American Oil and Gas Reporter - September 2016 - 63

SpecialReport: Horizontal & Innovative Drilling
and has a wide operating range with respect to flow rates as well as mud and
cement weights/viscosities. In fact, the
maximum flow rate is limited only by
how much additional standpipe pressure
is available, as well as considerations for
the shear values of other completion components in the string.
Niobrara/Codell Field Study
Niobrara/Codell formations present a
diverse variety of challenges for casing/liner running operations. Kaiser-Francis
challenged itself to advance casing running
methods to improve well economics by
maximizing efficiency and reducing the
costs associated with installing casing.
The objective was to implement a viable
solution that would decrease run times
and minimize the force needed to combat
the high drag and friction inherent in
horizontal well profiles.
The eight-well project analyzed three

methods of running casing for performance. By ensuring that formation characteristics were similar and drilling parameters were kept as close to identical as
possible, the disparity in downhole performance can be attributed to the casing
installation method used.
Four wells did not use a vibratory
casing tool. Casing was run in three wells
(Biscayne, Fury 1 and Shelby 1) using
buttress threads without a vibratory tool,
and in one well (Polara 1) it was run
using high-torque semi-flush (SF) threads
without a vibratory casing tool. Casing
in the other four wells (Worland 1B, Camaro 1, Thunderbird 1A and Malibu 1)
utilized high-torque SF threads and vibratory casing tools. A performance comparison of the three methods of running
casing illustrates that the four wells in
which casing was run with vibratory tools
consistently outperformed the four offsets
wells that did not use a vibratory tool.

Figure 1 shows the casing running
speeds for the eight-well performance
analysis. The four wells utilizing the vibratory casing tool appear to form a relatively compact grouping compared with
the other wells from the study, further
indicating the consistent performance of
the downhole vibratory method.
Figure 2 gives a more detailed
comparison of the average casing/liner
running speeds for the three casing
installation methods in this study. The
wells using the vibratory tool and hightorque SF casing had a 121 percent
average increase in running speed while
rotating the liner in the hole, compared
with the three wells that used buttressthread casing and no vibratory tool. Compared with the well using the same hightorque SF casing, but no vibratory tool,
the data show a 21 percent average
increase in running speed while rotating
the liner in the hole on the wells using

SEPTEMBER 2016 63


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Table of Contents for the Digital Edition of American Oil and Gas Reporter - September 2016

Contents
American Oil and Gas Reporter - September 2016 - Cover1
American Oil and Gas Reporter - September 2016 - Cover2
American Oil and Gas Reporter - September 2016 - Contents
American Oil and Gas Reporter - September 2016 - 4
American Oil and Gas Reporter - September 2016 - 5
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American Oil and Gas Reporter - September 2016 - Cover3
American Oil and Gas Reporter - September 2016 - Cover4
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