CO2, pH and temperature are the key factors influencing the stability of the dawsonite and ankerite. The presence of the anticlinal structure maintaining a locally high CO2 partial pressure in the waters beneath this structure is likely responsible for the observed long-term persistence of dawsonite and ankerite in this system.

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Section: Clay Mineralsmentioning

confidence: 74%

“…The CO2 dominated gas arrived later. Estimates of its arrival time range from 0.3 to 1.9 Ma (Fu et al, 2016;Huang et al, 2005;Wang et al, 2004;Xie et al, 2014). As such this basin provides a close natural analogue to the filling of a former hydrocarbon reservoir with CO2 as part of subsurface carbon storage efforts.…”

Section: Geological Settingmentioning

confidence: 99%

Dawsonite and ankerite formation in the LDX-1 structure, Yinggehai basin, South China sea: An analogy for carbon mineralization in subsurface sandstone aquifers

Lei

Liu

et al. 2020

Applied Geochemistry

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“…The fourth phase CO 2 ‐rich high‐temperature fluid is charged into the sandstone reservoirs, and dissolved glauconite, early‐stage authigenic clays and carbonate cements (such as calcite, dolomite, siderite, and ferrocalcite) (Figures 5 and 7; Fu et al, 2016; Giles & Boer, 1990; Irwin, Curtis, & Coleman, 1977; Mork, 2013). In addition, the abundant raw materials from dissolution can facilitate the late‐stage production of siderite, ferrocalcite, ankerite, and authigenic clays, and can influence clay transformation (Duan et al, 2020; Fu et al, 2016; Jiang, Xie, Chen, Wang, & Li, 2015). At wells S13A, S13B, and S13C, in contrast, the late‐stage dissolution produced massive CO 3 2− , Ca 2+ , and Fe 2+ ions, and facilitated the late‐stage formation of siderite (Duan et al, 2017).…”

Section: Discussionmentioning

confidence: 99%

“…Detrital grain contacts in sandstone give an indication of the degree of mechanical and chemical compaction (Feng, 1994; Fu et al, 2016). We use the visual compaction ratio of Houseknecht (1987) to quantify the compaction intensity:…”

Section: Samples and Methodsmentioning

confidence: 99%

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Formation of an anomalously high‐porosity zone of a very fine‐grained deep clastic reservoir in the Qiongdongnan Basin, South China Sea

Duan

Luo³

et al. 2020

Geological Journal

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Development of anomalously high porosities in very fine‐grained deep clastic reservoirs is still largely unknown. The reservoirs in the S13 block of the lower Meishan Formation in the Qiongdongnan Basin, South China Sea, developed a zone of anomalously high porosity up to 28.5%, and thus offers an ideal opportunity to quantitatively study the formation mechanism of the abnormally high porosity but fine‐grained deep clastic reservoir from the diagenetic perspective. Our study demonstrates that the first phase charging of oil and organic acid promoted the early‐stage dissolution. This process, however, restrained the early‐stage compaction, cementation, and transformation of clay minerals in sandstone reservoirs. CO2‐rich thermal fluid at the fourth phase enhanced the dissolution of late‐stage feldspar and early‐stage cements and authigenic clay minerals. The massive Ca2+, Mg2+, Fe2+, and other ions generated by the dissolution facilitated the formation of late‐stage siderite and ankerite, which filled the pore throats and lowered the reservoir permeability. Furthermore, the rapid deposition produced high primary porosities, and the early‐stage overpressure also inhibited the compaction, cementation, and clay transformation in the S13 block. All these processes promoted the preservation of primary pores, and the S13 block developed reservoirs with anomalously high porosity and low permeability. By contrast, the C24 block was only charged by oil and hydrocarbon‐rich gas at the second and third phases, and experienced strong compaction, weak dissolution, and strong cementation. Consequently, fewer primary and secondary pores, but higher contents of cements and authigenic clays were generated in the C24 block. The reservoirs in the C24 block exhibit medium porosity but low permeability.

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Coupling relationship between reservoir densification and hydrocarbon emplacement in the Jurassic Badaowan Formation sandstone reservoirs of the southern Junggar Basin, China

Zhou

Guan

et al. 2022

Geological Journal

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Understanding the interrelationship between diagenesis and hydrocarbon emplacement is crucially important for investigating tight sandstone reservoir‐forming processes. In this paper, efforts were made to elucidate this interrelationship in the Jurassic Badaowan Formation tight sandstone reservoirs of the southern margin of the Junggar Basin (SJB), China. Four lithofacies were clarified, including quartz cemented‐dissolution facies (QCDF), carbonate cemented facies (CCF), authigenic clay mineral facies (ACMF), and matrix‐caused tightly compacted facies (MCTF). Weak hydrocarbon migration forces and poor hydrocarbon preservation conditions were identified to be the main reasons for the limited hydrocarbon accumulation scale. The reservoir densification process, mostly before 100 Ma, was associated with four aspects, including the high matrix content, the intensive carbonate cementation, the limited dissolution and alteration, and the development of authigenic clay minerals. Hydrocarbons in the Badaowan Formation reservoir were demonstrated to be emplaced after reservoir densification. Overpressure resulting from hydrocarbon expulsion and tectonic compression should have acted as the main driver for hydrocarbon migration. Particularly, the tight sandstone in the Qigu anticline was charged with overpressurized hydrocarbons sourced from the middle‐lower Jurassic source rocks at the footwall of the Qigu north fault since the early Jurassic. The tectonic compression in the late Neogene eroded the core of the Qigu anticline, which destroyed the initially large palaeo‐oil reservoir into smaller ones. The first‐stage hydrocarbon emplacement greatly affected the diagenesis and physical properties of the reservoir. It played an important role in inhibiting cementation, promoting dissolution, and altering the petrophysical properties of the tight sandstone reservoir. The densification process controlled the wettability and capillary pressure of pores in the tight sandstone. Specifically, the high kaolinite cement raised the hydrophilia, while the ubiquitous densification increased the capillary pressure of pores.

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Diagenesis and reservoir quality of overpressured deep-water sandstone following inorganic carbon dioxide accumulation: Upper Miocene Huangliu Formation, Yinggehai Basin, South China Sea

Cited by 26 publications

References 36 publications

Dawsonite and ankerite formation in the LDX-1 structure, Yinggehai basin, South China sea: An analogy for carbon mineralization in subsurface sandstone aquifers

Dawsonite and ankerite formation in the LDX-1 structure, Yinggehai basin, South China sea: An analogy for carbon mineralization in subsurface sandstone aquifers

Formation of an anomalously high‐porosity zone of a very fine‐grained deep clastic reservoir in the Qiongdongnan Basin, South China Sea

Coupling relationship between reservoir densification and hydrocarbon emplacement in the Jurassic Badaowan Formation sandstone reservoirs of the southern Junggar Basin, China

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