PeriScope Mapper Guides Precise Placement of CACT Extended-Reach Well | Schlumberger
Case Study

Challenge: Place extended-reach well in thin 2-m target zone with structural uncertainties without exceeding drilling torque limit

Solution: Land well using PeriScope bed boundary mapper and real-time images from EcoScope multifunction logging-while-drilling service. Guide lateral drain placement with adnVISION azimuthal density neutron and PeriScope services


  • Achieved 100% net to gross
  • Accomplished initial oil production rate of 2,000 bbl/d with 0% water cut
  • Drilled a 340-m landing section on a smooth trajectory that minimized accumulation of high drilling torque
  • Placed 415-m lateral drain within 0.5 m of top of pay zone without exiting the reservoir and avoided making unnecessary adjustments, keeping the well within the drilling torque limit
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PeriScope Mapper Guides Precise Placement of CACT Extended-Reach Well

Bed boundary mapper helps achieve 100% net to gross while geosteering high-tortuosity ERD well

Recover reserves in thin reservoir layer

The CACT Operators Group planned to drill an extended-reach horizontal well to recover reserves in a thin reservoir layer approximately 2 m thick. This well, which was designed to complement an existing well, was to be landed in the structure's flank while turning. Then the well's horizontal section was to be drilled eastward, following the structural slope, for 400 m, the distance required to achieve the well's economic limit.

The biggest challenge was meeting the directional steering and well placement goals to land the 300-m section within the thin target zone. Drilling would be along a downdip followed by an updip and then leveling off at the minimum depth required for setting the 7-in casing shoe. The team had to avoid drilling into the tight calcite cemented streak in the upper part of the reservoir. Doing so could cause an instant drilling torque increase that would make it impossible to drill the production interval to the planned 400-m length.

Minimize drilling torque, maintain trajectory

The team used rotary steerable systems and advanced LWD technology, including PeriScope bed boundary mapping, EcoScope LWD, and adnVISION services. While drilling the landing section, PeriScope deep azimuthal measurements kept them informed about the distance to the reservoir boundaries, and EcoScope density images provided real-time formation evaluation and structural dip interpretation. In the horizontal section, the adnVISION service was used for formation evaluation, and the PeriScope mapper's ability to simultaneously delineate multiple boundaries enabled accurate wellbore placement within the thin pay zone without drilling into the upper reservoir hard streak—despite the structural uncertainties.

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The well placement team planned to land the extended-reach horizontal well in the flank of the structure while turning and then drill a 400-m horizontal section straight eastward.
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Despite significant differences between the actual structural profile and the original predrill model, the horizontal section was successfully placed 0.5 m below

The actual structure updip began much sooner after the landing section entered the reservoir than the predrill model had indicated. However, using real-time PeriScope bed boundary mapping and EcoScope fullbore density images, the drilling team was able to adjust the trajectory smoothly with relatively low dogleg severity. This smooth adjustment minimized the accumulation of high drilling torque while keeping the trajectory within the porous zone and avoiding entering the tight calcite cemented streak in the upper part of the reservoir.

Achieve 100% net to gross

The actual structure found in the well's horizontal section varied significantly from the original predrill model, but the PeriScope mapper provided clear identification and delineation of the reservoir's top and bottom boundaries. This information made it possible to keep the well

trajectory 0.5 m below the top of the pay zone without exceeding the drilling torque limit of 42,000 lbf.ft. After drilling 290 m of the lateral section, total drilling torque had reached nearly 41,000 lbf.ft. However, the well placement team extended the section an additional 125 m within the remaining 1,000-lbf.ft drilling torque window—15 m beyond the planned 400-m lateral length—by avoiding unnecessary trajectory adjustments.

Precise placement of the lateral producing section resulted in 100% net to gross, ensuring optimum reserve recovery. The well has been producing 2,000 bbl/d of oil with 0% water cut. Well test data showed that the well could have produced up to 4,000 bbl/d of oil, but CACT elected to limit production for reservoir management purposes.

“Very good and reliable PeriScope LWD technology and the high skill set of the Schlumberger well placement team drilled 415 m of smooth lateral and achieved 100% net pay in a thin sand target of 2 m with only 1,000 lbf.ft of drilling torque available.”

Thanh Binh Tran, Asset Team Coordinator, CACT Operators Group

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