“Double sweet spot” identification method via cluster analysis of petrophysical properties from well logg data: A case study of a tight sandstone reservoir

Zhou, Xin; Wei, Jiang; Hadavimoghaddam, Fahimeh; Gayubov, Abdumalik; Ostadhassan, Mehdi; Chen, Yinghe; Wang, Yuan; Yang, Bo; ogli, Ibragimov Jovdat Jamshid; Pu, Baoping; Zhang, Xiao; Liu, Songze

doi:10.1016/j.geoen.2023.211821

Cited by 7 publications

(3 citation statements)

References 17 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Fractures and vugs, referred to in this article as non-matrix-related pores, are of paramount importance in carbonate reservoirs, driving recent studies (e.g., [9,17,18]) focused on understanding their impact on storage, fluid flow, and oil production. However, an early step in understanding the impact of non-matrix-related pores is their identification.…”

Section: Of 35mentioning

confidence: 99%

“…Acknowledging the inherent uncertainty associated with the nature of data, recent emphasis has been on integrating data at various scales to enhance results. Several scholars, including [18,20,[22][23][24][25][26], have made considerable efforts to formulate methodologies focused on data integration to mitigate uncertainties and enhance the identification and characterization of distinct geological features.…”

Section: Of 35mentioning

confidence: 99%

“…The examination of conventional well logs through petrophysical analysis serves as a crucial methodology for delineating fundamental physical attributes of rocks, encompassing lithology, porosity, permeability, and water saturation ( [18,43,48]). Within the scope of this study, sonic and density logs served as pivotal tools for scrutinizing the isolated and synergistic behaviors of these well logs concerning porosity.…”

Section: Petrophysical Analysismentioning

confidence: 99%

See 2 more Smart Citations

Geological Insights from Porosity Analysis for Sustainable Development of Santos Basin’s Pre-Salt Carbonate Reservoir

Vásconez Garcia,

Mohammadizadeh,

Avansi

et al. 2024

Preprint

View full text Add to dashboard Cite

Carbonate reservoirs, influenced by depositional and diagenetic processes and characterized by features like faults and vugs that impact storage capacity, require more than traditional Borehole Imaging logs (BHI) for accurate porosity data. This data is essential for geological assessments, production forecasting, and reservoir simulations. This work aims to address this limitation by developing methods to measure and monitor the sustainability of carbonate reservoirs and exploring the application of sustainability principles to their management. The study integrates BHI and conventional logs from two wells to classify porosity-based facies within the Barra Velha Formation (BVF) in the Santos Basin. The methodology involves four steps: (i) analyzing conventional logs; (ii) segmenting BHI logs; (iii) integrating conventional and segmented BHI logs using Self-Organizing Maps (SOM); and (iv) interpreting the resulting classes. Matrix porosity values and non-matrix pore sizes categorize the porosity into four facies (A to D). Facies A has high non-matrix porosity with 14,560 small megapores, 5,419 large megapores, and 271 gigapores (71.9%, 26.76%, and 1.34% of the 20,250 pores, respectively). Facies B shows moderate non-matrix porosity with 8,669 small megapores, 2,642 large megapores, and 33 gigapores (76.42%, 23.29%, and 0.29% of the 11,344 pores, respectively) and medium matrix porosity. Facies C exhibits low non-matrix porosity with 7,749 small megapores, 2,132 large megapores, and 20 gigapores (78.27%, 21.53%, and 0.20% of the 9,901 pores, respectively) and medium matrix porosity. Facies D has low non-matrix porosity with 9,355 small megapores, 2,346 large megapores, and 19 gigapores (79.82%, 20.02%, and 0.16% of the 11,720 pores, respectively) and low matrix porosity. The novelty of this work lies in integrating data from two sources to classify porosity across the Pre-Salt reservoir interval, serving as a proxy for preliminary litho-facies identification without core data. This study advances our understanding of carbonate reservoir sustainability and heterogeneity, offering valuable insights for robust, sustainable reservoir characterization and management in the context of global environmental and geological changes.

show abstract

Section: Of 35mentioning

confidence: 99%

Section: Of 35mentioning

confidence: 99%

Section: Petrophysical Analysismentioning

confidence: 99%

See 1 more Smart Citation

Geological Insights from Porosity Analysis for Sustainable Development of Santos Basin’s Pre-Salt Carbonate Reservoir

Vásconez Garcia,

Mohammadizadeh,

Avansi

et al. 2024

Preprint

View full text Add to dashboard Cite

show abstract

Analysis of the impact of geological and engineering parameters on productivity in tight oil reservoirs

Li,

Zhou,

et al. 2024

Can J Chem Eng

View full text Add to dashboard Cite

Tight oil resources are abundant, but the factors affecting production capacity are complex. In this paper, focusing on tight oil reservoirs, three research works were conducted. First, using the numerical simulation software, a numerical model of tight oil reservoirs was established. Second, the influence of geological parameters such as porosity and permeability on oil production were analyzed. Third, the influence of rock compression coefficient and injection fluid on tight oil production were analyzed. Results show that: (a) When the porosity is 0.05, the cumulative oil production in the first 6 years is the highest, while in the later stage of the simulation, the cumulative oil production with a porosity of 0.1 is the highest. (b) The higher the permeability, the greater the cumulative oil production. The cumulative oil production under different permeability conditions are 1392.044, 2178.805, 2939.1704, and 4038.0878 m3, respectively. (c) Under tight reservoir conditions, the impact of different rock compression coefficients on the daily oil production of oil and gas reservoirs is not very significant. (d) The recovery effect is optimal when using the N2 injection scheme. The effectiveness of the CH4 scheme is second, and there is a certain gap compared to the N2 scheme. The development plan of injecting water has the worst effect. However, compared to the depletion development model, the cumulative oil production by injecting N2, CO2, CH4, and water has all increased.

show abstract

Control of fracture toughness of kerogen on artificially-matured shale samples: An energy-based nanoindentation analysis

Zhang,

Zhao

2024

Gas Science and Engineering

View full text Add to dashboard Cite

“Double sweet spot” identification method via cluster analysis of petrophysical properties from well logg data: A case study of a tight sandstone reservoir

Cited by 7 publications

References 17 publications

Geological Insights from Porosity Analysis for Sustainable Development of Santos Basin’s Pre-Salt Carbonate Reservoir

Geological Insights from Porosity Analysis for Sustainable Development of Santos Basin’s Pre-Salt Carbonate Reservoir

Analysis of the impact of geological and engineering parameters on productivity in tight oil reservoirs

Control of fracture toughness of kerogen on artificially-matured shale samples: An energy-based nanoindentation analysis

Contact Info

Product

Resources

About