A Comprehensive Well Test Model For Horizontal Wells With Complex Boundaries

Gang, Du; Wei, Chengzhou; Shen, Lin; Bin, Qu

doi:10.2118/98-21

Cited by 3 publications

(7 citation statements)

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“…First, we seek to the solution of a point source and then obtain the solution of line source Fig. 4 The views of horizontal well in different coordinate systems by superposition integrals to point source solution along the horizontal length (Ozkan and Raghavan 1991a;Duan et al 1998;Zhan and Zlotnik 2002).…”

Section: Mathematical Modelmentioning

confidence: 99%

“…So the dimensionless pressure at the wall of wellbore in Laplace space by superposition integrals to point source solution along the horizontal length (Duan et al 1998;Ozkan and Raghavan 1991a,b) can be expressed by …”

Section: Solution To Mathematical Modelmentioning

confidence: 99%

“…The shape and location of type curves in this stage are affected by the horizontal length L, the formation thickness h, the ratio of horizontal permeability to perpendicular permeability k h /k p , the relative location of horizontal wellbore in formation z wD and the skin factor S. We only show the type curves characteristics affected by S (see Fig. 15), and the characteristics affected by the parameters L , h, k h /k p and z wD (Duan et al 1998;Hashemi et al 2006) are omitted here. Stage III: Inter-porosity flow stage of matrix system to fracture system.…”

Section: Type Curvesmentioning

confidence: 99%

“…These models considered the fracture and matrix systems as the flow pathway directly connected with wellbore, in addition, considered the inter-porosity flow between matrix and fracture systems. (3) Flow models of horizontal well production in a single medium, such as analytical models (Frick et al 1996; Goode and Thambynayagam 1987;Kuchuk et al 1991;Ozkan et al 1989;Sheng 2008), semi-analytical models (Duan et al 1998;Kuchuk and Hbashy 1996;Ozkan and Raghavan 1991a,b) and numerical models (Hashemi et al 2006;Gill and Issaka 2007). In these models, there have various complex boundaries for different porous medium, such as homogeneous media, anisotropic media; (4) Flow models of horizontal well in naturally fractured reservoirs, such as analytical model (Du and Stewart 1992) and semi-analytical models (Ng and Aguilera 1999;Ozkan and Raghavan 1991a,b).…”

Section: Introductionmentioning

confidence: 99%

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Dual Porosity and Dual Permeability Modeling of Horizontal Well in Naturally Fractured Reservoir

et al. 2011

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This article is the first investigation on the dual permeability flow issue for horizontal well-production in a naturally fractured dual-porosity reservoir. Based on the inter-porosity flow from matrix system to fracture system and treating the media directly connected with horizontal wellbore as matrix and fracture systems, we established a model of horizontal well-production and then solved the model using some modern mathematical methods, such as Laplace integral transformation, separation of variables, eigenvalue, and eigenfunction. Later in the article, we obtained the standard log-log type curves using numerical simulation and analyzed the transient flow behavior thoroughly, which showed it is dual porosity and dual permeability flow behavior. The numerical simulation results showed that there are obvious differences between dual permeability and single permeability models. The dual permeability flow behavior accelerates energy supplement during production and reduces the classical matrix-fracture (V-shaped) response. We also showed that type curves characteristics are affected by external boundary conditions, the parameter κ, ω f and λ mf , etc. The research results show that our model would be a good semi-analytical model supplied to users. Because the single permeability modeling ignores the direct fluid supply from matrix to wellbore, we recommend using the dual permeability modeling to make well testing and rate decline interpretation in real case studies.

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Section: Mathematical Modelmentioning

confidence: 99%

Section: Solution To Mathematical Modelmentioning

confidence: 99%

Section: Type Curvesmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Dual Porosity and Dual Permeability Modeling of Horizontal Well in Naturally Fractured Reservoir

et al. 2011

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“…Camacho-Velázquez et al (2005) considered the vug system as a continuum medium. Thus fracture system and vug system were treated as pathways directly connected to the wellbore and inter-porosity flows between matrix, fracture and vug systems were considered; (3) flow models of horizontal well production in homogeneous reservoirs (Duan et al, 1998;Ozkan and Raghavan, 1991a,b); and (4) dual porosity and single permeability flow models of horizontal well production in naturally fractured reservoirs. The fracture system was treated as the main pathway and inter-porosity flow from the matrix system to the fracture system was considered (Ng and Aguilera, 1999;Ozkan and Raghavan, 1991a,b).…”

Section: Introductionmentioning

confidence: 99%

Dual permeability flow behavior for modeling horizontal well production in fractured-vuggy carbonate reservoirs

Guo

Nie

Jia

2012

Journal of Hydrology

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New Type Curves for Modeling Productivity of Horizontal Well With Negative Skin Factors

Nie

Jia

Meng

et al. 2012

SPE Reservoir Evaluation &Amp; Engineering

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Summary This paper first establishes a comprehensive semianalytical model for a horizontal well in a homogeneous, dual- or triple-porosity reservoir. By taking a negative-skin approach, including Laplace transform, separation of variables, and inverse Laplace transform, we obtain the solutions in a unified formula for both constant-rate production and constant-wellbore-pressure production. In the model, we consider a set of rich boundary conditions, including infinite reservoir and closed or constant-pressure boundary conditions for the top, bottom, and side of the bounded reservoir. Consequently, we plot a series of new standard log-log type curves and make a clear observation of different flow periods (e.g., early radial flow, hemiradial flow, linear flow, and late pseudoradial flow) from negative-skin type curves. We make a comparison between the solutions using the negative-skin approach and conventional solutions, which shows that there are some small differences between the two methods. We also analyze the type-curve characteristics for horizontal-well production in dual- and triple-porosity reservoirs, which shows that the derivative curves are V-shaped for dual media and W-shaped for triple media. Finally, we perform well-test interpretations for a horizontal well with positive skin and a horizontal well with negative skin and bottomwater, which shows that our new model performs well against the real field data.

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A Comprehensive Well Test Model For Horizontal Wells With Complex Boundaries

Cited by 3 publications

References 0 publications

Dual Porosity and Dual Permeability Modeling of Horizontal Well in Naturally Fractured Reservoir

Dual Porosity and Dual Permeability Modeling of Horizontal Well in Naturally Fractured Reservoir

Dual permeability flow behavior for modeling horizontal well production in fractured-vuggy carbonate reservoirs

New Type Curves for Modeling Productivity of Horizontal Well With Negative Skin Factors

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