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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
______________________
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2004
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
FOR THE TRANSITION PERIOD FROM ______ TO ______.
COMMISSION FILE NUMBER 333-75899
______________________
TRANSOCEAN INC.
(Exact name of registrant as specified in its charter)
______________________
CAYMAN ISLANDS 66-0582307
(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
4 GREENWAY PLAZA
HOUSTON, TEXAS 77046
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (713) 232-7500
______________________
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
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Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act). Yes X No
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As of July 30, 2004, 320,841,141 ordinary shares, par value $0.01 per
share, were outstanding.
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TRANSOCEAN INC.
INDEX TO FORM 10-Q
QUARTER ENDED JUNE 30, 2004
Page
----
PART I - FINANCIAL INFORMATION
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ITEM 1. Financial Statements (Unaudited)
Condensed Consolidated Statements of Operations
Three and Six Months Ended June 30, 2004 and 2003 1
Condensed Consolidated Statements of Comprehensive Income
Three and Six Months Ended June 30, 2004 and 2003 2
Condensed Consolidated Balance Sheets
June 30, 2004 and December 31, 2003 3
Condensed Consolidated Statements of Cash Flows
Three and Six Months Ended June 30, 2004 and 2003 4
Notes to Condensed Consolidated Financial Statements 5
ITEM 2. Management's Discussion and Analysis of Financial
Condition and Results of Operations 19
ITEM 3. Quantitative and Qualitative Disclosures About Market Risk 43
ITEM 4. Controls and Procedures 44
PART II - OTHER INFORMATION
- -------------------------------
ITEM 1. Legal Proceedings 45
ITEM 4. Submission of Matters to a Vote of Security Holders 45
ITEM 5. Other Information 45
ITEM 6. Exhibits and Reports on Form 8-K 46
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
TRANSOCEAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per share data)
(Unaudited)
Three Months Ended June 30, Six Months Ended June 30,
--------------------------------- -------------------------------
2004 2003 2004 2003
---------------- --------------- -------------- ---------------
Operating Revenues
Contract drilling revenues $ 584.9 $ 574.7 $ 1,182.4 $ 1,162.2
Other revenues 48.3 29.2 102.8 57.7
- ----------------------------------------------------------------------------------------------------------------------------
633.2 603.9 1,285.2 1,219.9
- ----------------------------------------------------------------------------------------------------------------------------
Costs and Expenses
Operating and maintenance 406.2 426.5 818.6 800.6
Depreciation 133.0 127.5 264.5 254.3
General and administrative 14.0 14.9 29.1 28.8
Impairment loss on long-lived assets - 15.8 - 16.8
Gain from sale of assets, net (23.8) (0.6) (27.6) (2.0)
Gain from TODCO initial public offering - - (39.4) -
- ----------------------------------------------------------------------------------------------------------------------------
529.4 584.1 1,045.2 1,098.5
- ----------------------------------------------------------------------------------------------------------------------------
Operating Income 103.8 19.8 240.0 121.4
Other Income (Expense), net
Equity in earnings of joint ventures 3.7 1.8 6.0 5.4
Interest income 1.9 5.8 4.0 12.7
Interest expense (42.6) (52.8) (90.0) (105.4)
Loss on retirement of debt - (15.7) (28.1) (15.7)
Impairment loss on note receivable from related party - (21.3) - (21.3)
Other, net (1.1) (2.7) 0.3 (3.3)
- ----------------------------------------------------------------------------------------------------------------------------
(38.1) (84.9) (107.8) (127.6)
- ----------------------------------------------------------------------------------------------------------------------------
Income (Loss) Before Income Taxes and Minority Interest 65.7 (65.1) 132.2 (6.2)
Income Tax Expense (Benefit) 19.9 (20.8) 67.9 (9.0)
Minority Interest (2.2) 0.2 (6.4) 0.1
- ----------------------------------------------------------------------------------------------------------------------------
Net Income (Loss) $ 48.0 $ (44.5) $ 70.7 $ 2.7
============================================================================================================================
Earnings (Loss) Per Share
Basic and Diluted $ 0.15 $ (0.14) $ 0.22 $ .01
============================================================================================================================
Weighted Average Shares Outstanding
Basic 320.8 319.8 320.7 319.7
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Diluted 324.1 319.8 324.2 321.5
- ----------------------------------------------------------------------------------------------------------------------------
See accompanying notes
1
TRANSOCEAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(In millions)
(Unaudited)
Three Months Ended June 30, Six Months Ended June 30,
--------------------------------- -------------------------------
2004 2003 2004 2003
---------------- --------------- -------------- ---------------
Net Income (Loss) $ 48.0 $ (44.5) $ 70.7 $ 2.7
- ----------------------------------------------------------------------------------------------------------------------------------
Other Comprehensive Income (Loss), net of tax
Amortization of gain on terminated interest rate swaps (0.1) (0.1) (0.2) (0.1)
Change in unrealized loss on securities available for sale (0.1) 0.2 (0.1) 0.2
Change in share of unrealized loss in unconsolidated joint
venture's interest rate swaps (net of tax of $0.6 for the
three and six months ended June 30, 2003) - 1.4 - 1.1
Minimum pension liability adjustments (net of tax of $0.2
for the three and six months ended June 30, 2004 and $0.4
million for the six months ended June 30, 2003) 0.5 0.1 0.5 0.8
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Other Comprehensive Income 0.3 1.6 0.2 2.0
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Total Comprehensive Income (Loss) $ 48.3 $ (42.9) $ 70.9 $ 4.7
==================================================================================================================================
See accompanying notes
2
TRANSOCEAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In millions, except share data)
June 30, December 31,
2004 2003
------------ --------------
(Unaudited)
ASSETS
Cash and Cash Equivalents $ 322.1 $ 474.0
Accounts Receivable, net of allowance for doubtful accounts of $11.9
and $29.1 at June 30, 2004 and December 31, 2003, respectively 512.1 480.3
Materials and Supplies, net of allowance for obsolescence of $18.0 and $17.5
at June 30, 2004 and December 31, 2003, respectively 151.9 152.0
Deferred Income Taxes 39.2 41.0
Other Current Assets 47.2 31.6
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Total Current Assets 1,072.5 1,178.9
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Property and Equipment 10,642.3 10,673.0
Less Accumulated Depreciation 2,863.5 2,663.4
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Property and Equipment, net 7,778.8 8,009.6
- ----------------------------------------------------------------------------------------------------------
Goodwill 2,232.0 2,230.8
Investments in and Advances to Joint Ventures 6.8 5.5
Deferred Income Taxes 28.2 28.2
Other Assets 217.4 209.6
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Total Assets $ 11,335.7 $ 11,662.6
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LIABILITIES AND SHAREHOLDERS' EQUITY
Accounts Payable $ 157.3 $ 146.1
Accrued Income Taxes 54.7 57.2
Debt Due Within One Year 398.9 45.8
Other Current Liabilities 260.9 262.0
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Total Current Liabilities 871.8 511.1
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Long-Term Debt 2,678.0 3,612.3
Deferred Income Taxes 69.2 42.8
Other Long-Term Liabilities 310.1 299.4
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Total Long-Term Liabilities 3,057.3 3,954.5
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Commitments and Contingencies
Minority Interest 120.8 4.4
Preference Shares, $0.10 par value; 50,000,000 shares authorized,
none issued and outstanding - -
Ordinary Shares, $0.01 par value; 800,000,000 shares authorized,
320,819,763 and 319,926,500 shares issued and outstanding at
June 30, 2004 and December 31, 2003, respectively 3.2 3.2
Additional Paid-in Capital 10,666.1 10,643.8
Accumulated Other Comprehensive Loss (20.0) (20.2)
Retained Deficit (3,363.5) (3,434.2)
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Total Shareholders' Equity 7,285.8 7,192.6
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Total Liabilities and Shareholders' Equity $ 11,335.7 $ 11,662.6
==========================================================================================================
See accompanying notes
3
TRANSOCEAN INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions)
(Unaudited)
Three Months Ended June 30, Six Months Ended June 30,
--------------------------------- -------------------------------
2004 2003 2004 2003
---------------- --------------- --------------- --------------
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss) $ 48.0 $ (44.5) $ 70.7 $ 2.7
Adjustments to reconcile net income (loss) to
net cash provided by operating activities
Depreciation 133.0 127.5 264.5 254.3
Deferred income taxes (3.3) (87.1) 28.0 (59.5)
Equity in earnings of joint ventures (3.7) (1.8) (6.0) (5.4)
Net (gain) loss from disposal of assets (23.1) 8.5 (25.0) 7.8
Gain from TODCO initial public offering - - (39.4) -
Loss on retirement of debt - 15.7 28.1 15.7
Impairment loss on long-lived assets - 15.8 - 16.8
Impairment loss on note receivable from related party - 21.3 - 21.3
Amortization of debt-related discounts/premiums, fair
value adjustments and issue costs, net (4.9) (6.1) (12.5) (7.9)
Deferred income, net 17.4 (8.0) 14.1 (1.6)
Deferred expenses, net (10.8) 7.5 (12.7) 2.7
Other long-term liabilities 4.7 6.6 6.9 13.5
Other, net 3.9 7.3 9.2 8.0
Changes in operating assets and liabilities
Accounts receivable (61.6) 34.0 (31.8) 51.6
Accounts payable and other current liabilities (23.5) (44.0) 0.1 (1.6)
Income taxes receivable/payable, net 4.4 50.3 2.0 9.6
Other current assets 8.9 11.2 (15.6) (23.3)
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Net Cash Provided by Operating Activities 89.4 114.2 280.6 304.7
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CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (37.3) (25.8) (55.8) (50.2)
Note issued to related party, net of repayments - (45.3) - (45.3)
Proceeds from disposal of assets, net 31.5 1.0 42.0 3.2
Deepwater Drilling II LLC's cash acquired, net of cash
paid - 18.1 - 18.1
Proceeds from TODCO initial public offering - - 155.7 -
Joint ventures and other investments, net 3.2 0.8 4.7 2.2
- ---------------------------------------------------------------------------------------------------------------------------------
Net Cash Provided by (Used in) Investing Activities (2.6) (51.2) 146.6 (72.0)
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CASH FLOWS FROM FINANCING ACTIVITIES
Repayments on revolving credit agreements (150.0) - (200.0) -
Repayments on other debt instruments (13.6) (871.4) (395.2) (919.2)
Cash from termination of interest rate swaps - - - 173.5
Net proceeds from issuance of ordinary shares under
stock-based compensation plans 1.0 0.8 15.0 11.7
Other, net - 1.2 1.1 1.1
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Net Cash Used in Financing Activities (162.6) (869.4) (579.1) (732.9)
- ---------------------------------------------------------------------------------------------------------------------------------
Net Decrease in Cash and Cash Equivalents (75.8) (806.4) (151.9) (500.2)
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Cash and Cash Equivalents at Beginning of Period 397.9 1,520.4 474.0 1,214.2
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Cash and Cash Equivalents at End of Period $ 322.1 $ 714.0 $ 322.1 $ 714.0
=================================================================================================================================
See accompanying notes
4
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
NOTE 1 - NATURE OF BUSINESS AND PRINCIPLES OF CONSOLIDATION
Transocean Inc. (together with our subsidiaries and predecessors, unless
the context requires otherwise, "Transocean," "we," "us" or "our") is a leading
international provider of offshore contract drilling services for oil and gas
wells. As of June 30, 2004, we owned, had partial ownership interests in or
operated 95 mobile offshore and barge drilling units, excluding the 70-rig fleet
of TODCO (together with its subsidiaries and predecessors, unless the context
requires otherwise, "TODCO"), a publicly traded company in which we own a
majority interest. We contract our drilling rigs, related equipment and work
crews primarily on a dayrate basis to drill oil and gas wells. We also provide
additional services, including integrated well services and management of third
party well service activities.
On January 31, 2001, we completed a merger transaction (the "R&B Falcon
merger") with R&B Falcon Corporation ("R&B Falcon"). At the time of the merger,
R&B Falcon owned, had partial ownership interests in, operated or had under
construction more than 100 mobile offshore drilling units consisting of
drillships, semisubmersibles, jackup rigs and other units including the Gulf of
Mexico Shallow and Inland Water segment fleet. As a result of the merger, R&B
Falcon became our indirect wholly owned subsidiary. The merger was accounted for
as a purchase and we were the accounting acquiror.
In July 2002, we announced plans to pursue a divestiture of our Gulf of
Mexico Shallow and Inland Water business, which was a part of R&B Falcon. R&B
Falcon's overall business was considerably broader than the Gulf of Mexico
Shallow and Inland Water business. In preparation for this divestiture, we began
the transfer of all assets and businesses out of R&B Falcon that were unrelated
to the Gulf of Mexico Shallow and Inland Water business. In December 2002, R&B
Falcon changed its name to TODCO and, in January 2004, the Gulf of Mexico
Shallow and Inland Water business segment became known as the TODCO segment. In
February 2004, we completed an initial public offering ("IPO") of TODCO (see
Note 3). Before the closing of the IPO, TODCO completed the transfer of all
unrelated assets and businesses to us.
Our operations are aggregated into two reportable business segments: (i)
Transocean Drilling and (ii) TODCO. We provide services with different types of
drilling equipment in several geographic regions. The location of our operating
assets and the allocation of resources to build or upgrade drilling units are
determined by the activities and needs of customers. See Note 9.
For investments in joint ventures and other entities that do not meet the
criteria of a variable interest entity and where we are not deemed to be the
primary beneficiary for accounting purposes of those entities that meet the
variable interest entity criteria, we use the equity method of accounting where
our ownership is between 20 percent and 50 percent and where our ownership is
more than 50 percent and we do not have significant influence or control over
the joint venture. We use the cost method of accounting for investments in joint
ventures where our ownership is less than 20 percent and where we do not have
significant influence over the joint venture. We consolidate those investments
in joint ventures that meet the criteria of a variable interest entity where we
are deemed to be the primary beneficiary for accounting purposes and for
entities in which we have a majority voting interest. Intercompany transactions
and accounts are eliminated.
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation - Our accompanying condensed consolidated financial
statements have been prepared without audit in accordance with accounting
principles generally accepted in the United States for interim financial
information and with the instructions to Form 10-Q and Article 10 of Regulation
S-X of the Securities and Exchange Commission ("SEC"). Accordingly, pursuant to
such rules and regulations, these financial statements do not include all
disclosures required by accounting principles generally accepted in the U.S. for
complete financial statements. The condensed consolidated financial statements
reflect all adjustments, which are, in the opinion of management,
5
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
necessary for a fair statement of financial position, results of operations and
cash flows for the interim periods. Such adjustments are considered to be of a
normal recurring nature unless otherwise identified. Operating results for the
three and six months ended June 30, 2004 are not necessarily indicative of the
results that may be expected for the year ending December 31, 2004 or for any
future period. The accompanying condensed consolidated financial statements and
notes thereto should be read in conjunction with the audited consolidated
financial statements and notes thereto included in our Annual Report on Form
10-K for the year ended December 31, 2003.
Accounting Estimates - The preparation of financial statements in
conformity with accounting principles generally accepted in the U.S. requires
management to make estimates and assumptions that affect the reported amounts of
assets, liabilities, revenues, expenses and disclosure of contingent assets and
liabilities. On an ongoing basis, we evaluate our estimates, including those
related to bad debts, materials and supplies obsolescence, investments,
intangible assets and goodwill, property and equipment and other long-lived
assets, income taxes, workers' insurance, pensions and other postretirement
benefits, other employment benefits and contingent liabilities. We base our
estimates on historical experience and on various other assumptions we believe
are reasonable under the circumstances, the results of which form the basis for
making judgments about the carrying values of assets and liabilities that are
not readily apparent from other sources. Actual results could differ from such
estimates.
Supplementary Cash Flow Information - Cash payments for interest and income
taxes, net, were $103.5 million and $35.9 million, respectively, for the six
months ended June 30, 2004 and $106.1 million and $40.9 million, respectively,
for the six months ended June 30, 2003.
Goodwill - In accordance with the Financial Accounting Standards Board's
("FASB") Statement of Financial Accounting Standards ("SFAS") 142, Goodwill and
Other Intangible Assets, goodwill is no longer amortized and is tested for
impairment at the reporting unit level, which is defined as an operating segment
or a component of an operating segment that constitutes a business for which
financial information is available and is regularly reviewed by management.
Management has determined that our reporting units are the same as our operating
segments for the purpose of allocating goodwill and the subsequent testing of
goodwill for impairment. Goodwill resulting from the R&B Falcon merger was
allocated to our two reporting units, Transocean Drilling and TODCO, at a ratio
of 68 percent and 32 percent, respectively. The allocation was determined based
on the percentage of each reporting unit's assets at fair value to the total
fair value of assets acquired in the R&B Falcon merger. The fair value was
determined from a third party valuation. Goodwill resulting from previous
mergers was allocated entirely to the Transocean Drilling reporting unit. The
remaining goodwill balance at June 30, 2004 and December 31, 2003 relates to our
Transocean Drilling segment.
Impairment of Long-Lived Assets - The carrying value of long-lived assets,
principally property and equipment, is reviewed for potential impairment when
events or changes in circumstances indicate that the carrying amount of such
assets may not be recoverable. For property and equipment held for use, the
determination of recoverability is made based upon the estimated undiscounted
future net cash flows of the related asset or group of assets being evaluated.
Property and equipment held for sale are recorded at the lower of net book value
or fair value. See Note 4.
Income Taxes - Income taxes have been provided based upon the tax laws and
rates in the countries in which operations are conducted and income is earned.
The income tax rates imposed by these taxing authorities vary substantially.
Taxable income may differ from pre-tax income for financial accounting purposes,
particularly in countries with revenue-based taxes. There is no expected
relationship between the provision for income taxes and income before income
taxes because the countries in which we operate have different taxation regimes
that vary not only with respect to nominal rate but also in terms of the
availability of deductions, credits and other benefits. Variations also arise
because income earned and taxed in any particular country or countries may
fluctuate from period to period. Deferred tax assets and liabilities are
recognized for the anticipated future tax effects of temporary differences
between the financial statement basis and the tax basis of our assets and
liabilities using the applicable tax
6
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
rates in effect at period end. A valuation allowance for deferred tax assets is
recorded when it is more likely than not that some or all of the benefit from
the deferred tax asset will not be realized. See Note 5.
Comprehensive Income - The components of accumulated other comprehensive
loss at June 30, 2004 and December 31, 2003, net of tax, are as follows (in
millions):
Unrealized
Gain on Loss on Accumulated
Terminated Available- Minimum Other
Interest Rate for-Sale Pension Comprehensive
Swap Securities Liability Loss
--------------- ------------ ----------- ---------------
Balance at December 31, 2003 $ 3.4 $ (0.4) $ (23.2) $ (20.2)
Change in other comprehensive income, net of tax (0.2) (0.1) 0.5 0.2
--------------- ------------ ----------- ---------------
Balance at June 30, 2004 $ 3.2 $ (0.5) $ (22.7) $ (20.0)
=============== ============ =========== ===============
Stock-Based Compensation - Through December 31, 2002 and in accordance with
the provisions of SFAS 123, Accounting for Stock-Based Compensation, we had
elected to follow Accounting Principles Board Opinion ("APB") 25, Accounting for
Stock Issued to Employees, and related interpretations in accounting for our
employee stock-based compensation plans. Stock-based compensation awards granted
prior to January 1, 2003, if not subsequently modified, will continue to be
accounted for under the recognition and measurement provisions of APB 25.
Effective January 1, 2003, we adopted the fair value recognition provisions of
SFAS 123 using the prospective method proscribed in SFAS 148, Accounting for
Stock-Based Compensation - Transition and Disclosure. Under the prospective
method, all future employee stock-based compensation awards granted on or
subsequent to January 1, 2003 are expensed over the vesting period based on the
fair value of the underlying awards on the date of grant. The fair value of the
stock options is determined using the Black-Scholes option pricing model, while
the fair value of restricted stock grants is determined based on the market
price of our stock on the date of grant. Additionally, stock appreciation rights
are recorded at fair value with the changes in fair value being recorded as
compensation expense as incurred.
7
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
If compensation expense for grants to employees under our long-term
incentive plan and employee stock purchase plan prior to January 1, 2003 was
recognized using the fair value method of accounting under SFAS 123 rather than
the intrinsic value method under APB 25, net income and earnings per share would
have been reduced to the pro forma amounts indicated below (in millions, except
per share data):
Three Months Ended Six Months Ended
June 30, June 30,
----------------------- ------------------------
2004 2003 2004 2003
-------------- ------- ------------ ----------
Net Income (Loss) as Reported $ 48.0 $(44.5) $ 70.7 $ 2.7
Add back: Stock-based compensation expense
included in reported net income, net of related
tax effects 1.5 1.3 8.8 2.5
Deduct: Total stock-based compensation expense
determined under the fair value method for all
awards, net of related tax effects
Long-Term Incentive Plan (3.2) (3.7) (12.9) (8.3)
Employee Stock Purchase Plan (0.5) (1.2) (1.1) (2.1)
-------------- ------- ------------ ----------
Pro Forma Net Income (Loss) $ 45.8 $(48.1) $ 65.5 $ (5.2)
============== ======= ============ ==========
Basic and Diluted Earnings (Loss) Per Share
As Reported $ 0.15 $(0.14) $ 0.22 $ 0.01
Pro Forma 0.14 (0.15) 0.20 (0.02)
New Accounting Pronouncements - In April 2004, the FASB issued FASB Staff
Position ("FSP") 129-1, Disclosure of Information about Capital Structure,
Relating to Contingently Convertible Securities, which applies to all
contingently convertible securities and became effective the date of issue. The
FSP requires disclosure of the nature of the contingency and the potential
impact of conversion on the financial statements, particularly the impact on
earnings per share, and whether the securities have been included in the
entity's calculation of diluted earnings per share. The implementation of this
FSP did not have an effect on our condensed consolidated financial statements
and related notes thereto as our disclosures are in accordance with the
disclosure requirements as stated in this FSP.
Reclassifications - Certain reclassifications have been made to prior
period amounts to conform with the current period's presentation.
NOTE 3 - TODCO INITIAL PUBLIC OFFERING
In February 2004, we completed the TODCO IPO, in which we sold 13.8 million
shares of TODCO's class A common stock, representing approximately 23 percent of
TODCO's total outstanding shares, at $12.00 per share. We received net proceeds
of $155.7 million from the IPO and recognized a gain of approximately $39.4
million ($0.12 per diluted share) in the first quarter of 2004, which
represented the excess of net proceeds received over the net book value of the
TODCO shares sold in the IPO. We hold an approximate 77 percent interest in
TODCO, represented by 46.2 million shares of class B common stock, and we have
approximately 94 percent of the outstanding voting interest in TODCO. Each share
of our class B common stock has five votes per share compared to one vote per
share of class A common stock. We consolidate TODCO in our financial statements
as a business segment.
We entered into various agreements with TODCO to set forth our respective
rights and obligations relating to our businesses and to effect the separation
of our two companies. These agreements included a master separation agreement,
tax sharing agreement, employee matters agreement, transition services agreement
and registration rights agreement.
8
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
As a result of the deconsolidation of TODCO from our other U.S.
subsidiaries for U.S. federal income tax purposes in conjunction with the IPO,
we established in the first quarter of 2004 an initial valuation allowance of
approximately $31.0 million ($0.09 per diluted share) against the estimated
deferred tax assets of TODCO in excess of its deferred tax liabilities, taking
into account prudent and feasible planning strategies as required by SFAS 109,
Accounting for Income Taxes. The ultimate amount of such valuation allowance
could vary significantly depending upon a number of factors, including the final
allocation of tax benefits between TODCO and our other subsidiaries under
applicable law, taxable income for calendar year 2004 and our ability to
implement planning strategies under SFAS 109. See Note 5.
In conjunction with the closing of the TODCO IPO, TODCO granted restricted
stock and stock options to certain of its employees under its long-term
incentive plan and certain of these awards vested at the time of grant. In
accordance with the provisions of SFAS 123, TODCO expects to recognize
compensation expense of approximately $17.0 million over the vesting periods of
the awards. TODCO recognized approximately $6.0 million ($0.02 per Transocean's
diluted share) in the first quarter of 2004 as a result of the immediate vesting
of certain awards. TODCO will amortize the remaining amount of approximately
$11.0 million to compensation expense over the next three years with
approximately $5.0 million over the remainder of 2004 and approximately $5.0
million and $1.0 million in 2005 and 2006, respectively. In addition, certain of
TODCO's employees held options that were granted prior to the IPO to acquire our
ordinary shares. In accordance with the employee matters agreement, these
options were modified at the IPO date, which resulted in the accelerated vesting
of the options and the extension of the term of the options through the original
contractual life. TODCO recognized approximately $1.5 million additional
compensation expense in the first quarter of 2004 as a result of the
modification.
NOTE 4 - ASSET DISPOSITIONS, RETIREMENTS AND IMPAIRMENTS
Asset Dispositions and Retirements - In June 2004, in our Transocean
Drilling segment, we completed the sale of a semisubmersible rig, the Sedco 602,
for net proceeds of $28.0 million and recognized a gain of $21.6 million ($0.07
per diluted share).
During the six months ended June 30, 2004, we settled insurance claims and
sold marine support vessels and certain other assets for net proceeds of
approximately $14.0 million. We recorded net gains of $1.0 million, net of tax
of $0.4 million, in our Transocean Drilling segment and $4.6 million ($0.01 per
diluted share), which had no tax effect, in our TODCO segment.
In January 2003, in our Transocean Drilling segment, we completed the sale
of a jackup rig, the RBF 160, for net proceeds of $13.1 million and recognized a
gain of $0.2 million, net of tax of $0.1 million. The proceeds were received in
December 2002.
During the six months ended June 30, 2003, we settled an insurance claim
and sold certain other assets for net proceeds of approximately $3.2 million. We
recorded net gains of $1.3 million, which had no tax effect, in our Transocean
Drilling segment and $0.3 million, net of tax of $0.1 million, in our TODCO
segment.
Impairments - During the six months ended June 30, 2003, we recorded
after-tax non-cash impairment charges of $5.2 million ($0.02 per diluted share)
in our Transocean Drilling segment associated with the removal of two rigs from
drilling service and the value assigned to leases on oil and gas properties that
we intended to discontinue. The determination of fair market value was based on
an offer from a potential buyer, in the case of the two rigs, and management's
assessment of fair value, in the case of the leases on oil and gas properties,
where third party valuations were not available.
During the six months ended June 30, 2003, we recorded pre-tax non-cash
impairment charges of $11.6 million ($7.6 million, or $0.02 per diluted share,
after-tax) in our TODCO segment associated with the removal of five
9
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
jackup rigs from drilling service and the write down in the value of an
investment in a joint venture to fair value. The determination of fair market
value was based on third party valuations, in the case of the jackup rigs, and
management's assessment of fair value, in the case of the investment in a joint
venture, where third party valuations were not available.
NOTE 5 - INCOME TAXES
The annual effective tax rate for 2004 is estimated to be approximately 35
percent of earnings before TODCO IPO-related items, loss on debt retirements and
gains on significant asset sales. The effective tax rate increased from
approximately 27 percent estimated at March 31, 2004 as a result of developments
in the second quarter on certain international tax disputes, an increase in the
valuation allowance established at the time of the TODCO IPO and changes in the
expected amount and geographical concentration of taxable income. The catch-up
effect of the increase in the annual effective tax rate, a reduction in earnings
of $4.6 million ($0.01 per diluted share), was reflected in the second quarter
of 2004 resulting in an effective tax rate of 45 percent on earnings for the
three months ended June 30, 2004, excluding the sale of the semisubmersible rig
Sedco 602.
During the quarter ended March 31, 2004 and in conjunction with the IPO, we
established a valuation allowance of approximately $31.0 million ($0.09 per
diluted share) against the deferred tax assets of TODCO in excess of its
deferred tax liabilities. See Note 3.
At June 30, 2003, we estimated the annual effective tax rate for 2003 to be
approximately 38 percent of earnings before non-cash note receivable and other
asset impairments and loss on debt retirements. The rate increased from an
estimated annual effective tax rate of approximately 20 percent at March 31,
2003 due to a change in the amount and mix of estimated earnings for the year.
As a result of the catch-up effect of the change in the annual effective tax
rate, earnings for the three months ended June 30, 2003 were reduced by $10.7
million ($0.03 per diluted share).
In June 2003, we recorded a $14.6 million ($0.04 per diluted share) foreign
tax benefit attributable to the favorable resolution of a non-U.S. income tax
liability.
10
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
NOTE 6 - DEBT
Debt, net of unamortized discounts, premiums and fair value adjustments, is
comprised of the following (in millions):
June 30, December 31,
2004 2003
--------- -------------
6.75% Senior Notes, due April 2005 $ 356.9 $ 361.2
7.31% Nautilus Class A1 Amortizing Notes - final maturity May 2005 42.0 63.6
6.95% Senior Notes, due April 2008 267.4 269.5
9.5% Senior Notes, due December 2008 11.3 357.3
800 Million Revolving Credit Agreement - final maturity December 2008 50.0 250.0
6.625% Notes, due April 2011 791.6 797.3
7.375% Senior Notes, due April 2018 250.4 250.4
Zero Coupon Convertible Debentures, due May 2020 (put options exercisable
May 2008 and May 2013) 16.8 16.5
1.5% Convertible Debentures, due May 2021 (put options exercisable May
2006, May 2011 and May 2016) 400.0 400.0
8% Debentures, due April 2027 198.1 198.1
7.45% Notes, due April 2027 (put options exercisable April 2007) 94.9 94.8
7.5% Notes, due April 2031 597.5 597.5
Other - 1.9
--------- -------------
Total Debt 3,076.9 3,658.1
Less Debt Due Within One Year 398.9 45.8
--------- -------------
Total Long-Term Debt $ 2,678.0 $ 3,612.3
========= =============
The scheduled maturity of our debt, at face value, assumes the bondholders
exercise their options to require us to repurchase the 1.5% Convertible
Debentures, 7.45% Notes and Zero Coupon Convertible Debentures in May 2006,
April 2007 and May 2008, respectively, and is as follows (in millions):
Twelve Months
Ending
June 30,
--------------
2005 $ 392.3
2006 400.0
2007 100.0
2008 269.0
2009 60.2
Thereafter 1,750.0
--------------
Total $ 2,971.5
==============
Commercial Paper Program - We have a revolving credit agreement, described
below, which, together with previous revolving credit agreements, provided
liquidity for commercial paper borrowings during 2003. Because we believe our
current cash balances and the revolving credit agreement described below provide
us with adequate liquidity, we terminated our Commercial Paper Program during
the first quarter of 2004.
Revolving Credit Agreements - We are party to an $800.0 million five-year
revolving credit agreement (the "Revolving Credit Agreement") dated December 16,
2003. The Revolving Credit Agreement bears interest, at our option, at a base
rate or London Interbank Offered Rate ("LIBOR") plus a margin that can vary from
0.35 percent to
11
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
0.95 percent depending on our non-credit enhanced senior unsecured public debt
rating. At June 30, 2004, the applicable margin was 0.5 percent. A facility fee
varying from 0.075 percent to 0.225 percent depending on our non-credit enhanced
senior unsecured public debt rating, is incurred on the daily amount of the
underlying commitment, whether used or unused, throughout the term of the
facility. At June 30, 2004, the applicable facility fee was 0.125 percent. A
utilization fee of 0.125 percent is payable if amounts outstanding under the
Revolving Credit Agreement are greater than $264.0 million. At June 30, 2004,
$50.0 million was outstanding under the Revolving Credit Agreement.
The Revolving Credit Agreement requires compliance with various covenants
and provisions customary for agreements of this nature, including an earnings
before interest, taxes, depreciation and amortization ("EBITDA") to interest
coverage ratio, as defined by the credit agreement, of not less than three to
one, a debt to total tangible capital ratio, as defined by the credit agreement,
of not greater than 50 percent, and limitations on creating liens, incurring
debt, transactions with affiliates, sale/leaseback transactions and mergers and
sale of substantially all assets.
In December 2003, TODCO entered into a $75.0 million two-year revolving
credit agreement (the "TODCO Revolving Credit Agreement"), which will reduce to
$60.0 million in December 2004. The TODCO Revolving Credit Agreement bears
interest, at TODCO's option, at a base rate plus a margin of 2.50 percent or
LIBOR plus a margin of 3.50 percent. Utilization of the facility is limited by
a borrowing base. Commitment fees on the unused portion of the facility are
1.50 percent of the average daily balance and are payable quarterly. At June
30, 2004, there were no borrowings under the TODCO Revolving Credit Agreement.
The TODCO Revolving Credit Agreement requires compliance with various covenants
and provisions customary for similar agreements of non-investment grade
facilities. TODCO's Revolving Credit Agreement is not guaranteed by us.
Debt Redeemed, Retired and Repurchased - In March 2004, we completed the
redemption of our $289.8 million principal amount outstanding 9.5% Senior Notes
due December 2008 at the make-whole premium price provided in the indenture. We
redeemed these notes at 127.796% of face value or $370.3 million, plus accrued
and unpaid interest. We recognized an after-tax loss on the redemption of debt
of approximately $28.1 million ($0.09 per diluted share) in the first quarter of
2004, which reflected adjustments for fair value of the debt at the R&B Falcon
merger and the premium on the termination of the related interest rate swap. We
funded the redemption with existing cash balances, which included proceeds from
the TODCO IPO. The redemption did not affect the 9.5% Senior Notes due December
2008 of TODCO, which had an aggregate principal amount outstanding of $10.2
million at June 30, 2004.
In May 2003, we repurchased and retired all of the $50.0 million principal
amount outstanding 9.41% Nautilus Class A2 Notes due May 2005 and funded the
repurchase from existing cash balances. We recognized a loss on retirement of
debt of approximately $3.6 million ($0.01 per diluted share), net of tax of $1.9
million, in the second quarter of 2003.
In May 2003, holders of our Zero Coupon Convertible Debentures due May 24,
2020 had the option to require us to repurchase their debentures. Holders of
$838.6 million aggregate principal amount, or approximately 97 percent, of these
debentures exercised this option, and we repurchased their debentures at a
repurchase price of $628.57 per $1,000 principal amount. Under the terms of the
debentures, we had the option to pay for the debentures with cash, our ordinary
shares or a combination of cash and shares, and we elected to pay the $527.2
million repurchase price from existing cash balances. We recognized additional
expense of approximately $10.2 million ($0.03 per diluted share) as an after-tax
loss on retirement of debt in the second quarter of 2003 to fully amortize the
remaining debt issue costs related to the repurchased debentures.
In April 2003, we repaid the entire $239.5 million principal amount
outstanding 6.5% Senior Notes, of which $5.0 million principal amount
outstanding was the obligation of TODCO, plus accrued and unpaid interest, in
accordance with their scheduled maturity. We funded the repayment from existing
cash balances.
12
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
NOTE 7 - FINANCIAL INSTRUMENTS AND RISK CONCENTRATION
Foreign Exchange Risk - Our international operations expose us to foreign
exchange risk. This risk is primarily associated with compensation costs
denominated in currencies other than the U.S. dollar and with purchases from
foreign suppliers. We may use a variety of techniques to minimize exposure to
foreign exchange risk, including customer contract payment terms and foreign
exchange derivative instruments.
Our primary foreign exchange risk management strategy involves structuring
customer contracts to provide for payment in both U.S. dollars and local
currency. The payment portion denominated in local currency is based on
anticipated local currency requirements over the contract term. Due to various
factors, including local banking laws, other statutory requirements, local
currency convertibility and the impact of inflation on local costs, actual
foreign exchange needs may vary from those anticipated in the customer
contracts, resulting in partial exposure to foreign exchange risk. Fluctuations
in foreign currencies typically have not had a material impact on overall
results. In situations where payments of local currency do not equal local
currency requirements, foreign exchange derivative instruments, specifically
foreign exchange forward contracts, or spot purchases may be used to mitigate
foreign currency risk. A foreign exchange forward contract obligates us to
exchange predetermined amounts of specified foreign currencies at specified
exchange rates on specified dates or to make an equivalent U.S. dollar payment
equal to the value of such exchange.
In January 2003, Venezuela implemented foreign exchange controls that limit
the Company's ability to convert local currency into U.S. dollars and transfer
excess funds out of Venezuela. The Company's drilling contracts in Venezuela
typically call for payments to be made in local currency, even when the dayrate
is denominated in U.S. dollars. The exchange controls could also result in an
artificially high value being placed on the local currency. As a result, the
Company recognized a loss of $1.5 million, net of tax of $0.8 million, on the
revaluation of the local currency into functional U.S dollars for the six months
ended June 30, 2003.
We do not enter into derivative transactions for speculative purposes. At
June 30, 2004, we had no open foreign exchange derivative contracts.
NOTE 8 - INTEREST RATE SWAPS
In January 2003, we terminated swaps with respect to our 6.75% Senior Notes
due April 2005, 6.95% Senior Notes due April 2008 and 9.5% Senior Notes due
December 2008. In March 2003, we terminated swaps with respect to our 6.625%
Notes. As a result of these terminations, we received cash proceeds, net of
accrued interest, of approximately $173.5 million that was recognized as a fair
value adjustment to long-term debt in our consolidated balance sheet and the
fair value adjustment is being amortized as a reduction to interest expense over
the life of the underlying debt. During the six months ended June 30, 2004 and
2003, such reduction amounted to $12.4 million (or $0.04 per diluted share) and
$10.0 million (or $0.03 per diluted share), respectively. As a result of the
redemption of our 9.5% Senior Notes in March 2004, we recognized a swap premium
of $22.0 million on the termination of the related interest rate swap as a
reduction to our loss on retirement of debt (see Note 6).
At June 30, 2004 and December 31, 2003, we had no outstanding interest rate
swaps.
NOTE 9 - SEGMENTS
Our operations are aggregated into two reportable segments: (i) Transocean
Drilling and (ii) TODCO. The Transocean Drilling segment consists of floaters,
jackups and other rigs used in support of offshore drilling activities and
offshore support services. The TODCO segment consists of our interest in TODCO,
which conducts jackup, drilling barge, land rig, submersible and other
operations located in the U.S. Gulf of Mexico and inland waters, Mexico,
Trinidad and Venezuela. We provide services with different types of drilling
equipment in several geographic regions. The location of our rigs and the
allocation of resources to build or upgrade rigs is determined by the activities
13
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
and needs of customers. Accounting policies of the segments are the same as
those described in Note 2. We account for intersegment revenue and expenses as
if the revenue or expenses were to third parties at current market prices.
Operating revenues and income (loss) before income taxes and minority
interest by segment were as follows (in millions):
Three Months Ended June 30, Six Months Ended June 30,
--------------------------------- ------------------------------
2004 2003 2004 2003
---------------- --------------- ------------ ----------------
Operating Revenues
Transocean Drilling $ 552.5 $ 548.5 $ 1,130.7 $ 1,111.2
TODCO 80.7 55.4 154.5 108.7
---------------- --------------- ------------ ----------------
Total Operating Revenues $ 633.2 $ 603.9 $ 1,285.2 $ 1,219.9
---------------- --------------- ------------ ----------------
Operating Income (Loss) Before General and
Administrative Expense
Transocean Drilling (a) $ 127.2 $ 84.2 $ 305.4 $ 228.2
TODCO (b) (9.4) (49.5) (36.3) (78.0)
---------------- --------------- ------------ ----------------
117.8 34.7 269.1 150.2
Unallocated general and administrative expense (14.0) (14.9) (29.1) (28.8)
Unallocated other expense, net (38.1) (84.9) (107.8) (127.6)
---------------- --------------- ------------ ----------------
Income (Loss) Before Income Taxes and Minority
Interest $ 65.7 $ (65.1) $ 132.2 $ (6.2)
================ =============== ============ ================
______________
(a) The six months ended June 30, 2004 includes a $39.4 million gain from the TODCO initial public offering.
(b) The three and six months ended June 30, 2004 include $7.1 million and $19.4 million, respectively, of operating
and maintenance expense that TODCO classifies as general and administrative expense. The three and six months
ended June 30, 2003 include $3.6 million and $7.3 million, respectively, of operating and maintenance expense
that TODCO classifies as general and administrative expense.
Depreciation expense by segment was as follows (in millions):
Three Months Ended June 30, Six Months Ended June 30,
------------------------------ -----------------------------
2004 2003 2004 2003
------------- --------------- -------------- -------------
Transocean Drilling $ 109.1 $ 104.4 $ 216.4 $ 208.0
TODCO 23.9 23.1 48.1 46.3
------------- --------------- -------------- -------------
Total Depreciation Expense $ 133.0 $ 127.5 $ 264.5 $ 254.3
============= =============== ============== =============
Total assets by segment were as follows (in millions):
June 30, December 31,
2004 2003
--------- -------------
Transocean Drilling $10,589.3 $ 10,874.0
TODCO 746.4 788.6
--------- -------------
Total Assets $11,335.7 $ 11,662.6
========= =============
14
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
Total capital expenditures by segment were as follows (in millions):
Three Months Ended June 30, Six Months Ended June 30,
------------------------------- -----------------------------
2004 2003 2004 2003
---------------- ------------- -------------- -------------
Transocean Drilling $ 35.5 $ 24.3 $ 51.0 $ 47.1
TODCO 1.8 1.5 4.8 3.1
---------------- ------------- -------------- -------------
Total Capital Expenditures $ 37.3 $ 25.8 $ 55.8 $ 50.2
================ ============= ============== =============
NOTE 10 - EARNINGS PER SHARE
The reconciliation of the numerator and denominator used for the
computation of basic and diluted earnings (loss) per share is as follows (in
millions, except per share data):
Three Months Ended June 30, Six Months Ended June 30,
------------------------------- -----------------------------
2004 2003 2004 2003
------------- ---------------- -------------- -------------
NUMERATOR FOR BASIC AND DILUTED EARNINGS (LOSS)
PER SHARE
Net Income (Loss) for Basic and Diluted Earnings per
Share $ 48.0 $ (44.5) $ 70.7 $ 2.7
============= ================ ============== =============
DENOMINATOR FOR DILUTED EARNINGS (LOSS) PER SHARE
Weighted-average shares outstanding for basic
earnings per share 320.8 319.8 320.7 319.7
Effect of dilutive securities:
Employee stock options and unvested stock grants 2.0 - 2.1 1.2
Warrants to purchase ordinary shares 1.3 - 1.4 0.6
------------- ---------------- -------------- -------------
Adjusted weighted-average shares and assumed
conversions for diluted earnings per share 324.1 319.8 324.2 321.5
============= ================ ============== =============
BASIC AND DILUTED EARNINGS (LOSS) PER SHARE
Net Income (Loss) $ 0.15 $ (0.14) $ 0.22 $ 0.01
============= ================ ============== =============
Ordinary shares subject to issuance pursuant to the conversion features of
the convertible debentures are not included in the calculation of adjusted
weighted-average shares and assumed conversions for diluted earnings per share
because the effect of including those shares is anti-dilutive for all periods
presented. Ordinary shares subject to issuance pursuant to the conversion
features of the contingently convertible debentures are not included in the
calculation of adjusted weighted-average shares and assumed conversions for
diluted earnings per share because the conversion features have not been
triggered for all periods presented. Incremental shares related to stock
options, unvested stock grants and warrants are not included in the calculation
of adjusted weighted-average shares and assumed conversions for diluted earnings
per share for the three months ended June 30, 2003, because the effect of
including those shares is anti-dilutive for that period.
NOTE 11 - CONTINGENCIES
Legal Proceedings - In 1990 and 1991, two of our subsidiaries were served
with various assessments collectively valued at approximately $5.8 million from
the municipality of Rio de Janeiro, Brazil to collect a municipal tax on
services. We believe that neither subsidiary is liable for the taxes and have
contested the assessments in the Brazilian administrative and court systems. In
October 2001, the Brazil Supreme Court rejected our appeal of an adverse lower
court's ruling with respect to a June 1991 assessment, which is valued at
approximately $5 million. We are continuing to challenge the assessment and have
an action to suspend a related tax foreclosure proceeding. We have received a
favorable ruling in connection with a disputed August 1990 assessment but the
government has appealed that ruling. We also are awaiting a ruling from the
Taxpayer's Council in connection with an October 1990 assessment. If our
defenses are ultimately unsuccessful, we believe that the Brazilian
government-controlled oil company, Petrobras, has a contractual obligation to
reimburse us for municipal tax payments required to be paid by them. We do not
expect the liability, if any, resulting from these assessments to have a
material adverse effect on our business or consolidated financial position.
15
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
The Indian Customs Department, Mumbai, filed a "show cause notice" against
one of our subsidiaries and various third parties in July 1999. The show cause
notice alleged that the initial entry into India in 1988 and other subsequent
movements of the Trident II jackup rig operated by the subsidiary constituted
imports and exports for which proper customs procedures were not followed and
sought payment of customs duties of approximately $31 million based on an
alleged 1998 rig value of $49 million, with interest and penalties, and
confiscation of the rig. In January 2000, the Customs Department issued its
order, which found that we had imported the rig improperly and intentionally
concealed the import from the authorities, and directed us to pay a redemption
fee of approximately $3 million for the rig in lieu of confiscation and to pay
penalties of approximately $1 million in addition to the amount of customs
duties owed. In February 2000, we filed an appeal with the Customs, Excise and
Gold (Control) Appellate Tribunal ("CEGAT") together with an application to have
the confiscation of the rig stayed pending the outcome of the appeal. In March
2000, the CEGAT ruled on the stay application, directing that the confiscation
be stayed pending the appeal. The CEGAT issued its opinion on our appeal on
February 2, 2001, and while it found that the rig was imported in 1988 without
proper documentation or payment of duties, the redemption fee and penalties were
reduced to less than $0.1 million in view of the ambiguity surrounding the
import practice at the time and the lack of intentional concealment by us. The
CEGAT further sustained our position regarding the value of the rig at the time
of import as $13 million and ruled that subsequent movements of the rig were not
liable to import documentation or duties in view of the prevailing practice of
the Customs Department, thus limiting our exposure as to custom duties to
approximately $6 million. Following the CEGAT order, we tendered payment of
redemption, penalty and duty in the amount specified by the order by offset
against a $0.6 million deposit and $10.7 million guarantee previously made by
us. The Customs Department attempted to draw the entire guarantee, alleging the
actual duty payable is approximately $22 million based on an interpretation of
the CEGAT order that we believe is incorrect. This action was stopped by an
interim ruling of the High Court, Mumbai on writ petition filed by us. We and
the Customs Department both filed appeals with the Supreme Court of India
against the order of the CEGAT, and both appeals have been admitted. We are now
awaiting a hearing date. We and our customer agreed to pursue and obtained the
issuance of documentation from the Ministry of Petroleum that, if accepted by
the Customs Department, would reduce the duty to nil. The agreement with the
customer further provided that if this reduction was not obtained by the end of
2001, our customer would pay the duty up to a limit of $7.7 million. The Customs
Department did not accept the documentation or agree to refund the duties
already paid. We are pursuing our remedies against the Customs Department and
our customer. We do not expect, in any event, that the ultimate liability, if
any, resulting from the matter will have a material adverse effect on our
business or consolidated financial position.
In October 2001, TODCO was notified by the U.S. Environmental Protection
Agency ("EPA") that the EPA had identified a subsidiary as a potentially
responsible party in connection with the Palmer Barge Line superfund site
located in Port Arthur, Jefferson County, Texas. Based upon the information
provided by the EPA and a review of TODCO's internal records to date, TODCO
disputes its designation as a potentially responsible party. Pursuant to the
master separation agreement with TODCO, we are responsible and will indemnify
TODCO for any losses TODCO incurs in connection with this action. We do not
expect that the ultimate outcome of this case will have a material adverse
effect on our business or consolidated financial position.
In August 2003, a judgment of approximately $9.5 million was entered by the
Labor Division of the Provincial Court of Luanda, Angola, against us and one of
our labor contractors, Hull Blyth, in favor of certain former workers on several
of our drilling rigs. The workers were employed by Hull Blyth to work on several
drilling rigs while the rigs were located in Angola. When the drilling contracts
concluded and the rigs left Angola, the workers' employment ended. The workers
brought suit claiming that they were not properly compensated when their
employment ended. In addition to the monetary judgment, the Labor Division
ordered the workers to be hired by us. We believe that this judgment is without
sufficient legal foundation and have appealed the matter to the Angola Supreme
Court. We further believe that Hull Blyth has an obligation to protect us from
any judgment. We do not believe that the ultimate outcome of this matter will
have a material adverse effect on our business or consolidated financial
position.
One of our subsidiaries is involved in an action with respect to customs
penalties relating to the Sedco 710 semisubmersible drilling rig. Prior to our
merger with Sedco Forex Holdings Limited ("Sedco Forex"), this drilling rig,
which was working for Petrobras in Brazil at the time, had been admitted into
the country on a temporary basis under authority granted to a Schlumberger
entity. Prior to the merger with Sedco Forex at the end of 1999, the drilling
contract was moved to an entity that would become one of our subsidiaries. In
early 2000, the drilling contract was extended for another year. On January 10,
2000, the temporary import permit granted to the Schlumberger entity expired,
and renewal filings were not made until later that January. In April 2000, the
Brazilian customs authorities cancelled the import permit. The Schlumberger
entity filed an action in the Brazilian federal court of Campos for the purpose
of extending the temporary admission. Other proceedings were also initiated in
order to secure the transfer of the temporary admission to our subsidiary.
Ultimately, the court permitted the transfer to our entity but has not ruled
that the temporary admission could be extended without the payment of a
financial penalty. During the first quarter of 2004, the customs office renewed
its efforts to collect a penalty and issued a second assessment for this penalty
but has now done so against our subsidiary. The assessment is for approximately
$50 million. We believe that the amount of the assessment, even if it were
appropriate, should only be approximately $7.6 million and should in any event
be assessed against the Schlumberger entity. We and Schlumberger are contesting
our respective assessments. We have put Schlumberger on notice that we consider
any assessment to be the responsibility of Schlumberger. We do not expect the
ultimate outcome of this matter to have a material adverse effect on our
business or consolidated financial position.
We are involved in a number of other lawsuits, all of which have arisen in
the ordinary course of our business. We do not believe that ultimate liability,
if any, resulting from any such other pending litigation will have a material
adverse effect on our business or consolidated financial position.
Letters of Credit and Surety Bonds - We had letters of credit outstanding
totaling $174.4 million and $186.2 million at June 30, 2004 and December 31,
2003, respectively. These letters of credit guarantee various contract bidding
and performance activities under various uncommitted lines provided by several
banks.
As is customary in the contract drilling business, we also have various
surety bonds in place that secure customs obligations relating to the
importation of our rigs and certain performance and other obligations. Surety
bonds outstanding totaled $22.5 million and $169.5 million at June 30, 2004 and
December 31, 2003, respectively. The decrease in outstanding surety bonds is
primarily attributable to the expiration of three such bonds totaling $151.1
million related to our Brazil operations.
NOTE 12 - SALE/LEASEBACK TRANSACTION
We lease the drillship M. G. Hulme, Jr. from Deep Sea Investors, L.L.C., a
special purpose entity formed by several leasing companies to acquire the rig
from one of our subsidiaries in November 1995 in a sale/leaseback transaction.
We are obligated to pay rent of approximately $13 million per year through
November 2005. At the termination of the lease, we may purchase the rig for a
maximum amount of approximately $35.7 million. Effective September 2002, the
lease neither requires that collateral be maintained nor contains any credit
rating triggers.
Effective December 31, 2003, we adopted and applied the provisions of FASB
Interpretation ("FIN") 46, Consolidation of Variable Interest Entities, as
revised December 31, 2003, for all variable interest entities. FIN 46 requires
the consolidation of variable interest entities in which an enterprise absorbs a
majority of the entity's expected losses, receives a majority of the entity's
expected residual returns, or both, as a result of ownership, contractual or
other financial interests in the entity. Because the sale/leaseback agreement is
with an entity in which we have no direct investment, we are not entitled to
receive the financial statements of the leasing entity and the equity holders of
the leasing company will not release the financial statements or other financial
information to us in order for us to make the determination of whether the
entity is a variable interest entity. In addition, without the financial
statements, we are unable to determine if we are the primary beneficiary of the
entity and, if so, what we would consolidate. We have no exposure to loss as a
result of the sale/leaseback agreement. We currently account for the lease of
this semisubmersible drilling rig as an operating lease.
NOTE 13 - RELATED PARTY TRANSACTIONS
Delta Towing - TODCO owns a 25 percent interest in a joint venture, Delta
Towing Holdings, LLC ("Delta Towing"), and TODCO holds notes receivable from
Delta Towing with a face amount of approximately $143.0 million, which at the
time of the R&B Falcon merger were valued at $80.0 million. Delta Towing
defaulted on the notes receivable in January 2003 by failing to make its
scheduled quarterly interest payment and remained in default as a result of its
continued failure to make its quarterly interest payments. As a result of
TODCO's continued evaluation of the collectibility of the notes, TODCO recorded
an impairment on the notes receivable of $13.8 million ($0.04 per diluted
share), net of tax of $7.5 million, in June 2003 based on Delta Towing's
discounted cash flows over the terms of the notes, which deteriorated in the
second quarter of 2003 as a result of the continued decline in Delta Towing's
business outlook. During the six months ended June 30, 2003, we earned interest
income related to the notes receivable and the three-year revolving credit
facility of $3.1 million and $0.2 million, respectively.
As a result of the adoption of FIN 46 and a determination that TODCO was
the primary beneficiary for accounting purposes of Delta Towing, TODCO
consolidated Delta Towing effective December 31, 2003 and intercompany
transactions and accounts have been eliminated, including the above described
notes receivable.
16
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
DDII LLC - In May 2003, WestLB AG, one of the lenders in the Deepwater
Frontier synthetic lease financing facility, assigned its $46.1 million
remaining promissory note receivable to us in exchange for cash of $46.1
million. Also in May 2003, but subsequent to the WestLB AG assignment, we
purchased ConocoPhillips' 40 percent interest in Deepwater Drilling II L.L.C.
("DDII LLC") for approximately $5.0 million. As a result of this purchase, we
consolidated DDII LLC late in the second quarter of 2003. In addition, we
acquired certain drilling and other contracts from ConocoPhillips for
approximately $9.0 million in cash.
NOTE 14 - RETIREMENT PLANS AND OTHER POSTEMPLOYMENT BENEFITS
Defined Benefit Pension Plans - We have several defined benefit pension
plans, both funded and unfunded, covering substantially all U.S. employees
except for TODCO employees. We also have various defined benefit plans that
cover Norway and Nigeria employees and various current and former employees
covered under certain frozen plans acquired in connection with the R&B Falcon
merger. Net periodic benefit cost for these defined benefit pension plans
included the following components (in millions):
Three Months Ended June 30, Six Months Ended June 30,
-------------------------------- -------------------------------
2004 2003 2004 2003
-------------- ---------------- -------------- ---------------
COMPONENTS OF NET PERIODIC BENEFIT COST (a)
Service cost $ 3.9 $ 4.1 $ 7.8 $ 8.3
Interest cost 4.1 4.6 8.3 9.2
Expected return on plan assets (4.9) (4.9) (9.7) (9.8)
Amortization of transition obligation - 0.1 0.1 0.2
Amortization of prior service cost 0.2 0.4 0.3 0.7
Recognized net actuarial losses 0.7 - 1.3 0.2
-------------- ---------------- -------------- ---------------
Benefit cost $ 4.0 $ 4.3 $ 8.1 $ 8.8
============== ================ ============== ===============
______________
(a) Amounts are before income tax effect.
Postretirement Benefits Other Than Pensions - We have several unfunded
contributory and noncontributory postretirement benefit plans covering
substantially all of our Transocean Drilling segment U.S. employees. Net
periodic benefit cost for these other postretirement plans included the
following components (in millions):
Three Months Ended June 30, Six Months Ended June 30,
------------------------------- -------------------------------
2004 2003 2004 2003
-------------- --------------- --------------- --------------
COMPONENTS OF NET PERIODIC BENEFIT COST (a)
Service cost $ 0.2 $ 0.5 $ 0.5 $ 1.0
Interest cost 0.6 0.8 1.1 1.7
Amortization of prior service cost (0.5) 0.1 (1.1) 0.2
Recognized net actuarial losses 0.4 0.3 0.8 0.6
SFAS 88 settlements/curtailments - - - (0.6)
-------------- --------------- --------------- --------------
Benefit cost $ 0.7 $ 1.7 $ 1.3 $ 2.9
============== =============== =============== ==============
______________
(a) Amounts are before income tax effect.
In December 2003, the Medicare Prescription Drug, Improvement and
Modernization Act of 2003 (the "Act") was signed into law. The Act introduced a
prescription drug benefit under Medicare (Medicare Part D) as well as a federal
subsidy to sponsors of retiree health care benefit plans that provide a
prescription drug benefit that is at least actuarially equivalent to Medicare
Part D. The Act introduces two new features to Medicare that employers must
consider in determining the effect of the Act on their accumulated
postretirement benefit obligation (''APBO'') and net periodic post retirement
benefit cost: (i) a subsidy based on 28 percent of an individual beneficiary's
annual prescription drug costs between $250 and $5,000, and (ii) the opportunity
for a retiree to obtain a prescription drug
17
TRANSOCEAN INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
(Unaudited)
benefit under Medicare. In accordance with SFAS 106, Employers' Accounting for
Postretirement Benefits Other Than Pensions, employers are required to consider
presently enacted changes in relevant laws in current period measurements of
postretirement benefit costs and the APBO. As a result, the APBO and net
periodic postretirement benefit costs for future periods should reflect the
effects of the Act. At present, detailed regulation necessary to implement the
Act have not been issued, including those that would specify the manner in which
actuarial equivalency must be determined, the evidence required to demonstrate
actuarial equivalency and the documentation requirements necessary to be
entitled to the subsidy.
In May 2004, the FASB staff issued FSP 106-2, Accounting and Disclosure
Requirements Related to the Medicare Prescription Drug, Improvement and
Modernization Act of 2003. FSP 106-2, which supercedes the same titled FSP
106-1, considers the effect of the two new features introduced in the Act in
determining our APBO and net periodic post retirement benefit cost. The effect
on the APBO will be accounted for as an actuarial gain to be amortized into
income over the average remaining service period of plan participants. Companies
may elect to defer accounting for this benefit or attempt to reflect the best
estimate of the impact of the Act on their net periodic costs currently. The FSP
is effective for the first interim or annual period beginning after June 15,
2004. We have chosen to defer accounting for the benefit and will implement
these requirements effective July 1, 2004 using the prospective method outlined
in FSP 106-2. The adoption of these requirements is not expected to have a
material impact on our condensed consolidated financial position or results of
operations. As a result of our election to defer the implementation of the FSP,
our measures of APBO and net periodic postretirement benefit costs included in
the condensed consolidated financial statements herein do not reflect the
effects of the Act.
NOTE 15 - SUBSEQUENT EVENTS
Norway Strike - In July 2004, members of the OFS, one of three unions
representing offshore workers in Norway, called a strike on our semisubmersible
units operating in the country. OFS called the strike after it was unable to
reach an agreement with the Norwegian Shipowners Association, which represents
rig owners in Norway. The rigs immediately affected are the Polar Pioneer,
Transocean Searcher and Transocean Leader. Although not currently operating, the
semisubmersible Transocean Arctic was expected to commence a contract by
mid-August 2004 but could now be affected by the strike. The striking workers
have now departed the rigs and the crews have been reduced to essential
personnel only. We do not believe a resolution is imminent and cannot provide
any assurance as to when the rigs will be able to go back to work. At this time,
we cannot estimate the aggregate financial impact of the strike.
Trident 20 Incident - In July 2004, the jackup rig Trident 20 suffered
damage resulting from a fire in the rig's engine room while operating offshore
Turkmenistan in the Caspian Sea. The cause of the fire is under investigation
and the rig is expected to be idle for approximately four months. The rig has
been under a three-well contract. Pursuant to the contract, our customer has the
right to terminate the contract. While the contract has been suspended by the
customer to allow time for rig repairs and we expect that drilling will resume
under the terms of the original contract upon completion of the repairs, no
assurances can be given that the contract will not be terminated. We are in the
process of completing an estimate of the expected costs to repair the rig.
TODCO Secondary Offering - On August 3, 2004, TODCO filed a registration
statement with the SEC relating to an offering of up to $230 million of Class A
common stock. We will sell our Class B common stock in the offering, which will
convert to Class A common stock upon sale. TODCO will not sell any stock in the
offering and will not receive any proceeds. We expect to complete this offering
when market conditions warrant, subject to various factors.
18
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
The following information should be read in conjunction with the unaudited
condensed consolidated financial statements included herein under "Item 1.
Financial Statements" and the audited consolidated financial statements and the
notes thereto and "Item 7. Management's Discussion and Analysis of Financial
Condition and Results of Operations" included in our Annual Report on Form 10-K
for the year ended December 31, 2003.
OVERVIEW
Transocean Inc. (together with our subsidiaries and predecessors, unless
the context requires otherwise, "Transocean," "we," "us" or "our") is a leading
international provider of offshore contract drilling services for oil and gas
wells. As of July 30, 2004, we owned, had partial ownership interests in or
operated 95 mobile offshore and barge drilling units, excluding the fleet of
TODCO (together with its subsidiaries and predecessors, unless the context
requires otherwise, "TODCO"), a publicly traded company in which we own a
majority interest. As of this date, our fleet included 32 High-Specification
semisubmersibles and drillships ("floaters"), 25 Other Floaters, 26 Jackup Rigs
and 12 Other Rigs. As of July 30, 2004, TODCO's fleet consisted of 24 jackup
rigs, 30 drilling barges, nine land rigs, three submersible drilling rigs and
four other drilling rigs.
Our mobile offshore drilling fleet is considered one of the most modern and
versatile fleets in the world. Our primary business is to contract these
drilling rigs, related equipment and work crews primarily on a dayrate basis to
drill oil and gas wells. We specialize in technically demanding segments of the
offshore drilling business with a particular focus on deepwater and harsh
environment drilling services. We also provide additional services, including
integrated well services and management of third party well service activities.
Certain key measures of our total company results of operations and
financial condition are as follows:
Three Months Ended June 30, Six Months Ended June 30, Three Six
--------------------------------- ------------------------------- Months Months
2004 2003 2004 2003 Change Change
---------------- --------------- --------------- -------------- -------------- ------------
(In millions, except dayrates and percentages)
Average dayrate (a) $ 69,600 $ 65,300 $ 70,600 $ 67,100 $ 4,300 $ 3,500
Utilization (b) 56% 57% 56% 56% N/A N/A
STATEMENT OF OPERATIONS
Operating revenue $ 633.2 $ 603.9 $ 1,285.2 $ 1,219.9 $ 29.3 $ 65.3
Operating and maintenance
expense 406.2 426.5 818.6 800.6 (20.3) 18.0
Operating income 103.8 19.8 240.0 121.4 84.0 118.6
Net income (loss) 48.0 (44.5) 70.7 2.7 92.5 68.0
June 30, December 31,
2004 2003 Change
-------------- ------------- --------
(In millions)
BALANCE SHEET DATA (AT END OF PERIOD)
Cash $ 322.1 $ 474.0 $(151.9)
Total Assets 11,335.7 11,662.6 (326.9)
Debt 3,076.9 3,658.1 (581.2)
_____________________
"N/A" means not applicable.
(a) Average dayrate is defined as contract drilling revenue earned per revenue
earning day in the period.
(b) Utilization is defined as the total actual number of revenue earning days
as a percentage of the total number of calendar days in the period.
19
Our revenue and operating and maintenance expenses for the six months ended
June 30, 2004 increased from the comparable period last year due to the current
year effect of including the operations of the drillships Deepwater Pathfinder
and Deepwater Frontier as a result of the 2003 acquisitions of the portions of
the Deepwater Drilling L.L.C. ("DD LLC") and Deepwater Drilling II L.L.C. ("DDII
LLC") joint ventures previously held by ConocoPhillips and the subsequent payoff
of the synthetic lease financing arrangements in late December 2003. In
addition, operating revenue and operating and maintenance expense increased due
to the riser separation incident on the drillship Discoverer Enterprise, which
idled the rig for a portion of 2003 (see "-Significant Events"), as well as from
higher integrated services provided to our clients in 2004. Our six months ended
June 30, 2004 financial results included a non-cash charge pertaining to a loss
on retirement of debt partially offset by the recognition of a gain on the sale
of a semisubmersible rig. We also recognized a gain on the TODCO initial public
offering ("IPO") that was partially offset by a tax valuation allowance and
stock option expense recorded in relation to the IPO (see "-Significant
Events"). Debt and cash decreased during the six months ended June 30, 2004
primarily as a result of repayments on debt instruments as we continue to
maintain our focus on debt reduction. The decrease in cash was partially offset
by proceeds received from the TODCO IPO.
Our operations are aggregated into two reportable segments: (i) Transocean
Drilling and (ii) TODCO. The Transocean Drilling segment consists of floaters,
jackups and other rigs used in support of offshore drilling activities and
offshore support services. The TODCO segment consists of our interest in TODCO,
which conducts jackup, drilling barge, land rig, submersible and other
operations in the U.S. Gulf of Mexico and inland waters, Mexico, Trinidad and
Venezuela. We provide services with different types of drilling equipment in
several geographic regions. The location of our rigs and the allocation of
resources to build or upgrade rigs is determined by the activities and needs of
our customers.
We categorize our Transocean Drilling segment fleet into a
"High-Specification Floaters" category, consisting of our "Fifth-Generation
Deepwater Floaters," "Other Deepwater Floaters" and "Other High-Specification
Floaters," an "Other Floaters" category, a "Jackups" category and an "Other
Rigs" category. Within our High-Specification Floaters category, we consider our
Fifth-Generation Deepwater Floaters to be the semisubmersibles Deepwater
Horizon, Cajun Express, Deepwater Nautilus, Sedco Energy and Sedco Express and
the drillships Deepwater Discovery, Deepwater Expedition, Deepwater Frontier,
Deepwater Millennium, Deepwater Pathfinder, Discoverer Deep Seas, Discoverer
Enterprise, and Discoverer Spirit. These rigs were built in the last
construction cycle and have high-pressure mud pumps and a water depth capability
of 7,500 feet or greater. The Other Deepwater Floaters are generally those other
semisubmersible rigs and drillships that have a water depth capacity of at least
4,500 feet. The Other High-Specification Floaters are those rigs capable of
drilling in harsh environments that were built as fourth-generation rigs in the
mid- to late-1980's and have greater displacement than previously constructed
rigs resulting in larger variable load capacity, more useable deck space and
better motion characteristics. The Other Floaters category is generally
comprised of those non-high-specification floaters with a water depth capacity
of less than 4,500 feet. The Jackups category consists of this segment's jackup
fleet, and the Other Rigs category consists of other rigs that are of a
different type or use. These categories reflect how we view, and how we believe
our investors and the industry generally view, our fleet, and reflect our
strategic focus on the ownership and operation of premium high-specification
floating rigs and jackups.
SIGNIFICANT EVENTS
Transocean Drilling Segment
Operational Incidents - In May 2003, we announced that a drilling riser had
separated on our deepwater drillship Discoverer Enterprise and that the rig had
temporarily suspended drilling operations for our customer. The rig resumed
operations in July 2003 and we resolved a disagreement with our customer
regarding the incident in early 2004, the result of which had no significant
effect on our results of operations. In June 2004, we finalized discussions with
our insurers relating to an insurance claim for a portion of our losses stemming
from this incident and received a significant portion of an insurance settlement
in June 2004, which had a favorable effect on pre-tax earnings of approximately
$11.5 million.
20
In July 2004, members of the OFS, one of three unions representing offshore
workers in Norway, called a strike on our semisubmersible units operating in the
country. OFS called the strike after it was unable to reach an agreement with
the Norwegian Shipowners Association, which represents rig owners in Norway. The
rigs immediately affected are the Polar Pioneer, Transocean Searcher and
Transocean Leader. Although not currently operating, the semisubmersible
Transocean Arctic was expected to commence a contract by mid-August 2004 but
could now be affected by the strike. The striking workers have now departed the
rigs and the crews have been reduced to essential personnel only. We do not
believe a resolution is imminent and cannot provide any assurance as to when the
rigs will be able to go back to work. At this time, we cannot estimate the
aggregate financial impact of the strike.
In July 2004, the jackup rig Trident 20 suffered damage resulting from a
fire in the rig's engine room while operating offshore Turkmenistan in the
Caspian Sea. The cause of the fire is under investigation and the rig is
expected to be idle for approximately four months. The rig has been under a
three-well contract. Pursuant to the contract, our customer has the right to
terminate the contract. While the contract has been suspended by the customer to
allow time for rig repairs and we expect that drilling will resume under the
terms of the original contract upon completion of the repairs, no assurances can
be given that the contract will not be terminated. We are in the process of
completing an estimate of the expected costs to repair the rig.
We expect the Norway strike and effect of the Trident 20 fire to negatively
impact third quarter revenue and related earnings.
Asset Disposition - In June 2004, we completed the sale of a
semisubmersible rig, the Sedco 602, for net proceeds of approximately $28.0
million and recognized a gain of $21.6 million.
Debt Redemption - In March 2004, we completed the redemption of our $289.8
million principal amount outstanding 9.5% Senior Notes due December 2008 at the
make-whole premium price provided in the indenture. We redeemed these notes at
127.796% of face value or $370.3 million, plus accrued and unpaid interest. We
recognized an after-tax loss on the redemption of debt of approximately $28.1
million in the first quarter of 2004, which reflected adjustments for fair value
of the debt at the merger ("R&B Falcon merger") with R&B Falcon Corporation
("R&B Falcon") and the premium on the termination of the related interest rate
swap. We funded the redemption with existing cash balances, which included
proceeds from the TODCO IPO. The redemption did not affect the 9.5% Senior
Notes due December 2008 of TODCO, which had an aggregate principal amount
outstanding of $10.2 million at June 30, 2004.
TODCO Segment
IPO and Secondary Offering - In February 2004, we completed the TODCO IPO,
in which we sold 13.8 million shares of TODCO's class A common stock,
representing approximately 23 percent of TODCO's total outstanding shares, at
$12.00 per share. We received net proceeds of $155.7 million from the IPO and
recognized a gain of approximately $39.4 million in the first quarter of 2004,
which represents the excess of net proceeds received over the net book value of
the TODCO shares sold in the IPO. Additionally, as a result of the
deconsolidation of TODCO from our other U.S. subsidiaries for U.S. federal
income tax purposes in conjunction with the IPO, we established an initial
valuation allowance in the first quarter of 2004 of approximately $31.0 million
against the estimated deferred tax assets of TODCO in excess of its deferred tax
liabilities, taking into account prudent and feasible planning strategies as
required by Financial Accounting Standards Board's ("FASB") Statement of
Financial Accounting Standards ("SFAS") 109, Accounting for Income Taxes. The
ultimate amount of such valuation allowance could vary significantly depending
upon a number of factors, including the final allocation of tax benefits between
TODCO and our other subsidiaries under applicable law, taxable income for
calendar year 2004 and our ability to implement tax planning strategies under
SFAS 109.
In conjunction with the closing of the TODCO IPO, TODCO granted restricted
stock and stock options to certain of its employees under its long-term
incentive plan and certain of these awards vested at the time of grant. In
accordance with the provisions of the SFAS 123, Accounting for Stock-Based
Compensation, TODCO expects to recognize compensation expense of approximately
$17.0 million over the vesting periods of the awards. TODCO recognized
approximately $6.0 million in the first quarter of 2004 as a result of the
immediate vesting of certain
21
awards. TODCO will amortize the remaining amount of approximately $11.0 million
to compensation expense over the next three years with approximately $5.0
million over the remainder of 2004 and approximately $5.0 million and $1.0
million in 2005 and 2006, respectively. In addition, certain of TODCO's
employees held options that were granted prior to the IPO to acquire our
ordinary shares. In accordance with the employee matters agreement, these
options were modified, which resulted in the accelerated vesting of the options
and the extension of the term of the options through the original contractual
life. In connection with the modification of these options, TODCO recognized
approximately $1.5 million additional compensation expense in the first quarter
of 2004.
As of July 30, 2004, we held an approximate 77 percent interest in TODCO,
represented by 46.2 million shares of class B common stock, and we have
approximately 94 percent of the outstanding voting interest in TODCO. Each share
of our class B common stock has five votes per share compared to one vote per
share of the class A common stock. We consolidate TODCO in our financial
statements as a separate business segment and expect to continue to consolidate
TODCO in our financial statements until we no longer own a majority voting
interest. TODCO was formerly known as R&B Falcon. Before the closing of the IPO,
TODCO transferred to us all assets and businesses unrelated to TODCO's business.
R&B Falcon's business was previously considerably broader than TODCO's ongoing
business.
Our current long-term intent is to dispose of our remaining interest in
TODCO, which could be achieved through a number of possible transactions
including additional public offerings, open market sales, sales to one or more
third parties, a spin-off to our shareholders, split-off offerings to our
shareholders that would allow for the opportunity to exchange our shares for
shares of TODCO class A common stock or a combination of these transactions. On
August 3, 2004, TODCO filed a registration statement with the Securities and
Exchange Commission ("SEC") relating to an offering of up to $230 million of
Class A common stock. We will sell our Class B common stock in the offering,
which will convert to Class A common stock upon sale. TODCO will not sell any
stock in the offering and will not receive any proceeds. We expect to complete
this offering when market conditions warrant, subject to various factors. We
plan to use the proceeds from this offering to reduce debt and for other general
corporate purposes.
Delta Towing - As a result of the adoption of FASB Interpretation ("FIN")
46 and a determination that TODCO was the primary beneficiary for accounting
purposes of our joint venture, Delta Towing Holdings, LLC ("Delta Towing"),
TODCO consolidated Delta Towing at December 31, 2003. Due to the consolidation
of Delta Towing, operating revenue and operating and maintenance expense
increased during the six months ended June 30, 2004 by $13.6 million and $11.9
million, respectively.
Effective Tax Rate
The annual effective tax rate for 2004 is estimated to be approximately 35
percent of earnings before TODCO IPO-related items, loss on debt retirements and
gains on significant asset sales. The effective tax rate increased from
approximately 27 percent estimated at March 31, 2004 as a result of developments
in the second quarter on certain international tax disputes, an increase in the
valuation allowance established at the time of the TODCO IPO and changes in the
expected amount and geographical concentration of taxable income. The catch-up
effect of the increase in the annual effective tax rate was reflected in the
second quarter of 2004 resulting in an effective tax rate of 45 percent on
earnings for the three months ended June 30, 2004, excluding the sale of the
semisubmersible rig Sedco 602. As a result, earnings for the three months ended
June 30, 2004 were reduced by $4.6 million.
OUTLOOK
Drilling Market - During the second quarter of 2004, commodity prices
remained at historically strong levels. While commodity prices may vary from
current levels, we expect them to remain strong in historical terms. Future
commodity price expectations have historically been a key driver for offshore
drilling demand, although recent price levels have not necessarily translated
into increased rig demand. The availability of quality drilling prospects,
exploration success, relative production costs, the stage of reservoir
development and political and regulatory environments also affect our customers'
drilling programs.
22
Prospects for our High-Specification Floaters appear to be gaining strength
over the balance of 2004. However, a number of these units will conclude
contracts in 2004 and, as a result, intermittent idle time remains a possibility
for some of these rigs. We have recently received several new contracts or
extensions for our High Specification fleet. The Sedco Express was awarded a
three-year contract for BP's Plutonio project in Angola. The Paul B. Loyd, Jr.
received a two-year contract extension, the Cajun Express was awarded a new
210-day contract, the Deepwater Discovery was awarded a combined three-well
commitment and the Sovereign Explorer was awarded two contracts totaling 320
days. We continue to believe that over the long term, deepwater exploration and
development drilling opportunities in the Gulf of Mexico, West Africa, India and
other market sectors represent a significant source of future deepwater rig
demand, although the risk of project delays remains, especially in Nigeria and
Angola. We are also seeing a strong customer preference for using
fifth-generation equipment in these deepwater areas.
The outlook for activity for the non-U.S. jackup market sector is expected
to remain strong, particularly in Asia and the Middle East. There remains a
current overcapacity in the West Africa jackup sector and Transocean is
repositioning two units, the Trident VI and the J. T. Angel, from West Africa
and India, respectively, to Asia to capture the growth opportunities there. The
Trident VI is expected to be on contract by October of this year.
The outlook for our Other Floaters that operate in the mid-water sector
remains weak as this sector continues to be significantly oversupplied globally.
We expect overall North Sea industry fleet utilization to increase beyond the
usual normal seasonal upswing in the summer months. A number of rigs have now
been contracted through the winter months and there is a growing expectation
that overall utilization next year will be higher than 2004. Utilization in the
U.S. Gulf of Mexico market sector continues to be dampened by an over supply of
units. There is a possibility of additional work in Brazil and India, and we
are evaluating these opportunities.
We expect additional downtime during the third quarter to result from other
rig mobilizations, primarily the Jack Bates, which we expect to mobilize in
August of this year from the UK sector of the North Sea to Australia upon
completion of its current contract, and the Actinia, which is currently idle in
Egypt and will mobilize to India. In addition to these mobilizations, we expect
downtime to result from planned shipyards for the Polar Pioneer, Sedco 706,
Sedco 709 and the Transocean Arctic. These rig mobilizations and planned
shipyard projects are expected to have a negative impact on third quarter
revenues and related earnings.
TODCO expects the declining jackup rig supply in the U.S. Gulf Coast region
to continue to support higher dayrates for its jackup fleet compared to the
beginning of the year. TODCO has seen a slight improvement in dayrates and
utilizations for its inland barges in 2004 in this region.
Our operations are geographically dispersed in oil and gas exploration and
development areas throughout the world. Rigs can be moved from one region to
another, but the cost of moving a rig and the availability of rig-moving vessels
may cause the supply and demand balance to vary somewhat between regions.
However, significant variations between regions do not tend to exist long-term
because of mobility. Consequently, we operate in a single, global offshore
drilling market.
The offshore contract drilling market remains highly competitive and
cyclical, and it has been historically difficult to forecast future market
conditions. Extraneous risks include declines in oil and/or gas prices that
reduce rig demand and adversely affect utilization and dayrates. Major operator
and national oil company capital budgets are key drivers of the overall business
climate, and these may change within a fiscal year depending on exploration
results and other factors. Additionally, increased competition for our
customers' drilling budgets could come from, among other areas, land-based
energy markets in Russia, other former Soviet Union states and the Middle East.
As of July 27, 2004, approximately 60 percent of our Transocean Drilling
segment fleet days were committed for the remainder of 2004 and approximately 34
percent for the year 2005.
Tax Matters - We are a Cayman Islands company registered in Barbados. We
operate through our various subsidiaries in a number of countries throughout the
world. Consequently, we are subject to changes in tax laws, treaties and
regulations in and between the countries in which we operate, including treaties
that the U.S. has with other nations. A material change in these tax laws,
treaties or regulations, including those in and involving the U.S.,
23
could result in a higher effective tax rate on our worldwide earnings. Recent
developments in this area include proposed tax legislation in the U.S. that
would change the tax law applicable to companies like us that have undertaken a
transaction commonly referred to as an inversion and the recent protocol signed
by the U.S. and Barbados which would amend the tax treaty between the two
countries.
Our income tax returns are subject to review and examination in the various
jurisdictions in which we operate. The U.S. Internal Revenue Service is
currently auditing our tax returns for calendar years 1999, the year we became a
Cayman Islands company, and 2000. In addition, other tax authorities have
examined the amounts of income and expense subject to tax in their jurisdiction
for prior periods. We are currently contesting various non-U.S. assessments that
have been asserted and would expect to contest any future U.S. or non-U.S.
assessments. While we cannot predict or provide assurance as to the final
outcome of existing or future assessments, we do not believe that the ultimate
resolution of these asserted income tax liabilities will have a material adverse
effect on our business or consolidated financial position.
As a result of the deconsolidation of TODCO from our other U.S.
subsidiaries for U.S. federal income tax purposes in conjunction with the IPO,
we established an initial valuation allowance of approximately $31.0 million
against the estimated deferred tax assets of TODCO in excess of its deferred tax
liabilities, taking into account prudent and feasible planning strategies as
required by SFAS 109. See "-Significant Events."
Stock-Based Compensation Expense - As a result of the adoption in January
2003 of the fair value recognition provisions of SFAS 123, Accounting for
Stock-Based Compensation, using the prospective method prescribed by SFAS 148,
Accounting for Stock-Based Compensation Transition and Disclosure, our
stock-based compensation expense is expected to increase in 2004. The increase
will result from the impact of a full year of expense related to our 2003
awards, compared to six months of expense in 2003, and expense related to our
2004 awards, which were granted in July 2004. Future periods will continue to
have increases in stock-based compensation expense until the impact of the
layering effect of future awards is normalized. In addition, TODCO now has a
long-term incentive plan under which it grants stock options and restricted
stock to certain key employees (see "-Significant Events"). Awards made under
this plan in 2004 will result in an increase in stock-based compensation expense
in 2004.
24
PERFORMANCE AND OTHER KEY INDICATORS
Fleet Utilization and Dayrates - The following table shows our average
dayrate and utilization for the quarterly periods ended on or prior to June 30,
2004. Average dayrate is defined as contract drilling revenue earned per revenue
earning day in the period. 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.
Three Months Ended
-----------------------------------
June 30, March 31, June 30,
2004 2004 2003
---------- ----------- ----------
Average Dayrates
Transocean Drilling Segment:
High-Specification Floaters
Fifth-Generation Deepwater Floaters $ 177,800 $ 191,800 $ 185,100
Other Deepwater Floaters $ 107,800 $ 101,300 $ 111,500
Other High-Specification Floaters $ 115,500 $ 115,200 $ 114,400
Total High-Specification Floaters $ 141,100 $ 143,500 $ 143,300
Other Floaters $ 65,000 $ 62,800 $ 64,800
Jackups $ 52,700 $ 51,400 $ 57,400
Other Rigs $ 43,300 $ 44,200 $ 41,500
---------- ----------- ----------
Segment Total $ 89,100 $ 90,200 $ 88,900
---------- ----------- ----------
---------- ----------- ----------
TODCO Segment $ 26,200 $ 25,700 $ 17,500
---------- ----------- ----------
Total Drilling Fleet $ 69,600 $ 71,600 $ 65,300
========== =========== ==========
Utilization
Transocean Drilling Segment:
High-Specification Floaters
Fifth-Generation Deepwater Floaters 90% 92% 88%
Other Deepwater Floaters 70% 78% 70%
Other High-Specification Floaters 75% 73% 75%
Total High-Specification Floaters 79% 83% 77%
Other Floaters 45% 42% 52%
Jackups 85% 83% 86%
Other Rigs 46% 54% 41%
---------- ----------- ----------
Segment Total 68% 69% 68%
---------- ----------- ----------
---------- ----------- ----------
TODCO Segment 41% 38% 42%
---------- ----------- ----------
Total Drilling Fleet 56% 56% 57%
========== =========== ==========
Contract Drilling Revenue - Our contract drilling revenues are based
primarily on dayrates received for our drilling services and the number of
operating days during the relevant periods. The level of our contract drilling
revenue depends on dayrates, which in turn are primarily a function of industry
supply and demand for drilling units in the markets in which we operate. During
periods of high demand, our rigs typically achieve higher utilization and
dayrates than during periods of low demand. Some of our drilling contracts also
enable us to earn mobilization, contract preparation, capital upgrade, bonus and
demobilization revenue. Mobilization, contract preparation and capital upgrade
revenue earned on a lump sum basis is recognized over the original contract
term. Bonus and demobilization revenue is recognized when earned.
25
Other Revenue - Beginning with the first quarter of 2004, we began
classifying our revenues into two categories: (1) contract drilling revenue and
(2) other revenue. Our other revenue represents client reimbursable revenue,
integrated services revenue, management service revenues, revenues from
operation of Delta Towing's fleet of marine support vessels and other
miscellaneous revenues. From time to time, we provide well services in addition
to our normal drilling services through third party contractors. We refer to
these other services as integrated services.
Operating and Maintenance Costs - Our operating and maintenance costs
represent all direct and indirect costs associated with the operation and
maintenance of our drilling rigs. The principal elements of these costs are
direct and indirect labor and benefits, repair and maintenance, 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 and insurance costs
represent the most significant components of our operating and maintenance
costs.
We do not expect operating and maintenance expenses to necessarily
fluctuate in proportion to changes in operating revenues. Operating revenues may
fluctuate as a function of changes in dayrate. However, costs for operating a
rig are generally fixed or only semi-variable regardless of the dayrate being
earned. In addition, should our rigs incur idle time between contracts, we
typically do not de-man those rigs because we will use the crew to prepare the
rig for its next contract. During times of reduced activity, reductions in costs
may not be immediate as portions of the crew may be required to prepare our rigs
for stacking, after which time the crew members are assigned to active rigs or
dismissed. In general, labor costs increase primarily due to higher salary
levels and inflation. Equipment maintenance expenses fluctuate depending upon
the type of activity the unit is performing and the age and condition of the
equipment. While our per occurrence deductible levels for our hull and machinery
and our protection and indemnity policies remained unchanged from 2003 at $10
million, we increased our additional aggregate annual insurance deductible for
the current policy year in an effort to reduce costs. This additional aggregate
annual deductible of $20 million is applied after the per occurrence deductible
is met until it is fully utilized at which time the $10 million per occurrence
applies for all remaining claims during the year.
Depreciation Expense - Our depreciation expense is based on estimates,
assumptions and judgments relative to capitalized costs, useful lives and
salvage values of our assets. We generally compute depreciation using the
straight-line method after allowing for salvage values.
General and Administrative Expense - General and administrative expense
includes all costs related to our corporate executives, directors, investor
relations, corporate accounting and reporting, information technology, internal
audit, legal, tax, treasury, risk management and human resource functions.
Interest Expense - Interest expense consists of interest associated with
our senior notes and other debt and related financing cost amortization.
Interest expense is partially offset by the amortization of gains on interest
rate swaps terminated during 2003. We expect the amortization of these gains to
continue over the life of the related debt instruments (see "-Derivative
Instruments").
Income Taxes - Provisions for income taxes are based on expected taxable
income, statutory rates and tax planning opportunities available to us in the
various jurisdictions in which we operate. Taxable income may differ from
pre-tax income for financial accounting purposes, particularly in countries with
revenue-based taxes. There is no expected relationship between the provision for
income taxes and income before income taxes because the countries in which we
operate have different taxation regimes. We provide a valuation allowance for
deferred tax assets when it is more likely than not that some or all of the
benefit from the deferred tax asset will not be realized. See "-Critical
Accounting Policies."
26
FINANCIAL CONDITION
JUNE 30, 2004 COMPARED TO DECEMBER 31, 2003
June 30, December 31,
2004 2003 Change % Change
--------- ------------- -------- ---------
(In millions, except % change)
TOTAL ASSETS
Transocean Drilling $10,589.3 $ 10,874.0 $(284.7) (3)%
TODCO 746.4 788.6 (42.2) (5)%
--------- ------------- -------- ---------
$11,335.7 $ 11,662.6 $(326.9) (3)%
========= ============= ======== =========
The decrease in Transocean Drilling segment assets was mainly due to asset
depreciation ($216.4 million), a decrease in cash and cash equivalents ($159.4
million) that resulted primarily from the repayment of debt of approximately
$592.2 million during the six months ended June 30, 2004 and the sale of a
semisubmersible rig ($6.0 million), partially offset by proceeds received from
the TODCO IPO ($155.7 million) and cash from operations. The decrease in TODCO
segment assets was primarily due to depreciation ($48.1 million).
LIQUIDITY AND CAPITAL RESOURCES
SOURCES AND USES OF CASH
Six Months Ended
June 30,
------------------------
2004 2003 Change
------------ ---------- --------
(In millions)
NET CASH PROVIDED BY OPERATING ACTIVITIES
Net income $ 70.7 $ 2.7 $ 68.0
Depreciation 264.5 254.3 10.2
Other non-cash items (9.3) 11.4 (20.7)
Working capital (45.3) 36.3 (81.6)
------------ ---------- --------
$ 280.6 $ 304.7 $ (24.1)
============ ========== ========
Net cash provided by operating activities decreased $24.1 million due to a
decrease in cash provided by working capital items of $81.6 million, partially
offset by an increase in cash generated from net income adjusted for non-cash
activity of $57.5 million during the six months ended June 30, 2004 as compared
to the corresponding prior year period.
Six Months Ended
June 30,
------------------------
2004 2003 Change
------------ ---------- --------
(In millions)
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES
Capital expenditures $ (55.8) $ (50.2) $ (5.6)
Proceeds from disposal of assets 42.0 3.2 38.8
Proceeds from TODCO IPO 155.7 - 155.7
DDII LLC's cash acquired, net of cash paid - 18.1 (18.1)
Note issued to related party, net of repayments - (45.3) 45.3
Other, net 4.7 2.2 2.5
------------ ---------- --------
$ 146.6 $ (72.0) $ 218.6
============ ========== ========
Net cash provided by investing activities increased approximately $218.6
million for the six months ended June 30, 2004 as compared to net cash used in
investing activities in the same period in the previous year. The increase
27
is primarily the result of the proceeds from the TODCO IPO of $155.7 million
(see "-Significant Events") combined with an increase in proceeds from asset
sales as compared to the corresponding prior year period. In addition, we
acquired ConocoPhillips' 40 percent interest in DDII LLC and issued a note
receivable to a related party during the six months ended June 30, 2003, with no
comparable activity for the same period in 2004.
Six Months Ended
June 30,
------------------------
2004 2003 Change
------------ ---------- --------
(In millions)
NET CASH USED IN FINANCING ACTIVITIES
Repayments on revolving credit agreements $ (200.0) $ - $(200.0)
Cash received from termination of interest rate swaps - 173.5 (173.5)
Repayments on other debt instruments (395.2) (919.2) 524.0
Other, net 16.1 12.8 3.3
------------ ---------- --------
$ (579.1) $ (732.9) $ 153.8
============ ========== ========
We repaid $200.0 million under our $800.0 million revolving credit facility
during the six months ended June 30, 2004 while no such payment was made for the
same period in 2003. For the six months ended June 30, 2004, we used cash of
$370.3 million for the early redemption of our 9.5% Senior Notes (see
"-Significant Events") and $21.9 million in other scheduled debt maturities. For
the six months ended June 30, 2003, we received interest rate swap termination
proceeds of $173.5 million (see "-Derivative Instruments") for which there was
no comparable activity in 2004. In addition, we used cash of $527.2 million to
repurchase our Zero Coupon Convertible Debentures that were put to us in May
2003, $50.0 million for the early repayment of our 9.41% Nautilus Class A2
Notes, and $342.0 million for other scheduled debt maturities during the six
months ended June 30, 2003.
CAPITAL EXPENDITURES
Capital expenditures totaled $55.8 million during the six months ended June
30, 2004 of which $51.0 million and $4.8 million related to the Transocean
Drilling and TODCO segments, respectively.
During 2004, we expect to spend approximately $90 million to $100 million
on our existing Transocean Drilling segment fleet, corporate infrastructure and
major upgrades, excluding upgrades required and funded by our drilling
contracts, which we anticipate will be approximately $30 million to $40 million.
These amounts are dependent upon the actual level of operational and contracting
activity. We intend to fund the cash requirements relating to our capital
expenditures through available cash balances, cash generated from operations and
asset sales. We also have available credit under our revolving credit agreement
(see "-Sources of Liquidity") and may engage in other commercial bank or capital
market financings.
TODCO expects to spend approximately $13 million on capital expenditures in
2004.
ACQUISITIONS AND DISPOSITIONS
From time to time, we review possible acquisitions of businesses and
drilling units and may in the future make significant capital commitments for
such purposes. Any such acquisition could involve the payment by us of a
substantial amount of cash or the issuance of a substantial number of additional
ordinary shares or other securities. We would likely fund the cash portion of
any such acquisition through cash balances on hand, the incurrence of additional
debt, sales of assets, issuance of ordinary shares or other securities or a
combination thereof. In addition, from time to time, we review possible
dispositions of drilling units.
Dispositions - In February 2004, we completed the TODCO IPO. See
"-Significant Events."
In March 2004, in our Transocean Drilling segment we entered into
agreements to sell two semisubmersible rigs, the Sedco 600 and Sedco 602, for
net proceeds of $52.7 million, in connection with our efforts to dispose of
28
certain non-strategic assets. In June 2004, we completed the sale of a
semisubmersible rig, the Sedco 602, for net proceeds of $28.0 million and
recognized a gain of $21.6 million, which had no tax effect. The sale of the
Sedco 600 is expected to close during the fourth quarter of 2004 after
completion of a drilling project.
During the six months ended June 30, 2004, we settled insurance claims and
sold marine support vessels and certain other assets for net proceeds of
approximately $14.0 million and recorded net gains of $1.0 million, net of tax
of $0.4 million, and $4.6 million, which had no tax effect, in our Transocean
Drilling and TODCO segments, respectively.
SOURCES OF LIQUIDITY
Our primary sources of liquidity in the second quarter of 2004 were our
cash flows from operations, proceeds from asset sales and existing cash
balances. Our primary uses of cash were debt repayments and capital
expenditures. At June 30, 2004, we had $322.1 million in cash and cash
equivalents.
We expect to use existing cash balances, internally generated cash flows
and proceeds from assets sales, including potential additional sales of our
interest in TODCO, to fulfill anticipated obligations such as scheduled debt
maturities, capital expenditures and working capital needs. From time to time,
we may also use bank lines of credit to maintain liquidity for short-term cash
needs.
Excluding the acquisition of the Deepwater Pathfinder and Deepwater
Frontier in December 2003, we have significantly reduced our capital
expenditures compared to prior years due to the completion of our newbuild
program in 2001 and ongoing efforts to contain capital expenditures. See
"-Capital Expenditures."
When cash on hand, cash flows from operations, proceeds from asset sales,
including potential additional sales of our interest in TODCO, and committed
bank facility availability exceed our expected liquidity needs, we may use a
portion of such cash to reduce debt prior to scheduled maturity through
repurchases, redemptions or tender offers, or make repayments on bank
borrowings.
At June 30, 2004 and December 31, 2003, our total debt was $3,076.9 million
and $3,658.1 million, respectively. Net debt, a non-GAAP financial measure
defined as total debt less cash and cash equivalents, at such dates was $2,754.8
million and $3,184.1 million, respectively. During the six months ended June 30,
2004, we reduced net debt by $429.3 million. The reconciliation of total debt to
net debt at carrying value is as follows (in millions):
June 30, December 31,
2004 2003
---------- --------------
Total Debt $ 3,076.9 $ 3,658.1
Less: Cash and cash equivalents (322.1) (474.0)
---------- --------------
Net Debt $ 2,754.8 $ 3,184.1
========== ==============
We believe net debt provides useful information regarding the level of our
indebtedness by reflecting the amount of indebtedness assuming cash and
investments are used to repay debt. Net debt declined each year since 2001
because cash flows, primarily from operations and asset sales, have exceeded
capital expenditures.
Our internally generated cash flow is directly related to our business and
the market sectors in which we operate. Should the drilling market deteriorate,
or should we experience poor results in our operations, cash flow from
operations may be reduced. Also, as a result of the TODCO IPO, we do not have
access to TODCO's cash flows as we do with our wholly owned subsidiaries. We
have, however, continued to generate positive cash flow from operating
activities over recent years and expect cash flow will continue to be positive
over the next year.
We have access to a bank line of credit under an $800.0 million five-year
revolving credit agreement expiring in December 2008. As of June 30, 2004,
$750.0 million remained available under this credit line. Because our current
cash balances, expected cash flow and this revolving credit agreement provide us
with adequate liquidity, we terminated our commercial paper program during the
first quarter of 2004.
29
The bank credit line requires compliance with various covenants and
provisions customary for agreements of this nature, including an earnings before
interest, taxes, depreciation and amortization ("EBITDA") to interest coverage
ratio and a debt to tangible capital ratio, both as defined by the credit
agreement, of not less than three to one and not greater than 50 percent,
respectively. Other provisions of the credit agreement includes limitations on
creating liens, incurring debt, transactions with affiliates, sale/leaseback
transactions and mergers and sale of substantially all assets. Should we fail to
comply with these covenants, we would be in default and may lose access to this
facility. We are also subject to various covenants under the indentures pursuant
to which our public debt was issued, including restrictions on creating liens,
engaging in sale/leaseback transactions and engaging in merger, consolidation or
reorganization transactions. A default under our public debt could trigger a
default under our credit line and cause us to lose access to this facility.
TODCO has access to a bank line of credit under a $75.0 million two-year
revolving credit agreement (the "TODCO Revolving Credit Agreement"), which will
reduce to $60.0 million in December 2004 and expires in December 2005. As of
June 30, 2004, $75.0 million remained available under this line of credit. The
TODCO Revolving Credit Agreement requires compliance with various covenants and
provisions customary for similar agreements of non-investment grade facilities.
TODCO's Revolving Credit Agreement is not guaranteed by us.
In April 2001, the SEC declared effective our shelf registration statement
on Form S-3 for the proposed offering from time to time of up to $2.0 billion in
gross proceeds of senior or subordinated debt securities, preference shares,
ordinary shares and warrants to purchase debt securities, preference shares,
ordinary shares or other securities. At June 30, 2004, $1.6 billion in gross
proceeds of securities remained unissued under the shelf registration statement.
Our access to debt and equity markets may be reduced or closed to us due to
a variety of events, including, among others, downgrades of ratings of our debt,
industry conditions, general economic conditions, market conditions and market
perceptions of us and our industry.
As is customary in the contract drilling business, we also have various
surety bonds in place that secure customs obligations relating to the
importation of our rigs and certain performance and other obligations. Surety
bonds outstanding totaled $22.5 million and $169.5 million at June 30, 2004 and
December 31, 2003, respectively. The decrease in outstanding surety bonds is
primarily attributable to the expiration of three such bonds totaling $151.1
million related to our Brazil operations.
DERIVATIVE INSTRUMENTS
We have established policies and procedures for derivative instruments that
have been approved by our Board of Directors. These policies and procedures
provide for the prior approval of derivative instruments by our Chief Financial
Officer. From time to time, we may enter into a variety of derivative financial
instruments in connection with the management of our exposure to fluctuations in
foreign exchange rates and interest rates. We do not enter into derivative
transactions for speculative purposes; however, for accounting purposes, certain
transactions may not meet the criteria for hedge accounting.
Gains and losses on foreign exchange derivative instruments that qualify as
accounting hedges are deferred as accumulated other comprehensive income (loss)
and recognized when the underlying foreign exchange exposure is realized. Gains
and losses on foreign exchange derivative instruments that do not qualify as
hedges for accounting purposes are recognized currently based on the change in
market value of the derivative instruments. At June 30, 2004, we had no material
open foreign exchange derivative instruments.
From time to time, we may use interest rate swaps to manage the effect of
interest rate changes on our future earnings. Interest rate swaps that we enter
into are designated as a hedge of future interest payments on our underlying
debt. The interest rate differential to be received or paid under the swaps is
recognized over the lives of the swaps as an adjustment to interest expense. If
an interest rate swap is terminated, the gain or loss is amortized over the
remaining life of the underlying debt. We do not enter into interest rate swaps
for speculative purposes.
30
In January 2003, we terminated swaps with respect to our 6.75% Senior Notes
due April 2005, 6.95% Senior Notes due April 2008 and 9.5% Senior Notes due
December 2008. In March 2003, we terminated swaps with respect to our 6.625%
Notes due April 2011. As a result of these terminations, we received cash
proceeds, net of accrued interest, of approximately $173.5 million that was
recognized as a fair value adjustment to long-term debt in our consolidated
balance sheet and is being amortized as a reduction to interest expense over the
life of the underlying debt. As a result of the redemption of our 9.5% Senior
Notes in March 2004, we recognized a swap premium of $22.0 million on the
termination of the related interest rate swap as a reduction to our loss on
retirement of debt (see "-Operating Results"). Based on the unamortized premiums
remaining on the terminated interest rate swaps, we expect our interest expense
to be approximately $24.0 million lower in 2004.
OPERATING RESULTS
QUARTER ENDED JUNE 30, 2004 COMPARED TO QUARTER ENDED JUNE 30, 2003
Following is an analysis of our Transocean Drilling segment and TODCO
segment operating results, as well as an analysis of income and expense
categories that we have not allocated to our two segments.
Transocean Drilling Segment
Three Months Ended
-----------------------------
June 30,
2004 2003 Change % Change
--------------- ------------ ------------- ------------
(In millions, except day amounts and percentages)
Operating days 5,795 5,887 (92) (2)%
Utilization (a) 68% 68% N/A N/M
Average dayrate (b) $ 89,100 $ 88,900 $ 200 N/M
Contract drilling revenues $ 516.6 $ 523.6 $ (7.0) (1)%
Other revenues 35.9 24.9 11.0 44%
--------------- ------------ ------------- ------------
552.5 548.5 4.0 1%
Operating and maintenance expense 338.1 355.9 (17.8) (5)%
Depreciation 109.1 104.4 4.7 5%
Impairment loss on long-lived assets - 4.2 (4.2) N/M
Gain from sale of assets, net (21.9) (0.2) (21.7) N/M
--------------- ------------ ------------- ------------
Operating income before general and administrative expense $ 127.2 $ 84.2 $ 43.0 51%
=============== ============ ============= ============
_________________
"N/A" means not applicable
"N/M" means not meaningful
(a) Utilization is defined as the total actual number of revenue earning days as a percentage of total number of
calendar days in the period.
(b) Average dayrate is defined as contract drilling revenue earned per revenue earning day.
This segment's contract drilling revenues increased by approximately $42.5
million as a result of additional revenues from the Deepwater Frontier and
Deepwater Pathfinder due to the consolidation of DDII LLC and DD LLC late in the
second and fourth quarters, respectively, of 2003 and lower revenues in 2003
resulting from the labor strike in Nigeria, the Discoverer Enterprise riser
incident and the Peregrine I electrical fire during the second quarter of 2003
with no comparable activity for the same period in 2004. These increases were
more than offset by approximately $49.5 million due to a decline in average
dayrates, which exclude the rigs previously discussed.
Other revenues for the three months ended June 30, 2004 included increases
of $13.1 million related to integrated services, partially offset by a decrease
of $2.6 million in client reimbursable revenue and the absence of
31
revenue from management fees in 2004 as a result of the consolidation of DDII
LLC and DD LLC late in the second and fourth quarters, respectively, of 2003.
The decrease in this segment's operating and maintenance expenses of
approximately $19.5 million resulted primarily from the settlement in 2004 of
the Discoverer Enterprise May 2003 riser incident and a decrease in insurance
expense in the second quarter of 2004. Additional decreases of approximately
$13.3 million resulted from costs associated with the Peregrine I insurance
claim settlement, the labor strike in Nigeria, reserve for allowance for
doubtful accounts related to two client receivables and a favorable turnkey
settlement that occurred in the second quarter of 2003 with no comparable
activity in 2004. Partially offsetting these decreases were increased operating
and maintenance expenses of approximately $14.2 million related primarily to the
Deepwater Pathfinder as a result of the consolidation of DD LLC late in the
fourth quarter of 2003, higher integrated services activity and higher
provisions for local tax matters in 2004.
The increase in this segment's depreciation expense resulted primarily from
$4.9 million of additional depreciation expense related to the Deepwater
Frontier and Deepwater Pathfinder as a result of the late December 2003 payoff
of the synthetic lease financing arrangements by DDII LLC and DD LLC,
respectively, which were consolidated late in the second and fourth quarters,
respectively, of 2003 and the Discoverer Enterprise purchase of tensioner system
equipment.
During the three months ended June 30, 2003, we recorded non-cash
impairment charges in this segment of $4.2 million associated with the removal
of two rigs from drilling service. The determination of fair market value was
based on an offer from a potential buyer.
During the three months ended June 30, 2004, this segment recognized net
gains of $21.9 million related to the sale of the semisubmersible rig Sedco 602
and the sale of other assets.
32
TODCO Segment
Three Months Ended
June 30,
-----------------------------
2004 2003 Change % Change
--------------- ------------ ------------- ------------
(In millions, except day amounts and percentages)
Operating days 2,612 2,919 (307) (11)%
Utilization (a) 41% 42% N/A (2)%
Average dayrate (b) $ 26,200 $ 17,500 $ 8,700 50%
Contract drilling revenues $ 68.3 $ 51.1 $ 17.2 34%
Other revenues 12.4 4.3 8.1 N/M
--------------- ------------ ------------- ------------
80.7 55.4 25.3 46%
Operating and maintenance 68.1 70.6 (2.5) (4)%
Depreciation 23.9 23.1 0.8 3%
Impairment loss on long-lived assets - 11.6 (11.6) N/M
Gain from sale of assets, net (1.9) (0.4) (1.5) N/M
--------------- ------------ ------------- ------------
Operating loss before general and administrative expense $ (9.4) $ (49.5) $ 40.1 (81)%
=============== ============ ============= ============
_________________
"N/A" means not applicable
"N/M" means not meaningful
(a) Utilization is defined as the total actual number of revenue earning days as a percentage of total number of
calendar days in the period.
(b) Average dayrate is defined as contract drilling revenue earned per revenue earning day.
This segment's contract drilling revenues increased by approximately $23.2
million due primarily to an increase in average dayrates, which included the
operations of three jackup rigs in Venezuela (THE 156) and Mexico (THE 205 and
THE 206) after being transferred from the Gulf of Mexico during the fourth
quarter of 2003. These increases were partially offset by decreased utilization
of approximately $5.9 million.
Other revenues for the three months ended June 30, 2004 included increases
of approximately $8.1 million related to the consolidation of Delta Towing at
December 31, 2003 and client reimbursable revenue.
The decrease in this segment's operating and maintenance expense was
primarily due to approximately $11.8 million of costs associated with the inland
barge Rig 62 well control incident in 2003 with no comparable activity in 2004
and a decrease in insurance expense. Partially offsetting the above decreases
were increases primarily due to approximately $5.6 million of costs associated
with the consolidation of Delta Towing at December 31, 2003 and $4.8 million of
operating and maintenance expense associated with operating two jackup rigs in
Mexico (THE 205 and THE 206) after being transferred from the Gulf of Mexico and
compensation expense related to stock options and restricted stock as the result
of the TODCO IPO.
The increase in this segment's depreciation expense resulted primarily from
the consolidation of Delta Towing, partially offset by a reduction in
depreciation resulting from the write down to fair market value of five jackup
rigs removed from active drilling service in 2003.
During the three months ended June 30, 2003, we recorded non-cash
impairment charges in this segment of $11.6 million associated with the removal
of five jackup rigs from drilling service and the write down in the value of an
investment in a joint venture to fair value. The determination of fair market
value was based on third party valuations, in the case of the jackup rigs, and
management's assessment of fair value, in the case of the investment in a joint
venture, where third party valuations were not available.
33
During the three months ended June 30, 2004, this segment recognized net
gains of $1.9 million primarily related to the sale of three marine support
vessels by Delta Towing and the sale of other assets.
Total Company Results of Operations
Three Months Ended
June 30,
------------------------
2004 2003 Change % Change
---------- ------------ -------- ---------
(In millions, except % change)
General and Administrative Expense $ 14.0 $ 14.9 $ (0.9) (6)%
Other (Income) Expense, net
Equity in earnings of joint ventures (3.7) (1.8) (1.9) N/M
Interest income (1.9) (5.8) 3.9 (67)%
Interest expense 42.6 52.8 (10.2) (19)%
Loss on retirement of debt - 15.7 (15.7) N/M
Impairment loss on note receivable from related party - 21.3 (21.3) N/M
Other, net 1.1 2.7 (1.6) (59)%
Income Tax Expense (Benefit) 19.9 (20.8) 40.7 N/M
Minority Interest (2.2) 0.2 (2.4) N/M
_________________________
"N/M" means not meaningful
The decrease in general and administrative expense was primarily
attributable to a reduction of costs related to employee benefits and lower
advertising and public relations fees, partially offset by increases in
professional fees related to compliance with corporate governance regulations
effective for 2004.
Equity in earnings of joint ventures increased approximately $4.1 million
primarily related to our 50 percent share of earnings from Overseas Drilling
Limited, which owns the drillship Joides Resolution, combined with the absence
of our share of losses from Delta Towing in 2004 due to the consolidation of the
joint venture at December 31, 2003 as a result of the adoption of FIN 46.
Offsetting these increases was a decrease in equity in earnings of $2.3 million
related to our consolidation of DD LLC and DDII LLC in 2003, which resulted from
the completion of the buyout of Conoco's share of the joint ventures.
The decrease in interest income was primarily due to a decrease in average
cash balances for 2004 compared to 2003 as cash was utilized for debt reduction
and capital expenditures, which resulted in a reduction of interest income of
$2.3 million. Additional decreases resulted from the absence in 2004 of $1.7
million of interest earned in the second quarter of 2003 on the notes receivable
from Delta Towing, which was consolidated at December 31, 2003 as a result of
the adoption of FIN 46.
The decrease in interest expense was attributable to reductions in interest
expense of $11.5 million associated with debt that was redeemed, retired or
repurchased during or subsequent to the second quarter of 2003. Partially
offsetting this decrease was the issuance of new debt subsequent to the second
quarter of 2003, which resulted in an increase in interest expense of $1.7
million.
During the three months ended June 30, 2003, we recognized a $15.7 million
loss related to the repurchase of $838.6 million aggregate principal amount of
our Zero Coupon Convertible Debentures due May 2020 and the repurchase and
retirement of the $50.0 million principal amount 9.41% Nautilus Class A2 Notes
due May 2005.
During the three months ended June 30, 2003, we recognized a $21.3 million
impairment loss on our note receivable from Delta Towing.
34
We recognized a $2.3 million loss in other, net in the second quarter of
2003 relating to the effect of foreign currency exchange rate changes on our
monetary assets and liabilities denominated in Venezuelan bolivars, partially
offset by proceeds received from the sale of a patent with no comparable
activity for the same period in 2004.
We operate internationally and provide for income taxes based on the tax
laws and rates in the countries in which we operate and earn income. There is no
expected relationship between the provision for income taxes and income before
income taxes. The annual effective tax rate for 2004 is estimated to be
approximately 35 percent of earnings before TODCO IPO-related items, loss on
debt retirements and gains on significant asset sales. The effective tax rate
increased from approximately 27 percent estimated at March 31, 2004 as a result
of developments in the second quarter on certain international tax disputes, an
increase in the valuation allowance established at the time of the TODCO IPO and
changes in the expected amount and geographical concentration of taxable income.
The catch-up effect of the increase in the annual effective tax rate, a
reduction in earnings of $4.6 million, was reflected in the second quarter of
2004 resulting in an effective tax rate of 45 percent on earnings for the three
months ended June 30, 2004, excluding the sale of the semisubmersible rig Sedco
602. The three months ended June 30, 2003 included a foreign tax benefit of
$14.6 million attributable to the favorable resolution of a non-U.S. income tax
liability and income tax benefits resulting from non-cash impairments and loss
on debt retirements. At June 30, 2003, we estimated the annual effective tax
rate for 2003 to be approximately 38 percent of earnings before non-cash note
receivable and other asset impairments and loss on debt retirements. The rate
increased from an estimated annual effective tax rate of approximately 20
percent at March 31, 2003, due to a change in the amount and mix of estimated
earnings for the year. As a result of the catch-up effect of the change in the
annual effective tax rate, earnings for the three months ended June 30, 2003
were reduced by $10.7 million.
The increase in minority interest was primarily attributable to the
minority interest owners' share of TODCO resulting from the IPO.
SIX MONTHS ENDED JUNE 30, 2004 COMPARED TO SIX MONTHS ENDED JUNE 30, 2003
Following is an analysis of our Transocean Drilling segment and TODCO
segment operating results, as well as an analysis of income and expense
categories that we have not allocated to our two segments.
Transocean Drilling Segment
Six Months Ended
June 30,
-----------------------------
2004 2003 Change % Change
--------------- ------------ ------------- ------------
(In millions, except day amounts and percentages)
Operating days 11,731 11,769 (38) N/M
Utilization (a) 68% 68% N/A N/M
Average dayrate (b) $ 89,700 $ 90,300 $ (600) (1)%
Contract drilling revenues $ 1,052.1 $ 1,062.6 $ (10.5) (1)%
Other revenues 78.6 48.6 30.0 62%
--------------- ------------ ------------- ------------
1,130.7 1,111.2 19.5 2%
Operating and maintenance expense 671.3 671.4 (0.1) N/M
Depreciation 216.4 208.0 8.4 4%
Impairment loss on long-lived assets - 5.2 (5.2) N/M
Gain from sale of assets, net (23.0) (1.6) (21.4) N/M
Gain from TODCO initial public offering (39.4) - (39.4) N/M
--------------- ------------ ------------- ------------
Operating income before general and administrative expense $ 305.4 $ 228.2 $ 77.2 34%
=============== ============ ============= ============
_________________
"N/A" means not applicable
35
"N/M" means not meaningful
(a) Utilization is defined as the total actual number of revenue earning days as a percentage of total number of
calendar days in the period.
(b) Average dayrate is defined as contract drilling revenue earned per revenue earning day.
This segment's contract drilling revenues were negatively impacted by
approximately $88.6 million due to a decline in average dayrates and by the
release of a provision of $3.3 million due to a favorable settlement of a
contract dispute related to penalties on the Peregrine I during the first
quarter of 2003 with no comparable benefit for the same period in 2004.
Partially offsetting these decreases were revenues for the full six months in
2004 on the Discoverer Enterprise, which was inactive for the latter part of the
second quarter of 2003 due to a riser separation incident, and revenues from the
consolidation of DDII LLC and DD LLC, which occurred late in the second and
fourth quarters of 2003, respectively. Additionally, a labor strike in Nigeria
and the Peregrine I electrical fire during the second quarter of 2003 negatively
impacted revenues during that period as compared to 2004. These items resulted
in a positive impact of $81.4 million over the prior year.
Other revenues for the six months ended June 30, 2004 included increases of
$37.9 million primarily related to integrated services, partially offset by a
decrease of $8.7 million from client reimbursable revenue and the absence of
revenue from management fees as a result of the consolidation of DDII LLC and DD
LLC late in the second and fourth quarters, respectively, of 2003.
The decrease in this segment's operating and maintenance expenses was
primarily due to approximately $41.7 million related to decreased activity, the
settlement of the Discoverer Enterprise May 2003 riser incident, the favorable
insurance settlement related to the Peregrine I riser incident, a decrease in
insurance expense and the favorable settlement of a turnkey dispute during 2004.
Additional decreases of approximately $4.8 million resulted from costs incurred
in 2003 related to the Peregrine I electrical fire and the Nigeria labor strike
with no comparable activity in 2004. Largely offsetting these decreases were
increased operating and maintenance expenses of approximately $39.8 million
related primarily to higher integrated services activity, the Deepwater Frontier
and Deepwater Pathfinder as a result of the consolidation of DDII LLC and DD LLC
late in the second and fourth quarters, respectively, of 2003, a loss on
retirement and higher provisions for local tax matters in 2004. Additional
increases of approximately $6.7 million resulted from favorable litigation and
turnkey settlements during 2003 with no comparable activity during 2004.
The increase in this segment's depreciation expense resulted primarily from
$6.5 million of additional depreciation expense related to the Deepwater
Frontier and Deepwater Pathfinder as a result of the late December 2003 payoff
of the synthetic lease financing arrangements by DDII LLC and DD LLC,
respectively, which were consolidated late in the second and fourth quarters,
respectively, of 2003.
During the six months ended June 30, 2003, we recorded non-cash impairment
charges in this segment of $5.2 million associated with the removal of two rigs
from drilling service and the value assigned to leases on oil and gas properties
that we intended to discontinue. The determination of fair market value was
based on an offer from a potential buyer, in the case of the two rigs, and
management's assessment of fair value, in the case of the leases on oil and gas
properties, where third party valuations were not available.
During the six months ended June 30, 2004, this segment recognized net
gains of $23.0 million related to the sale of the semisubmersible rig Sedco 602
and the sale of other assets. During the six months ended June 30, 2003, this
segment recognized net gains of $1.6 million related to the sale of the jackup
rig RBF 160, the settlement of an insurance claim and the sale of other assets.
36
TODCO Segment
Six Months Ended
June 30,
-----------------------------
2004 2003 Change % Change
--------------- ------------ ------------- ------------
(In millions, except day amounts and percentages)
Operating days 5,026 5,541 (515) (9)%
Utilization (a) 39% 40% N/A N/M
Average dayrate (b) $ 25,900 $ 18,000 $ 7,900 44%
Contract drilling revenues $ 130.3 $ 99.6 $ 0.7 31%
Other revenues 24.2 9.1 15.1 N/M
--------------- ------------ ------------- ------------
154.5 108.7 45.8 42%
Operating and maintenance 147.3 129.2 18.1 14%
Depreciation 48.1 46.3 1.8 4%
Impairment loss on long-lived assets - 11.6 (11.6) N/M
Gain from sale of assets, net (4.6) (0.4) (4.2) N/M
--------------- ------------ ------------- ------------
Operating loss before general and administrative expense $ (36.3) $ (78.0) $ 41.7 (53)%
=============== ============ ============= ============
_________________
"N/A" means not applicable
"N/M" means not meaningful
(a) Utilization is defined as the total actual number of revenue earning days as a percentage of total number of
calendar days in the period.
(b) Average dayrate is defined as contract drilling revenue earned per revenue earning day.
This segment's contract drilling revenues increased by approximately $24.4
million due to an increase in average dayrates, partially offset by decreased
utilization of approximately $10.9 million. Additional increases of
approximately $17.3 million resulted from increased average dayrates and
utilization related to operations of three jackup rigs in Venezuela (THE 156)
and Mexico (THE 205 and THE 206) after being transferred from the Gulf of Mexico
during the fourth quarter of 2003.
Other revenues for the six months ended June 30, 2004 included increases of
approximately $15.1 million related to the consolidation of Delta Towing at
December 31, 2003 and client reimbursable revenue.
The increase in this segment's operating and maintenance expense was
primarily due to approximately $11.9 million of costs associated with the
consolidation of Delta Towing at December 31, 2003, $9.4 million of operating
and maintenance expense related to the operations of three jackup rigs in
Venezuela (THE 156) and Mexico (THE 205 and THE 206) after being transferred
from the Gulf of Mexico and $9.4 million of higher compensation expense related
to stock option and restricted stock grants as the result of the TODCO IPO.
Partially offsetting the above increases were decreases primarily due to
approximately $11.8 million of costs associated with the well control incident
on inland barge Rig 62 during 2003 and a decrease in insurance expense.
The increase in this segment's depreciation expense resulted primarily from
$2.6 million of additional depreciation expense related to the consolidation of
Delta Towing, partially offset by a reduction in depreciation resulting from the
write down to fair market value of five jackup rigs removed from active drilling
service in 2003.
During the six months ended June 30, 2003, we recorded non-cash impairment
charges in this segment of $11.6 million associated with the removal of five
jackup rigs from drilling service and the write down in the value of an
investment in a joint venture to fair value. The determination of fair market
value was based on third party valuations, in the case of the jackup rigs, and
management's assessment of fair value, in the case of the investment in a joint
venture, where third party valuations were not available.
37
During the six months ended June 30, 2004, this segment recognized net
gains of $4.6 million primarily related to the sale of four marine support
vessels by Delta Towing, as well as the sale of other assets and the settlement
of an October 2000 insurance claim for one of our jackup rigs.
Total Company Results of Operations
Six Months Ended
June 30,
-----------------------
2004 2003 Change % Change
---------- ----------- -------- ---------
(In millions, except % change)
General and Administrative Expense $ 29.1 $ 28.8 $ 0.3 1%
Other (Income) Expense, net
Equity in earnings of joint ventures (6.0) (5.4) (0.6) 11%
Interest income (4.0) (12.7) 8.7 69%
Interest expense 90.0 105.4 (15.4) (15)%
Loss on retirement of debt 28.1 15.7 12.4 79%
Impairment loss on note receivable from related party - 21.3 (21.3) N/M
Other, net (0.3) 3.3 (3.6) N/M
Income Tax Expense (Benefit) 67.9 (9.0) 76.9 N/M
Minority Interest (6.4) 0.1 (6.5) N/M
_________________________
"N/M" means not meaningful
The increase in general and administrative expense was primarily
attributable to costs related to compliance with corporate governance
regulations effective for 2004.
Equity in earnings of joint ventures increased approximately $6.1 million
primarily related to our 50 percent share of earnings from Overseas Drilling
Limited, which owns the drillship Joides Resolution, combined with the absence
of our share of losses from Delta Towing in the six months ended June 30, 2003
due to the consolidation of the joint venture at December 31, 2003 as a result
of the adoption of FIN 46. Offsetting these increases was a decrease in equity
in earnings of $5.6 million related to our consolidation of DD LLC and DDII LLC
in 2003, which resulted from the completion of the buyout of ConocoPhillips'
share of the joint ventures.
The decrease in interest income was primarily related to a decrease in
average cash balances for 2004 compared to 2003 as cash was utilized for debt
reduction and capital expenditures, which resulted in a reduction of interest
income of $5.0 million. Additional decreases resulted from the absence in 2004
of $3.3 million of interest earned in 2003 on the notes receivable from Delta
Towing, which was consolidated at December 31, 2003 as a result of the adoption
of FIN 46.
The decrease in interest expense was attributable to reductions in interest
expense of $24.5 million associated with debt that was redeemed, retired or
repurchased during or subsequent to the six months ended June 30, 2003.
Partially offsetting these decreases was the termination of our fixed to
floating interest rate swaps in the first quarter of 2003, which resulted in a
net increase in interest expense of $4.8 million (see "-Derivative Instruments")
and the issuance of new debt subsequent to the six months ended June 30, 2003,
which resulted in an increase in interest expense of $3.6 million. In addition,
we received a refund of interest from a taxing authority that resulted in a
reduction of interest expense of $0.8 million in the six months ended June 30,
2003, with no comparable activity for the same period in 2004.
During the six months ended June 30, 2004, we recognized a $28.1 million
loss related to the redemption of $289.8 million principal amount outstanding
9.5% Senior Notes due December 2008 (see "-Significant Events"). During the six
months ended June 30, 2003, we recognized a $15.7 million loss related to the
repurchase of $838.6
38
million aggregate principal amount of our Zero Coupon Convertible Debentures due
May 2020 and the repurchase and retirement of the $50.0 million principal amount
9.41% Nautilus Class A2 Notes due May 2005.
During the six months ended June 30, 2003, we recognized a $21.3 million
impairment loss on our notes receivable from Delta Towing.
We recognized a $3.3 million favorable change in other, net relating to the
effect of foreign currency exchange rate changes on our monetary assets and
liabilities denominated in non-U.S. currencies, partially offset by proceeds
received from the sale of a patent with no comparable activity for the same
period in 2004.
We operate internationally and provide for income taxes based on the tax
laws and rates in the countries in which we operate and earn income. There is no
expected relationship between the provision for income taxes and income before
income taxes. During the six months ended June 30, 2004, we recorded a valuation
allowance of approximately $31.0 million related to the TODCO IPO (see
"-Significant Events"). The six months ended June 30, 2003 included a foreign
tax benefit of $14.6 million attributable to the favorable resolution of a
non-U.S. income tax liability and income tax benefits resulting from non-cash
impairments and loss on debt retirements, partially offset by an increase in the
estimated annual effective tax rate for the six months ended June 30, 2003. The
annual effective tax rate was estimated to be approximately 35 percent during
2004 on earnings before TODCO IPO-related items, loss on debt retirements and
gains on significant asset sales compared to approximately 38 percent during
2003 on earnings before non-cash note receivable and other asset impairments and
loss on debt retirements.
The increase in minority interest was primarily attributable to the
minority interest owners' share of TODCO resulting from the IPO.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
Our discussion and analysis of our financial condition and results of
operations are based upon our condensed consolidated financial statements. This
discussion should be read in conjunction with disclosures included in the notes
to our condensed consolidated financial statements related to estimates,
contingencies and new accounting pronouncements. Significant accounting policies
are discussed in Note 2 to our condensed consolidated financial statements
included elsewhere and in Note 2 to our consolidated financial statements in our
Annual Report on Form 10-K for the year ended December 31, 2003. The preparation
of these financial statements requires us to make estimates and judgments that
affect the reported amounts of assets, liabilities, revenues, expenses and
related disclosure of contingent assets and liabilities. On an on-going basis,
we evaluate our estimates, including those related to bad debts, materials and
supplies obsolescence, investments, property and equipment, intangible assets
and goodwill, income taxes, workers' insurance, pensions and other
post-retirement and employment benefits and contingent liabilities. We base our
estimates on historical experience and on various other assumptions that are
believed to be reasonable under the circumstances, the results of which form the
basis for making judgments about the carrying values of assets and liabilities
that are not readily apparent from other sources. Actual results may differ from
these estimates under different assumptions or conditions.
For a discussion of the critical accounting policies and estimates that we
use in the preparation of our condensed consolidated financial statements, see
"Item 7. Management's Discussion and Analysis of Financial Condition and Results
of Operations" in our Annual Report on Form 10-K for the year ended December 31,
2003. There have been no material changes to these policies during the six
months ended June 30, 2004. These policies require significant judgments and
estimates used in the preparation of our consolidated financial statements.
Management has discussed each of these critical accounting policies and
estimates with the Audit Committee of the Board of Directors.
RETIREMENT PLANS AND OTHER POSTEMPLOYMENT BENEFITS
Defined Benefit Pension Plans - We have several defined benefit pension
plans, both funded and unfunded, covering substantially all U.S. employees
except for TODCO employees. We also have several defined benefit plans,
39
both funded and unfunded, that cover Norway employees, Nigeria employees, and
various current and former employees covered under certain frozen plans acquired
in connection with the R&B Falcon merger.
For the funded plans, our funding policy consists of reviewing the funded
status of these plans annually and contributing an amount at least equal to the
minimum contribution required under the Employee Retirement Income Security Act
of 1974 (ERISA) or other applicable funding regulations. Employer contributions
to the funded plan are based on actuarial computations that establish the
minimum contribution required under ERISA and the maximum deductible
contribution for income tax purposes.
We expect to contribute approximately $10.0 million to our defined benefit
pension plans in 2004, which will be funded from our cash flow from operations.
As of June 30, 2004, $1.0 million in contributions have been made to the defined
benefit pension plans.
Postretirement Benefits Other Than Pensions - We have several unfunded
contributory and noncontributory postretirement benefit plans covering
substantially all of our Transocean Drilling segment U.S. employees. Funding of
benefit payments for plan participants will be made as costs are incurred.
In December 2003, the Medicare Prescription Drug, Improvement and
Modernization Act of 2003 (the "Act") was signed into law. The Act introduced a
prescription drug benefit under Medicare (Medicare Part D) as well as a federal
subsidy to sponsors of retiree health care benefit plans that provide a
prescription drug benefit that is at least actuarially equivalent to Medicare
Part D. The Act introduces two new features to Medicare that employers must
consider in determining the effect of the Act on their accumulated
postretirement benefit obligation (''APBO'') and net periodic post retirement
benefit cost: (i) a subsidy based on 28 percent of an individual beneficiary's
annual prescription drug costs between $250 and $5,000, and (ii) the opportunity
for a retiree to obtain a prescription drug benefit under Medicare. In
accordance with SFAS 106, Employers' Accounting for Postretirement Benefits
Other Than Pensions, employers are required to consider presently enacted
changes in relevant laws in current period measurements of postretirement
benefit costs and the APBO. As a result, the APBO and net periodic
postretirement benefit costs for future periods should reflect the effects of
the Act. At present, detailed regulation necessary to implement the Act have not
been issued, including those that would specify the manner in which actuarial
equivalency must be determined, the evidence required to demonstrate actuarial
equivalency and the documentation requirements necessary to be entitled to the
subsidy.
In May 2004, the FASB staff issued FASB Staff Position ("FSP") 106-2,
Accounting and Disclosure Requirements Related to the Medicare Prescription
Drug, Improvement and Modernization Act of 2003. FSP 106-2, which supercedes the
same titled FSP 106-1, considers the effect of the two new features introduced
in the Act in determining our APBO and net periodic post retirement benefit
cost. The effect on the APBO will be accounted for as an actuarial gain to be
amortized into income over the average remaining service period of plan
participants. Companies may elect to defer accounting for this benefit or
attempt to reflect the best estimate of the impact of the Act on their net
periodic costs currently. The FSP is effective for the first interim or annual
period beginning after June 15, 2004. We have chosen to defer accounting for the
benefit and will implement these requirements effective July 1, 2004 using the
prospective method outlined in FSP 106-2. The adoption of these requirements is
not expected to have a material impact on our consolidated financial position or
results of operations. As a result of our election to defer the implementation
of the FSP, our measures of APBO and net periodic postretirement benefit costs
included in the condensed consolidated financial statements herein do not
reflect the effects of the Act.
40
SALE/LEASEBACK TRANSACTION
We lease the drillship M. G. Hulme, Jr. from Deep Sea Investors, L.L.C., a
special purpose entity formed by several leasing companies to acquire the rig
from one of our subsidiaries in November 1995 in a sale/leaseback transaction.
We are obligated to pay rent of approximately $13 million per year through
November 2005. At the termination of the lease, we may purchase the rig for a
maximum amount of approximately $35.7 million. Effective September 2002, the
lease neither requires that collateral be maintained nor contains any credit
rating triggers.
Effective December 31, 2003, we adopted and applied the provisions of FIN
46, Consolidation of Variable Interest Entities, as revised December 31, 2003,
for all variable interest entities. FIN 46 requires the consolidation of
variable interest entities in which an enterprise absorbs a majority of the
entity's expected losses, receives a majority of the entity's expected residual
returns, or both, as a result of ownership, contractual or other financial
interests in the entity. Because the sale/leaseback agreement is with an entity
in which we have no direct investment, we are not entitled to receive the
financial statements of the leasing entity and the equity holders of the leasing
company will not release the financial statements or other financial information
to us in order for us to make the determination of whether the entity is a
variable interest entity. In addition, without the financial statements, we are
unable to determine if we are the primary beneficiary of the entity and, if so,
what we would consolidate. We have no exposure to loss as a result of the
sale/leaseback agreement. We currently account for the lease of this
semisubmersible drilling rig as an operating lease.
NEW ACCOUNTING PRONOUNCEMENTS
In April 2004, the FASB issued FSP 129-1, Disclosure of Information about
Capital Structure, Relating to Contingently Convertible Securities, which
applies to all contingently convertible securities and became effective the date
of issue. The FSP requires disclosure of the nature of the contingency and the
potential impact of conversion on the financial statements, particularly the
impact on earnings per share, and whether the securities have been included in
the entity's calculation of diluted earnings per share. The implementation of
this FSP did not have an effect on our condensed consolidated financial
statements and related notes thereto as our disclosures are in accordance with
the disclosure requirements as stated in this FSP.
FORWARD-LOOKING INFORMATION
The statements included in this quarterly report regarding future financial
performance and results of operations and other statements 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. Statements to the effect that we or management "anticipates,"
"believes," "budgets," "estimates," "expects," "forecasts," "intends," "plans,"
"predicts," or "projects" a particular result or course of events, or that such
result or course of events "could," "might," "may," "scheduled" or "should"
occur, and similar expressions, are also intended to identify forward-looking
statements. Forward-looking statements in this quarterly report include, but are
not limited to, statements involving contract commencements, revenues, expenses,
commodity prices, customer drilling programs, supply and demand, utilization
rates, dayrates, planned shipyard projects and rig mobilizations, expected
downtime, future activity in the deepwater, mid-water and the shallow and inland
water market segments, market outlook for our various geographical operating
sectors, rig classes and business segments, plans to dispose of our remaining
interest in TODCO, the valuation allowance for deferred net tax assets of TODCO,
intended reduction of debt, planned asset sales, timing of asset sales,
including the Sedco 600, proceeds from asset sales, the effect and duration of
the Norway strike, the effect of the Trident 20 fire, our effective tax rate,
the purchase of the M.G. Hulme, Jr., changes in tax laws, treaties and
regulations, our other expectations with regard to market outlook, operations in
international markets, expected capital expenditures, results and effects of
legal proceedings and governmental audits and assessments, adequacy of
insurance, liabilities for tax issues, liquidity, cash flow from operations,
adequacy of cash flow for our obligations, effects of accounting changes,
pension plan contributions and the timing and cost of completion of capital
projects. Such statements are subject to numerous risks, uncertainties and
assumptions, including, but not limited to, those described in "Item 7.
Management's Discussion and Analysis of Financial Condition and Results of
Operations Risk Factors" included in our Annual Report on Form 10-K for the year
ended December 31, 2003, the adequacy of sources of liquidity, the effect and
results of litigation, audits and contingencies and other factors discussed in
this annual report
41
and in our other filings with the SEC, which are available free of charge on the
SEC's 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. All subsequent written and oral
forward-looking statements attributable to us or to persons acting on our behalf
are expressly qualified in their entirety by reference to these risks and
uncertainties. You should not 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.
42
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
INTEREST RATE RISK
Our exposure to market risk for changes in interest rates relates primarily
to our long-term and short-term debt obligations. The table below presents
scheduled debt maturities and related weighted-average interest rates for each
of the 12-month periods ending June 30 relating to debt obligations as of June
30, 2004. Weighted-average variable rates are based on London Interbank Offered
Rate in effect at June 30, 2004, plus applicable margins.
At June 30, 2004 (in millions, except interest rate percentages):
Scheduled Maturity Date (a) (b) Fair Value
-------------------------------------------------------------------- -----------
2005 2006 2007 2008 2009 Thereafter Total 06/30/04
------- ------- ------- -------- ------ ------------ --------- -----------
Total debt
Fixed Rate $392.3 $400.0 $100.0 $ 269.0 $10.2 $ 1,750.0 $2,921.5 $ 3,178.8
Average interest rate 6.8% 1.5% 7.5% 6.7% 9.5% 7.2% 6.3%
Variable Rate $ - $ - $ - $ - $50.0 $ - $ 50.0 $ 50.0
Average interest rate - - - - 1.7% - 1.7%
__________________________
(a) Maturity dates of the face value of our debt assume the put options on 1.5% Convertible Debentures,
7.45% Notes and the Zero Coupon Convertible Debentures will be exercised in May 2006, April 2007 and May
2008, respectively.
(b) Expected maturity amounts are based on the face value of debt.
At June 30, 2004, we had approximately $50.0 million of variable rate debt
at face value (approximately 1.7 percent of total debt at face value). This
variable rate debt represented revolving credit bank debt. Given outstanding
amounts as of that date, a one percent rise in interest rates would result in an
additional $0.4 million in interest expense per year. Offsetting this, a large
part of our cash investments would earn commensurately higher rates of return.
Using June 30, 2004 cash investment levels, a one percent increase in interest
rates would result in approximately $2.4 million of additional interest income
per year.
FOREIGN EXCHANGE RISK
Our international operations expose us to foreign exchange risk. We use a
variety of techniques to minimize the exposure to foreign exchange risk. Our
primary foreign exchange risk management strategy involves structuring customer
contracts to provide for payment in both U.S. dollars, which is our functional
currency, and local currency. The payment portion denominated in local currency
is based on anticipated local currency requirements over the contract term. Due
to various factors, including local banking laws, other statutory requirements,
local currency convertibility and the impact of inflation on local costs, actual
foreign exchange needs may vary from those anticipated in the customer
contracts, resulting in partial exposure to foreign exchange risk. Fluctuations
in foreign currencies typically have not had a material impact on overall
results. In situations where payments of local currency do not equal local
currency requirements, foreign exchange derivative instruments, specifically
foreign exchange forward contracts or spot purchases, may be used to mitigate
foreign currency risk. We do not enter into derivative transactions for
speculative purposes. At June 30, 2004, we had no open foreign exchange
derivative contracts.
43
ITEM 4. CONTROLS AND PROCEDURES
In accordance with Exchange Act Rules 13a-15 and 15d-15, we carried out an
evaluation, under the supervision and with the participation of management,
including our Chief Executive Officer and Chief Financial Officer, of the
effectiveness of our disclosure controls and procedures as of the end of the
period covered by this report. Based on that evaluation, our Chief Executive
Officer and Chief Financial Officer concluded that our disclosure controls and
procedures were effective as of June 30, 2004 to provide reasonable assurance
that information required to be disclosed in our reports filed or submitted
under the Exchange Act is recorded, processed, summarized and reported within
the time periods specified in the Securities and Exchange Commission's rules and
forms.
There has been no change in our internal controls over financial reporting
that occurred during the three months ended June 30, 2004 that has materially
affected, or is reasonably likely to materially affect, our internal controls
over financial reporting.
44
PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
We have certain actions or claims pending that have been previously
discussed and reported in our Annual Report on Form 10-K for the year ended
December 31, 2003 and our other reports filed with the Securities and Exchange
Commission. There have been no material developments in these previously
reported matters. We are involved in a number of other lawsuits, all of which
have arisen in the ordinary course of our business. We do not believe that
ultimate liability, if any, resulting from any such other pending litigation
will have a material adverse effect on our business or consolidated financial
position. We cannot predict with certainty the outcome or effect of any of the
litigation matters specifically described above or of any such other pending
litigation. There can be no assurance that our beliefs or expectations as to the
outcome or effect of any lawsuit or other litigation matter will prove correct
and the eventual outcome of these matters could materially differ from
management's current estimates.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
At the Annual General Meeting of Transocean Inc. held on May 13, 2004,
275,561,965 shares were represented in person or by proxy out of 320,751,973
shares outstanding and entitled to vote as of the record date, constituting a
quorum. The matters submitted to a vote of shareholders, as set forth in the
Company's Proxy Statement relating to the meeting, and the corresponding voting
results were as follows:
(i) With respect to the election of Class II Director nominees as set forth in
the Company's Proxy Statement relating to the meeting, the following number
of votes were cast:
NAME OF NOMINEE FOR WITHHELD/
CLASS II DIRECTOR FOR ABSTAIN
-------------------------------------------
Robert L. Long 268,544,067 7,017,898
Martin B. McNamara 270,326,740 5,235,225
Robert M. Sprague 270,263,399 5,298,566
J. Michael Talbert 267,857,741 7,704,224
(ii) With respect to the amendment of the Company's Long-Term Incentive Plan to
increase the number of ordinary shares reserved for issuance to employees
under the plan from 18,900,000 to 22,900,000, increase the number of
ordinary shares that may be issued to employees under the plan as
restricted shares or deferred units from 2,000,000 to 6,000,000, provide
for the award of deferred units, replace automatic awards to outside
directors with discretionary awards that are determined by our board,
restate the performance criteria specified in the plan for certain types of
awards, allow net share counting in determining the number of shares
available for issuance under the plan and modify other provisions of the
plan as described in the Proxy Statement, the following number of votes
were cast:
AGAINST/ EXCEPTIONS/ BROKER
FOR AUTHORITY WITHHELD ABSTAIN NON-VOTES
--------------------------------------------------------
211,304,002 15,726,837 1,743,430 46,787,696
(iii) With respect to the approval of the Company's appointment of Ernst & Young
LLP as independent auditors for 2004, the following number of votes were
cast:
AGAINST/ EXCEPTIONS/ BROKER
FOR AUTHORITY WITHHELD ABSTAIN NON-VOTES
-------------------------------------------------------
270,643,296 3,460,435 1,458,234 -
ITEM 5. OTHER INFORMATION
We hired William G. Henderson effective as of June 14, 2004 to be our Vice
President and Controller.
45
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
The following exhibits are filed in connection with this Report:
NUMBER DESCRIPTION
- ------ -----------
*3.1 Memorandum of Association of Transocean Inc., as amended (incorporated by reference to Annex E
to the Joint Proxy Statement/Prospectus dated October 30, 2000 included in a 424(b)(3) prospectus
filed by us on November 1, 2000)
*3.2 Articles of Association of Transocean Inc., as amended (incorporated by reference to Annex F to the
Joint Proxy Statement/Prospectus dated October 30, 2000 included in a 424(b)(3) prospectus filed by
us on November 1, 2000)
*3.3 Certificate of Incorporation on Change of Name to Transocean Inc. (incorporated by reference to
Exhibit 3.3 to our Form 10-Q for the quarter ended June 30, 2002)
*10.1 Long-Term Incentive Plan of Transocean Inc. (as Amended and Restated Effective February 12, 2004)
(incorporated by reference to Appendix B to the Proxy Statement dated March 19, 2004 filed by us on
March 19, 2004)
**31.1 CEO Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
**31.2 CFO Certification Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
**32.1 CEO Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
**32.2 CFO Certification Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
_________________________
* Incorporated by reference as indicated.
** Filed herewith.
(b) Reports on Form 8-K
We filed a Current Report on Form 8-K on April 27, 2004 (information
furnished not filed) announcing the issuance of the first quarter 2004 financial
results, a Current Report on Form 8-K on April 27, 2004 (information furnished
not filed) announcing our "Monthly Fleet Update" report as of April 27, 2004, a
Current Report on Form 8-K on May 28, 2004 (information furnished not filed)
announcing our "Monthly Fleet Update" report as of May 28, 2004, a Current
Report on Form 8-K on June 1, 2004 (information furnished not filed) announcing
updates to operating revenues, utilization and average dayrates for each quarter
of 2003 from that previously reported by rig category in the case of our
business segments and a Current Report on Form 8-K on June 30, 2004 (information
furnished not filed) announcing our "Monthly Fleet Update" report as of June 30,
2004.
46
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) 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, on August 6, 2004.
TRANSOCEAN INC.
By: /s/ Gregory L. Cauthen
--------------------------
Gregory L. Cauthen
Senior Vice President and Chief Financial Officer
(Principal Financial Officer)
By: /s/ William G. Henderson
--------------------------
William G. Henderson
Vice President and Controller
(Principal Accounting Officer)
47