Simulation of Complex Carbonate Field: Double Media vs. Single Media Kharyaga Field Case

Khvatova, Irina Evgenievna; Renaud, Antoine; Malyutina, Galia-Banu; Sansiev, Georgiy; Kuzilov, Igor; Minnibaeva, Tatyana

doi:10.2118/160585-ms

Cited by 5 publications

(2 citation statements)

References 5 publications

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“…Naturally fractured carbonate karst reservoirs are commonly found all over the world (Dabbouk et al 2002;Khvatova et al 2012;Peng et al 2009). The modeling and numerical simulation of such reservoirs are a challenging problem because of the presence of vugs (cavities from small to medium size) and caves (large size cavities) which are usually interconnected by natural fractures.…”

Section: Introductionmentioning

confidence: 99%

A Unified Finite Difference Model for The Simulation of Transient Flow in Naturally Fractured Carbonate Karst Reservoirs

Killough

Fadlelmula

et al. 2015

SPE Reservoir Simulation Symposium

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The presence of cavities connected by fracture networks at multiple levels make the simulation of fluid flow in naturally fractured carbonate karst reservoirs a challenging problem. The challenge arises in properly treating the Darcy and non-Darcy flow in the different areas of fractured medium. In this paper, we present a single-phase transient flow model which is based on the Stokes-Brinkman equation and a generalized material balance equation. The generalized material balance equation proves to be exact in both cavities and porous media, and the Stokes-Brinkman equation mathematically combines Darcy and Stokes flow, thus allowing a seamless transition between the cavities and porous media with only minor amounts of perturbation introduced into the solutions. Finite differences are implemented for the solution of the proposed transient flow model. This solution method provides a smooth transition from standard multiple-porosity/permeability reservoir simulators and moreover, it is physically more straightforward, mathematically easier to derive and implement, and more apt to generalization from two-dimensional to three-dimensional cases than alternative techniques. Application of the derived transient flow model is shown by examples of three fine-scale 2-D geological models. The first two models, although simple, provide verification of the proposed transient flow model. The third example presents a more complex and realistic geological model derived from multiple-point statistics simulation technique with the second model used as the training image. The results of the third model form the foundation for future study of multi-phase and 3-D reservoir cases. cavities and fractures (Tuncay et al. 1998) and Darcy flow in the porous media makes the coupled solution of fluid transport in these reservoirs very difficult. Various continuum approaches have been developed for the modeling of fluid flow in naturally fractured carbonate karst reservoirs. Methods based on the multiple-continuum concept model fractures and vugs as porous media with high permeability values (

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Section: Introductionmentioning

confidence: 99%

A Unified Finite Difference Model for The Simulation of Transient Flow in Naturally Fractured Carbonate Karst Reservoirs

Killough

Fadlelmula

et al. 2015

SPE Reservoir Simulation Symposium

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“…Os reservatórios de carbonato naturalmente fraturados são comumente encontrados em todo o mundo Dabbouk (2002), Khvatova (2012) e Peng (2009. A modelagem e a simulação numérica desses reservatórios são um problema desafiador devidoà presença de vugs (cavidades de pequeno a médio porte) e de cavernas (cavidades de grandes dimensões) que normalmente são interligadas por fraturas naturais.…”

Section: Organização Do Trabalhounclassified

Produtividade De Poços Em Reservatórios De Alta Heterogeneidade De Permeabilidade

DIAS¹

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Dias, Rodrigo Araujo Cardoso; Nieckele, Angela Ourivio (Advisor); Fernandes, Paulo Dore (Co-Advisor). Wells Productivity in High Heterogeneity Reservoirs. Rio de Janeiro, 2017. 229p. Tese de Doutorado -Departamento de Engenharia Mecânica, Pontifícia Universidade Católica do Rio de Janeiro.Predicting wellbore production plays a crucial role in petroleum engineering. Therefore, the modeling of the flow in reservoir and in wellbore is fundamental in several problems in this area. In the overwhelming majority problems, Darcy's equation is the choice to predict the behavior of flow in reservoirs. The great success of Darcy's equation, unfortunately, took its application out of the scope of the problems for which it applies. The classic Darcy's equation presents limitations when applied in highly heterogeneous porous media, for example with cavities connected by fracture networks, with vugs and caves. Over the years, other models have been proposed and derived from other points of view to treat flow in porous media, for example through the average volume process or through mixture theory. The present work considers the average volume process in porous media. The developed model includes additional terms for the linear momentum equation that are relevant in several practical situations, and involves the joint solution of conservation equations. In the model developed in this work, the flow in the reservoir is solved coupled to the wellbore flow, considering the possibility of using different completion types. The pressure and velocity fields predictions as well as the productivity of oil wellbores using the developed model are compared with the predictions of the model based on the Darcy's equation. It is shown that for certain situations, especially in highly heterogeneous carbonate reservoirs, large differences can be obtained. The prediction of the productivity of a wellbore from the Darcy's equation can be significantly overestimated.

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Darcy model with optimized permeability distribution (DMOPD) approach for simulating two-phase flow in karst reservoirs

Jamal

Awotunde

2021

J Petrol Explor Prod Technol

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Darcy model fails to accurately model flow in karst reservoirs because the flow profiles in free-flow regions such as vugs, fractures and caves do not conform to Darcy’s law. Flows in karsts are often modelled using the Brinkman model. Recently, the DMOPD approach was introduced to reduce the complexity of modelling single-phase flow in Karst aquifers. Modelling two-phase flow using the Brinkman’s equation requires either a method of tracking the front or introducing the saturation component in the Brinkman’s equation. Both of these methods introduce further complexity to an already complex problem. We propose an alternative approach called the two-phase Darcy’s Model with optimized permeability distribution (TP-DMOPD) to model pressure and saturation distributions in karst reservoirs. The method is a modification to the DMOPD approach. Under the TP-DMOPD model, the caves are initially divided into zones and the permeability of each zone is estimated. During this stage of the TP-DMOPD model, the fluid inside the reservoir is assumed to be in a single-phase. Once the permeability distribution is obtained, the two-phase Darcy model is used to simulate flow in the reservoir. The example applications tested showed that the TP-DMOPD approach was able to model two-phase flow in karst reservoirs.

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Simulation of Complex Carbonate Field: Double Media vs. Single Media Kharyaga Field Case

Cited by 5 publications

References 5 publications

A Unified Finite Difference Model for The Simulation of Transient Flow in Naturally Fractured Carbonate Karst Reservoirs

A Unified Finite Difference Model for The Simulation of Transient Flow in Naturally Fractured Carbonate Karst Reservoirs

Produtividade De Poços Em Reservatórios De Alta Heterogeneidade De Permeabilidade

Darcy model with optimized permeability distribution (DMOPD) approach for simulating two-phase flow in karst reservoirs

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