Pressure transient behavior analysis in a dual-porosity reservoir with partially communicating faults

Gao, Feng; Liu, Qiguo; Zhang, Liehui; Yang, Zai

doi:10.1016/j.jngse.2016.04.046

Cited by 12 publications

(2 citation statements)

References 18 publications

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“…11 and 12. The α terms are used to improve readability of the equations and (−1) H Ω has been replaced with the leakage term: γ( − ) where γ is a leakage constant acting on the boundary between the porous and the fractured regions (Feng et al 2016). Each point within the defined mesh as assigned a leak-off coefficient value depending on if the point is being used to define a fracture or porous section, the same is true for the alpha coupling terms used to determine the rate of swelling or dilation due to fracture pressure.…”

Section: Coupled Flow Formulationmentioning

confidence: 99%

A Fully Coupled Computational Framework for Fluid Pressurized Crack Evolution in Porous Media

et al. 2019

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This paper presents a computational framework for modelling hydraulic fracture on the basis of combining continuum porous media and damage theories. By considering the continuum as two separate domains of damaged and intact porous domains, model components are isolated and considered separately. This simplifies the whole modelling approach. The mathematical model used consists of a set of coupled partial differential equations in continuum space that govern compressible flow in damaged and intact porous media, mechanical deformation of the domains and damage evolution. We particularly focus on the flow of fluid within the intact and damaged porous zones. The porous domain typically has a lower permeability than the fractured zone, therefore a more complicated flow of fluid is expected within the damage zone. To model the exchange of fluid in the interface of damage zone and intact porous domain, a double permeability concept has been utilized. The evolution of cracks is modelled using Francfort and Marigo's variational theory which approximates the fracture by a diffusive damage zone using a phase field variable. The governing model equations are discretised and solved using finite element method. The framework capabilities are verified using experimental data from a one-dimensional consolidation test and a plane stress pressured penny crack benchmark example. The framework performance highlights its capabilities in analysing hydraulic driven fracture process and the associated permeability variations.

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Section: Coupled Flow Formulationmentioning

confidence: 99%

A Fully Coupled Computational Framework for Fluid Pressurized Crack Evolution in Porous Media

et al. 2019

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“…For example, interpretation of well testing results of a naturally fractured reservoir is carried out remarkably easier with the aid of pressure derivative (Cinco-Ley 1996). Interpreting of the transition period of naturally fractured reservoirs is an obstacle which many analyzers tackle with (Aguilera 1987;Feng et al 2016;Seyedi et al 2014). Many authors applied this period for different models of naturally fractured reservoirs and their corresponding pressure transient analyses published in the literature (Dejam et al 2018;Aguilera 1987;Najurieta 1980;Warren and Root 1963;Odeh 1965;Kazemi 1969;Kazemi et al 1969;de Swaan 1976;Aguilera and Song 1988;Kuchuk and Biryukov 2014;Al-Rbeawi 2017).…”

Section: Introductionmentioning

confidence: 99%

Possible pitfalls in pressure transient analysis: Effect of adjacent wells

Dastjerdi

Farab²,

Sharifi

2019

J Petrol Explor Prod Technol

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Well testing is one of the important methods to provide information about the reservoir heterogeneity and boundary limits by analyzing reservoir dynamic responses. Despite the significance of well testing data, misinterpreted data can lead us to a wrong reservoir performance prediction. In this study, we focus on cases ignoring the adjacent well's production history, which may lead to misinterpretation. The analysis was conducted on both homogeneous and naturally fractured reservoirs in infinite-acting and finite-acting conditions. The model includes two wells: one is "tested well" and the other is "adjacent one." By studying different scenarios and focusing on derivative plots, it was perceived that both reservoir and boundary models might be misinterpreted. Additionally, in all cases, a sensitivity analysis was performed on parameters affecting interpretation process. Studying the literatures, few articles have focused on drawbacks during diagnostic plot interpretation and also the effect of adjacent wells. Hence, these issues were addressed. Overall, considering several cases it was proved that neglecting the production effect of adjacent wells causes wrong interpretation, and this should be avoided in all interpretation cases. Regarding the importance of reservoir characteristics and its flow regime, any wrong interpretation may create huge uncertainties in the reservoir development. As a result, this paper aimed to address the well testing, especially in brown fields where the production of other wells may affect the pressure response of the tested well; therefore, it will be pivotal to consider the effect of adjacent wells' production history.

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Analyzing fluid flow characteristics in a dual-porosity reservoir with an elastic outer boundary

Kim¹,

Han²,

Rim³

et al. 2021

Acta Geophys.

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Pressure transient behavior analysis in a dual-porosity reservoir with partially communicating faults

Cited by 12 publications

References 18 publications

A Fully Coupled Computational Framework for Fluid Pressurized Crack Evolution in Porous Media

A Fully Coupled Computational Framework for Fluid Pressurized Crack Evolution in Porous Media

Possible pitfalls in pressure transient analysis: Effect of adjacent wells

Analyzing fluid flow characteristics in a dual-porosity reservoir with an elastic outer boundary

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