UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Date of Report (Date of earliest event reported): November 4, 2009 (November 4, 2009)
TRANSOCEAN LTD.
(Exact name of registrant as specified in its charter)
Switzerland | 000-53533 | 98-0599916 | ||
(State or other jurisdiction of incorporation or organization) |
(Commission File Number) |
(I.R.S. Employer Identification No.) |
Blandonnet International Business Center Building F, 7th Floor Chemin de Blandonnet 2 Vernier, Switzerland |
CH-1214 | |
(Address of principal executive offices) | (zip code) |
Registrants telephone number, including area code: +41 (22) 930-9000
(Former name or former address, if changed since last report)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
¨ | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
¨ | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
¨ | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) |
¨ | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) |
Item 2.02. | Results of Operations and Financial Condition. |
Our news release dated November 4, 2009, concerning third quarter 2009 financial results, furnished as Exhibit 99.1 to this report, is incorporated by reference herein.
Item 7.01. | Regulation FD Disclosure. |
Slide Presentation
On November 4, 2009, we are posting the slide presentation furnished as Exhibit 99.2 to this report on our website at www.deepwater.com. Exhibit 99.2 is incorporated in this Item 7.01 by reference.
Statements contained within the slide presentation that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements include but are not limited to projections relating to out-of-service forecasts, operating and maintenance costs trends, contract backlog, and other statements that are not historical facts. Such statements are subject to numerous risks, uncertainties and assumptions, including but not limited to, uncertainties relating to the level of activity in offshore oil and gas exploration and development, exploration success by producers, oil and gas prices, rig demand and capacity, drilling industry market conditions, possible delays or cancellation of drilling contracts, work stoppages, operational or other downtime, the Companys ability to enter into and the terms of future contracts, the availability of qualified personnel, labor relations, future financial results, operating hazards, political and other uncertainties inherent in non-U.S. operations (including exchange and currency fluctuations), war, terrorism, natural disaster and cancellation or unavailability of insurance coverage, the impact of governmental laws and regulations, the adequacy of sources of liquidity, the effect of litigation and contingencies and other factors discussed in the Companys Form 10-K for the year ended December 31, 2008, and in the Companys other filings with the Securities and Exchange Commission (SEC), which are available free of charge on the SECs website at www.sec.gov. Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those indicated. We caution investors not to place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statements, except as required by law.
Item 9.01. | Financial Statements and Exhibits. |
(d) Exhibits.
The exhibits to this report furnished pursuant to items 2.02, and 7.01 are as follows:
Exhibit |
Description | |
99.1 |
Transocean Ltd. Release Reporting Third Quarter 2009 Financial Results | |
99.2 |
Slide Presentation |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
TRANSOCEAN LTD. | ||||
Date: November 4, 2009 | By | /S/ MARGARET C. FITZGERALD | ||
Margaret C. Fitzgerald | ||||
Associate General Counsel |
Index to Exhibits
Exhibit Number |
Description | |
99.1 |
Transocean Ltd. Release Reporting Third Quarter 2009 Financial Results | |
99.2 |
Slide Presentation |
| ||||||
Transocean Ltd. Investor Relations and Communications Dept. | ||||||
| ||||||
Analyst Contact: | Gregory S. Panagos + 1 713-232-7551 |
News Release | ||||
Media Contact: | Guy A. Cantwell +1 713-232-7647 |
FOR RELEASE: November 4, 2009 |
TRANSOCEAN LTD. REPORTS
THIRD QUARTER 2009 FINANCIAL RESULTS
ZUG, SWITZERLANDTransocean Ltd. (NYSE: RIG) today reported net income attributable to controlling interest for the three months ended September 30, 2009 of $710 million, or $2.19 per diluted share, compared to net income attributable to controlling interest of $1.063 billion, or $3.30 per diluted share for the three months ended September 30, 2008. Revenues for the third quarter of 2009 were $2.823 billion compared to $3.192 billion for the third quarter 2008.
Third quarter 2009 results were adversely impacted by certain net charges, after tax, totaling $148 million, or $0.46 per diluted share, as follows:
| $132 million related to various litigation matters, |
| $46 million for impairment of intangible assets related to drilling management services, |
| $10 million primarily related to the retirement of debt and expenses associated with the GlobalSantaFe merger, |
| partially offset by $40 million of income related to discrete tax items and gains on settlements of certain tax matters. |
Operations Quarterly Review
Revenues for the three months ended September 30, 2009 decreased slightly to $2.823 billion, compared to revenues of $2.882 billion during the three months ended June 30, 2009. The decrease was primarily due to a $164 million reduction in revenue resulting from the stacking of rigs and decreased activity, partially offset by a $108 million increase in revenue due to the commencement of operations of two of our newbuild drillships and improvements in dayrates and revenue efficiency.
Operating and maintenance expenses for three months ended September 30, 2009 were $1.396 billion, compared to $1.277 billion for the prior three-month period, an increase of $119 million or 9.3 percent. The quarter-to-quarter increase in operating and maintenance costs primarily consisted of $137 million related to various litigation matters and increased shipyard expenditures, partially offset by the cost benefits resulting from the stacking of rigs.
General and administrative expenses of $54 million for the third quarter of 2009 were essentially unchanged, compared to the second quarter of 2009.
Interest Expense and Liquidity
Interest expense, net of amounts capitalized, for the third quarter of 2009 totaled $115 million, compared to $114 million for the second quarter of 2009.
As of September 30, 2009, total debt was $11.922 billion, compared to total debt of $12.053 billion as of June 30, 2009, a decrease of $131 million. During the third quarter 2009, the company repaid approximately $1.2 billion of debt. This was offset by an increase of debt of $1.1 billion, including $716 million associated with the Petrobras 10000 capital lease and $353 million of other borrowings.
Cash flow from operating activities totaled $1.406 billion for the third quarter of 2009, compared to $1.576 billion for the second quarter 2009.
Effective Tax Rate
Transoceans reported Effective Tax Rate(1) of 16.4 percent for the third quarter of 2009 reflects a benefit from various discrete tax items of $29 million which primarily resulted from changes in estimates. Excluding these items as well as the adverse charges detailed above, the Annual Effective Tax Rate(2) for the third quarter of 2009 was 16.4 percent versus 15.7 percent in the second quarter of 2009.
Conference Call Information
Transocean will conduct a teleconference call at 10:00 a.m. Eastern time, 4:00 p.m. Swiss time, today. To participate, dial +1 (913) 312-1305 and refer to confirmation code 4209411 approximately five to 10 minutes prior to the scheduled start time of the call. In addition, the conference call will be simultaneously broadcast in a listen-only mode over the Internet and can be accessed by logging onto the companys Web address at www.deepwater.com and selecting Investor Relations. It may also be accessed at www.CompanyBoardroom.com by typing in Transoceans New York Stock Exchange trading symbol, RIG. A file containing five charts to be discussed during the conference call, titled 3Q09 Charts, has been posted to Transoceans Web site and can be found by selecting Investor Relations.
A telephonic replay of the conference call should be available after 1:00 p.m. Eastern time, 7:00 p.m. Swiss time, on November 4, 2009 and can be accessed by dialing +1 (719) 457-0820 and referring to the passcode 4209411. Also, a replay will be available through the Internet and can be accessed by visiting either of the above-referenced Worldwide Web addresses. Both replay options will be available for approximately 30 days.
Transocean is the worlds largest offshore drilling contractor and the leading provider of drilling management services worldwide. With a fleet of 136 mobile offshore drilling units plus seven announced ultra-deepwater newbuild units, Transoceans fleet is considered one of the most modern and versatile in the world due to its emphasis on technically demanding segments of the offshore drilling business. Transocean owns or operates a contract drilling fleet of 42 High-Specification Floaters (Ultra-Deepwater, Deepwater and Harsh-Environment semisubmersibles and drillships), 26 Midwater Floaters, 10 High-Specification Jackups, 55 Standard Jackups and other assets utilized in the support of offshore drilling activities worldwide.
(1) | Effective Tax Rate is defined as income tax expense divided by income before income taxes. See the accompanying schedule entitled Supplemental Effective Tax Rate Analysis. |
(2) | Annual Effective Tax Rate is defined as income tax expense excluding various discrete items (such as changes in estimates and tax on items excluded from income before income taxes) divided by income before income taxes excluding gains on sales and similar items pursuant to the accounting standard for income taxes and estimating the annual effective tax rate. See the accompanying schedule entitled Supplemental Effective Tax Rate Analysis. |
### | 09-36 |
TRANSOCEAN LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per share data)
(Unaudited)
Three months ended September 30, |
Nine months ended September 30, |
|||||||||||||||
2009 | 2008 | 2009 | 2008 | |||||||||||||
(As adjusted) | (As adjusted) | |||||||||||||||
Operating revenues |
||||||||||||||||
Contract drilling revenues |
$ | 2,602 | $ | 2,699 | $ | 8,061 | $ | 7,926 | ||||||||
Contract drilling intangible revenues |
58 | 143 | 237 | 557 | ||||||||||||
Other revenues |
163 | 350 | 525 | 921 | ||||||||||||
2,823 | 3,192 | 8,823 | 9,404 | |||||||||||||
Costs and expenses |
||||||||||||||||
Operating and maintenance |
1,396 | 1,426 | 3,844 | 3,947 | ||||||||||||
Depreciation, depletion and amortization |
367 | 336 | 1,082 | 1,040 | ||||||||||||
General and administrative |
54 | 46 | 163 | 140 | ||||||||||||
1,817 | 1,808 | 5,089 | 5,127 | |||||||||||||
Impairment loss |
(46 | ) | | (334 | ) | | ||||||||||
Loss from disposal of assets, net |
(3 | ) | (1 | ) | (3 | ) | (4 | ) | ||||||||
Operating income |
957 | 1,383 | 3,397 | 4,273 | ||||||||||||
Other income (expense), net |
||||||||||||||||
Interest income |
| 7 | 2 | 30 | ||||||||||||
Interest expense, net of amounts capitalized |
(115 | ) | (143 | ) | (365 | ) | (473 | ) | ||||||||
Loss on retirement of debt |
(7 | ) | | (17 | ) | (3 | ) | |||||||||
Other, net |
9 | (12 | ) | 9 | (20 | ) | ||||||||||
(113 | ) | (148 | ) | (371 | ) | (466 | ) | |||||||||
Income before income tax expense |
844 | 1,235 | 3,026 | 3,807 | ||||||||||||
Income tax expense |
138 | 175 | 573 | 533 | ||||||||||||
Net income |
706 | 1,060 | 2,453 | 3,274 | ||||||||||||
Net loss attributable to noncontrolling interest |
(4 | ) | (3 | ) | (5 | ) | (3 | ) | ||||||||
Net income attributable to controlling interest |
$ | 710 | $ | 1,063 | $ | 2,458 | $ | 3,277 | ||||||||
Earnings per share |
||||||||||||||||
Basic |
$ | 2.20 | $ | 3.32 | $ | 7.63 | $ | 10.27 | ||||||||
Diluted |
$ | 2.19 | $ | 3.30 | $ | 7.61 | $ | 10.19 | ||||||||
Weighted average shares outstanding |
||||||||||||||||
Basic |
321 | 319 | 320 | 318 | ||||||||||||
Diluted |
322 | 321 | 321 | 321 |
TRANSOCEAN LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In millions, except share data)
(Unaudited)
September 30, 2009 |
December 31, 2008 |
|||||||
(As adjusted) | ||||||||
Assets |
||||||||
Cash and cash equivalents |
$ | 886 | $ | 963 | ||||
Short-term investments |
180 | 333 | ||||||
Accounts receivable, net of allowance for doubtful accounts of $76 and $114 at September 30, 2009 and December 31, 2008, respectively |
2,614 | 2,864 | ||||||
Materials and supplies, net of allowance for obsolescence of $57 and $49 at September 30, 2009 and December 31, 2008, respectively |
457 | 432 | ||||||
Deferred income taxes, net |
87 | 63 | ||||||
Assets held for sale |
186 | 464 | ||||||
Other current assets |
193 | 230 | ||||||
Total current assets |
4,603 | 5,349 | ||||||
Property and equipment |
28,513 | 25,836 | ||||||
Less accumulated depreciation |
5,983 | 4,975 | ||||||
Property and equipment, net |
22,530 | 20,861 | ||||||
Goodwill |
8,134 | 8,128 | ||||||
Other assets |
751 | 844 | ||||||
Total assets |
$ | 36,018 | $ | 35,182 | ||||
Liabilities and equity |
||||||||
Accounts payable |
$ | 827 | $ | 914 | ||||
Accrued income taxes |
136 | 317 | ||||||
Debt due within one year |
702 | 664 | ||||||
Other current liabilities |
919 | 806 | ||||||
Total current liabilities |
2,584 | 2,701 | ||||||
Long-term debt |
11,220 | 12,893 | ||||||
Deferred income taxes, net |
772 | 666 | ||||||
Other long-term liabilities |
1,736 | 1,755 | ||||||
Total long-term liabilities |
13,728 | 15,314 | ||||||
Commitments and contingencies |
||||||||
Shares, CHF 15.00 par value, 502,852,947 authorized, 167,617,649 contingently authorized, 335,235,298 issued and 321,139,451 outstanding at September 30, 2009; 502,852,947 authorized, 167,617,649 contingently authorized, 335,235,298 issued and 319,262,113 outstanding at December 31, 2008 |
4,470 | 4,444 | ||||||
Additional paid-in capital |
7,394 | 7,313 | ||||||
Retained earnings |
8,285 | 5,827 | ||||||
Accumulated other comprehensive loss |
(442 | ) | (420 | ) | ||||
Total controlling interest shareholders equity |
19,707 | 17,164 | ||||||
Noncontrolling interest |
(1 | ) | 3 | |||||
Total equity |
19,706 | 17,167 | ||||||
Total liabilities and equity |
$ | 36,018 | $ | 35,182 | ||||
TRANSOCEAN LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions)
(Unaudited)
Three months ended September 30, |
Nine months ended September 30, |
|||||||||||||||
2009 | 2008 | 2009 | 2008 | |||||||||||||
(As adjusted) | (As adjusted) | |||||||||||||||
Cash flows from operating activities |
||||||||||||||||
Net income |
$ | 706 | $ | 1,060 | $ | 2,453 | $ | 3,274 | ||||||||
Adjustments to reconcile net income to net cash provided by operating activities |
||||||||||||||||
Amortization of drilling contract intangibles |
(58 | ) | (143 | ) | (237 | ) | (557 | ) | ||||||||
Depreciation, depletion and amortization |
367 | 336 | 1,082 | 1,040 | ||||||||||||
Share-based compensation expense |
23 | 16 | 66 | 49 | ||||||||||||
Excess tax benefit from share-based compensation plans |
(9 | ) | | (10 | ) | (11 | ) | |||||||||
Impairment loss |
46 | 16 | 334 | 16 | ||||||||||||
Loss from disposal of assets, net |
3 | 1 | 3 | 4 | ||||||||||||
Loss on retirement of debt |
7 | | 17 | 3 | ||||||||||||
Amortization of debt issue costs, discounts and premiums, net |
51 | 44 | 160 | 129 | ||||||||||||
Deferred revenue, net |
29 | (3 | ) | 72 | 22 | |||||||||||
Deferred expenses, net |
(3 | ) | (3 | ) | (38 | ) | (132 | ) | ||||||||
Deferred income taxes |
24 | 60 | 50 | 4 | ||||||||||||
Other, net |
7 | 7 | 30 | (1 | ) | |||||||||||
Changes in operating assets and liabilities |
213 | (121 | ) | 441 | (77 | ) | ||||||||||
Net cash provided by operating activities |
1,406 | 1,270 | 4,423 | 3,763 | ||||||||||||
Cash flows from investing activities |
||||||||||||||||
Capital expenditures |
(540 | ) | (514 | ) | (2,195 | ) | (1,703 | ) | ||||||||
Proceeds from disposal of assets, net |
2 | 5 | 10 | 352 | ||||||||||||
Proceeds from short-term investments |
29 | 14 | 422 | 14 | ||||||||||||
Purchases of short-term investments |
(34 | ) | (408 | ) | (268 | ) | (408 | ) | ||||||||
Joint ventures and other investments, net |
5 | | 5 | (3 | ) | |||||||||||
Net cash used in investing activities |
(538 | ) | (903 | ) | (2,026 | ) | (1,748 | ) | ||||||||
Cash flows from financing activities |
||||||||||||||||
Change in short-term borrowings, net |
254 | 202 | (246 | ) | (153 | ) | ||||||||||
Proceeds from debt |
26 | 303 | 345 | 2,354 | ||||||||||||
Repayments of debt |
(1,173 | ) | (1,000 | ) | (2,583 | ) | (4,673 | ) | ||||||||
Payments for warrant exercises, net |
| | (13 | ) | (4 | ) | ||||||||||
Proceeds from (taxes paid for) share-based compensation plans, net |
(6 | ) | (12 | ) | 16 | 49 | ||||||||||
Excess tax benefit from share-based compensation plans |
9 | | 10 | 11 | ||||||||||||
Other, net |
1 | (7 | ) | (3 | ) | (11 | ) | |||||||||
Net cash used in financing activities |
(889 | ) | (514 | ) | (2,474 | ) | (2,427 | ) | ||||||||
Net decrease in cash and cash equivalents |
(21 | ) | (147 | ) | (77 | ) | (412 | ) | ||||||||
Cash and cash equivalents at beginning of period |
907 | 976 | 963 | 1,241 | ||||||||||||
Cash and cash equivalents at end of period |
$ | 886 | $ | 829 | $ | 886 | $ | 829 | ||||||||
TRANSOCEAN LTD.
FLEET OPERATING STATISTICS
Operating Revenues ($ Millions) (1) | ||||||||||||||||||||
Three months ended | Nine months ended September 30, |
|||||||||||||||||||
September 30, 2009 |
June 30, 2009 |
September 30, 2008 |
2009 | 2008 | ||||||||||||||||
Contract Drilling Revenues |
||||||||||||||||||||
High-Specification Floaters: |
||||||||||||||||||||
Ultra Deepwater Floaters |
$ | 732 | $ | 673 | $ | 617 | $ | 2,107 | $ | 1,783 | ||||||||||
Deepwater Floaters |
463 | 406 | 323 | 1,282 | 1,025 | |||||||||||||||
Harsh Environment Floaters |
141 | 159 | 163 | 458 | 481 | |||||||||||||||
Total High-Specification Floaters |
1,336 | 1,238 | 1,103 | 3,847 | 3,289 | |||||||||||||||
Midwater Floaters |
618 | 644 | 690 | 1,971 | 2,015 | |||||||||||||||
High-Specification Jackups |
104 | 128 | 144 | 383 | 448 | |||||||||||||||
Standard Jackups |
537 | 608 | 749 | 1,835 | 2,134 | |||||||||||||||
Other Rigs |
6 | 7 | 13 | 25 | 40 | |||||||||||||||
Subtotal |
2,602 | 2,625 | 2,699 | 8,061 | 7,926 | |||||||||||||||
Contract Intangible Revenue |
58 | 75 | 143 | 237 | 557 | |||||||||||||||
Other Revenues |
||||||||||||||||||||
Client Reimbursable Revenues |
49 | 48 | 55 | 148 | 152 | |||||||||||||||
Integrated Services and Other |
53 | 52 | 12 | 158 | 8 | |||||||||||||||
Drilling Management Services |
54 | 74 | 257 | 198 | 693 | |||||||||||||||
Oil and Gas Properties |
7 | 8 | 26 | 21 | 68 | |||||||||||||||
Subtotal |
163 | 182 | 350 | 525 | 921 | |||||||||||||||
Total Company |
$ | 2,823 | $ | 2,882 | $ | 3,192 | $ | 8,823 | $ | 9,404 | ||||||||||
Average Dayrates (1) | ||||||||||||||||||||
Three months ended | Nine months ended September 30, |
|||||||||||||||||||
September 30, 2009 |
June 30, 2009 |
September 30, 2008 |
2009 | 2008 | ||||||||||||||||
High-Specification Floaters: |
||||||||||||||||||||
Ultra Deepwater Floaters |
$ | 458,500 | $ | 450,500 | $ | 401,300 | $ | 453,400 | $ | 390,700 | ||||||||||
Deepwater Floaters |
$ | 355,600 | $ | 339,600 | $ | 322,700 | $ | 344,300 | $ | 307,600 | ||||||||||
Harsh Environment Floaters |
$ | 386,000 | $ | 374,500 | $ | 363,500 | $ | 369,400 | $ | 362,400 | ||||||||||
Total High-Specification Floaters |
$ | 409,300 | $ | 397,600 | $ | 369,300 | $ | 400,300 | $ | 356,600 | ||||||||||
Midwater Floaters |
$ | 355,800 | $ | 302,700 | $ | 292,900 | $ | 322,200 | $ | 294,800 | ||||||||||
High-Specification Jackups |
$ | 161,000 | $ | 161,400 | $ | 178,500 | $ | 164,400 | $ | 176,700 | ||||||||||
Standard Jackups |
$ | 156,200 | $ | 149,200 | $ | 158,700 | $ | 153,800 | $ | 151,400 | ||||||||||
Other Rigs |
$ | 73,300 | $ | 48,300 | $ | 48,900 | $ | 51,400 | $ | 49,000 | ||||||||||
Total Drilling Fleet |
$ | 283,800 | $ | 255,900 | $ | 242,200 | $ | 264,500 | $ | 236,500 | ||||||||||
Utilization (1) | ||||||||||||||||||||
Three months ended | Nine months ended September 30, |
|||||||||||||||||||
September 30, 2009 |
June 30, 2009 |
September 30, 2008 |
2009 | 2008 | ||||||||||||||||
High-Specification Floaters: |
||||||||||||||||||||
Ultra Deepwater Floaters |
90 | % | 91 | % | 93 | % | 93 | % | 93 | % | ||||||||||
Deepwater Floaters |
89 | % | 82 | % | 68 | % | 85 | % | 76 | % | ||||||||||
Harsh Environment Floaters |
80 | % | 93 | % | 98 | % | 91 | % | 97 | % | ||||||||||
Total High-Specification Floaters |
88 | % | 88 | % | 83 | % | 89 | % | 86 | % | ||||||||||
Midwater Floaters |
72 | % | 84 | % | 88 | % | 82 | % | 86 | % | ||||||||||
High-Specification Jackups |
70 | % | 87 | % | 87 | % | 85 | % | 93 | % | ||||||||||
Standard Jackups |
68 | % | 82 | % | 93 | % | 79 | % | 92 | % | ||||||||||
Other Rigs |
42 | % | 59 | % | 100 | % | 70 | % | 100 | % | ||||||||||
Total Drilling Fleet |
75 | % | 84 | % | 89 | % | 83 | % | 89 | % |
(1) | Average daily revenue is defined as contract drilling revenue earned per revenue earning day in the period. A revenue earning day is defined as a day for which a rig earns dayrate after commencement of operations. Utilization is defined as the total actual number of revenue earning days in the period as a percentage of the total number of calendar days in the period for all drilling rigs in our fleet. |
Transocean Ltd. and Subsidiaries
Supplemental Effective Tax Rate Analysis
(In millions)
Three months ended | Nine months ended | |||||||||||||||||||
Sept 30, 2009 |
June 30, 2009 |
Sept 30, 2008 |
Sept 30, 2009 |
Sept 30, 2008 |
||||||||||||||||
(As adjusted) | (As adjusted) | |||||||||||||||||||
Income before income taxes and minority interest |
$ | 844 | $ | 992 | $ | 1,235 | $ | 3,026 | $ | 3,807 | ||||||||||
Add back (subtract): |
||||||||||||||||||||
Litigation matters |
132 | | | 132 | | |||||||||||||||
GSF merger related costs |
4 | 2 | 1 | 12 | 5 | |||||||||||||||
Impairment loss |
46 | 67 | 16 | 334 | 16 | |||||||||||||||
Loss on sale of CDC interest |
| 4 | | 4 | | |||||||||||||||
Gain on sale of Sedco 135-D |
(1 | ) | (1 | ) | | (2 | ) | | ||||||||||||
Loss on retirement of debt |
7 | 8 | | 17 | 3 | |||||||||||||||
Income from TODCO tax sharing agreement |
(11 | ) | | (14 | ) | (11 | ) | (14 | ) | |||||||||||
Adjusted income before income tax expense |
1,021 | 1,072 | 1,238 | 3,512 | 3,817 | |||||||||||||||
Income tax expense |
138 | 184 | 175 | 573 | 533 | |||||||||||||||
Add back (subtract): |
||||||||||||||||||||
GSF merger related costs |
1 | | 1 | 2 | 1 | |||||||||||||||
Impairment loss |
| | 2 | | 2 | |||||||||||||||
Changes in estimates (1) |
28 | (16 | ) | 15 | (24 | ) | (10 | ) | ||||||||||||
Adjusted income tax expense (2) |
$ | 167 | $ | 168 | $ | 193 | $ | 551 | $ | 526 | ||||||||||
Effective Tax Rate (3) |
16.4 | % | 18.5 | % | 14.2 | % | 18.9 | % | 14.0 | % | ||||||||||
Annual Effective Tax Rate (4) |
16.4 | % | 15.7 | % | 15.6 | % | 15.7 | % | 13.8 | % |
(1) | Our estimates change as we file tax returns, settle disputes with tax authorities or become aware of other events and include changes in deferred taxes, valuation allowances on deferred taxes and other tax liabilities. |
(2) | The three months ended September 30, 2009 include $7 million of additional tax expense (benefit) reflecting the catch-up effect of an increase (decrease) in the annual effective tax rate from the previous quarter estimate. |
(3) | Effective Tax Rate is income tax expense divided by income before income tax expense. |
(4) | Annual Effective Tax Rate is income tax expense excluding various discrete items (such as changes in estimates and tax on items excluded from income before income tax expense) divided by income before income tax expense excluding gains and losses on sales and similar items pursuant to the accounting standards for income taxes and estimating the annual effective tax rate. |
Transocean Ltd.
Reports Third Quarter 2009 Results Exhibit 99.2 |
Chart #1: Average
Contracted Dayrate by Rig Type Qtr 4 2009 through Qtr 3 2010 (Unaudited) The Jackups category consists of our jackup fleet. Jackups The Midwater Floaters category is generally comprised of those non-High-Specification Floaters with a water depth capacity of less than 4,500 feet. Midwater Floaters The Other Deepwater Floaters include the remaining semi-submersible rigs and drillships that have a water depth capacity of at least 4,500 feet. Other High-Specification Floaters were built in the mid to late 1980s, are capable of drilling in harsh environments and have greater displacement than previously constructed rigs resulting in larger variable load capacity, more useable deck space and better motion characteristics. Ultra-Deepwater Floaters have high-pressure mud pumps and a water depth capability of 7,500 feet or greater. The High-Specification Floaters category is a consolidation of the Ultra-Deepwater Floaters, Other High-Specification Floaters and Other Deepwater Floaters as described below. High- Specification Floaters The weighted average contract dayrate for each rig type based on current backlog from the company's most recent Fleet Status Report as of November 2, 2009. Includes firm contracts only. Average Dayrate Definitions (Remaining) 458 433 423 419 348 336 335 343 147 153 161 155 $50k $100k $150k $200k $250k $300k $350k $400k $450k $500k Qtr 4 09 Qtr 1 10 Qtr 2 10 Qtr 3 10 High Specification Floaters Midwater Floaters Jackups |
Chart #2:
Out-of-Service Rig Months* Qtr 1 2009 through Qtr 4 2010 (Unaudited) Refers to periods during which a rig is out of service as a result of contract preparation, other planned shipyards, surveys, repairs, regulatory inspections or other planned service or work on the rig excluding reactivations and upgrades. Shipyard Includes the Sedco 702 and the Sedco 706 which have undergone shipyard projects to enhance the operational capabilities. Upgrade Includes mobilization and demobilization to and from operating contracts and other activities such as shipyards excluding those mobilization and demobilization periods covered in Upgrade. Excludes Newbuild mobilization prior to commencement of operations. Mobilization Time when a rig is not available to earn an operating dayrate due to shipyard, mobilization, and upgrades. Out-of-Service Time expressed in months that each rig has been, or is forecast to be Out of Service as reflected in the company's Fleet Status Report as of November 2, 2009. Also includes out of service time of less than 14 days that is not disclosed in the Fleet Status Report. Rig Months Definitions * Excludes stacked rigs and mobilization to stacking locations. 8 18 24 19 11 23 13 7 3 2 3 2 5 2 2 1 - - - - - - - 3 1 - 5 10 15 20 25 30 35 40 Qtr 1 - 09A Qtr 2 - 09A Qtr 3 - 09A Qtr 4 - 09F Qtr 1 - 10F Qtr 2 - 10F Qtr 3 - 10F Qtr 4 - 10F Period (A = actual data, F = forecast data) Shipyard Mobilization Upgrade 14 21 27 21 16 25 15 8 |
Chart #3: Operating
& Maintenance (O&M) Costs Trends (Unaudited) Operating and maintenance costs represent all direct and indirect costs associated with the operation and maintenance of our drilling rigs. Operating and maintenance costs also includes all costs related to local and Unit offices as well as all costs related to operations support, engineering support, marketing and other similar costs. The principal elements of these costs are direct and indirect labor and benefits, repair and maintenance, contract preparation expenses, insurance, boat and helicopter rentals, professional and technical fees, freight costs, communications, customs duties, tool rentals and services, fuel and water, general taxes and licenses. Labor, repair and maintenance costs, insurance premiums, personal injury losses and drilling rig casualty losses represent the most significant components of our operating and maintenance costs O&M Costs Includes the total amount of days a rig is deemed to be out of service. This relates to times when a rig is out of service due to shipyards, mobilization, short-term idle periods and stacked periods. Out of Service Days Denotes the total O&M costs while a rig is out of service based upon Out of Service Days, as defined below. Out of Service costs are the difference between total operating and maintenance costs and the In-Service Costs. Out of Service $ Denotes the total amount of days a rig is deemed to be in- service under contract operations. This excludes all out of service time relating to shipyards, mobilization and short- term out of contract periods but includes the operational downtime of in service rigs. The average number of days may also fluctuate from quarter to quarter as a result of rigs being reactivated, sold or stacked in the quarters. Rig Operating Days Denotes the total O&M costs of a rig while in service based upon the Rig Operating Days (excluding shorebase or common support costs), as defined below. Operating Rig $ Includes all shorebase and common support costs such as onshore offices, yards and pool equipment and other direct costs such as labor pools and newbuild expenses. Includes Integrated Services, Drilling Management, and Oil & Gas Services, and non-drilling overhead Drilling - Support Costs & Other Direct Non Drilling Operations Definitions $220 $263 $212 $126 $110 $101 $181 $213 $200 $194 $207 $322 $787 $841 $922 $801 $795 $737 $176 $109 $74 $50 $165 $236 $- $200 MM $400 MM $600 MM $800 MM $1,000 MM $1,200 MM $1,400 MM $1,600 MM Qtr2'08 Qtr3'08 Qtr4'08 Qtr1'09 Qtr2'09 Qtr3'09 Period Non Drilling Operations $ Drilling-Support Costs & Other Direct $ Operating Rig $ Out of Service $ $1,171 $1,408 $1,426 $1,364 $1,277 $1,396 |
Chart #4: Contract
Backlog by Client Rating (1) (Unaudited) Total Contract Backlog (2) = $32.2 Billion (1) Credit ratings represent the rating of client parent companies; however, our contracts may or may not be
with the parent company. (2) Calculated by multiplying the contracted operating dayrate by the firm contract period from November 2,
2009 forward. Reflects firm commitments represented by signed contracts. Contract
backlog excludes revenues from mobilization, demobilization, contract preparation, integrated services and customer reimbursables. Our backlog calculation assumes that we receive the full contractual
dayrate, which could be higher than the actual Dayrate that we receive because of a number of
factors (rig downtime, suspension of operations, etc.) including some beyond our control. (3) Other includes non-investment grade and unrated companies A Rated Other Investment Grade Other A Rated 61% Other (3) 4% Other Investment Grade 35% |
Chart #5: Free Cash Flow
Backlog and Debt Maturities (Unaudited) Total Free Cash Flow Backlog (1) = $17.2 Billion (1) Defined as Revenue Backlog, plus Firm Mobilization Revenue for contracts not started, less the following: Operating Expenditures, Overhead costs (except General & Administrative), Firm Mobilization costs, Cash Taxes, Firm Sustaining Capital Expenditures, all newbuild Capital Expenditures and upgrade Capital Expenditures based on current backlog from the company's Fleet Status Report as of November
2, 2009. (2) Total Face Value of Debt as of September 30, 2009 Total Free Cash Flow Backlog $17.2 B Total Face Value of Debt (2) $12.4 B Difference $4.8 B Remaining 0.4 1.9 2.5 2.3 0.9 1.9 2.5 0.6 4.4 4.1 3.2 2.4 2.5 0.0 1.0 2.0 3.0 4.0 5.0 2009 2010 2011 2012 2013 2014-2019 2020-2038 (US$ Billions) Scheduled Debt Maturities Free Cash Flow Backlog |