Permeability Estimation Using Hydraulic Flow Units in a Central Arabia Reservoir

Al-Ajmi, Fahad; Aramco, Saudi; Holditch, Stephen A.

doi:10.2118/63254-ms

Cited by 58 publications

(20 citation statements)

References 2 publications

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“…After the FZI core analysis, we transposed the cut-off values to the well log data, using the magnetic resonance porosity and Schlumberger-Doll-Research permeability (Al-Ajmi and Holditch, 2000). Figure 4 shows an example of the FZI cutoff discretization in Well 7, as well as some relevant well logs for comparison.…”

Section: Rock Typing For Seismic Flow Unitsmentioning

confidence: 99%

3D Seismic Flow Units and Petrophysical Property Modelling in Brazilian Pre-salt Reservoirs

Penna

Lupinacci

2021

Braz J Geophys

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Abstract. Rock typing into flow units (FU) is a well-known technique for characterizing flow heterogeneities in reservoirs and producing reliable estimations of petrophysical properties. Despite the large availability of methods that correlate a specific pore-throat size to petrophysical attributes, extrapolating FU rock typing from the core and well log scales into the whole reservoir is a major challenge due to the scale differences between data and the lack of correlation with the common-used sedimentological facies. Most 3D generations of flow units and petrophysical property studies available in the literature are merely a geostatistical procedure, without any spatial data constraints in the 3D seismic data. We propose a new approach to discretize flow units in the core and well logs considering the decametric scale characteristics of the seismic data, generating a 3D model of FU facies and calculating porosities and permeabilities that are more accurate than the usual estimation based on sedimentary facies. Despite the complexity of the geological setting and the reduced number of FU, we produced volumes of permeability and porosity that are still capable of obtaining complex reservoir flow characteristics and could be directly considered as variables in lateral interpolation of reservoir parameters, seismic 4D interpretations and seismic-assisted history matching.Keywords: flow unit, pre-salt reservoir, porosity modelling, permeability modelling.Modelagem sísmica 3D de unidades de fluxo e de propriedades petrofísicas em reservatórios do pré-sal brasileiroResumo. A tipagem de rochas em unidades de fluxo (FU) é uma técnica conhecida para caracterizar heterogeneidades de fluxo em reservatórios e produzir estimativas confiáveis de propriedades petrofísicas. Apesar da grande disponibilidade de métodos que correlacionam um tamanho específico de garganta de poro a atributos petrofísicos, extrapolar a tipagem de rocha feita em testemunho e/ou perfil de poço para todo o reservatório é um desafio, principalmente devido às diferenças de escala entre os dados e à falta de correlação das FU com fácies sedimentológicas. A maioria dos exemplos de gerações 3D de unidades de fluxo e de propriedades petrofísicas são meramente um procedimento geoestatístico, sem quaisquer restrições de dados espaciais com os dados sísmicos. Propomos uma abordagem para discretizar unidades de fluxo em amostras laterais e nos poços considerando as características da escala decamétrica dos dados sísmicos, gerando um modelo 3D de fácies FU e calculando porosidades e permeabilidades, que são mais precisas do que a estimativa baseada em fácies sedimentares. Apesar da complexidade geológica e do número reduzido de FU, produzimos volumes de permeabilidade e porosidade que são capazes de obter características de fluxo de reservatório complexas e podem ser considerados como variáveis na interpolação lateral de parâmetros de reservatório, interpretações sísmicas 4D e no ajuste de histórico assistido por sísmica.Palavras-chave: unidade de fluxo, reservatório pré-sal, modelagem de porosidade, modelagem de permeabilidade.

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Section: Rock Typing For Seismic Flow Unitsmentioning

confidence: 99%

3D Seismic Flow Units and Petrophysical Property Modelling in Brazilian Pre-salt Reservoirs

Penna

Lupinacci

2021

Braz J Geophys

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“…The Hydraulic Unit concept [50] can be used to divide a reservoir into distinct petrophysical types, each with a unique Flow Zone Indicator (FZI) value [53]. Kozeny (1927) and Carmen (1937) [54] [55] simulated a porous medium as a bundle of capillary tubes that combine Darcy's law for flow in a porous medium and Poiseuille's law for flow in a tube.…”

Section: Hydraulic Flow Unit (Hfu) Determination Using a Flow Zone Inmentioning

confidence: 99%

Investigation of Microfacies—Electrofacies and Determination of Rock Types on the Aptian Dariyan Formation NW Persian Gulf

Rezaeeparto¹,

Rahimpour‐Bonab²,

Kadkhodaie³

et al. 2016

OJG

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Dariyan (Shuaiba) Formation is one of the main reservoir units in the Persian Gulf and South Western Iran. The microfacies and depositional environment of this formation is been investigated in the current study and influencing factors in reservoir characteristics have been discussed for Dariyan reservoir in the Soroush oil field. Facies analysis conducted on core and cutting samples indicated that Dariyan Formation is mainly deposited on a carbonate ramp setting with a shallow intra shelf basin. In addition, it has been demonstrated that facies changes reflect the main controls of the tectonic and climate (sea level fluctuations) during the deposition of these sediments. To determine the reservoir unites in this formation, 5 electrofacies were determined by neural network method that it is using different petrophysical logs (i.e. GR, PHIE and SWE). Using rock typing as the best way to establish an association between the various collected data (e.g. logs and cores) and geological descriptions 4 hydraulic flow units or rock types, determined on the basis of the Flow Zone Indicator (FZI) method in the Dariyan Formation of the Soroush field. Establishing a correlation between microfacies and rock types, the carbonate zones with moderate to good reservoir properties and also the intervals with the highest reservoir quality were determined.

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“…The concept of hydraulic flow unit and petrophysics have been well documented in recent time (Amaefule et al, 1993;Abbaszadeh et al, 1996;Gunter et al, 1997a;1997b;Porras et al, 1999;Al-Ajmi and Holditch, 2000;Yasin et al, 2001;Rushing and Newsham, 2001b;Aguilera and Aguilera, 2002;Civan, 2003;Tiab and Donaldson, 2004;Perez et al, 2005;Taslimi et al, 2008;Bhattacharya et al, 2008;Rahimpour-Bonab et al, 2012). In this study, the Stratigraphic Modified Lorenzo Plots by Gunter et al, (1997a) and adopted by Rahimpour-Bonab et al (2014), will be adopted to identify flow units and also to understand the hydraulic behaviour of sand-bodies deposited within a specific depositional environment.…”

Section: Introductionmentioning

confidence: 96%

Petrophysical Characterization and Flow Models for Agbada Reservoirs, Onshore Niger Delta, Nigeria

Momta

Etu-Efeotor

Ugwueze

2015

American Journal of Geoscience

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Three selected reservoirs (XB, XC and XE) from three wells (A, B and C) occurring within the Agbada producing sands in part of the Greater Ughelli Depobelt of the onshore Niger Delta have been studied. The study aims at evaluating the petrophysical characteristics of the sandbodies and also identifies the various flow units present within each reservoir. Petrophysical parameters were used as input data to generate the Stratigraphic Modified Lorenzo Plots (SMLP). This model uses a graphical method to quantitatively determine flow units and to understand the flow and storage capacities of sedimentary rocks. Results of the analysis shows that average porosity and permeability range is between 7-28.8% and 1.20-529 mD, indicating poor to very good reservoir quality in different parts of the field. Generally, porosity and permeability decrease with increasing depth in the field reflecting burial diagenetic porosity loss in response to increasing thermal exposure with depth. Porosity and permeability change laterally across the field from west to east. Increase in porosity and permeability towards the eastern part of the field reflects lateral change in facies. Well C has the best porosity (28%) and permeability (529 mD), lowest water saturation (0.01), hence, highest hydrocarbon prospect. The stratigraphic Modified Lorenzo Plots (SMLP) revealed a total of seventy five (75) Flow Units (FU) in the three studied reservoirs. Each reservoir displays similar flow pattern relative to others suggesting that facies (rock properties) have a strong control on flow in each reservoir. Generally, poor quality units occur towards the bottom of each reservoir in a well and good quality units towards the top. The dominant flow units in the three reservoirs fall within the high storage and flow (normal flow unit) unit category, suggesting that the dominant depositional setting (shallow marine shoreface/beach/barrier) and facies type beside diagenetic effects play significant role in fluid dynamic behaviour of any rock body. Depositional environments and subsequent diagenesis are the primary factors controlling porosity distribution, pore connectivity and fluid flow in the three studied reservoirs.

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Permeability Estimation Using Hydraulic Flow Units in a Central Arabia Reservoir

Cited by 58 publications

References 2 publications

3D Seismic Flow Units and Petrophysical Property Modelling in Brazilian Pre-salt Reservoirs

3D Seismic Flow Units and Petrophysical Property Modelling in Brazilian Pre-salt Reservoirs

Investigation of Microfacies—Electrofacies and Determination of Rock Types on the Aptian Dariyan Formation NW Persian Gulf

Petrophysical Characterization and Flow Models for Agbada Reservoirs, Onshore Niger Delta, Nigeria

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