Attached files
| file | filename |
|---|---|
| 8-K - ROWAN COMPANIES PLC | v199777_8k.htm |
| EX-99.1 - ROWAN COMPANIES PLC | v199777_ex99-1.htm |
 |
LAND
RIG FLEET AND CONTRACT STATUS
As
of October 25, 2010
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ONSHORE RIGS
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Maximum
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Contract Status
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Horsepower
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Drilling
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Estimated
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Name
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Type
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Drawworks
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Mud Pumps
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Depth (feet)
|
Location
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Customer
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Duration
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Comments
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Rig
9
|
SCR
diesel electric
|
2,000 | 3,200 | 20,000 |
Louisiana
|
Midstates
Petroleum
|
January
2011
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Rig
12
|
SCR
diesel electric
|
1,500 | 2,600 | 18,000 |
Louisiana
|
EOG
|
January
2011
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Rig
14
|
AC
electric
|
3,000 | 3,200 | 35,000 |
Texas
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Available
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Rig
15
|
AC
electric
|
3,000 | 3,200 | 35,000 |
Texas
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Available
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Rig
26
|
SCR
diesel electric
|
2,000 | 4,800 | 25,000 |
Texas
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BBX
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November
2010
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Rig
29
|
SCR
diesel electric
|
1,500 | 2,600 | 18,000 |
Texas
|
Available
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Rig
30
|
AC
electric
|
2,000 | 2,600 | 20,000 |
Louisiana
|
Chesapeake
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December
2010
|
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Rig
31
|
SCR
diesel electric
|
3,000 | 4,400 | 35,000 |
Texas
|
Available
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Rig
33
|
SCR
diesel electric
|
1,500 | 3,200 | 18,000 |
Texas
|
Plains
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February
2011
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Rig
35
|
SCR
diesel electric
|
1,500 | 4,400 | 18,000 |
Texas
|
EXCO
Resources
|
September
2011
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|
Rig
51
|
SCR
diesel electric
|
2,000 | 4,400 | 25,000 |
Texas
|
Krescent
|
November
2010
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Rig
52
|
SCR
diesel electric
|
2,000 | 4,400 | 25,000 |
Texas
|
Swift
|
December
2010
|
Rig
commenced operations in October 2010.
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Rig
53
|
SCR
diesel electric
|
2,000 | 4,400 | 25,000 |
Louisiana
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Chesapeake
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December
2010
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Rig
54
|
SCR
diesel electric
|
2,000 | 4,400 | 25,000 |
Louisiana
|
Chesapeake
|
December
2010
|
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Rig
59
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EnCana
|
August
2012
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Rig
60
|
AC
electric
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2,000 | 3,200 | 25,000 |
Oklahoma
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Devon
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April
2011
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Rig
61
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
Wynn-Crosby
|
December
2010
|
Rig
commenced operations in October 2010.
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Rig
62
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Oklahoma
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Devon
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March
2011
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Rig
63
|
AC
electric
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2,000 | 3,200 | 25,000 |
Texas
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EnCana
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November
2014
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Rig
64
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AC
electric
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2,000 | 3,200 | 25,000 |
Louisiana
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EnCana
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January
2011
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Rig
65
|
AC
electric
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2,000 | 3,200 | 25,000 |
Louisiana
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EnCana
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January
2011
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Rig
66
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EnCana
|
June
2015
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Rig
67
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EnCana
|
January
2011
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Rig
68
|
AC
electric
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2,000 | 3,200 | 25,000 |
Alaska
|
Pioneer
|
December
2010
|
Rig
is on standby at a reduced rate.
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|
Rig
76
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Louisiana
|
EnCana
|
April
2011
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Rig
77
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EnCana
|
December
2012
|
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Rig
84
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EnCana
|
June
2011
|
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Rig
85
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Alabama
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Chevron
|
April
2011
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Rig
86
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EnCana
|
February
2012
|
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Rig
87
|
AC
electric
|
2,000 | 3,200 | 25,000 |
Texas
|
EXCO
Resources
|
May
2012
|
||||||||||||||
Rigs 9
through 35 were constructed at various dates between 1960 and 1982, utilizing
new as well as used equipment, and have since been substantially
rebuilt. Rigs 51, 52, 53 and 54 were constructed during
2001-02. Rigs 59 through 66 were completed during 2006, Rigs 67
through 77 during 2007, Rigs 84 and 85 in 2008 and Rigs 86 and 87 in
2009. All but Rig 29 are equipped with a top-drive drilling
system. Operating day rates range from $15,500 to
$27,000. Estimated contract durations reflect either stated drilling
periods expected time required for the contracted well or
wells. Estimated number of idle days during September 2010 was 178 (80% utilization).
ROWAN
HEREBY ADVISES THAT THE TABLE SET FORTH ABOVE MAY CONTAIN INACCURATE, INCOMPLETE
AND/OR INCORRECT INFORMATION AND IS SUBJECT TO CHANGE AT ANY
TIME. THE INFORMATION SHOULD NOT BE RELIED UPON FOR ANY PURPOSE, AND
ROWAN HEREBY DISCLAIMS ANY LIABILITY RELATING TO THE USE OF THE INFORMATION SET
FORTH ABOVE.
This
report contains forward looking statements within the meaning of the Private
Securities Litigation Reform Act of 1995, including, without limitation,
statements as to the expectations, beliefs and future expected financial
performance of the Company that are based on current expectations and are
subject to certain risks, trends and uncertainties that could cause actual
results to differ materially from those projected by the Company. Relevant
factors have been disclosed in the Company's filings with the U. S. Securities
and Exchange Commission.
Revisions
to Fleet Status Report Noted in Bold