PowerDrive vorteX Max System Reduces Average Total Drilling Cost by 30% per Lateral Foot, Permian Basin
Drill through challenging formation while extending lateral footage and improving speed
During 2016, Parsley Energy faced the challenge of improving drilling efficiency for multiwell pads in the Midland basin, focusing on extending production-hole lengths from 1-mi [1.609-km] laterals to 2 mi [3.218 km] or more. Well designs consisted of 12 1/4-in intermediate sections followed by 8 3/4-in curves and 8 1/2-in laterals. Production-hole trajectories targeted the Wolfcamp Formation, an interbedded abrasive formation primarily of salts and limestone. There was severe shock and vibration in the offsets. Combined, all these factors caused an overall well delivery time that ranged between 20 and 35 days.
Additionally, the basin consisted of other multiwell-pad drilling activity, which increased the risk of wellbore collision. Offset wells using high dogleg severities (DLS) experienced BHA failures that resulted in multiple lateral runs.
Optimize the PowerDrive vorteX Max system to increase drill speed and trajectory control
Schlumberger recommended deploying the PowerDrive vorteX Max system to continue drilling the 8 1/2-in lateral sections of Parsley Energy wells in that basin. The system is both rugged and customizable, enabling it to be optimized to endure drilling conditions through the Wolfcamp Formation, as well as to allow the BHA to pass throuhg the high dogleg severities curve section. The power section can be adjusted to improve drill speed once the curve is built. Also, the self-steering mode for both inclination and azimuth provides better trajectory control in the dense, multiwell environment.
Delivered improved drilling efficiency, record-setting drilling speed, and extended footage
The PowerDrive vorteX Max system helped Parsley Energy drill 80 wells in Permian Basin in 2016, representing a year-over-year increase of 74%. The average lateral footage increased 9% per well. Rig days were reduced by 17% and drilling costs per lateral foot decreased 30%. The total lateral footage drilled increased by 89% year on year.
A record was set for one well in the Wolfcamp Formation by drilling a 7,128-ft [2,172.61-m] lateral section with one run in less than 3 days.