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.-in intermediate sections followed by 8¾-in curves and 8½-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.
SLB deployed PowerDrive vorteX Max™ high-powered rotary steerable system (RSS) to mitigate trajectory deviation due to formation characteristics.
We reduced the average drilling cost per lateral foot by 30%, drilled 7,128 lateral feet [2,172.61 m] in 1.7 days, increased total production wells drilled by 89%, and extended total lateral footage drilled per well by an average of 9%.
SLB recommended deploying the PowerDrive vorteX Max system to continue drilling the 8½-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.
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.
