Form 8-K

 

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

Date of Report (Date of earliest event reported): November 5, 2008 (November 5, 2008)

TRANSOCEAN INC.

(Exact name of registrant as specified in its charter)

 

Cayman Islands   333-75899   66-0582307

(State or other jurisdiction of

incorporation or organization)

 

(Commission

File Number)

 

(I.R.S. Employer

Identification No.)

 

4 Greenway Plaza  
Houston, Texas   77046
(Address of principal executive offices)   (zip code)

 

70 Harbour Drive  
Grand Cayman, Cayman Islands   KY1-1003
(Address of principal executive offices)   (zip code)

Registrant’s telephone number, including area code: (713) 232-7500

 

(Former name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

 

  ¨ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

 

  ¨ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

 

  ¨ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

 

  ¨ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

 

 

 


Item 2.02. Results of Operations and Financial Condition.

Our news release dated November 5, 2008, concerning third quarter 2008 financial results, furnished as Exhibit 99.1 to this report, is incorporated by reference herein. The press release contains certain measures (discussed below) which may be deemed “non-GAAP financial measures” as defined in Item 10 of Regulation S-K of the Securities Exchange Act of 1934, as amended.

In the press release, we present field operating income for the three months ended September 30, 2008, June 30, 2008 and September 30, 2007 and for the nine months ended September 30, 2008, and September 30, 2007. Management believes field operating income is a useful measure of operating results since the measure only deducts expenses directly related to operations from revenues. The most directly comparable GAAP financial measure, operating income before general and administrative expenses, and information reconciling the GAAP and non-GAAP measures are included in the press release.

 

Item 7.01. Regulation FD Disclosure.

Slide Presentation

On November 5, 2008, we are posting the slide presentation furnished as Exhibit 99.2 to this report on our website at www.deepwater.com. Exhibit 99.2 is incorporated in this Item 7.01 by reference.

Statements contained within the slide presentation that are not historical facts are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements include, but are not limited to projections relating to out-of-service forecasts, operating and maintenance costs trends, contract backlog, and other statements that are not historical facts. Such statements are subject to numerous risks, uncertainties and assumptions, including but not limited to, uncertainties relating to the level of activity in offshore oil and gas exploration and development, exploration success by producers, oil and gas prices, rig demand and capacity, drilling industry market conditions, possible delays or cancellation of drilling contracts, work stoppages, operational or other downtime, the Company’s ability to enter into and the terms of future contracts, the availability of qualified personnel, labor relations, future financial results, operating hazards, political and other uncertainties inherent in non-U.S. operations (including exchange and currency fluctuations), war, terrorism, natural disaster and cancellation or unavailability of insurance coverage, the impact of governmental laws and regulations, the adequacy of sources of liquidity, the effect of litigation and contingencies and other factors discussed in the Company’s Form 10-K for the year ended December 31, 2007, and in the Company’s other filings with the Securities and Exchange Commission (“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. We caution investors not to place undue reliance on forward-looking statements. Each forward-looking statement speaks only as of the date of the particular statement, and we undertake no obligation to publicly update or revise any forward-looking statements, except as required by law.


Item 9.01. Financial Statements and Exhibits

(d) Exhibits.

The exhibits to this report furnished pursuant to items 2.02 and 7.01 are as follows:

 

Exhibit No.

  

Description

99.1    Transocean Inc. Release Reporting Third Quarter 2008 Financial Results
99.2    Slide Presentation

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

 

    TRANSOCEAN INC.
Date: November 5, 2008     By   /s/ Eric B. Brown
      Eric B. Brown
     

Senior Vice President and

General Counsel


Index to Exhibits

 

Exhibit
Number

  

Description

99.1    Transocean Inc. Release Reporting Third Quarter 2008 Financial Results
99.2    Slide Presentation
Press Release

Exhibit 99.1

 

          
LOGO      

Transocean Inc.

Post Office Box 2765

Houston TX 77252 2765

                
Analyst Contact:    Gregory S. Panagos

713-232-7551

     

News Release

Media Contact:    Guy A. Cantwell

713-232-7647

      FOR RELEASE: November 5, 2008

TRANSOCEAN INC. REPORTS

THIRD QUARTER 2008 FINANCIAL RESULTS

HOUSTON – Transocean Inc. (NYSE: RIG) today reported net income for the three months ended September 30, 2008 of $1.106 billion, or $3.44 per diluted share, compared to net income of $973 million, or $4.63 per diluted share for the three months ended September 30, 2007. Revenues for the third quarter of 2008 were $3.192 billion compared to $1.538 billion for the third quarter of 2007.

For the nine months ended September 30, 2008, net income totaled $3.402 billion, or $10.59 per diluted share, on revenues of $9.404 billion. For the same period in 2007, net income totaled $2.075 billion, or $9.87 per diluted share, on revenues of $4.300 billion. Net income for the nine months ended September 30, 2008 included after-tax charges of $16 million, or $0.05 per diluted share, resulting primarily from a $14 million loss on short-term investments, $10 million of discrete tax items, $3 million of merger-related costs and a $3 million loss from the early retirement of debt. These charges were offset by income of $14 million from the TODCO tax sharing agreement. For the same period last year, net income included after-tax gains of $369 million, or $1.75 per diluted share, from the TODCO tax sharing agreement, rig sales and discrete tax items.

On November 27, 2007, Transocean Inc. merged with GlobalSantaFe Corporation and reclassified its ordinary shares into cash and shares (the “Reclassification”). Reported results for the third quarter and first nine months of 2008 include a full three and nine months, respectively, from GlobalSantaFe’s operations. Diluted earnings per share for the third quarter and first nine months of 2007 exclude GlobalSantaFe’s operations and are based on a weighted average diluted share count of 210 million and 211 million shares, respectively, which includes the effect of restating the historical diluted share count for the Reclassification.

Operations Quarterly Review

Revenues for the three months ended September 30, 2008 were $3.192 billion compared to revenues of $3.102 billion during the three months ended June 30, 2008. The $90 million quarter-to-quarter increase in total revenues included $112 million of higher contract drilling revenues reflecting a decrease in out-of-service time for planned shipyards, an increase in average dayrates and a $25 million increase in other revenues primarily from increases in integrated services and non-drilling activities. A $47 million decline in contract drilling intangible revenues partially offset these increases. The average dayrate for the fleet increased two percent from $238,600 in the second quarter to $242,200 in the third quarter, primarily as a result of rigs commencing new contracts at higher dayrates in the third quarter.

Operating and maintenance expenses for the three months ended September 30, 2008 were $1.426 billion compared to $1.364 billion for the prior three-month period. The $62 million increase in operating and maintenance expenses primarily reflects estimated expenses of $44 million related to dropped riser and an increase in maintenance and non-drilling and integrated services costs compared to the second quarter of 2008, partially offset by reduced shipyard costs.


Interest Expense and Liquidity

Interest expense, net of amounts capitalized, for the third quarter of 2008 decreased to $100 million compared to $111 million for the second quarter of 2008. The decrease resulted primarily from a quarter-to-quarter reduction in total debt of approximately $496 million. As of September 30, 2008, total debt was $14.783 billion compared to $15.279 billion as of June 30, 2008.

Cash flow from operating activities totaled $1.270 billion for the third quarter of 2008 compared to $1.011 billion for the second quarter of 2008. Higher quarter-to-quarter cash flow during the third quarter primarily reflects increases in net income, decreases in deferred expenses and deferred taxes, partially offset by an increase in working capital.

Effective Tax Rate

The Annual Effective Tax Rate(1) for each of the third quarter and first nine months of 2008 was 15.1 percent and 13.3 percent, respectively. The Effective Tax Rate(2) for first nine months of 2008 was 13.6 percent, which reflects the impact of various discrete tax items totaling $7 million, primarily related to changes in estimates. The Effective Tax Rate(2) for the third quarter of 2008 was 13.7 percent.

Conference Call Information

Transocean will conduct a teleconference call at 10:00 a.m. Eastern Time on November 5, 2008. To participate, dial 913-981-5568 and refer to confirmation code 7057401 approximately five to 10 minutes prior to the scheduled start time of the call.

In addition, the conference call will be simultaneously broadcast over the Internet in a listen-only mode and can be accessed by logging onto the company’s website at www.deepwater.com and selecting “Investor Relations/News & Events/Webcasts & Presentations.” A file containing four charts to be discussed during the conference call, titled “3Q08 Charts,” has been posted to the company’s website and can also be found by selecting “Investor Relations/News & Events/Webcasts & Presentations.” The conference call may also be accessed via the Internet at www.CompanyBoardroom.com by typing in the company’s New York Stock Exchange trading symbol, “RIG.”

A telephonic replay of the conference call should be available after 1:00 p.m. Eastern Time on November 5, 2008 and can be accessed by dialing 719-457-0820 and referring to the passcode 7057401. Also, a replay will be available through the Internet and can be accessed by visiting either of the above-referenced Worldwide Web addresses.

Transocean Inc. is the world’s largest offshore drilling contractor and the leading provider of drilling management services worldwide. With a fleet of 136 mobile offshore drilling units plus 10 announced ultra-deepwater newbuild units, the company’s fleet is considered one of the most modern and versatile in the world due to its emphasis on technically demanding segments of the offshore drilling business. The company owns or operates a contract drilling fleet of 39 High-Specification Floaters (Ultra-Deepwater, Deepwater and Harsh-Environment semisubmersibles and drillships), 29 Midwater Floaters, 10 High-Specification Jackups, 54 Standard Jackups and other assets utilized in the support of offshore drilling activities worldwide.

 

(1)

Annual Effective Tax Rate is defined as income tax expense excluding various discrete items (such as changes in estimates and tax on items excluded from income before income taxes) divided by income before income taxes excluding gains on sales and similar items pursuant to Financial Accounting Standards Board Interpretation No. 18. See the accompanying schedule entitled “Supplemental Effective Tax Rate Analysis.”

(2)

Effective Tax Rate is defined as income tax expense divided by income before income taxes. See the accompanying schedule entitled “Supplemental Effective Tax Rate Analysis.”

 

  ###   08-47


TRANSOCEAN INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(In millions, except per share data)

(Unaudited)

 

     Three months ended
September 30,
    Nine months ended
September 30,
 
     2008     2007     2008     2007  

Operating revenues

        

Contract drilling revenues

   $ 2,699     $ 1,455     $ 7,926     $ 4,088  

Contract drilling intangible revenues

     143       —         557       —    

Other revenues

     350       83       921       212  
                                
     3,192       1,538       9,404       4,300  
                                

Costs and expenses

        

Operating and maintenance

     1,426       663       3,947       1,858  

Depreciation, depletion and amortization

     336       103       1,040       304  

General and administrative

     46       27       140       82  
                                
     1,808       793       5,127       2,244  
                                

Gain (loss) from disposal of assets, net

     (1 )     8       (4 )     30  
                                

Operating income

     1,383       753       4,273       2,086  
                                

Other income (expense), net

        

Interest income

     7       7       30       17  

Interest expense, net of amounts capitalized

     (100 )     (23 )     (348 )     (93 )

Other, net

     (12 )     287       (23 )     295  
                                
     (105 )     271       (341 )     219  
                                

Income before income taxes and minority interest

     1,278       1,024       3,932       2,305  

Income tax expense

     175       52       533       230  

Minority interest

     (3 )     (1 )     (3 )     —    
                                

Net income

   $ 1,106     $ 973     $ 3,402     $ 2,075  
                                

Earnings per share

        

Basic

   $ 3.47     $ 4.80     $ 10.69     $ 10.25  

Diluted

   $ 3.44     $ 4.63     $ 10.59     $ 9.87  
                                

Weighted average shares outstanding

        

Basic

     319       203       318       202  

Diluted

     321       210       321       211  
                                


TRANSOCEAN INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In millions, except share data)

 

     September 30,
2008
    December 31,
2007
 
     (Unaudited)        

ASSETS

    

Cash and cash equivalents

   $ 829     $ 1,241  

Short-term investments

     392       —    

Accounts receivable, net of allowance for doubtful accounts of $65 and $50 at September 30, 2008 and December 31, 2007, respectively

     2,783       2,370  

Materials and supplies, net of allowance for obsolescence of $28 and $22 at September 30, 2008 and December 31, 2007, respectively

     429       333  

Deferred income taxes, net

     55       119  

Assets held for sale

     564       —    

Other current assets

     236       233  
                

Total current assets

     5,288       4,296  
                

Property and equipment

     25,152       24,545  

Less accumulated depreciation

     4,597       3,615  
                

Property and equipment, net

     20,555       20,930  
                

Goodwill

     8,346       8,219  

Other assets

     976       919  
                

Total assets

   $ 35,165     $ 34,364  
                

LIABILITIES AND SHAREHOLDERS’ EQUITY

    

Accounts payable

   $ 934     $ 805  

Accrued income taxes

     234       99  

Debt due within one year

     932       6,172  

Other current liabilities

     853       826  
                

Total current liabilities

     2,953       7,902  
                

Long-term debt

     13,851       11,085  

Deferred income taxes, net

     755       681  

Other long-term liabilities

     1,528       2,125  
                

Total long-term liabilities

     16,134       13,891  
                

Commitments and contingencies

    

Minority interest

     3       5  

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, 319,068,820 and 317,222,909 shares issued and outstanding at September 30, 2008 and December 31, 2007, respectively

     3       3  

Additional paid-in capital

     10,911       10,799  

Accumulated other comprehensive loss

     (46 )     (42 )

Retained earnings

     5,207       1,806  
                

Total shareholders’ equity

     16,075       12,566  
                

Total liabilities and shareholders’ equity

   $ 35,165     $ 34,364  
                


TRANSOCEAN INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In millions)

(Unaudited)

 

     Three months ended
September 30,
    Nine months ended
September 30,
 
     2008     2007     2008     2007  

Cash flows from operating activities

        

Net income

   $ 1,106     $ 973     $ 3,402     $ 2,075  

Adjustments to reconcile net income to net cash provided by operating activities:

        

Amortization of drilling contract intangibles

     (143 )     —         (557 )     —    

Depreciation, depletion and amortization

     336       103       1,040       304  

Share-based compensation expense

     16       11       49       30  

(Gain) loss from disposal of assets, net

     1       (8 )     4       (30 )

Impairment of short-term investments

     16       —         16       —    

Deferred revenue, net

     (3 )     (20 )     22       18  

Deferred expenses, net

     (3 )     (4 )     (132 )     (17 )

Deferred income taxes

     60       9       4       2  

Other, net

     (6 )     2       3       6  

Changes in operating assets and liabilities

     (110 )     (169 )     (88 )     (230 )
                                

Net cash provided by operating activities

     1,270       897       3,763       2,158  
                                

Cash flows from investing activities

        

Capital expenditures

     (514 )     (305 )     (1,703 )     (1,060 )

Proceeds from disposal of assets, net

     5       21       352       62  

Proceeds from sale of investments

     14       —         14       —    

Short-term investments

     (408 )     —         (408 )     —    

Joint ventures and other investments, net

     —         —         (3 )     (3 )
                                

Net cash used in investing activities

     (903 )     (284 )     (1,748 )     (1,001 )
                                

Cash flows from financing activities

        

Borrowings (repayments) under commercial paper program, net

     (213 )     —         932       —    

Borrowings (repayments) under revolving credit facilities, net

     415       —         (1,085 )     —    

Proceeds from debt

     303       —         2,354       —    

Repayments of debt

     (1,000 )     (470 )     (4,673 )     (700 )

Repurchase of ordinary shares

     —         —         —         (400 )

Proceeds from (payments made upon) exercise of warrants, net

     —         16       (4 )     16  

Proceeds from (taxes paid for) issuance of ordinary shares under share-based compensation plans, net

     (12 )     1       49       56  

Excess tax benefit from issuance of ordinary shares under share-based compensation plans

     —         23       11       33  

Other, net

     (7 )     (10 )     (11 )     (11 )
                                

Net cash used in financing activities

     (514 )     (440 )     (2,427 )     (1,006 )
                                

Net increase (decrease) in cash and cash equivalents

     (147 )     173       (412 )     151  

Cash and cash equivalents at beginning of period

     976       445       1,241       467  
                                

Cash and cash equivalents at end of period

   $ 829     $ 618     $ 829     $ 618  
                                


Transocean Inc.

Fleet Operating Statistics

 

     Operating Revenues ($ Millions) (1)  
     Three months ended     Nine months ended
September 30,
 
     September 30,
2008
    June 30,
2008
    September 30,
2007
    2008     2007  

Contract Drilling Revenues

          

High-Specification Floaters:

          

Ultra Deepwater Floaters

   $ 617     $ 558     $ 381     $ 1,783     $ 1,057  

Deepwater Floaters

     323       377       280       1,025       778  

Harsh Environment Floaters

     163       168       122       481       358  

Total High-Specification Floaters

     1,103       1,103       783       3,289       2,193  

Midwater Floaters

     690       650       409       2,015       1,177  

High-Specification Jackups

     144       147       12       448       36  

Standard Jackups

     749       674       236       2,134       637  

Other Rigs

     13       13       15       40       45  

Subtotal

     2,699       2,587       1,455       7,926       4,088  

Contract Intangible Revenue

     143       190       0       557       0  

Other Revenues

          

Client Reimbursable Revenues

     55       51       32       152       91  

Integrated Services and Other

     12       48       51       8       121  

Drilling Management Services

     257       208       0       693       0  

Oil and Gas Properties

     26       18       0       68       0  

Subtotal

     350       325       83       921       212  

Total Company

   $ 3,192     $ 3,102     $ 1,538     $ 9,404     $ 4,300  
     Average Dayrates (1)  
     Three months ended     Nine months ended
September 30,
 
     September 30,
2008
    June 30,
2008
    September 30,
2007
    2008     2007  

High-Specification Floaters:

          

Ultra Deepwater Floaters

   $ 401,300     $ 390,400     $ 323,200     $ 390,700     $ 304,600  

Deepwater Floaters

   $ 322,700     $ 317,400     $ 251,600     $ 307,600     $ 227,400  

Harsh Environment Floaters

   $ 363,500     $ 379,400     $ 312,300     $ 362,400     $ 281,100  

Total High-Specification Floaters

   $ 369,300     $ 360,500     $ 291,900     $ 356,600     $ 268,600  

Midwater Floaters

   $ 292,900     $ 299,300     $ 254,000     $ 294,800     $ 240,100  

High-Specification Jackups

   $ 178,500     $ 178,000     $ 131,600     $ 176,700     $ 131,800  

Standard Jackups

   $ 158,700     $ 149,400     $ 120,000     $ 151,400     $ 113,800  

Other Rigs

   $ 48,900     $ 48,400     $ 54,800     $ 49,000     $ 54,100  

Total Drilling Fleet

   $ 242,200     $ 238,600     $ 219,700     $ 236,500     $ 206,800  
     Utilization (1)  
     Three months ended     Nine months ended
September 30,
 
     September 30,
2008
    June 30,
2008
    September 30,
2007
    2008     2007  

High-Specification Floaters:

          

Ultra Deepwater Floaters

     93 %     87 %     99 %     93 %     98 %

Deepwater Floaters

     68 %     81 %     76 %     76 %     78 %

Harsh Environment Floaters

     98 %     98 %     85 %     97 %     93 %

Total High-Specification Floaters

     83 %     86 %     86 %     86 %     88 %

Midwater Floaters

     88 %     82 %     92 %     86 %     95 %

High-Specification Jackups

     87 %     91 %     100 %     93 %     100 %

Standard Jackups

     93 %     89 %     89 %     92 %     85 %

Other Rigs

     100 %     100 %     98 %     100 %     99 %

Total Drilling Fleet

     89 %     87 %     89 %     89 %     89 %

(1) Average daily revenue is defined as contract drilling revenue earned per revenue earning day in the period. A revenue earning day is defined as a day for which a rig earns dayrate after commencement of operations. Utilization is defined as the total actual number of revenue earning days in the period as a percentage of the total number of calendar days in the period for all drilling rigs in our fleet.


LOGO

Transocean Inc. and Subsidiaries

Supplemental Effective Tax Rate Analysis

(In millions)

 

     Three months ended     Nine months ended     Years ended
Dec. 31,
 
     Sept. 30,
2008
    June 30,
2008
    Sept. 30,
2007
    Sept. 30,
2008
    Sept. 30,
2007
    2007     2006  

Income (Loss) before income taxes and minority interest

   $ 1,278     $ 1,246     $ 1,024     $ 3,932     $ 2,305     $ 3,384     $ 1,607  

Add back (subtract):

              

(Gain) loss on disposal of assets, net

     —         —         (9 )     —         (31 )     (264 )     (410 )

Income from TODCO tax sharing agreement

     (14 )     —         (276 )     (14 )     (276 )     (277 )     (51 )

Loss on The Reserve Funds

     16       —         —         16       —         —         —    

(Gain) loss on retirement of debt

     —         1       —         3       —         8       —    

GSF Merger related costs

     1       3       —         5       —         82       —    
                                                        

Adjusted income before income taxes

     1,281       1,250       739       3,942       1,998       2,933       1,146  

Income tax expense

     175       140       52       533       230       253       222  

Add back (subtract):

              

(Gain) loss on disposal of assets, net

     —         —         —         —         (3 )     (3 )     (24 )

Loss on The Reserve Funds

     2       —         —         2       —         —         —    

GSF Merger related costs

     1       —         —         1       —         15       —    

Changes in estimates (1)

     15       2       52       (10 )     65       101       14  
                                                        

Adjusted income tax expense (2)

   $ 193     $ 142     $ 104     $ 526     $ 292     $ 366     $ 212  
                                                        

Effective Tax Rate (3)

     13.7 %     11.2 %     5.1 %     13.6 %     10.0 %     7.5 %     13.8 %

Annual Effective Tax Rate (4)

     15.1 %     11.4 %     14.0 %     13.3 %     14.6 %     12.5 %     18.5 %

 

(1) Our estimates change as we file tax returns, settle disputes with tax authorities or become aware of other events and include changes in deferred taxes valuation allowances on deferred taxes and other tax liabilities.
(2) The three months ended Sept. 30, 2008 include $21 million of additional tax expense (benefit) reflecting the catch-up effect of an increase (decrease) in the annual effective tax rate from the previous quarter estimate.
(3) Effective Tax Rate is income tax expense divided by income before income taxes.
(4) Annual Effective Tax Rate is income tax expense excluding various discrete items (such as changes in estimates and tax on items excluded from income before income taxes) divided by income before income taxes excluding gains on sales and similar items pursuant to Financial Accounting Standards Board Interpretation No. 18.


LOGO

Transocean Inc. and Subsidiaries

Non-GAAP Financial Measures and Reconciliations

Operating Income Before General and Administrative Expense

to Field Operating Income

(in US$ millions)

 

     Three months ended     Nine months ended  
     September 30,
2008
   June 30,
2008
   September 30,
2007
    September 30,
2008
   September 30,
2007
 

Operating revenue

   $ 3,192    $ 3,102    $ 1,538     $ 9,404    $ 4,300  

Operating and maintenance expense

     1,426      1,364      663       3,947      1,858  

Depreciation, depletion and amortization

     336      337      103       1,040      304  

(Gain) loss from disposal of assets, net

     1      6      (8 )     4      (30 )
                                     

Operating income before general and administrative expense

     1,429      1,395      780       4,413      2,168  

Add back (subtract):

             

Depreciation, depletion and amortization

     336      337      103       1,040      304  

(Gain) loss from disposal of assets, net

     1      6      (8 )     4      (30 )
                                     

Field operating income

   $ 1,766    $ 1,738    $ 875     $ 5,457    $ 2,442  
                                     
Slide Presentation
Transocean
Inc.
Reports
Third
Quarter
2008
Results
Exhibit 99.2


371
382
388
400
318
329
349
337
160
161
160
159
$50k
$100k
$150k
$200k
$250k
$300k
$350k
$400k
$450k
Qtr 4 08
Qtr 1 09
Qtr 2 09
Qtr 3 09
High Specification Floaters
Other Floaters
Jackups
Chart
#1:
Average
Contracted
Dayrate
by
Rig
Type
Qtr
4
2008
through
Qtr
3
2009
(Unaudited)
The
Jackups
category
consists
of
our
jackup
fleet.
Jackups
The
Other
Floaters
category
is
generally
comprised
of
those
non-High-Specification
Floaters
with
a
water
depth
capacity
of
less
than
4,500
feet.
Other
Floaters
The
Other
Deepwater
Floaters
include
the
remaining semi-
submersible
rigs
and
drillships
that
have
a
water
depth
capacity
of
at
least
4,500
feet.
Other
High-Specification
Floaters
were
built
in
the
in
the
mid
to
late
1980s,
are
capable
of
drilling
in
harsh
environments
and
have
greater
displacement
than
previously
constructed
rigs
resulting
in
larger
variable
load
capacity,
more
useable
deck
space
and
better
motion
characteristics.
Ultra-Deepwater
Floaters
have
high-pressure
mud
pumps
and
a
water
depth
capability
of
7,500
feet
or greater.
The
High-Specification
Floaters
category
is
a
consolidation
of
the
Ultra-Deepwater
Floaters,
Other High-
Specification
Floaters
and
Other
Deepwater
Floaters
as
described
below.
High-
Specification
Floaters
The
weighted
average
contract
dayrate
for
each
rig
type
based
on
current
backlog
from
the
company's
most
recent
Fleet
Status
Update
Report
as
of
November
3,
2008.
Includes
firm
contracts
only.
Average Dayrate
Definitions


Chart
#2:
Out-of-Service
Rig
Months
Qtr
1
2008
through
Qtr
4
2009
(Unaudited)
Rig
time
described
as
"shipyard"
refers
to
periods
during
which
a
rig
is
out
of
service
as
a
result
of
other
planned
shipyards,
surveys,
repairs,
regulatory
inspections
or
other
planned
service
or
work
on
the
rig
excluding
reactivations
and upgrades.
Shipyard
Rig
time
described
as
"upgrade"
includes
the
Sedco
702
and
Sedco
706
which
are
undergoing
or
forecast
to
undergo
a
shipyard
project
to
enhance
the
operational
capabilities
of
the
rig.
Upgrade
Includes
mobilization
and
demobilization
to
and
from
operating
contracts
and
other
activities
such
as
shipyards
excluding
those
mobilization
and
demobilization
periods
covered
in
Reactivation and
Upgrades.
Mobilization
Time
when
a
rig
is
not
available
to
earn
an
operating
dayrate
due
to
shipyards,
contract
preparation,
mobilization,
reactivation
or upgrades.
Out-of-Service
Time
expressed
in
months
that
each
rig
has
been,
or
is
forecast
to
be
Out
of
Service
as
reflected
in
the
company's
Fleet
Status
Update
Report
as
of
November
3,
2008.
Also
includes
out
of
service
time
of
less
than
14
days
that
is
not
disclosed
in
the
Fleet
Status
report.
Rig Months
Definitions
16
33
20
21
18
26
19
19
6
3
6
7
5
2
3
2
5
5
3
3
0
5
10
15
20
25
30
35
40
45
50
Qtr 1 - 08A
Qtr 2 - 08A
Qtr 3 - 08A
Qtr 4 - 08F
Qtr 1 - 09F
Qtr 2 - 09F
Qtr 3 - 09F
Qtr 4 - 09F
Period ( A = actual data, F = forecast data)
Shipyard
Mobilization
Upgrade
28 
42
30
31
23
28
22
21


Chart
#3:
Operating
&
Maintenance
(O&M)
Costs
Trends
(Unaudited)
Our
operating
and
maintenance
costs
represent
all
direct
and
indirect
costs
associated
with
the
operation
and
maintenance
of
our
drilling
rigs.
Operating
and
maintenance
costs
also
includes
all
costs
related
to
local
and
regional
offices
as
well
as
all
costs
related
to
operations
support,
engineering
support,
marketing
and
other
similar
costs.
The
principal
elements
of
these
costs
are
direct
and
indirect
labor
and
benefits,
repair
and
maintenance,
contract
preparation
expenses,
insurance,
boat
and
helicopter
rentals,
professional
and
technical
fees,
freight
costs,
communications,
customs
duties,
tool
rentals
and
services,
fuel
and
water,
general
taxes
and
licenses.
Labor,
repair
and
maintenance
costs,
insurance
premiums,
personal
injury
losses
and
drilling
rig
casualty
losses
represent
the
most
significant
components
of
our
operating
and
maintenance
costs
O&M
Costs
*
Includes
the
total
amount
of
days
a
rig
is
deemed
to
be
out
of
service.
This
relates
to
times
when
a
rig
is
out
of
service
due
to
shipyards,
mobilization
and
short-term
idle
periods.
Out
of
Service
Days
Denotes
the
total
O&M
costs
while
a
rig
is
out
of
service
based
upon
Out
of
Service
Days,
as
defined
below.
Out
of
Service
costs
are
the
difference
between
total
operating
and
maintenance
costs
and
the
In-Service
Costs.
Out
of
Service
Denotes
the
total
amount
of
days
a
rig
is
deemed
to
be
in-
service
under
contract
operations.
This
excludes
all
out
of
service
time
relating
to
shipyards,
mobilization
and
short-term
out
of
contract
periods
but
includes
the
operational
downtime
of
in
service
rigs.
The
average
number
of
days
may
also
fluctuate
from
quarter
to
quarter
as
a
result
of
rigs
being
reactivated,
sold
or
stacked
in
the
quarters.
Rig
Operating
Days
Denotes
the
total
O&M
costs
of
a
rig
while
in
service
based
upon
the
Rig
Operating
Days
(excluding
shorebase
or
common
support
costs),
as
defined
below.
Operating
Rigs
Includes
Integrated
Services,
Drilling
Management
Services,
Oil
and
Gas
Properties,
and
all
shorebase
or
common
support
costs
(on-shore
offices,
yards,
pool
equipment).
Support
&
Non-
Drilling
Costs
Definitions
$36
$148
$167
$205
$82
$105
$117
$130
$216
$182
$211
$284
$425
$419
$474
$488
$599
$762
$809
$823
$62
$45
$36
$44
$73
$65
$177
$114
$-
$200 MM
$400 MM
$600 MM
$800 MM
$1,000 MM
$1,200 MM
$1,400 MM
$1,600 MM
Qtr4'06
Qtr1'07
Qtr2'07
Qtr3'07
Qtr4'07
Qtr1'08
Qtr2'08
Qtr3'08
Period
Drilling Management Services and Oil & Gas $
Support and Integrated Services $
Operating Rig $
Out of Service $


Chart
#4:
Contract
Backlog
by
Years
(Unaudited)
Total
Contract
Backlog
(1)
=
$41.1
Billion
Remaining
(1)
Calculated
by
multiplying
the
contracted
operating
dayrate
by
the
firm
contract
period
from
November
3,
2008
forward.
Reflects
firm
commitments
represented
by
signed
contracts.
Contract
backlog
excludes
revenues
from
mobilization,
demobilization,
contract
preparation,
integrated
services
and
customer
reimbursables.
Our
backlog
calculation
assumes
that
we
receive
the
full
contractual
dayrate,
which
could
be
higher
than
the
actual
Dayrate
that
we
receive
because
of
a
number
of
factors
(rig
downtime,
suspension
of
operations,
etc.)
including
some
beyond
our
control.
0.8
5.6
5.9
5.5
4.3
8.1
1.1
5.3
2.8
1.0
0.4
0.4
$0.0B
$1.0B
$2.0B
$3.0B
$4.0B
$5.0B
$6.0B
$7.0B
$8.0B
$9.0B
$10.0B
$11.0B
$12.0B
2008
2009
2010
2011
2012
2013-2020
High-Spec Fleet
Remaining Fleet
$1.9
$8.5
$4.7
$6.5
$8.7
$10.9