Pore system characterisation in heterogeneous carbonates: An alternative approach to widely-used rock-typing methodologies

Hollis, Cathy; Vahrenkamp, Volker; Tull, Simon; Mookerjee, Abhijit; Taberner, C.; Huang, Yaduo

doi:10.1016/j.marpetgeo.2009.12.002

Cited by 158 publications

(96 citation statements)

References 25 publications

(23 reference statements)

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“…According to (10), water saturation, porosity, permeability, and oil column height relationship can be obtained by multiple regressions. The oil column height can be calculated based on the depth difference between water/oil contact and grid depth, and the water saturation is calculated for each grid.…”

Section: D Water Saturation Modelmentioning

confidence: 99%

“…Rock typing is an essential step in the process of the carbonate reservoir characterization and geological modeling, and it is the method of classifying reservoir rocks which have the same fluid flow features into groups [1][2][3][4][5][6]. Rock typing is an effective way to obtain accurate permeability, and it enables us to get better understanding of the fluid movement and to enhance oil recovery [7][8][9][10][11].…”

Section: Introductionmentioning

confidence: 99%

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Numerical Simulation Modeling of Carbonate Reservoir Based on Rock Type

Lian

et al. 2017

Journal of Engineering

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There are many types of carbonate reservoir rock spaces with complex shapes, and their primary pore structure changes dramatically. In order to describe the heterogeneity of carbonate reservoir, equations of porosity, permeability, and pore throat radii under different mercury injection saturations are fitted, and it shows that 30% is the best percentile. 30 method is presented for rock typing, and six rock types are divided according to 30 value of plugs. The porosity-permeability relationship is established for each rock type, and the relevant flow characteristics of each rock type have been studied. Logs are utilized to predict rock types of noncored wells, and a three-dimensional (3D) rock type model has been established based on the well rock type curves and the sedimentary facies constraint. Based on the relationship between function and water saturation, the formula of water saturation, porosity, permeability, and oil column height can be obtained by multiple regressions for each rock type. Then, the water saturation is calculated for each grid, and a 3D water saturation model is established. The model can reflect the formation heterogeneity and the fluid distribution, and its accuracy is verified by the history matching.

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Section: D Water Saturation Modelmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Numerical Simulation Modeling of Carbonate Reservoir Based on Rock Type

Lian

et al. 2017

Journal of Engineering

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“…Cement precipitation (drusy or blocky) and/or by matrix during deposition or post-deposition by compaction processes can clog the pores resulting in lower permeability (Tucker, 2009;Lucia, 2007). Drusy calcite cement is thought to be a sign of early diagenesis in a meteoric environment, whereas the saddle dolomite and the fluorite mineral are believed to be formed by circulation of hydrothermal fluids at a deep (Flügel, 2004;Tucker, 2009;Lambert et al, 2006;Hollis et al, 2010;Alsharhan and Nairn, 1990). It is also believed to have occurred after reaching burial depth of around 600 m at temperatures of around 65.6°C (Cox et al, 2010).…”

Section: Cementationmentioning

confidence: 99%

Petrographic and diagenetic studies of thick transition zone of a middle-east carbonate reservoir

Mohamed¹,

Belhaj²,

Gomes³

et al. 2017

J. Petroleum Gas Eng.

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This work aims to characterize petrographically some of the transition zone plug samples in order to understand the impact of diagenetic processes on the transition zone rock quality. Three carbonate samples were collected from the same well which cuts through a thick transition zone of a heterogeneous cyclic carbonate reservoir of Abu Dhabi with respect to depth. The petrographic analysis was conducted by the thin sections study and scanning electron microscope (SEM) imaging in order to interpret the main depositional facies, diagenetic features and how the poro-perm characteristics were affected by them. SEM analysis is utilized in order to observe and recognize in detail the diagenetic relationships between different mineral phases or cement types and to help in identifying the pore geometry. Diagenesis in the transition zone is very extensive especially affected by micritization and cementation. The diagenetic features are increasing with depth as the zone is having higher water saturations. The importance of this analysis is to better understand the rock fabric heterogeneity and capillary pressure behavior as a function of depth of thick carbonate transition zones.

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“…However, ignoring the geological controls such as pore space evolution is caused by the focus on grouping samples with consistent petrophysical properties, rather than geological characteristics. It is also problematic to achieve a fit-for-purpose rock-typing scheme separate from the influence of diagenetic processes on characteristics such as rock petrophysic, hydrocarbon recovery efficiency and fluid in-place volumes [1] [2] [3] [4] and [5]. Integrating large scale dynamic data to the wireline scale (small scale) is another inevitable challenge.…”

Section: Introductionmentioning

confidence: 99%

Inspecting the Reservoir Characteristics of the Burgan Formation of Soroosh Oil Field Applying Rock Typing Methods in the Context of Geological Studies

Ebrahimi¹,

Amini²,

Hajikazemi³

et al. 2017

OJG

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The Albian age Burgan Formation is one of the most important siliciclastic reservoirs in the Arabian Plate. Northwest of Persian Gulf is the main area in Iran invaded by these siliciclastic sediments. This study uses a new and comprehensive procedure to identify the reservoir characteristics of the Burgan Formation in Soroush oil field (NW Persian Gulf). Results from core and petrographic studies led identification of 7 microfacies (MF1 to MF7) that are grouped into 3 main facies association (FA1, to FA3). Results from reservoir characterization indicate a dramatic decrease in reservoir quality from bottom to top (FA1 toward FA3). Using the Flow Zone Indicator (FZI) method, 5 Hydraluic flow units (HFUs) were recognized in the formation. The HFUs are in a notable accordance with facies associations. The HFUs 1 and 2 correlate with theFA1, the HFUs 3 and 4 with the FA2 and the HFU5 cover intervals defined by FA3. Cluster analysis of wireline logs resulted in determination of 5 electrofacies (EF1 to EF5) which are in agreement with the ascertained HFUs. Inspecting the vertical distribution of FAs, HFUs and EFs, three distinct zones are determined. The lower zone is characterized by good reservoir quality, abundance of FA1, HFUs1 and 2 and also EFs 1 and 2 is observed there. The middle zone with a moderate reservoir quality and upper zone presents the poorest quality. In the middle zone FA2, HFUs3 and 4 and also EFs 3 and 4 are more abundant while in the upper one interval are clearly correlated with FA3, HFU5 and also EF5.

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Pore system characterisation in heterogeneous carbonates: An alternative approach to widely-used rock-typing methodologies

Cited by 158 publications

References 25 publications

Numerical Simulation Modeling of Carbonate Reservoir Based on Rock Type

Numerical Simulation Modeling of Carbonate Reservoir Based on Rock Type

Petrographic and diagenetic studies of thick transition zone of a middle-east carbonate reservoir

Inspecting the Reservoir Characteristics of the Burgan Formation of Soroosh Oil Field Applying Rock Typing Methods in the Context of Geological Studies

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