Horizontal-Well Productivity Equations With Both Uniform-Flux and Uniform-Pressure Wellbore Modes

Chen, Her-Yuan; Liu, Yi; Asaad, Neil M.

doi:10.2118/97190-ms

Cited by 12 publications

(12 citation statements)

References 6 publications

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“…The largest error is 8.7% for the reservoir with an aspect ratio of two. In all cases, the calculated PI for a fracture length of 0.9 is larger than the maximum possible PI for a completely penetrating fracture, confirming the calculations of Chen and Asaad (2005).…”

Section: Ep Methodssupporting

confidence: 78%

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The Productivity of a Well with a Vertical Infinite-Conductivity Fracture in a Rectangular Closed Reservoir

Hagoort¹

2009

SPE Journal

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In this work, we have evaluated the productivity index (PI) of a well with a vertical, infinite-conductivity fracture in a closed rectangular reservoir for a wide range of fracture lengths, reservoir aspect ratios, and fracture eccentricities. The reported PIs are based on a rigorous analytical solution for the semi-steady-state pressure distribution created by a uniform-flux fracture in combination with Muskat's method to convert the uniform-flux to a uniformpressure solution. The PIs based on Earlougher's shape factors are too optimistic. The equivalent-pressure (EP) method works very well at small fracture lengths but overestimates the PI at medium and large fracture lengths. The average-pressure (AP) method is too pessimistic at all fracture lengths.

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Section: Ep Methodssupporting

confidence: 78%

“…Recently, Chen and Asaad (2005) showed that the EP and AP methods produce significantly different productivities, particularly for medium and large fracture lengths. Generally, the productivity based on the EP method is larger and, in the case of long fractures, could even exceed the maximum theoretical productivity.…”

Section: Introductionmentioning

confidence: 99%

The Productivity of a Well with a Vertical Infinite-Conductivity Fracture in a Rectangular Closed Reservoir

Hagoort¹

2009

SPE Journal

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“…Babu and Odeh (1988) proposed (Chen and Asaad, 2005;Economides et al, 1991;Giger, 1985;Helmy and Wattenbarger, 1998;Joshi, 1986;Lu and Tiab, 2007;Mutalik and Godbole, 1988). A comprehensive review of productivity indexes was created by Choi et al (2008).…”

Section: Current Oilfield Assumptionsmentioning

confidence: 99%

CFD-based representation of non-Newtonian polymer injectivity for a horizontal well with coupled formation-wellbore hydraulics

Jackson¹,

Balhoff

Huh

et al. 2011

Journal of Petroleum Science and Engineering

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“…The DVS method has been validated through comparison with existing analytical models for determining pressure distributions caused by various sink configurations (Gringarten et al 1974;Ozkan 1988;Yildiz and Bassiouni 1990;Cinco-Ley et al 1978;Cinco-Ley and Meng 1988) and for determining productivities of simple completion schemes (Babu and Odeh 1989;Goode and Kuchuck 1991;Chen and Asaad 2005). Comparisons provided by Amini (2007) also include results obtained with a numerical reservoir simulator for a system of a horizontal well with multiple transverse fractures.…”

Section: Problem Backgroundmentioning

confidence: 99%

Using Distributed Volumetric Sources to Predict Production from Multiple-Fractured Horizontal Wells Under Non-Darcy-Flow Conditions

Amini

Valkó

2009

SPE Journal

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The method of distributed volumetric sources (DVS) has been applied to predict gas production from a horizontal well with multiple transverse fractures in a bounded reservoir. Combining the quasianalytical DVS method, which provides us with the opportunity to predict pressure and production behavior of complex well/fracture configurations, with non-Darcy flow in the fracture enables us to calculate the optimum configuration in terms of the number and dimensions of fractures per well for a certain amount of proppant of a given type. The method is applied to an example case of a tight gas reservoir to maximize the production performance of this complex well/fracture configuration. Comparing results with and without inclusion of the non-Darcy effect in the fracture shows that a decrease in production occurs because of non-Darcy flow in all cases. However, a systematic screening of a realistic set of well/fracture configurations reveals that the detrimental effect of non-Darcy flow can be substantially compensated for by selecting the right number of fractures and shifting the fracture dimensions in favor of thicker fractures. While a simultaneous decrease in optimum lateral (and vertical) extension is necessary, it has limited effect on productivity. The simplicity, robustness, and small computational demand of the model allow seamless integration with external economic and operational constraints, providing a tool to screen and optimize a large set of possible configurations most suited for the development of economically marginal fields. Shahram Amini is with Schlumberger (SRPC),

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Horizontal-Well Productivity Equations With Both Uniform-Flux and Uniform-Pressure Wellbore Modes

Cited by 12 publications

References 6 publications

The Productivity of a Well with a Vertical Infinite-Conductivity Fracture in a Rectangular Closed Reservoir

The Productivity of a Well with a Vertical Infinite-Conductivity Fracture in a Rectangular Closed Reservoir

CFD-based representation of non-Newtonian polymer injectivity for a horizontal well with coupled formation-wellbore hydraulics

Using Distributed Volumetric Sources to Predict Production from Multiple-Fractured Horizontal Wells Under Non-Darcy-Flow Conditions

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