Flow unit modeling and fine-scale predicted permeability validation in Atokan sandstones: Norcan East field, Kansas

Bhattacharya, Saibal; Byrnes, Alan P.; Watney, W. Lynn; Doveton, John H.

doi:10.1306/01140807081

Cited by 32 publications

(14 citation statements)

References 40 publications

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“…For reservoir evaluation at the field scale and regional description, up-scaling is crucial. However, careful selection of flow units may reduce or eliminate the necessity of up-scaling reservoir models for simulation (Bhattacharya et al, 2008). Flow modelling using flow units derived from SML plots has an upscaling concept and is useful for field-scale investigations (Fig.…”

Section: Discussionmentioning

confidence: 99%

“…A flow unit is a part of a reservoir which has lateral and vertical continuity and homogeneous flow and bedding characteristics (Hearn et al, 1984). Flow units can be used to divide a reservoir into geobodies appropriate for flow simulation (Bhattacharya et al, 2008) and to investigate production behaviour. Flow unit modelling can be used in field development planning, water flooding programmes and the dynamic simulation of hydrocarbon production (Borgomano et al, 2008), as well as to predict reservoir performance.…”

Section: Introductionmentioning

confidence: 99%

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Flow Unit Characterisation in the Permian‐triassic Carbonate Reservoir Succession at South Pars Gasfield, Offshore Iran

Enayati-Bidgoli

Rahimpour‐Bonab

Mehrabi

2014

Journal of Petroleum Geology

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The South Pars gasfield (offshore southern Iran) has been investigated in detail in recent studies in terms of depositional, diagenetic and reservoir properties of the Permian-Triassic carbonate succession. In the present paper, a variety of flow unit approaches were applied to identify reservoir (flow) and non-reservoir (baffle or barrier) units within the Permian-Triassic carbonates. The zonation scheme was based on three approaches; (i) flow units were identified using the stratigraphic modified Lorenz plot (SMLP) method; (ii) hydraulic flow units were identified using a parameter known as the flow zone indicator (FZI); and (iii) petrophysical flow units (PFUs) were determined using the pore throat radius (R 35 ) and water saturation (S w ) parameters. Studies of flow units at both macro-and micro-scales showed that flow properties were controlled by both depositional and diagenetic features. In order to construct a reservoir flow model, the flow units and PFUs were correlated between the four wells studied within a sequence stratigraphic framework. SMLP-derived flow units appeared to be distributed homogenously within the reservoir succession resulting in a layer-cake architecture. By contrast, the FZI-derived hydraulic flow units drew attention to the presence of small-scale heterogeneities within the reservoir. A comparison between these methods showed that the flow model derived from PFUs included greater vertical and horizontal heterogeneities, especially in the Upper Dalan Member (upper K4 reservoir unit). This was due to depositional/diagenetic heterogeneities in both lateral and vertical directions, and the parameters applied in the PFU method. The PFU-derived flow model showed a closer relationship to the actual reservoir performance than the flow units derived by the other methods and can therefore be used as the basis for future dynamic flow simulation.

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Section: Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Flow Unit Characterisation in the Permian‐triassic Carbonate Reservoir Succession at South Pars Gasfield, Offshore Iran

Enayati-Bidgoli

Rahimpour‐Bonab

Mehrabi

2014

Journal of Petroleum Geology

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“…The Gunter et al (1997a), method was adopted to subdivide the reservoirs into Flow units. Flow unit demarcation is useful in reservoir modeling and flow simulation (Amaefule et al, 1993;Bhattacharya et al, 2008;Rahimpour-Bonab et al, 2012;. Gunter et al (1997a;1997b) presented a graphical method for quantifying the flow units according to the petrophysical rock/pore types, flow and storage capacities (Kh) and (Фh) and reservoir process speed (K/Ф).…”

Section: Methodsmentioning

confidence: 99%

“…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: 97%

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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“…Flow units of reservoirs show lateral and vertical continuity in their flow and bedding characteristics and can be practical for classifying a reservoir to distinctive zones (geobodies) with unique flow regime [30] and [31]. These units represent reservoir heterogeneity from well to field scales [11].…”

Section: Hydraulic Flow Units (Hfu)mentioning

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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Flow unit modeling and fine-scale predicted permeability validation in Atokan sandstones: Norcan East field, Kansas

Cited by 32 publications

References 40 publications

Flow Unit Characterisation in the Permian‐triassic Carbonate Reservoir Succession at South Pars Gasfield, Offshore Iran

Flow Unit Characterisation in the Permian‐triassic Carbonate Reservoir Succession at South Pars Gasfield, Offshore Iran

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

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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