Rock typing of coquinas from the Morro do Chaves Formation

Lima, Maria Luiza Cunha; Martins, Léo Anderson Meira; Rios, Edmilson Helton; Boyd, A. K.; Pontedeiro, Elizabeth M.; Hoerlle, Fernanda; Lipovetsky, T.; Neto, Agostinho Fernandes Sobreiro; Mendes, M. A. S.; Borghi, Leonardo; Couto, P.

doi:10.22564/16cisbgf2019.290

Cited by 2 publications

(2 citation statements)

References 5 publications

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“…Rock Types composed of highly clayey lithologies had lower average porosity than those with lower matrix and cement contents than bioclasts, especially highly fragmented ones. When associated with dissolution events, diagenesis enhances permeability-porosity properties in rocks, but can also markedly reduce porosity if associated with compaction and cementation events (Corbett et al 2017;Lima et al 2019;Nunes et al 2021).…”

Section: Rock Typesmentioning

confidence: 99%

Petrophysical Characterization and porosity-permeability log calculation by Dual-Energy CT scan: Morro do Chaves Formation, Sergipe-Alagoas Basin, Brazil

Mendes

Favoreto

Nunes

et al. 2023

Anu. Inst. Geociênc.

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Considered important analogues of pre-salt reservoirs in hydrocarbon-producing basins throughout eastern Brazilian shore, the coquinas of the Morro do Chaves Formation (Barremian-Aptian of the Sergipe-Alagoas Basin) were studied in this work from a petrophysical standpoint using advanced characterization methods for cores recovered from four wells (2-SMC-01-AL, 2-SMC-02-AL, 2-SMC-03-AL e 2-SMC-01-AL) drilled in the Atoll Quarry, which is located in city of São Miguel dos Campos, Alagoas State, Brazil. To understand the relationships between lithological and diagenetic heterogeneities that control the distribution of permeability-porosity properties of this rock type, the cores underwent Dual-Energy X-ray imaging, which determines bulk density and photoelectric factor data to define seven rock types and generate effective porosity curves for the studied wells. Permeabilities in wells were modeled based on the Flow Zone Index (FZI) concept, and each reservoir interval based on the Global Hydraulic Elements (GHEs) approach. Results were calibrated with laboratory measurements in plugs, and porosity was classified by petrographic analysis by Digital Image Analysis (DIA). All wells were correlated and four internal flooding surfaces identified, with a regressive surface (RS) dividing the Morro do Chaves Formation into an upper section with better reservoir characteristics and a lower one with worse ones.

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Section: Rock Typesmentioning

confidence: 99%

Petrophysical Characterization and porosity-permeability log calculation by Dual-Energy CT scan: Morro do Chaves Formation, Sergipe-Alagoas Basin, Brazil

Mendes

Favoreto

Nunes

et al. 2023

Anu. Inst. Geociênc.

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“…Petrophysical analyses of these rocks indicate extreme heterogeneity in their lithology. Sedimentation and diagenetic action much affected their pore and particle size distributions and original shape (Sun et al 2016), ultimately reflected in the permeability and percolation properties of these rocks (Lima et al 2019). Understanding the petrophysical properties of carbonate rocks is essential for better assessment and exploration of hydrocarbon reservoirs (Sun et al 2016).…”

Section: Introductionmentioning

confidence: 99%

Petrophysical Correlations for the Permeability of Coquinas (Carbonate Rocks)

et al. 2020

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The pore structure of many carbonate formations is known to be very complex and heterogeneous. Heterogeneity is manifested by the presence of different types, sizes, and shapes of pores resulting from sedimentation and diagenetic actions. These complexities greatly increase uncertainties in estimated rock hydraulic properties in that different permeability values may occur for samples having similar porosities. In order to understand the effects of pore structure and heterogeneity, petrophysical analyses were performed on coquina samples from the Morro do Chaves Formation (Barremian, Sergipe-Alagoas Basin), which is an analogue of Brazilian Pre-salt oil reservoirs of Itapema Formation in the Santos Basin. Routine core analyses, and NMR and MICP measurements were carried out to obtain pore body and pore throat distributions. Obtained T2 relaxation times were converted to pore size radii by matching the NMR and MICP curves. Pore-scale imaging and pore network modelling were performed using microCT scans and the PoreFlow software, respectively. Calculated permeabilities using PoreFlow showed excellent agreement with the routine laboratory measurements. Samples having pore bodies with a higher coordination number showed much larger permeabilities at similar porosities. This study includes a statistical analysis of various features that caused the observed differences in permeability of the coquinas, including the role of connectivity of the entire porous system. Limitations and challenges of the various techniques, and the imaging and pore-scale flow simulations, are discussed.

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Rock typing of coquinas from the Morro do Chaves Formation

Cited by 2 publications

References 5 publications

Petrophysical Characterization and porosity-permeability log calculation by Dual-Energy CT scan: Morro do Chaves Formation, Sergipe-Alagoas Basin, Brazil

Petrophysical Characterization and porosity-permeability log calculation by Dual-Energy CT scan: Morro do Chaves Formation, Sergipe-Alagoas Basin, Brazil

Petrophysical Correlations for the Permeability of Coquinas (Carbonate Rocks)

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