Diagenesis of tight sandstone and its influence on reservoir properties: A case study of Fuyu reservoirs in Songliao Basin, China

Si, Shanghua; He, Junhao; Zhao, Yutao; Er, Chuang; Bai, Yubin; Wu, Weitao

doi:10.1016/j.uncres.2022.12.002

Cited by 8 publications

(4 citation statements)

References 4 publications

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“…In the process of reservoir formation, diagenesis affects reservoir quality by controlling pore structure, – which is the main controlling factor of the lower limit of effective physical properties of reservoirs. The present burial depth of the lower E s 3 in Linnan Sag is 1600–3500 m, which belongs to the stage of middle diagenetic evolution .…”

Section: Discussionmentioning

confidence: 99%

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es₃ in the Jiangjiadian Area, Linnan Sag

Han,

Qi,

et al. 2023

ACS Omega

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The tight oil reservoir in Linnan Sag has great potential, a wide distribution range, and large total predicted resources. The rapid accumulation and burial of sediments in multiple source directions have resulted in the characteristics of low porosity and low permeability of the Lower Es 3 in the Jiangjiadian area, Linnan Sag. Based on conventional core analysis data, mercury injection data, and oil testing data, this paper comprehensively determines the lower limit of effective physical properties of reservoirs in the Jiangjiadian area of Linnan Sag and studies its main influencing factors. The results show that (1) the lower Es 3 reservoir in the Jiangjiadian area of Linnan Sag mainly develops feldspar sandstone and lithic feldspar sandstone. The porosity is mainly distributed at about 12%, and the permeability is mainly distributed at 0.3 mD; (2) based on the study of reservoir characteristics, the empirical statistical method based on core analysis data and the pore−permeability intersection method, the mercury injection parameter method based on test data, and the oil test verification method are used to comprehensively determine the lower limit of physical properties in the study area. The lower limit of porosity is 7.87%, and the lower limit of permeability is 0.16 mD; (3) sedimentation mainly affects the lower limit of physical properties by controlling reservoir lithology and pore structure. The existence of compaction and cementation in diagenesis will reduce the reservoir porosity and affect the lower limit of effective physical properties. The secondary dissolution pores formed by dissolution have a certain improvement effect on the effective physical properties of the reservoir.

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Section: Discussionmentioning

confidence: 99%

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es₃ in the Jiangjiadian Area, Linnan Sag

Han,

Qi,

et al. 2023

ACS Omega

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“…[9][10][11][12][13][14] In recent years, there has been an increasing focus on beach-bar sedimentary systems for exploring stratigraphic traps in various basins in eastern China. [15][16][17][18] Herein, beach bar sandstones are particular shallowwater deposits, with low mud content and good petrophysical properties. Most importantly, beach bar sandstones are generally covered by a thick layer of mudstone which creates a proper reservoir-cap combination, to trap hydrocarbons.…”

Section: Introductionmentioning

confidence: 99%

“…Overall, beach bar sand bodies have favorable conditions to become a target for hydrocarbon exploration activities due to their proximity to the oil source, good reservoir properties and well‐configuration of source, reservoir and cap rock, which is conducive to large‐scale oil and gas enrichment 9‐14 . In recent years, there has been an increasing focus on beach‐bar sedimentary systems for exploring stratigraphic traps in various basins in eastern China 15‐18 . Herein, beach bar sandstones are particular shallow‐water deposits, with low mud content and good petrophysical properties.…”

Section: Introductionmentioning

confidence: 99%

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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“…If the stress field simulation is carried out using an isotropic mechanical model, the accuracy of the simulation results will be greatly affected. Therefore, in this study, we divided the mechanical parameters into different regions based on the distributions of mechanical parameters of rocks, which could effectively improve the accuracy of the simulation results (Yang et al, 2021;Si et al, 2023).…”

Section: Introductionmentioning

confidence: 99%

Prediction of formation pressure based on numerical simulation of in-situ stress field: a case study of the Longmaxi formation shale in the Nanchuan area, eastern Chongqing, China

Zhang,

Chen,

Tang

et al. 2023

Front. Earth Sci.

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The in-situ stress and formation pressure are important parameters in shale gas development. They directly affect the well wall stability, the direction of horizontal well drilling, and the fracturing effect during the shale gas development process. There are abundant shale gas resources in the southeastern Chongqing-Sichuan area, but the structure in the area is complex, and it is difficult to predict the in-situ stress and formation pressure. Therefore, in this paper, a finite element simulation model was established based on a large number of seismic, logging, and experimental rock mechanics data and the prediction accuracy of the stress field simulation was effectively improved. The construction of the stress field was based on the combined spring model, as well as the data related to the measured in-situ stress and the formation pressure obtained during drilling. The coupling relationship between the in-situ stress, the formation strain, and the formation pressure were derived to carry out the prediction of the distributions of the formation pressure and the formation pressure coefficient. The prediction results showed that the present-day maximum principal stress direction in the study area was about NE65°–110°, and the present-day maximum principal stress was 56.12–93.79 MPa. The present-day minimum principal stress direction was about NE335°–20°, and the present-day minimum principal stress was 48.06–71.67 MPa. The formation pressure was 2.8–88.25 MPa, and the formation pressure coefficient was 0.74–1.55. The formation pressure distribution was greatly affected by fault, tectonic location, in-situ stress and rock petrophysical properties, and the overpressure areas of the formation were distributed in the synclines and the deeply buried areas. This study shows that the finite element based formation pressure prediction method is effective.

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Diagenesis of tight sandstone and its influence on reservoir properties: A case study of Fuyu reservoirs in Songliao Basin, China

Cited by 8 publications

References 4 publications

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es₃ in the Jiangjiadian Area, Linnan Sag

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es₃ in the Jiangjiadian Area, Linnan Sag

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

Prediction of formation pressure based on numerical simulation of in-situ stress field: a case study of the Longmaxi formation shale in the Nanchuan area, eastern Chongqing, China

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Diagenesis of tight sandstone and its influence on reservoir properties: A case study of Fuyu reservoirs in Songliao Basin, China

Cited by 8 publications

References 4 publications

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es3 in the Jiangjiadian Area, Linnan Sag

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es3 in the Jiangjiadian Area, Linnan Sag

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

Prediction of formation pressure based on numerical simulation of in-situ stress field: a case study of the Longmaxi formation shale in the Nanchuan area, eastern Chongqing, China

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Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es₃ in the Jiangjiadian Area, Linnan Sag

Determination of the Lower Limit of Physical Properties of Tight Oil Reservoirs: A Case Study of the Lower Es₃ in the Jiangjiadian Area, Linnan Sag

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