Impacts of sedimentology and diagenesis on pore structure and reservoir quality in tight oil sandstone reservoirs: Implications for macroscopic and microscopic heterogeneities

Qiao, J.C.; Zeng, Jianhui; Jiang, Shu; Wang, Yanu

doi:10.1016/j.marpetgeo.2019.08.008

Cited by 65 publications

(33 citation statements)

References 69 publications

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“…The differences of porosity, connectivity, and topology of pore space always determine the macroscopic seepage properties [10,11]. The pore space of the reservoir core can be obtained by multi-laboratory test methods [12][13][14][15].…”

Section: Introductionmentioning

confidence: 99%

Pore Structure Fractal Characterization and Permeability Simulation of Natural Gas Hydrate Reservoir Based on CT Images

et al. 2020

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The gas-water two-phase seepage process is complex during the depressurization process of natural gas hydrate in a clayey silt reservoir in the South China Sea, the transport mechanism of which has not been clarified as it is affected by the pore structure. In this study, we select six clayey silt samples formed after the dissociation of natural gas hydrate in the South China Sea, employing CT scanning technology to observe the pore structure of clayey silt porous media directly. The original CT scanning images are further processed to get the binarized images of the samples, which can be used for simulation of the porosity and absolute permeability. Based on the fractal geometry theory, pore structures of the samples are quantitatively characterized from the aspect of pore distribution, heterogeneity, and anisotropy (represented by three main fractal geometric parameters: fractal dimension, lacunarity, and succolarity, respectively). As a comparison, the binarized CT images of two conventional sandstone cores are simulated with the same parameters. The results show that the correlation between porosity and permeability of the hydrate samples is poor, while there is a strong correlation among the succolarity and the permeability. Fractal dimension (represents complexity) of clayey silt samples is higher compared with conventional sandstone cores. Lacunarity explains the difference in permeability among samples from the perspective of pore throat diameter and connectivity. Succolarity indicates the extent to which the fluid in the pore is permeable, which can be used to characterize the anisotropy of pore structures. Therefore, these three fractal parameters clarify the relationship between the microstructure and macroscopic physical properties of clayey silt porous media.

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Section: Introductionmentioning

confidence: 99%

Pore Structure Fractal Characterization and Permeability Simulation of Natural Gas Hydrate Reservoir Based on CT Images

et al. 2020

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“…The effective identification of diagenetic facies is a difficult problem in reservoir evaluation. Due to the limitation of the core data, it is a common method to characterize sandstone reservoir by logging curve (Zhou et al, 2008;Hao et al, 2010;Qiao et al, 2020;Zhu et al, 2020). Scholars adopt different methods, including multi-parameter comprehensive identification (Paxton et al, 2002;Jiang et al, 2014;Lai et al, 2019;Li et al, 2019), optimization of Logging Mathematical Model for Identification (Cui et al, 2017;Qin et al, 2018;Guo et al, 2019).…”

Section: Automatic Identification Of Diagenetic Faciesmentioning

confidence: 99%

“…The spatial distribution of different types of diagenetic facies is a key problem in the evaluation of the tight sandstone reservoirs. Traditional diagenetic facies prediction is based on reservoir parameters such as thickness, porosity, and permeability (Zou et al, 2008;Hao et al, 2010;Lai et al, 2013;Guo et al, 2019;Li et al, 2020;Qiao et al, 2020). However, there is a problem of low accuracy under the influence of reservoir heterogeneity.…”

Section: Distribution Regularity Of Diagenetic Faciesmentioning

confidence: 99%

“…Due to the lack of effective prediction methods, the study of diagenetic facies distribution is less (Hao et al, 2010;Pan et al, 2011;Cai et al, 2014;Li et al, 2019). Most scholars believe that sedimentary differentiation, which results in the spatial distribution variation in debris mineral composition, interstitial material content, granule size, and pore fluid property, provides different prerequisites for the later diagenesis, so the diagenetic facies distribution is significantly controlled by sedimentary facies (Zhang et al, 2011;Zeng et al, 2018;Qiao et al, 2020). In this study, the face-controlling method is used to study the favorable diagenetic facies distribution.…”

Section: Distribution Regularity Of Diagenetic Faciesmentioning

confidence: 99%

“…The evaluation and prediction of the tight sandstone reservoirs have been hotspots for the petroleum industry (Guo et al, 2019;Ren et al, 2019;Xiao et al, 2019;Li et al, 2020). The actual exploration effect of the traditional method for the evaluation of tight sandstone reservoirs is poor, which is mainly because the fact that the reservoir physical parameters can not reflect the strong heterogeneity of tight sandstone reservoir (Nian et al, 2016;Zhu et al, 2016;Zhou et al, 2019;Qiao et al, 2020). Continuous researches on diagenesis have made significant achievements in which multi-technological quantitative evaluation is used (Hao et al, 2010;Guo et al, 2018;Qin et al, 2018;Xi et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

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Quantitative Evaluation of Tight Sandstone Reservoir Based on Diagenetic Facies—A Case of Lower Silurian Kepingtage Formation in Shuntuoguole Low Uplift, Tarim Basin, China

Zhang²,

Xia

et al. 2021

Front. Earth Sci.

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The tight sandstone reservoirs of the Lower Silurian Kepingtage Formation are important exploratory targets for tight gas resources in the Shuntuoguole Low Uplift of Tarim Basin. How to evaluate tight sandstone reservoir is an urgent problem to be solved. In this study, we investigated the effects of diagenesis on the heterogeneity of tight sandstone deposits in similar sedimentary facies and established the relationship between the diagenetic facies and reservoir quality. Cores of the tight sandstone reservoirs of Lower Silurian Kepingtage Formation in Shuntuoguole Low Uplift are studied with thin section observation, SEM, XRD, and mercury injection. Quantification of diagenesis influencing porosity suggests that sandstone densification is mainly controlled by compaction, cementation, and hydrocarbon charging (bitumen charging), and the reservoir properties are effectively improved by dissolution, based on which 6 types of diagenetic facies are classified. Interpretation of the log data from individual wells with “K nearest neighbor” algorithm concludes that top and base of the upper member of Kepingtage Formation are believed to have favorably diagenetic reservoirs mainly falling in Type V; favorably diagenetic facies develop best in the lower member of Kepingtage Formation predominated by Types V and VI which mainly distribute in its top. Composite analysis of diagenetic facies, sedimentary facies, and porosity distribution shows that the favorable area of further exploration and development is east of Well SH903 and north of Well SH10. The quantitative identification of diagenetic facies based on logging information can provide reasonable results for the evolution of the tight sandstone reservoirs for a similar area in the Tarim Basin.

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Sedimentary characteristics, formation conditions, and distribution mechanisms of beach bar sand bodies of Chang 8₂ submember, southwest Ordos Basin

Liao,

Xiao,

Long

et al. 2024

Energy Science & Engineering

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Beach bar sand bodies are a relatively new type of reservoir in oil exploration where they can be found in the proximity of the source rock. In this study, the genetic type of sand bodies in the Upper Triassic Yanchang Formation in the southwest Ordos Basin is systematically studied through the observation of outcrops, core description, microscopic inspection of thin sections, along with petrophysical properties, mineralogy, and geochemical analysis of trace elements. The results showed that a new sedimentary type of beach bar sand bodies are developed in the Chang 82 submember of the Yanchang Formation, that are generally characterized with a flat bottom and convex top, where the contact interface between the bottom of the single sand body and mudstone is flat, and the bottom lacks erosion and filling structure. Moreover, a variety of wave‐induced sedimentary structures are developed, showing a reverse sedimentary sequence from fine to coarse grains. The structural and compositional maturity of the beach bar sand bodies are higher than that of the river channel sand body. Moreover, reservoir pore type is mainly comprised of intergranular pores, and the porosity and permeability of the samples retrieved from the sand body are much higher than that of the river channel sand body. Finally, the main controlling factors of the formation and preservation of beach bar sands are found to be the lake basin bottom topography, the base level cycle, and the stable paleo‐lake shoreline. During the Chang 82 submember depositional period, a large area where the beach bar sand bodies were deposited parallel to the lake shoreline in the southwest of the basin was created. Such depositional environments had suitable conditions to host large‐scale oil‐bearing reservoirs, as major exploration and development targets in the Ordos Basin in the future.

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Impacts of sedimentology and diagenesis on pore structure and reservoir quality in tight oil sandstone reservoirs: Implications for macroscopic and microscopic heterogeneities

Cited by 65 publications

References 69 publications

Pore Structure Fractal Characterization and Permeability Simulation of Natural Gas Hydrate Reservoir Based on CT Images

Pore Structure Fractal Characterization and Permeability Simulation of Natural Gas Hydrate Reservoir Based on CT Images

Quantitative Evaluation of Tight Sandstone Reservoir Based on Diagenetic Facies—A Case of Lower Silurian Kepingtage Formation in Shuntuoguole Low Uplift, Tarim Basin, China

Sedimentary characteristics, formation conditions, and distribution mechanisms of beach bar sand bodies of Chang 8₂ submember, southwest Ordos Basin

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Impacts of sedimentology and diagenesis on pore structure and reservoir quality in tight oil sandstone reservoirs: Implications for macroscopic and microscopic heterogeneities

Cited by 65 publications

References 69 publications

Pore Structure Fractal Characterization and Permeability Simulation of Natural Gas Hydrate Reservoir Based on CT Images

Pore Structure Fractal Characterization and Permeability Simulation of Natural Gas Hydrate Reservoir Based on CT Images

Quantitative Evaluation of Tight Sandstone Reservoir Based on Diagenetic Facies—A Case of Lower Silurian Kepingtage Formation in Shuntuoguole Low Uplift, Tarim Basin, China

Sedimentary characteristics, formation conditions, and distribution mechanisms of beach bar sand bodies of Chang 82 submember, southwest Ordos Basin

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Sedimentary characteristics, formation conditions, and distribution mechanisms of beach bar sand bodies of Chang 8₂ submember, southwest Ordos Basin