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Unconventional Yearbook 2018

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78 | January 2018 | hartenergy.com 2018 UNCONVENTIONAL YEARBOOK | COMPLETION OPTIMIZATION 2010 to 60 wells per section in 2017, systematically increasing wellbore density and recovery. "Our Eagle Ford team pioneered these enhanced designs, based upon tighter cluster spacing and a thin fluids design with aggressive flowback," Fox said. "The advanced completion design produced strong results in new zones, increased our type curves and grew our premium return inventory and our margins." Fox said the success of the design in the Eagle Ford has encouraged Encana to test its advanced completions model, which includes an analyt- ics-based approach to completing a well, in the Montney, Duvernay and Permian basins as well. "Our approach is data-driven," Fox said. "In the Permian, for example, we studied and refined our development approach over several years after entering the basin. Our Vertical Optimiza- tion Experiment, or VOX well, drilled in Midland County in 2015, was equipped with 16 pressure gauges at various depths, along with 10 sliding sleeves across a 3,400-ft vertical section. It allowed for isolation and analysis of specific zones. These learnings were applied on the first 14 wells of the RAB Davidson cube development in early 2016. In turn, when we drilled the second phase of the RAB Davidson this year, we took the real-time data from those first 14 wells and evaluated the productivity of that pad and subsequent drawdown to drill 19 additional wells, including adding an additional layer and conducting a different style completion operation. Our approach with cube development is to create effective drawdown at the scale at which the reservoir exists from a single surface location." According to its second-quarter 2017 report, WPX has tested multiple completion designs in the Williston Basin for its Caribou, Grizzly and Beaks pads. According to WPX, these pads varied in their number of stages—40 versus 60—and the number of clusters per stage—five versus 10. Their proppant loading ranged between 6 million pounds and 9 million pounds. The company reported that its 30-, 60- and 90-day cumulative oil production for its 60-stage completions exceeded its 40-stage wells. WPX is actively testing its approach in the Perm- ian as well, where it plans to complete 50% more lateral feet in 2018 on its Delaware Basin wells than it did in 2017. Downey said the dynamics that dictate how WPX plans its laterals, spacing and stages are dependent upon that particular reservoir's characteristics. "As with any reservoir, it comes down to the res- ervoir pressure, permeability and porosity," he said. About 75% of WPX's 2018 drilling plan in the Delaware Basin involves 1.5-mile and 2-mile laterals. WPX's projected average lateral length in the basin for 2018 (8,000 ft) is 30% more than its 2017 average. (Photo by Jim Blecha, courtesy of WPX)

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