At-Bit Steerable System Cuts DLS in Lateral by 50% | Schlumberger
Case Study
Location
DJ Basin, United States, North America, Onshore
Details

By using the NeoSteer CL curve and lateral at-bit steerable system (ABSS) to drill 12 wells, SRC Energy achieved straighter laterals with nearly half the DLS—bringing the DLS in the lateral sections to 0.85 °/100 ft from 1.52 °/100 ft.

Products Used

At-Bit Steerable System Cuts DLS in Lateral by 50%

Closed loop steering automation feature enables straighter laterals, less friction, and more time in zone

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The pad plan view shows that the NeoSteer CL ABSS performed more smoothly than the standard RSS-BHA configuration.

The operator’s goal

SRC Energy wanted to drill 12 monobore wells with vertical, curve, and lateral sections in a single run as fast, as smooth, and as consistently as possible.

The previous method

SRC Energy drilled 12 wells in the previous half of the pad using a standard RSS BHA. The average tortuosity in the tangent section was 1.21°/100 ft. Of all the tangent sections drilled above 12° inclination, the average dogleg calculated was greater than 3.5°/100 ft for the majority of them. SRC Energy wanted to decrease the average tortuosity in the upcoming 12-well pad.

What SRC Energy achieved

Schlumberger recommended using the NeoSteer CL ABSS to drill the 12 planned wells. The NeoSteer CL ABSS’s closed loop autosteering algorithm feature is capable of delivering better steering control and drilling a straighter hole. The benefits of a straighter hole, in addition to tighter target adherence, are less side force generation and less friction within the wellbore. This makes it easier to stay in zone longer and run production casing.

Over 12 wells, for all the tangents that the NeoSteer CL ABSS drilled from 10° to 19°, the average DLS was always below 1.2°/100 ft. The average DLS produced within the tangent section by the NeoSteer CL ABSS was 0.80°/100 ft.

Products Used

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