Geomechanical Properties of Unconventional Shale Reservoirs

Eshkalak, Mohammad O.; Mohaghegh, Shahab D.; Esmaili, Soodabeh

doi:10.1155/2014/961641

Cited by 37 publications

(19 citation statements)

References 12 publications

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“…As it is a well know phenomena, pressure dependency of gas creates non-linearity, therefore we used pseudo gas pressure definition by following [10]. In addition, Laplace theorem is used to solve partial differential mathematical expressions with following [20] technique, and [21] numerical conversion algorithm is used to obtain current time step production rate.…”

Section: Natural Fracture Modeling For Unconventional Reservoirsmentioning

confidence: 99%

Modeling and Simulation of Natural Gas Production from Unconventional Shale Reservoirs

Feast¹,

Boosari²,

Kim³

et al. 2015

IJCCE

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Modeling and simulation of unconventional reservoirs are much more complicated than the conventional reservoir modeling, because of their complex flow characteristics. Mechanisms, which control the flow in the reservoir, are still under the investigation of researchers. However, it is important to investigate applications of mechanisms which are present to our knowledge. This paper presents the theory and applications of flow mechanisms in unconventional reservoir modeling. It is a well-known fact that most of the reservoir flow problems are non-linear due to pressure dependency of particular parameters. It is also widely accepted that fully numerical solutions are costly both computational and time wise. Therefore, the presented model in this paper follows semi-analytical solution methods. Gas adsorption in unconventional reservoirs is the major pressure dependent mechanism; in addition existence of natural fractures is also taken considerable attention. This paper aims to investigate combined effect of existence of natural fractures gas adsorption, and gas slippage effect while keeping the computational effort in acceptable range. Unlike the existing literature (Langmuir is widely used), BET multi-layer isotherm employed in this paper for gas adsorption modeling. A modified dual porosity modeling is used for natural fracture and gas slippage effect modeling. For model verification purposes a history matched is performed with real field data from Marcellus shale. The proposed model in this paper shows a good agreement with the field data. It is observed that BET isotherm models early time production performance more accurately than Langmuir isotherm. It is also concluded that gas adsorption significantly improves the production performances of unconventional reservoirs, with natural fractures. In addition, gas slippage has a slight effect in long term production.

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Section: Natural Fracture Modeling For Unconventional Reservoirsmentioning

confidence: 99%

Modeling and Simulation of Natural Gas Production from Unconventional Shale Reservoirs

Feast¹,

Boosari²,

Kim³

et al. 2015

IJCCE

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“…Bhatt (2002) generate synthetic density, resistivity, and neutron logs using other well-logs and location data as input. Eshkalak et al (2013Eshkalak et al ( , 2014 create artificial geomechanical logs and Johnson et al 2018predict geochemical logs with ML. All results are promising and motivate other researchers to adopt the similar approach.…”

Section: Discussionmentioning

confidence: 99%

Facies classification with different machine learning algorithm – An efficient artificial intelligence technique for improved classification

Mandal

Rezaee

2019

ASEG Extended Abstracts

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“…Results of this study prove that the minimum requirements necessary to model shale gas reservoirs are: 1) desorption phenomena and 2) pressure-sensitive permeability for hydraulic and induced-fractures (zones II and III) into the flow governing equations. Consequently, it is unnecessary to add more mechanisms and nonlinearity into the model (in agreement to [3] [18] [19]).…”

Section: Discussionmentioning

confidence: 99%

Unconventional Shale Reservoir’s Property Estimation through Modeling, Case Studies of Australian Shale

Shiver¹,

Nelsen²,

Li³

et al. 2015

EPE

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A simplified approach is introduced to model production from shale gas resources. In this approach, a multi-fractured horizontal gas well in a shale formation is divided into four zones. Shale formation between each pair of hydraulic fractures consists of four zones: compacted zone around well-bore (1), shale matrix (2), induced fractures (3) and main hydraulic fractures (4). The main contribution of this study is considering varying permeability for each specific zone implemented in the mathematical presentation of gas flow in shale. Further, gas desorption and slippage effect are applied to the model to capture the realistic gas flow in shale. The nonlinear partial differential equation of gas flow obtained from mass conservations law is then solved numerically for each specific zone with respect to their appropriate boundary conditions. This approach then is applied to three case studies, Cooper Basin, Georgina and Galilee shale. A history matching of the mentioned formations is accomplished to find the most uncertain parameters undertaken through this simplified approach. Results of this study are in an agreement with other methods and it is demonstrated that the simplified approach provides more accurate production forecast for the wellestablished Georgina asset and is in a good agreement for Cooper and Galilee. This study is also valuable since it provides some rough estimation for shale rock characteristics as the basis for rigorous simulation studies.

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Geomechanical Properties of Unconventional Shale Reservoirs

Cited by 37 publications

References 12 publications

Modeling and Simulation of Natural Gas Production from Unconventional Shale Reservoirs

Modeling and Simulation of Natural Gas Production from Unconventional Shale Reservoirs

Facies classification with different machine learning algorithm – An efficient artificial intelligence technique for improved classification

Unconventional Shale Reservoir’s Property Estimation through Modeling, Case Studies of Australian Shale

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