Determining permeability cut-off values for net pay study of a low-permeability clastic reservoir: A case study of the Dongying Sag, eastern China

Yang, Tian; Cao, Yingchang; Wang, Yanzhong; Liu, Keyu; He, Chen; Zhang, Shaomin

doi:10.1016/j.petrol.2019.03.030

Cited by 21 publications

(6 citation statements)

References 17 publications

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“…Consequently, effective porosity cut-off 8%, permeability cut-off of 1mD, and water saturation cut-off of 65% were used to estimate net pay intervals. The net pay refers to the interval or portion of the rock that can contain hydrocarbon (Yang et al 2019).…”

Section: Petrophysical Analysismentioning

confidence: 99%

Static reservoir modeling using stochastic method: a case study of the cretaceous sequence of Gamtoos Basin, Offshore, South Africa

Ayodele

Chatterjee

Opuwari

2021

J Petrol Explor Prod Technol

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Gamtoos Basin is an echelon sub-basin under the Outeniqua offshore Basin of South Africa. It is a complex rift-type basin with both onshore and offshore components and consists of relatively simple half-grabens bounded by a major fault to the northeast. This study is mainly focused on the evaluation of the reservoir heterogeneity of the Valanginian depositional sequence. The prime objective of this work is to generate a 3D static reservoir model for a better understanding of the spatial distribution of discrete and continuous reservoir properties (porosity, permeability, and water saturation). The methodology adopted in this work includes the integration of 2D seismic and well-log data. These data were used to construct 3D models of lithofacies, porosity, permeability, and water saturation through petrophysical analysis, upscaling, Sequential Indicator Simulation, and Sequential Gaussian Simulation algorithms, respectively. Results indicated that static reservoir modeling adequately captured reservoir geometry and spatial properties distribution. In this study, the static geocellular model delineates lithology into three facies: sandstone, silt, and shale. Petrophysical models were integrated with facies within the reservoir to identify the best location that has the potential to produce hydrocarbon. The statistical analysis model revealed sandstone is the best facies and that the porosity, permeability, and water saturation ranges between 8 and 22%, 0.1 mD (< 1.0 mD) to 1.0 mD, and 30–55%. Geocellular model results showed that the northwestern part of the Gamtoos Basin has the best petrophysical properties, followed by the central part of the Basin. Findings from this study have provided the information needed for further gas exploration, appraisal, and development programs in the Gamtoos Basin.

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Section: Petrophysical Analysismentioning

confidence: 99%

Static reservoir modeling using stochastic method: a case study of the cretaceous sequence of Gamtoos Basin, Offshore, South Africa

Ayodele

Chatterjee

Opuwari

2021

J Petrol Explor Prod Technol

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“…The key case layer L6-3 is one of the 11 non-main force layers in this study. Previous studies have shown that the main-force layers are mainly of distributary channel deposits Lin, 2007;Yang et al, 2019;Zhu et al, 2020) (i.e. sand-rich river channel microfacies), and non-main force layers are natural embankments and crevasse spray deposits (i.e.…”

Section: Geological Settingsmentioning

confidence: 99%

Detailed quantitative description of fluvial reservoirs: A case study of L6-3 Layer of Sandgroup 6 in the second member of Shahejie Formation, Shengtuo Oilfield, China

Yan

Ren

et al. 2020

Adv. Geo-Energ. Res.

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“…Compared with conventional reservoirs, the development of tight reservoirs faces greater difficulties and challenges; the research methods applied in conventional reservoirs cannot meet the production requirements in tight reservoirs, and the poor evaluation of parameters during the exploration period can have various effects on later production [9]. Among them, the identification of reservoir effectiveness as a key task in the identification of fluid property, reserve calculation, and the formulation of development plans [10][11][12][13][14] has always been a research hotspot and a major problem for scholars in related fields internationally, especially for complex reservoirs such as tight gas reservoirs.…”

Section: Introductionmentioning

confidence: 99%

A Method for Judging the Effectiveness of Complex Tight Gas Reservoirs Based on Geophysical Logging Data and Using the L Block of the Ordos Basin as a Case Study

2023

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As an important unconventional oil and gas resource, the tight gas reservoir faces many technical challenges due to its low porosity, low permeability, and strong heterogeneity. Among them, the accurate definition of effective reservoirs and ineffective reservoirs in tight gas reservoirs directly affects the formulation and adjustment of subsequent development plans. This paper proposes a reservoir effectiveness identification method based on double factors based on conventional geophysical logging data and core experimental data. The double factors considered are based on the logging response and physical parameters of the reservoir. The identification factor F1 is obtained by using the difference in the logging response values of the natural gamma logging curve, compensated density logging curve, and acoustic time difference logging curve in different reservoirs combined with mathematical operation, and the identification factor F2 is calculated by using porosity parameters combined with Archie’s formula. The validity of the reservoir can be judged by the intersection of the above double factors. This method is applied to the Shihezi Formation in the L block, and the applicability of the double factors is compared and analyzed using the traditional method. The results show that the method has strong applicability in tight gas reservoirs and that the accuracy rate reaches 96%. Compared with the direct use of the porosity lower limit method, the accuracy of the judgment is significantly improved, and the calculation is simple, easy to implement, and unaffected by mud invasion. For study areas with different geological backgrounds, the process of this method can also be used to determine the effectiveness of the reservoir. The reservoir effectiveness identification method proposed in this paper has practical engineering significance and lays a solid foundation for subsequent fluid property identification, production calculation, and development plan formulation and adjustment.

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Determining permeability cut-off values for net pay study of a low-permeability clastic reservoir: A case study of the Dongying Sag, eastern China

Cited by 21 publications

References 17 publications

Static reservoir modeling using stochastic method: a case study of the cretaceous sequence of Gamtoos Basin, Offshore, South Africa

Static reservoir modeling using stochastic method: a case study of the cretaceous sequence of Gamtoos Basin, Offshore, South Africa

Detailed quantitative description of fluvial reservoirs: A case study of L6-3 Layer of Sandgroup 6 in the second member of Shahejie Formation, Shengtuo Oilfield, China

A Method for Judging the Effectiveness of Complex Tight Gas Reservoirs Based on Geophysical Logging Data and Using the L Block of the Ordos Basin as a Case Study

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