American Oil and Gas Reporter - July 2015 - 60
because the CT was buckled helically
for significant lengths above the heel (reducing the benefit provided by CT weight
in the vertical).
Likewise, when the BUR was reduced
to 3.6 degrees/100 feet, lateral reach increased 290 feet because of the trade-off
of reduced vertical length with low buckling loads and increased buildup length
with high buckling loads. Unfortunately,
this trend did not continue to 2.0 degrees/100 feet, where the heel's buckling
load was not great enough to keep the
tubing from buckling in the top half of
the build section, and reach was actually
reduced compared to 3.0 degrees/100
feet BUR.
Figure 3 shows the rapid reduction of
buckling load in the heel as the build rate
declines from 3.0 to 1.0 degrees/100 feet.
These very low buckling loads combined
with CT operations near the lockup limits
cause the onset of buckling in the heel
and reduced lateral reach. As shown in
Figure 4, the optimal BUR range was
between 3.0 and 3.6/100 feet for the base
case well, with poor performance achieved
beyond 6.0 degrees and below 1.5 degrees/100 feet.
Analyses of additional TVDs of 8,000,
10,000 and 12,000 feet were performed
for BURs of 3.0, 5.0 and 8.0/100 feet. In
all of these cases, increases in TVD had
negligible impacts on lateral reach capability. This can be attributed to using the
same CT design in the deeper wells.
However, if stress in the deeper wells
had approached the tubing's working
limit, then an alternative CT design would
be necessary and could reduce lateral
reach if wall thickness or section lengths
were changed.
Completion Geometry
Completion geometry is important for
extending CT reach because the helical
buckling load and the wall contact force
caused by helical buckling are both a
function of radial clearance in the annulus.
Therefore, reducing the radial clearance
by narrowing the completion will reduce
buckling-related friction and extend reach.
The base case used 51⁄2-inch, 17-pound/foot
casing with a 4.892-inch internal diameter.
Increasing the casing weight to 23
pounds/foot reduced the ID to 4.67 inches
and extended the calculated reach by 235
feet. Using 41⁄2-inch, 15-pound/foot casing
with a 3.826-inch ID extended the calculated reach by 1,666 feet.
These calculations were done with a
monobore well completion, but simply
reducing the ID in the portions of the
well where buckling is expected would
achieve similar results. This frequently
means reducing the ID in the vertical
60 THE AMERICAN OIL & GAS REPORTER
American Oil and Gas Reporter - July 2015
Table of Contents for the Digital Edition of American Oil and Gas Reporter - July 2015
Contents
American Oil and Gas Reporter - July 2015 - Cover1
American Oil and Gas Reporter - July 2015 - Cover2
American Oil and Gas Reporter - July 2015 - Contents
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American Oil and Gas Reporter - July 2015 - Cover3
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