American Oil and Gas Reporter - September 2016 - 61
SpecialReport: Horizontal & Innovative Drilling
A secondary issue in horizontal wells
is cement channeling and poor cement/casing bonding in both the horizontal portion
of the intermediate casing string in the
curve section and in the lateral liner/casing.
Cement integrity is improved by the
casing vibrations produced when cement
is pumped through a vibratory tool.
To combat these problems in getting
casing/liners to bottom, operators increasingly are using downhole vibratory
tools similar to those common in horizontal well drilling operations to run
casing strings. Downhole vibratory tools
break the static friction between the work
string and the wellbore or casing. The
tool has been used for extended laterals,
deviated wellbores, liner hanger systems,
cemented and noncemented wells, openhole packer systems, sleeve-systems, and
intermediate casing.
Seeking to consistently attain maximum casing depth while improving casing
run times in its extended-reach wells,
Kaiser-Francis Oil Company conducted
an eight-well field study in the
Niobrara/Codell play in Wyoming utilizing
vibratory casing technology. In this project,
a vibratory casing tool was placed in the
shoe track between the shoe and collar
to run casing in four wells, while casing
was run in the other four wells without a
vibratory tool. All eight wells were completed with 41⁄2-inch, 13.5-pound, P-110
liner in two-section laterals.
The data show up to a 121 percent
average increase in running speed while
rotating the liner in the hole using the vibratory casing tool, resulting in as much
as an average 55 percent decrease in rig
time compared with offset wells (Table
1). Importantly, less torque at higher
rotary speeds also was seen on the wells
using the vibratory tool.
include:
* Failure to get casing to bottom;
* Excessive time spent running casing
(directly impacting operational costs);
* High residual stress left in casing
and other downhole components (often
causing issues later in the life of the
well);
* Damage to casing and sleeve systems caused by rough handling during
trip in (including "hammering" casing
into the well using the rig blocks); and
* Overtorqued connections during
rotation to get casing in hole.
Proper cementing is an integral operation that has significant impact on the
completion process and is essential to
well longevity. Displacing the drilling
mud column with cement can be difficult
in long-lateral liner/casing applications
because casing typically favors the low
side of the wellbore. Casing eccentricity
also impedes mud displacement in the
narrow side of the annulus, permitting
Downhole Problems
The problems caused by excessive
casing-related friction in horizontal wells
TABLE 1
Performance Comparison of Niobrara/Codell Casing Running Field Test
Niobrara/Codell Well Comparisons
Well Name
Vibe Tool
Trip Length
Past
7 in. CS
Distance
Rotating
Hours
Rotating
Running
Speed
(ft/hr)
Max
Torque
(k ft-lbf)
Thread Type
41⁄2"
P-110
Lateral
Dip
Torque at TD
(K ft-lbf)
Drilling
Off Bottom
(Benchmark) Method 1: Buttress Threads - No Casing Tool
Biscayne
No
5,649 ft
4,333 ft
51.5 hrs
84.1
9.5
BTC
Down 100 ft
14(K ft-lbf)
60-RPM
11 (K ft-lbf)
60-RPM
Fury 1
No
3,805 ft
5,852 ft
57.5 hrs
101.8
11.9
BTC
Up 122 ft
14(K ft-lbf)
60-RPM
12 (K ft-lbf)
90-RPM
Shelby 1
No
4,236 ft
5,778 ft
21.0 hrs
275.1
12.0
BTC
Down 74 ft
14(K ft-lbf)
60-RPM
12 (K ft-lbf)
90-RPM
15,963 ft
130 hrs
Totals:
15963 ft ÷ 130 hrs = average 122.79 ft/hr
Method 2: High Torque Threads - No Casing Tool
Polara 1
No
4,090 ft
Improvement vs. Method 1
5,831 ft
26 hrs
224.3
11.5
14 (K ft-lbf)
11 (K ft-lbf)
50-RPM
60-RPM
83% Speed Increase= 102 ft/hr Gained
Hyd 521 SF
45% Run Time Decrease= 19 hrs Saved
Down 18 ft
Method 3: Casing Tool with High Torque Threads
Worland 1B
Yes
6,069 ft
3,911 ft
14.5 hrs
269.7
9.5
Ultra-SF
Down 147 ft
10 (K ft-lbf)
70-RPM
10 (K ft-lbf)
80-RPM
Camaro 1
Yes
4,576 ft
4,830 ft
19.0 hrs
254.2
9.5
Ultra-SF
Down 290 ft
13 (K ft-lbf)
60-RPM
9 (K ft-lbf)
60-RPM
Thunderbird 1A
Yes
4,174 ft
5,368 ft
23.0 hrs
233.4
9.0
Ultra-SF
Up 140 ft
12 (K ft-lbf)
50-RPM
9 (K ft-lbf)
80-RPM
Malibu 1
Yes
4,185 ft
5,707 ft
16.5 hrs
345.9
10.5
Hyd 521 SF
Down 18 ft
14 (K ft-lbf)
70-RPM
11 (K ft-lbf)
70-RPM
19,816 ft
73 hrs
Totals:
19816 ft ÷ 73 hrs = 271.45 ft/hr
Improvement vs. Method 1
55% Run Time Decrease= 23 hrs Saved
121% Speed Increase= 149 ft/hr Gained
Improvement vs. Method 2
17% Run Time Decrease= 4 hrs Saved
21% Speed Increase= 47.15 ft/hr Gained
**The following calculation was used to compare casing run times in Table 1:
The average distance rotating for all eight wells (5,201 feet) ÷ the average casing running speed (ft/hr) for each casing method.
SEPTEMBER 2016 61
American Oil and Gas Reporter - September 2016
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
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American Oil and Gas Reporter - September 2016 - Cover3
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