EXHIBIT 99.1
ATWOOD OCEANICS, INC. AND SUBSIDIARIES FLEET STATUS REPORT
AS OF MARCH 27, 2007
As used herein, "we", "us", and "our" refers to Atwood Oceanics, Inc. and its
subsidiaries, except where the context indicates otherwise. Statements contained
in this Fleet Status Report, including information regarding our estimated rig
availability, contract duration, future dayrates, future daily operating costs,
future effective tax rates, customer or contract status are forward-looking
statements. These statements reflect management's reasonable judgment with
respect to future events. Forward-looking statements involve risks and
uncertainties. Actual results could differ materially from those anticipated as
a result of various factors including: our dependence on the oil and gas
industry; the risks involved in upgrade, repair and construction of our rigs;
competition; operating risks; risks involved in foreign operations; risks
associated with possible disruptions in operations due to terrorism; risks
associated with a possible disruption in operations due to the war with Iraq and
governmental regulations and environmental matters. A list of additional risk
factors can be found in our annual report on Form 10-K for the year ended
September 30, 2006, filed with the Securities and Exchange Commission. All
information in this Fleet Status Report is as of the date indicated above. We
undertake no duty to update the content of this Fleet Status Report or any
forward-looking statement contained herein to conform the statement to actual
results or to reflect changes in our expectations.
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<Caption>
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UNAUDITED
ESTIMATED AVERAGE PER
RATED ESTIMATED CONTRACT DAY OPERATING ADDITIONAL
RIG NAME WATER LOCATION CUSTOMER CONTRACT END DAYRATE COSTS (NOT COMMENTS
DEPTH DATE INCLUDING TAX)
FOR THE THREE
MONTHS ENDED
JANUARY 31,
2007/MONTH
ENDED JANUARY
31, 2005 ONLY
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SEMISUBMERSIBLES:
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ATWOOD 5000' Australia BHP BILLITON FIRM WORK -- 5 wells at $160,000 $89,000/93,000 Wells are
EAGLE PETROLEUM PTY (7 wells 1 well at $170,000 subject to a
("BHPB") remaining 1 well at $150,000 change in
including (expected to be sequence and a
current drilled in July portion of the
operation) and August 2007) dayrate is
October 2007 subject to some
change due to
currency
exchange rate
variance.
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</Table>
1
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Australia BHPB OPTIONS -- $170,000 N/A A portion of
(3 wells) the dayrate is
January 2008 subject to some
if all three change due to
option wells currency
are drilled exchange rate
(The first variance.
two option
wells must be
exercised no
later than 68
days prior to
the completion
of the firm
work)
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Australia ENI Spa AGIP FIRM WORK -- $360,000 N/A We expect the
EXPLORATION & (1 well) well to take 40
PRODUCTION March 2008 to 45 days to
DIVISION (assuming that complete.
("ENI") all of the
above option
wells are
drilled)
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Australia WOODSIDE FIRM WORK -- $405,000 N/A A portion of the
ENERGY LTD (2 years) dayrate is
("WOODSIDE") March 2010 subject to some
(assuming change due to
that all of currency
that option exchange rate
wells are variance.
drilled)
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Australia N/A N/A N/A N/A The rig could be
off dayrate for
ten to fourteen
days during the
second quarter
of fiscal year
2008 for
required
regulatory
inspections and
maintenance.
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2
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ATWOOD 5,000' Mauritania/ WOODSIDE FIRM WORK -- $240,000 $63,000/55,000 The rig is
HUNTER Libya April/May 2008 (Mauritania) currently being
$245,000 (Libya) mobilized to
Libya, which
should take
approximately
three weeks
with arrival in
Libya around
mid-April 2007.
(The dayrate
during the
mobilization
period is 95%
of $245,000 or
approximately
$233,000)
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TBD WOODSIDE OPTIONS -- TBD N/A
Two (2)
six-month
options.
April/May 2009,
if exercised at
negotiated
market rate.
(Agreement has
to be executed
by November
2007)
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ATWOOD 5,000' Malaysia SARAWAK FIRM WORK -- $113,000 $78,000/$49,000 (The $24 million
FALCON SHELL BERHAD July 10, 2007 (Average costs Shell reimburse-
("SHELL") for three months ment is being
ended January 31, amortized as
2007 is high due revenues over
to rig upgrade. the remaining
to rig costs for firm contract
January is more commitment
in lines with following the
current ongoing upgrade (32
expectation) months) which
will increase
dayrate revenues
by approximately
$24,000.)
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Malaysia SHELL FIRM WORK -- $160,000/ N/A Most of the
(2 years) $200,000 (dayrate work during
July 2009 depends on water this period is
depth of each expected to be
well) at the $160,000
dayrate level.
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Malaysia SHELL OPTION -- TBD N/A
(1 year)
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3
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ATWOOD 2,000' Bulgaria MELROSE FIRM WORK -- $125,000 (two wells) $51,000/$48,000
SOUTHERN RESOURCES (3 wells) $155,000 (one well)
CROSS ("MELROSE") June 2007
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Bulgaria MELROSE OPTIONS -- $125,000 N/A
(2 wells)
August 2007
(if both
option wells
are drilled)
Options must
be exercised
ten (10) days
prior to
completion
of second
firm well.
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Turkey TURKIYE FIRM WORK -- 3 wells at $290,000 N/A
PETROLLERI (4 wells) 1 well at $320,000
A.O. ("TPAO") February 2008
(assuming
above MELROSE
option wells
are drilled)
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Ukraine VANCO FIRM WORK -- $325,000 N/A See above
INTERNATIONAL (1 well)
LTD. April 2008
("VANCO") (assuming
MELROSE
options are
exercised)
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Ukraine VANCO OPTIONS -- $325,000 N/A See above
(1 well)
June 2008
(assuming
MELROSE, and
VANCO options
are all
exercised.
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4
<Table>
CANTILEVER JACK-UPS:
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ATWOOD 400' India GUJARAT STATE FIRM WORK -- $113,000 $44,000/$36,000
BEACON PETROLEUM January 2008
CORPORATION
LTD
("GSPC")
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India GSPC FIRM WORK -- $133,500 N/A
(12 months)
January 2009
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India GSPC OPTIONS -- TBD N/A
(1 year)
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VICKSBURG 300' Thailand CHEVRON FIRM WORK -- $94,500 $38,000/$34,000
OVERSEAS June 2007
PETROLEUM
("CHEVRON")
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Thailand CHEVRON FIRM WORK -- $154,000 N/A
(2 years)
June 2009
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Thailand N/A N/A N/A N/A The rig could
be off dayrate
for ten to
fourteen days
during the last
quarter of fiscal
year 200 or first
quarter of fiscal
year 2008
for required
regulatory
inspections and
maintenance.
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5
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SEMISUBMERSIBLE TENDER ASSIST UNIT:
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SEAHAWK 1,800' Equatorial AMERADA HESS FIRM WORK -- $68,430 $76,000/$67,000 Contract provides
Guinea EQUATORIAL September 2008 (plus approximately for dayrate
(GUINEA, INC. $19,000 of amortized increases based
"HESS") per day revenue.) upon certain
cost escalations
beginning with
the second year
of the contract.
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Equatorial HESS OPTIONS -- $68,430 N/A Dayrate subject
Guinea (2 years) to increase due
September 2010 to contract cost
(if all four escalations.
six-month
options are
exercised)
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SUBMERSIBLE:
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RICHMOND 70' US Gulf of HELIS FIRM WORK -- $80,000 $34,000/33,000
Mexico OIL & GAS October 2007
("HELIS")
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US Gulf of N/A N/A N/A N/A The rig could
Mexico be off dayrate
for ten to
fourteen days
during the first
or second
quarters of
fiscal year 2008
for required
regulatory
inspections and
maintenance.
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6
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MANAGEMENT CONTRACT
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NORTH N/A Australia WOODSIDE FIRM WORK -- Daily margin of The management
RANKIN 'A' May 2007 around $5,000 contract could
terminate in
May 2007.
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NOTE -- EXPECTED TAX RATE
1) The effective tax rate for fiscal year 2007 is now expected to be
13% to 18%. Virtually all of the Company's expected tax provision for fiscal
year 2007 relates to taxes in foreign jurisdictions. Working in foreign
jurisdictions with nontaxable or deemed profit tax systems contribute to the
effective tax rate being significantly less than the United States statutory
rate.
2) Other Drilling Costs in Addition to the Above Rig Costs --
PER DAY FOR THE MONTH ENDED JANUARY 2007 $13,000
7