EX-99 5 exhibit994.txt EXHIBIT 99.4 ATWOOD OCEANICS, INC. AND SUBSIDIARIES FLEET STATUS REPORT AS OF DECEMBER 7, 2006 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, 2005, 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. CHANGES WILL BE HIGHLIGHTED IN YELLOW ----------------------------------------------------------------------------------------------------------------------------------- AVERAGE PER DAY ESTIMATED ESTIMATED OPERATING COSTS (NOT RATED CONTRACT CONTRACT INCLUDING TAX) FOR ADDITIONAL RIG WATER LOCATION CUSTOMER END DATE DAYRATE THE THREE MONTHS COMMENTS NAME DEPTH ENDED SEPTEMBER 30, 2006/MONTH OF SEPTEMBER 30, 2006 ONLY ----------------------------------------------------------------------------------------------------------------------------------- SEMISUBMERSIBLES: ----------------------------------------------------------------------------------------------------------------------------------- ATWOOD 5000' Australia BHP BILLITON FIRM WORK - 8 wells at $158,000 $85,000/73,000 Wells are subject to a EAGLE PETROLEUM PTY (10 wells) 1 well at $168,000 change in sequence and ("BHPB") August 2007 1 well at $150,000 a portion of the dayrate is subject to some change due to currency exchange rate variance. ----------------------------------------------------------------------------------------------------------------------------------- Australia ENI Spa AGIP FIRM WORK - $360,000 N/A We expect the well to EXPLORATION & (1 well) take 40 to 45 days to PRODUCTION December 2007 complete. DIVISION (assuming that all ("ENI") of the above option wells are drilled) 1 ----------------------------------------------------------------------------------------------------------------------------------- Australia WOODSIDE FIRM WORK - $405,000 N/A A portion of the dayrate ENERGY LTD (2 years) is subject to some change December 2009 due to currency exchange (assuming that all of rate variance. the above option wells are drilled) ----------------------------------------------------------------------------------------------------------------------------------- Australia N/A N/A N/A N/A The rig could be off dayrates for ten to fourteen days during the first quarter of fiscal year 2008 for required regulatory inspections and maintenance. ----------------------------------------------------------------------------------------------------------------------------------- ATWOOD 5,000' Mauritania/ WOODSIDE FIRM WORK - $240,000 $64,000/57,000 Operating costs are HUNTER Libya April/May 2008 (Mauritania) (Operating costs expected to be $245,000 (Libya) were higher than be $55,000 to $60,000 (The rig incurred normal for the per day while working in two (2) days of three months ended Mauritania/Libya; zero rate in September 30, 2006 however, costs could be October 2006 due due to higher higher duing any to an equipment costs incurred location period. repair issue.) during the period that the rig was relocated from Egypt to Mauritania.) ----------------------------------------------------------------------------------------------------------------------------------- Mauritania N/A N/A N/A N/A The rig is expected to be off dayrate for ten to fourteen days during December 2006 for required regulatory inspections and maintenance. ----------------------------------------------------------------------------------------------------------------------------------- TBD WOODSIDE OPTIONS - TBD N/A Two (2) six-month options. 2 ----------------------------------------------------------------------------------------------------------------------------------- ATWOOD 5,000' Malaysia SARAWAK SHELL FIRM WORK - $93,200 $56,000/$85,000 (The $24 million Shell FALCON BERHAD (2 wells) (The rig incurred (Due to expensing reimbursement is being ("SHELL") January 2007 four (4) days of certain costs amortized as revenues zero rate at the incurred in the over the remaining firm end of its shipyard shipyard, operating contract commitment period due to costs were high for following the upgrade weather related the month and three (32 months)which will days and another (3) months ended increase dayrate three (3) days of September 30, 2006. revenues by zero rate after Also, due to approximately $24,000.) leaving the expensing certain shipyard due to costs incurred during final testing the shipyard period and commissioning subsequent to of new equipment.) September 30, 2006, we now expect operating costs for the ATWOOD FALCON in the first quarter of fiscal year 2007 to be between $8 million and $9 million.) ----------------------------------------------------------------------------------------------------------------------------------- Malaysia SHELL FIRM WORK - $113,000 N/A July 10, 2007 ----------------------------------------------------------------------------------------------------------------------------------- Malaysia SHELL FIRM WORK - $160,000/ N/A Most of the work during (2 years) $200,000 (dayrate this period is expected July 2009 depends on water depth to be at the $160,000 of each well) dayrate level. ----------------------------------------------------------------------------------------------------------------------------------- Malaysia SHELL OPTION - TBD N/A (1 year) ----------------------------------------------------------------------------------------------------------------------------------- ATWOOD 2,000' Turkey TOREADOR FIRM WORK - $125,000 $44,000/$49,000 TOREADOR will drill its SOUTHERN TURKEY (3 wells) (The rig incurred (During the rig's last well after the CROSS LIMITED February 2007 two (2) days of relocation to the MELROSE program is ("TOREADOR") zero rate in Black Sea in completed. The dayrate November due to October 2006, for the last well will an equipment operating costs be $135,000. repair issue.) were expected to average around $60,000 per day. Some of this excess costs were offset by receipt of a $300,000 mobilization fee.) 3 ----------------------------------------------------------------------------------------------------------------------------------- Bulgaria MELROSE RESOURCES FIRM WORK - $125,000 N/A ("MELROSE") (3 wells) May 2007 ----------------------------------------------------------------------------------------------------------------------------------- Bulgaria MELROSE OPTIONS - $125,000 N/A (2 wells) July 2007 (if both option wells are drilled) ----------------------------------------------------------------------------------------------------------------------------------- Turkey TURKIYE P FIRM WORK - $290,000 N/A PETROLLERI A.O. (3 wells) ("TPAO") October 2007 (assuming above option wells are drilled) ----------------------------------------------------------------------------------------------------------------------------------- Turkey TPAO OPTIONS - $320,000 N/A If TPAO exercises their (3 wells) options, the well January 2008 sequence for TPAO (assuming option wells and MELROSE VANCO wells could option wells drilled change. and TPAO exercises options to drill all three option wells) ----------------------------------------------------------------------------------------------------------------------------------- Ukraine VANCO FIRM WORK - $305,000 N/A See above INTERNATIONAL LTD. (1 well) ("VANCO") March 2008 (assuming MELROSE and TPAO options are exercised) ----------------------------------------------------------------------------------------------------------------------------------- Ukraine VANCO OPTIONS - $325,000 N/A See above (1 well) April 2008 (assuming MELROSE, TPAO and VANCO options are all exercised) 4 ----------------------------------------------------------------------------------------------------------------------------------- CANTILEVER JACK-UPS: ----------------------------------------------------------------------------------------------------------------------------------- ATWOOD 400' Mobilization GUJARAT STATE FIRM WORK - $110,000 $29,000/$28,000 BEACON to India PETROLEUM December 2006 CORPORATION LTD (Mobilization is ("GSPC") expected to take 17 days.) ----------------------------------------------------------------------------------------------------------------------------------- India GSPC FIRM WORK - $113,000 N/A (13 months) January 2008 ----------------------------------------------------------------------------------------------------------------------------------- India GSPC FIRM WORK - $133,500 N/A (12 months) January 2009 ----------------------------------------------------------------------------------------------------------------------------------- India GSPC OPTIONS - (1 year) TBD N/A ----------------------------------------------------------------------------------------------------------------------------------- VICKSBURG 300' Thailand CHEVRON FIRM WORK - $94,500 $36,000/$40,000 OVERSEAS (8 months) PETROLEUM June 2007 ("CHEVRON") ----------------------------------------------------------------------------------------------------------------------------------- Thailand CHEVRON FIRM WORK - $154,000 N/A (2 years) June 2009 ----------------------------------------------------------------------------------------------------------------------------------- Thailand N/A N/A N/A N/A The rig could be off dayrate for ten to fourteen days during the first quarter of fiscal year 2008 for required regulatory inspections and maintenance. 5 SEMISUBMERSIBLE TENDER ASSIST UNIT: ----------------------------------------------------------------------------------------------------------------------------------- SEAHAWK 1,800' Equatorial AMERADA HESS FIRM WORK - $68,430 Average per day Contract provides for Guinea EQUATORIAL GUINEA, (2 years) (plus approximately operating costs dayrate increases INC. ("HESS") September 2008 $19,000 of amortized during September based upon certain per day revenue.) 2006 were $72,000. cost escalations (Operating costs beginning with the were high in second year of the September due to contract. the start of drilling operations. Ongoing normal operating costs are expected to be around $45,000 per day. In addition to the expected daily operating costs of $45,000 , there will be another $16,000 of amortized daily costs which will be more than offset by approximately $19,000 of amortized daily revenue.) ----------------------------------------------------------------------------------------------------------------------------------- Equatorial HESS OPTIONS - $68,430 N/A Dayrate subject to Guinea (2 years) incrase due to September 2010 contract cost (if all four escalations. six-month options are exercised) ----------------------------------------------------------------------------------------------------------------------------------- SUBMERSIBLE: ----------------------------------------------------------------------------------------------------------------------------------- RICHMOND 70' US Gulf of HELIS OIL & GAS FIRM WORK - $80,000 $33,000/40,000 Mexico ("HELIS") (4 wells remaining, including current well) May/June 2007 ----------------------------------------------------------------------------------------------------------------------------------- US Gulf of HELIS OPTIONS - TBD N/A Mexico September/October 2007 (one option for four additional wells) 6 ----------------------------------------------------------------------------------------------------------------------------------- US Gulf of N/A N/A N/A N/A The rig could be off Mexico dayrate for ten to fourteen days during the first quarter of fiscal year 2008 for required regulatory inspections and maintenance. ----------------------------------------------------------------------------------------------------------------------------------- MANAGEMENT CONTRACT ----------------------------------------------------------------------------------------------------------------------------------- NORTH N/A Australia WOODSIDE FIRM WORK - Daily margin of The management contract RANKIN 'A' May 2007 around $5,000 contract could terminate in May 2007. ----------------------------------------------------------------------------------------------------------------------------------- NOTE - EXPECTED TAX RATE 1) The effective tax rate for the fourth quarter of fiscal year 2006 was 17%, with an effective tax rate of 6% for fiscal year 2006. The effective tax rate for fiscal year 2007 is now expected to be 15% to 20%. Virtually all of the Company's tax provision for fiscal year 2006 and 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 THREE MONTHS ENDED SEPTEMBER 2006 $21,000
7