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is shifted from the reported bottom-hole location. If the well
is truly hundreds of feet closer to the offset, there will be large
volumes of acreage that experience redundant stimulation, as
well as an equal amount of rock left unstimulated. Running a
high accuracy gyro survey in this same wellbore can reduce the
lateral uncertainty by 50% or more, enabling improvements
in well spacing, fracture designs, and significantly improved
ultimate recovery of the reservoir.
while minimizing well construction costs. As wells continue to extend farther, their true location is less
well known. Wellbore positional uncertainty is quantified using Ellipsoids of Uncertainty (EOU). This
uncertainty can lead to wells being located closer together or farther apart than they appear on paper.
The EOU associated with a Standard MWD survey at total depth of an extended reach horizontal
well can reach over 400’ laterally in each direction. There is a real possibility that the well is shifted from
the reported bottom-‐hole location. If the well is truly hundreds of feet closer to the offset, there will be
both large volumes acreage that experience redundant stimulation, as well as an equal amount of rock
left unstimulated. Running a high accuracy gyro survey in this same wellbore can reduce the lateral
uncertainty by 50% or more, enabling improvements in well spacing, fracture designs, and significantly
improved ultimate recovery of the reservoir.
Austin Pile
The blue lines are the MWD surveys for 3 wells. The ellipses are the associated uncertainty.
The red line is the true wellbore location
Fracture overlap
Missed acreage
Figure 3.
Threewells surveyedbyMWDand their uncertainties. The rectangles represent the expected stimulated rock volumes. The true position
of thewell may not be right on the blue line, resulting in inefficient wellbore stimulation.
