Abstract:Shale resource development technology is being improved and optimized over the last decade as the industry has seen a sharp rise in production and IP rates in North America and most recently from Europe and Australia while initial activities are on the rise in Latin America, Middle East and China. Despite such improvements, if one takes a closer look at the performance of the wells, one will find that not all wells are producing commercially and for that matter even wells that are producing commercially not al… Show more
“…Typically, 4 -6 wells per section are common based on the assumption that each lateral well will drain 160 to 100 acres respectively. Although these designs are presented as established practices by a resource industry which made the first serious entry in 2005 in the Barnett dry gas play (Ahmed, 2014), various engineers, geologists and geomechanics specialists have worked hard to establish principles of evaluation and appraisal based on physical measurements, modeling and field verification (Koutsabeloulis and Zhang, 2009;Vassilellis et al, 2009Vassilellis et al, , 2010Vassilellis et al, , 2011Moos et al 2011, Gui et al, 2013. These attempts to predict production performance based on geological characterization have produced in many cases encouraging results, and it is hopeful that in time widely accepted and applied practices will create a reliable link between geology and expected cash flows and introduce geology based incentives that will allow achieving better recoveries at lower costs of extraction.…”
In an unconventional tight oil play with natural fractures, the main drive mechanisms are depletion above the bubble point and compaction. They are not easily recognized yet play a major role in diminishing performance. An extensive integrated study, using the Event Solution approach, of a Mid-continent naturally fractured tight oil carbonate resource was undertaken to examine the causes of performance variability. The integrated study included a thorough petrophysical and fluid characterization. Drive mechanisms were associated with specific rock types and in relation with fracture density, explaining performance characteristics. Extensive numerical simulation was used to combine characterization and historical performance. Initially the dominant drive mechanisms are depletion and compaction. Later, gravity drainage plays a significant role but its benefits are not captured with the initial well designs. Previously, wells were placed at the top of the reservoir and hydraulic fractures extended downwards. The study concluded that applying a different well type, multi-laterals extended both laterally and stacked vertically, can leverage on gravity drainage. An innovative well design was implemented to capture the benefits of multiple drive mechanisms. Additionally, the optimized operating conditions were identified to maximize impact. As a result, it is possible to increase recovery efficiency at a lower capital and operating cost. The learnings from this project can benefit the continued development and also serve as a paradigm in the very important tight oil plays in North America, which are largely carbonate with various degrees of natural fracturing.
“…Typically, 4 -6 wells per section are common based on the assumption that each lateral well will drain 160 to 100 acres respectively. Although these designs are presented as established practices by a resource industry which made the first serious entry in 2005 in the Barnett dry gas play (Ahmed, 2014), various engineers, geologists and geomechanics specialists have worked hard to establish principles of evaluation and appraisal based on physical measurements, modeling and field verification (Koutsabeloulis and Zhang, 2009;Vassilellis et al, 2009Vassilellis et al, , 2010Vassilellis et al, , 2011Moos et al 2011, Gui et al, 2013. These attempts to predict production performance based on geological characterization have produced in many cases encouraging results, and it is hopeful that in time widely accepted and applied practices will create a reliable link between geology and expected cash flows and introduce geology based incentives that will allow achieving better recoveries at lower costs of extraction.…”
In an unconventional tight oil play with natural fractures, the main drive mechanisms are depletion above the bubble point and compaction. They are not easily recognized yet play a major role in diminishing performance. An extensive integrated study, using the Event Solution approach, of a Mid-continent naturally fractured tight oil carbonate resource was undertaken to examine the causes of performance variability. The integrated study included a thorough petrophysical and fluid characterization. Drive mechanisms were associated with specific rock types and in relation with fracture density, explaining performance characteristics. Extensive numerical simulation was used to combine characterization and historical performance. Initially the dominant drive mechanisms are depletion and compaction. Later, gravity drainage plays a significant role but its benefits are not captured with the initial well designs. Previously, wells were placed at the top of the reservoir and hydraulic fractures extended downwards. The study concluded that applying a different well type, multi-laterals extended both laterally and stacked vertically, can leverage on gravity drainage. An innovative well design was implemented to capture the benefits of multiple drive mechanisms. Additionally, the optimized operating conditions were identified to maximize impact. As a result, it is possible to increase recovery efficiency at a lower capital and operating cost. The learnings from this project can benefit the continued development and also serve as a paradigm in the very important tight oil plays in North America, which are largely carbonate with various degrees of natural fracturing.
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