An Improved Practical Solution for Modeling Single Phase Multi-Fractured Horizontal Well Performance

2017 ◽  
Author(s):  
H. Behmanesh ◽  
D. M. Anderson ◽  
J. M. Thompson ◽  
D. W. Nakaska
Keyword(s):  
Horizontal Well ◽  
Single Phase ◽  
Well Performance ◽  
Practical Solution ◽  
Fractured Horizontal Well

Evaluation of Multi-Fractured Horizontal Well Performance: Babbage Field Case Study

2014 ◽  
Author(s):  
Basil Al-Shamma ◽  
Helene Nicole ◽  
Peyman R. Nurafza ◽  
Wei Cher Feng
Keyword(s):  
Horizontal Well ◽  
Well Performance ◽  
Field Case ◽  
Fractured Horizontal Well

Comparison of Fractured-Horizontal-Well Performance in Tight Sand and Shale Reservoirs

2011 ◽  
Vol 14 (02) ◽  
pp. 248-259 ◽  
Author(s):  
E.. Ozkan ◽  
M Brown ◽  
R.. Raghavan ◽  
H.. Kazemi
Keyword(s):  
Hydraulic Fracture ◽  
Horizontal Well ◽  
Flow Model ◽  
Horizontal Wells ◽  
Natural Fracture ◽  
Well Performance ◽  
Fracture Conductivity ◽  
Fractured Horizontal Well ◽  
Shale Reservoirs ◽  
Fractured Horizontal Wells

Summary This paper presents a discussion of fractured-horizontal-well performance in millidarcy permeability (conventional) and micro- to nanodarcy permeability (unconventional) reservoirs. It provides interpretations of the reasons to fracture horizontal wells in both types of formations. The objective of the paper is to highlight the special productivity features of unconventional shale reservoirs. By using a trilinear-flow model, it is shown that the drainage volume of a multiple-fractured horizontal well in a shale reservoir is limited to the inner reservoir between the fractures. Unlike conventional reservoirs, high reservoir permeability and high hydraulic-fracture conductivity may not warrant favorable productivity in shale reservoirs. An efficient way to improve the productivity of ultratight shale formations is to increase the density of natural fractures. High natural-fracture conductivities may not necessarily contribute to productivity either. Decreasing hydraulic-fracture spacing increases the productivity of the well, but the incremental production gain for each additional hydraulic fracture decreases. The trilinear-flow model presented in this work and the information derived from it should help the design and performance prediction of multiple-fractured horizontal wells in shale reservoirs.

scholarly journals Evaluation of Reservoir Quality and Forecasted Production Variability along a Multi-Fractured Horizontal Well. Part 2: Selected Stage Forecasting

Energies ◽  
2021 ◽  
Vol 14 (19) ◽  
pp. 6007 ◽  
Author(s):  
Christopher R. Clarkson ◽  
Zhenzihao Zhang ◽  
Farshad Tabasinejad ◽  
Daniela Becerra ◽  
Amin Ghanizadeh
Keyword(s):  
History Matching ◽  
Horizontal Well ◽  
Production Performance ◽  
Reservoir Quality ◽  
Well Performance ◽  
Fracture Geometry ◽  
Fractured Horizontal Well ◽  
Production Variability ◽  
Montney Formation ◽  
Low Permeability Reservoirs

The current practice for multi-fractured horizontal well development in low-permeability reservoirs is to complete the full length of the well with evenly spaced fracture stages. Given methods to evaluate along-well variability in reservoir quality and to predict stage-by-stage performance, it may be possible to reduce the number of stages completed in a well without a significant sacrifice in well performance. Provision and demonstration of these methods is the goal of the current two-part study. In Part 1 of this study, reservoir and completion quality were evaluated along the length of a horizontal well in the Montney Formation in western Canada. In the current (Part 2) study, the along-well reservoir property estimates are first used to forecast per-stage production variability, and then used to evaluate production performance of the well when fewer stages are completed in higher quality reservoir. A rigorous and fast semi-analytical model was used for forecasting, with constraints on fracture geometry obtained from numerical model history matching of the studied Montney well flowback data. It is concluded that a significant reduction in the number of stages from 50 (what was implemented) to less than 40 could have yielded most of the oil production obtained over the forecast period.

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