þ
|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
¨
|
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|
Zug, Switzerland
|
98-0599916
|
(State or other jurisdiction of incorporation or organization)
|
(I.R.S. Employer Identification No.)
|
Chemin de Blandonnet 10
Vernier, Switzerland
|
1214
|
(Address of principal executive offices)
|
(Zip Code)
|
+41 (22) 930-9000
|
|
(Registrant’s telephone number, including area code)
|
|
PART I. FINANCIAL INFORMATION
|
Page
|
|
Item 1.
|
Financial Statements (Unaudited)
|
|
Condensed Consolidated Statements of Operations
|
1
|
|
Condensed Consolidated Statements of Comprehensive Income
|
2
|
|
Condensed Consolidated Balance Sheets
|
3
|
|
Condensed Consolidated Statements of Equity
|
4
|
|
Condensed Consolidated Statements of Cash Flows
|
5
|
|
Notes to Condensed Consolidated Financial Statements
|
6
|
|
Item 2.
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
24
|
Item 3.
|
Quantitative and Qualitative Disclosures About Market Risk
|
49
|
Item 4.
|
Controls and Procedures
|
50
|
PART II. OTHER INFORMATION
|
||
Item 1.
|
Legal Proceedings
|
51
|
Item 1A.
|
Risk Factors
|
51
|
Item 2.
|
Unregistered Sales of Equity Securities and Use of Proceeds
|
55
|
Item 6.
|
Exhibits
|
55
|
PART I.
|
FINANCIAL INFORMATION
|
Three months ended June 30,
|
Six months ended June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Operating revenues
|
||||||||||||||||
Contract drilling revenues
|
$
|
2,290
|
$
|
2,625
|
$
|
4,731
|
$
|
5,459
|
||||||||
Contract drilling intangible revenues
|
29
|
75
|
62
|
179
|
||||||||||||
Other revenues
|
186
|
182
|
314
|
362
|
||||||||||||
2,505
|
2,882
|
5,107
|
6,000
|
|||||||||||||
Costs and expenses
|
||||||||||||||||
Operating and maintenance
|
1,358
|
1,277
|
2,554
|
2,448
|
||||||||||||
Depreciation, depletion and amortization
|
400
|
360
|
801
|
715
|
||||||||||||
General and administrative
|
58
|
53
|
121
|
109
|
||||||||||||
1,816
|
1,690
|
3,476
|
3,272
|
|||||||||||||
Loss on impairment
|
—
|
(67
|
)
|
(2
|
)
|
(288
|
)
|
|||||||||
Gain (loss) on disposal of assets, net
|
268
|
(4
|
)
|
254
|
—
|
|||||||||||
Operating income
|
957
|
1,121
|
1,883
|
2,440
|
||||||||||||
Other income (expense), net
|
||||||||||||||||
Interest income
|
5
|
1
|
10
|
2
|
||||||||||||
Interest expense, net of amounts capitalized
|
(141
|
)
|
(114
|
)
|
(273
|
)
|
(250
|
)
|
||||||||
Gain (loss) on retirement of debt
|
—
|
(8
|
)
|
2
|
(10
|
)
|
||||||||||
Other, net
|
(3
|
)
|
(8
|
)
|
10
|
—
|
||||||||||
(139
|
)
|
(129
|
)
|
(251
|
)
|
(258
|
)
|
|||||||||
Income before income tax expense
|
818
|
992
|
1,632
|
2,182
|
||||||||||||
Income tax expense
|
98
|
184
|
227
|
435
|
||||||||||||
Net income
|
720
|
808
|
1,405
|
1,747
|
||||||||||||
Net income (loss) attributable to noncontrolling interest
|
5
|
2
|
13
|
(1
|
)
|
|||||||||||
Net income attributable to controlling interest
|
$
|
715
|
$
|
806
|
$
|
1,392
|
$
|
1,748
|
||||||||
Earnings per share
|
||||||||||||||||
Basic
|
$
|
2.23
|
$
|
2.50
|
$
|
4.32
|
$
|
5.43
|
||||||||
Diluted
|
$
|
2.22
|
$
|
2.49
|
$
|
4.31
|
$
|
5.42
|
||||||||
Weighted average shares outstanding
|
||||||||||||||||
Basic
|
319
|
320
|
320
|
320
|
||||||||||||
Diluted
|
320
|
321
|
321
|
321
|
Three months ended June 30,
|
Six months ended June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Net income
|
$
|
720
|
$
|
808
|
$
|
1,405
|
$
|
1,747
|
||||||||
Other comprehensive income (loss) before income taxes
|
||||||||||||||||
Unrecognized components of net periodic benefit cost
|
—
|
—
|
(10
|
)
|
(39
|
)
|
||||||||||
Recognized components of net periodic benefit cost
|
3
|
5
|
9
|
9
|
||||||||||||
Unrealized gain (loss) on derivative instruments
|
(11
|
)
|
10
|
(17
|
)
|
9
|
||||||||||
Other, net
|
(3
|
)
|
1
|
(3
|
)
|
—
|
||||||||||
Other comprehensive income (loss) before income taxes
|
(11
|
)
|
16
|
(21
|
)
|
(21
|
)
|
|||||||||
Income taxes related to other comprehensive income (loss)
|
(1
|
)
|
(6
|
)
|
(1
|
)
|
3
|
|||||||||
Other comprehensive income (loss), net of income taxes
|
(12
|
)
|
10
|
(22
|
)
|
(18
|
)
|
|||||||||
Total comprehensive income
|
708
|
818
|
1,383
|
1,729
|
||||||||||||
Total comprehensive income (loss) attributable to noncontrolling interest
|
(9
|
)
|
13
|
(8
|
)
|
10
|
||||||||||
Total comprehensive income attributable to controlling interest
|
$
|
717
|
$
|
805
|
$
|
1,391
|
$
|
1,719
|
June 30,
2010
|
December 31, 2009
|
|||||||
(Unaudited)
|
||||||||
Assets
|
||||||||
Cash and cash equivalents
|
$
|
2,888
|
$
|
1,130
|
||||
Accounts receivable, net of allowance for doubtful accounts
of $41 and $65 at June 30, 2010 and December 31, 2009, respectively
|
2,254
|
2,385
|
||||||
Materials and supplies, net of allowance for obsolescence
of $66 at June 30, 2010 and December 31, 2009
|
467
|
462
|
||||||
Deferred income taxes, net
|
121
|
104
|
||||||
Assets held for sale
|
—
|
186
|
||||||
Other current assets
|
184
|
209
|
||||||
Total current assets
|
5,914
|
4,476
|
||||||
Property and equipment
|
27,377
|
27,383
|
||||||
Property and equipment of consolidated variable interest entities
|
2,179
|
1,968
|
||||||
Less accumulated depreciation
|
7,034
|
6,333
|
||||||
Property and equipment, net
|
22,522
|
23,018
|
||||||
Goodwill
|
8,132
|
8,134
|
||||||
Other assets
|
984
|
808
|
||||||
Total assets
|
$
|
37,552
|
$
|
36,436
|
||||
Liabilities and equity
|
||||||||
Accounts payable
|
$
|
968
|
$
|
780
|
||||
Accrued income taxes
|
154
|
240
|
||||||
Debt due within one year
|
1,580
|
1,568
|
||||||
Debt of consolidated variable interest entities due within one year
|
82
|
300
|
||||||
Other current liabilities
|
1,884
|
730
|
||||||
Total current liabilities
|
4,668
|
3,618
|
||||||
Long-term debt
|
8,862
|
8,966
|
||||||
Long-term debt of consolidated variable interest entities
|
902
|
883
|
||||||
Deferred income taxes, net
|
710
|
726
|
||||||
Other long-term liabilities
|
1,683
|
1,684
|
||||||
Total long-term liabilities
|
12,157
|
12,259
|
||||||
Commitments and contingencies
|
||||||||
Shares, CHF 15.00 par value, 502,852,947 authorized, 167,617,649 conditionally authorized,
335,235,298 issued at June 30, 2010 and December 31, 2009;
318,916,207 and 321,223,882 outstanding at June 30, 2010 and December 31, 2009, respectively
|
4,479
|
4,472
|
||||||
Additional paid-in capital
|
6,421
|
7,407
|
||||||
Treasury shares, at cost, 2,863,267 and none held at June 30, 2010 and December 31, 2009, respectively
|
(240
|
)
|
—
|
|||||
Retained earnings
|
10,400
|
9,008
|
||||||
Accumulated other comprehensive loss
|
(336
|
)
|
(335
|
)
|
||||
Total controlling interest shareholders’ equity
|
20,724
|
20,552
|
||||||
Noncontrolling interest
|
3
|
7
|
||||||
Total equity
|
20,727
|
20,559
|
||||||
Total liabilities and equity
|
$
|
37,552
|
$
|
36,436
|
Six months ended June 30,
|
|||||||
2010
|
2009
|
||||||
Shares outstanding
|
|||||||
Balance, beginning of period
|
321
|
319
|
|||||
Issuance of shares under share-based compensation plans
|
1
|
2
|
|||||
Purchases of shares held in treasury
|
(3
|
)
|
—
|
||||
Balance, end of period
|
319
|
321
|
|||||
Shares
|
|||||||
Balance, beginning of period
|
$
|
4,472
|
$
|
4,444
|
|||
Issuance of shares under share-based compensation plans
|
7
|
24
|
|||||
Balance, end of period
|
$
|
4,479
|
$
|
4,468
|
|||
Additional paid-in capital
|
|||||||
Balance, beginning of period
|
$
|
7,407
|
$
|
7,313
|
|||
Share-based compensation expense
|
53
|
43
|
|||||
Issuance of shares under share-based compensation plans
|
(9
|
)
|
16
|
||||
Obligation for cash distribution
|
(1,024
|
)
|
—
|
||||
Repurchases of convertible senior notes
|
—
|
16
|
|||||
Changes in ownership of noncontrolling interest and other, net
|
(6
|
)
|
—
|
||||
Balance, end of period
|
$
|
6,421
|
$
|
7,388
|
|||
Treasury shares, at cost
|
|||||||
Balance, beginning of period
|
$
|
—
|
$
|
—
|
|||
Purchases of shares held in treasury
|
(240
|
)
|
—
|
||||
Balance, end of period
|
$
|
(240
|
)
|
$
|
—
|
||
Retained earnings
|
|||||||
Balance, beginning of period
|
$
|
9,008
|
$
|
5,827
|
|||
Net income attributable to controlling interest
|
1,392
|
1,748
|
|||||
Balance, end of period
|
$
|
10,400
|
$
|
7,575
|
|||
Accumulated other comprehensive loss
|
|||||||
Balance, beginning of period
|
$
|
(335
|
)
|
$
|
(420
|
)
|
|
Other comprehensive loss attributable to controlling interest
|
(1
|
)
|
(29
|
)
|
|||
Balance, end of period
|
$
|
(336
|
)
|
$
|
(449
|
)
|
|
Total controlling interest shareholders’ equity
|
|||||||
Balance, beginning of period
|
$
|
20,552
|
$
|
17,164
|
|||
Total comprehensive income attributable to controlling interest
|
1,391
|
1,719
|
|||||
Share-based compensation expense
|
53
|
43
|
|||||
Issuance of shares under share-based compensation plans
|
(2
|
)
|
40
|
||||
Purchases of shares held in treasury
|
(240
|
)
|
—
|
||||
Obligation for cash distribution
|
(1,024
|
)
|
—
|
||||
Repurchases of convertible senior notes
|
—
|
16
|
|||||
Changes in ownership of noncontrolling interest and other, net
|
(6
|
)
|
—
|
||||
Balance, end of period
|
$
|
20,724
|
$
|
18,982
|
|||
Total noncontrolling interest
|
|||||||
Balance, beginning of period
|
$
|
7
|
$
|
3
|
|||
Net income (loss) attributable to noncontrolling interest
|
13
|
(1
|
)
|
||||
Other comprehensive income (loss) attributable to noncontrolling interest
|
(21
|
)
|
11
|
||||
Changes in ownership of noncontrolling interest
|
4
|
—
|
|||||
Balance, end of period
|
$
|
3
|
$
|
13
|
|||
Total equity
|
|||||||
Balance, beginning of period
|
$
|
20,559
|
$
|
17,167
|
|||
Total comprehensive income
|
1,383
|
1,729
|
|||||
Share-based compensation expense
|
53
|
43
|
|||||
Issuance of shares under share-based compensation plans
|
(2
|
)
|
40
|
||||
Purchases of shares held in treasury
|
(240
|
)
|
—
|
||||
Obligation for cash distribution
|
(1,024
|
)
|
—
|
||||
Repurchases of convertible notes
|
—
|
16
|
|||||
Changes in ownership of noncontrolling interest and other, net
|
(2
|
)
|
—
|
||||
Balance, end of period
|
$
|
20,727
|
$
|
18,995
|
Three months ended June 30,
|
Six months ended June 30,
|
||||||||||||||||
2010
|
2009
|
2010
|
2009
|
||||||||||||||
Cash flows from operating activities
|
|||||||||||||||||
Net income
|
$
|
720
|
$
|
808
|
$
|
1,405
|
$
|
1,747
|
|||||||||
Adjustments to reconcile net income to net cash provided by operating activities
|
|||||||||||||||||
Amortization of drilling contract intangibles
|
(29
|
)
|
(75
|
)
|
(62
|
)
|
(179
|
)
|
|||||||||
Depreciation, depletion and amortization
|
400
|
360
|
801
|
715
|
|||||||||||||
Share-based compensation expense
|
18
|
24
|
53
|
43
|
|||||||||||||
Excess tax benefit from share-based compensation plans
|
(1
|
)
|
—
|
(1
|
)
|
(1
|
)
|
||||||||||
(Gain) loss on disposal of assets, net
|
(268
|
)
|
4
|
(254
|
)
|
—
|
|||||||||||
Loss on impairment
|
—
|
67
|
2
|
288
|
|||||||||||||
(Gain) loss on retirement of debt
|
—
|
8
|
(2
|
)
|
10
|
||||||||||||
Amortization of debt issue costs, discounts and premiums, net
|
51
|
57
|
100
|
109
|
|||||||||||||
Deferred income taxes
|
(12
|
)
|
20
|
(34
|
)
|
26
|
|||||||||||
Other, net
|
(6
|
)
|
14
|
(1
|
)
|
23
|
|||||||||||
Deferred revenue, net
|
7
|
49
|
158
|
43
|
|||||||||||||
Deferred expenses, net
|
(23
|
)
|
(37
|
)
|
(37
|
)
|
(35
|
)
|
|||||||||
Changes in operating assets and liabilities
|
412
|
277
|
313
|
228
|
|||||||||||||
Net cash provided by operating activities
|
1,269
|
1,576
|
2,441
|
3,017
|
|||||||||||||
Cash flows from investing activities
|
|||||||||||||||||
Capital expenditures
|
(300
|
)
|
(947
|
)
|
(679
|
)
|
(1,655
|
)
|
|||||||||
Proceeds from disposal of assets, net
|
10
|
—
|
51
|
8
|
|||||||||||||
Proceeds from insurance recoveries for loss of drilling unit
|
560
|
—
|
560
|
—
|
|||||||||||||
Proceeds from payments on notes receivable
|
11
|
—
|
21
|
—
|
|||||||||||||
Proceeds from short-term investments
|
—
|
172
|
5
|
393
|
|||||||||||||
Purchases of short-term investments
|
—
|
(234
|
)
|
—
|
(234
|
)
|
|||||||||||
Joint ventures and other investments, net
|
(1
|
)
|
—
|
(1
|
)
|
—
|
|||||||||||
Net cash provided by (used in) investing activities
|
280
|
(1,009
|
)
|
(43
|
)
|
(1,488
|
)
|
||||||||||
Cash flows from financing activities
|
|||||||||||||||||
Change in short-term borrowings, net
|
(46
|
)
|
(476
|
)
|
(177
|
)
|
(500
|
)
|
|||||||||
Proceeds from debt
|
—
|
231
|
54
|
319
|
|||||||||||||
Repayments of debt
|
(22
|
)
|
(708
|
)
|
(275
|
)
|
(1,410
|
)
|
|||||||||
Payments for warrant exercises, net
|
—
|
(13
|
)
|
—
|
(13
|
)
|
|||||||||||
Purchases of shares held in treasury
|
(180
|
)
|
—
|
(240
|
)
|
—
|
|||||||||||
Proceeds from (taxes paid for) share-based compensation plans, net
|
3
|
5
|
(1
|
)
|
22
|
||||||||||||
Excess tax benefit from share-based compensation plans
|
1
|
—
|
1
|
1
|
|||||||||||||
Other, net
|
(3
|
)
|
(1
|
)
|
(2
|
)
|
(4
|
)
|
|||||||||
Net cash used in financing activities
|
(247
|
)
|
(962
|
)
|
(640
|
)
|
(1,585
|
)
|
|||||||||
Net increase (decrease) in cash and cash equivalents
|
1,302
|
(395
|
)
|
1,758
|
(56
|
)
|
|||||||||||
Cash and cash equivalents at beginning of period
|
1,586
|
1,302
|
1,130
|
963
|
|||||||||||||
Cash and cash equivalents at end of period
|
$
|
2,888
|
$
|
907
|
$
|
2,888
|
$
|
907
|
June 30, 2010
|
December 31, 2009
|
||||||||||||||||||||||
Assets
|
Liabilities
|
Net carrying amount
|
Assets
|
Liabilities
|
Net carrying amount
|
||||||||||||||||||
Variable interest entity
|
|||||||||||||||||||||||
TPDI
|
$
|
1,600
|
$
|
806
|
$
|
794
|
$
|
1,500
|
$
|
763
|
$
|
737
|
|||||||||||
ADDCL
|
825
|
319
|
506
|
582
|
482
|
100
|
|||||||||||||||||
Total
|
$
|
2,425
|
$
|
1,125
|
$
|
1,300
|
$
|
2,082
|
$
|
1,245
|
$
|
837
|
June 30,
2010
|
December 31,
2009
|
||||||
Unrecognized tax benefits, excluding interest and penalties
|
$
|
457
|
$
|
460
|
|||
Interest and penalties
|
209
|
200
|
|||||
Unrecognized tax benefits, including interest and penalties
|
$
|
666
|
$
|
660
|
Three months ended June 30,
|
Six months ended June 30,
|
|||||||||||||||||||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||||||||||||||||||
Basic
|
Diluted
|
Basic
|
Diluted
|
Basic
|
Diluted
|
Basic
|
Diluted
|
|||||||||||||||||||||||||
Numerator for earnings per share
|
||||||||||||||||||||||||||||||||
Net income attributable to controlling interest
|
$
|
715
|
$
|
715
|
$
|
806
|
$
|
806
|
$
|
1,392
|
$
|
1,392
|
$
|
1,748
|
$
|
1,748
|
||||||||||||||||
Undistributed earnings allocable to participating securities
|
(4
|
)
|
(5
|
)
|
(5
|
)
|
(5
|
)
|
(8
|
)
|
(8
|
)
|
(10
|
)
|
(10
|
)
|
||||||||||||||||
Net income available to shareholders
|
$
|
711
|
$
|
710
|
$
|
801
|
$
|
801
|
$
|
1,384
|
$
|
1,384
|
$
|
1,738
|
$
|
1,738
|
||||||||||||||||
Denominator for earnings per share
|
||||||||||||||||||||||||||||||||
Weighted-average shares outstanding
|
319
|
319
|
320
|
320
|
320
|
320
|
320
|
320
|
||||||||||||||||||||||||
Effect of stock options and other share-based awards
|
—
|
1
|
—
|
1
|
—
|
1
|
—
|
1
|
||||||||||||||||||||||||
Weighted-average shares for per share calculation
|
319
|
320
|
320
|
321
|
320
|
321
|
320
|
321
|
||||||||||||||||||||||||
Earnings per share
|
$
|
2.23
|
$
|
2.22
|
$
|
2.50
|
$
|
2.49
|
$
|
4.32
|
$
|
4.31
|
$
|
5.43
|
$
|
5.42
|
Six months
ended
June 30,
2010
|
Through
December 31,
2009
|
Total
costs
|
||||||||||
Discoverer Luanda (a)
|
$
|
160
|
$
|
535
|
$
|
695
|
||||||
Deepwater Champion (b)
|
56
|
527
|
583
|
|||||||||
Discoverer India
|
50
|
541
|
591
|
|||||||||
Dhirubhai Deepwater KG2 (c) (d)
|
33
|
641
|
674
|
|||||||||
Discover Inspiration (c)
|
7
|
667
|
674
|
|||||||||
Capitalized interest
|
47
|
183
|
230
|
|||||||||
Mobilization costs
|
36
|
19
|
55
|
|||||||||
Total
|
$
|
389
|
$
|
3,113
|
$
|
3,502
|
(a)
|
The costs for Discoverer Luanda represent 100 percent of expenditures incurred since inception. ADDCL is responsible for all of these costs. We hold a 65 percent interest in ADDCL, and Angco Cayman Limited holds the remaining 35 percent interest.
|
(b)
|
These costs include our initial investment in Deepwater Champion of $109 million, representing the estimated fair value of the rig at the time of our merger with GlobalSantaFe Corporation (“GlobalSantaFe”) in November 2007.
|
(c)
|
The accumulated construction costs of these rigs are no longer included in construction work in progress, as their construction projects had been completed as of June 30, 2010.
|
(d)
|
The cost for Dhirubhai Deepwater KG2 represents 100 percent of TPDI’s expenditures, including those incurred prior to our investment in the joint venture. TPDI is responsible for all of these costs. We hold a 50 percent interest in TPDI, and Pacific Drilling Limited (“Pacific Drilling”) holds the remaining 50 percent interest.
|
June 30, 2010
|
December 31, 2009
|
||||||||||||||||||||||
Transocean Ltd.
and subsidiaries
|
Consolidated variable interest entities
|
Consolidated total
|
Transocean Ltd.
and subsidiaries
|
Consolidated variable interest entities
|
Consolidated total
|
||||||||||||||||||
ODL Loan Facility
|
$
|
10
|
$
|
—
|
$
|
10
|
$
|
10
|
$
|
—
|
$
|
10
|
|||||||||||
Commercial paper program (a)
|
104
|
—
|
104
|
281
|
—
|
281
|
|||||||||||||||||
6.625% Notes due April 2011 (a)
|
168
|
—
|
168
|
170
|
—
|
170
|
|||||||||||||||||
5% Notes due February 2013
|
254
|
—
|
254
|
247
|
—
|
247
|
|||||||||||||||||
5.25% Senior Notes due March 2013 (a)
|
509
|
—
|
509
|
496
|
—
|
496
|
|||||||||||||||||
TPDI Credit Facilities due March 2015
|
—
|
595
|
595
|
—
|
581
|
581
|
|||||||||||||||||
ADDCL Credit Facilities due August 2017
|
—
|
241
|
241
|
—
|
454
|
454
|
|||||||||||||||||
TPDI Notes due October 2019
|
—
|
148
|
148
|
—
|
148
|
148
|
|||||||||||||||||
6.00% Senior Notes due March 2018 (a)
|
997
|
—
|
997
|
997
|
—
|
997
|
|||||||||||||||||
7.375% Senior Notes due April 2018 (a)
|
247
|
—
|
247
|
247
|
—
|
247
|
|||||||||||||||||
Capital lease obligation due July 2026
|
—
|
—
|
—
|
15
|
—
|
15
|
|||||||||||||||||
8% Debentures due April 2027 (a)
|
57
|
—
|
57
|
57
|
—
|
57
|
|||||||||||||||||
7.45% Notes due April 2027 (a)
|
96
|
—
|
96
|
96
|
—
|
96
|
|||||||||||||||||
7% Senior Notes due June 2028
|
312
|
—
|
312
|
313
|
—
|
313
|
|||||||||||||||||
Capital lease contract due August 2029
|
703
|
—
|
703
|
711
|
—
|
711
|
|||||||||||||||||
7.5% Notes due April 2031 (a)
|
598
|
—
|
598
|
598
|
—
|
598
|
|||||||||||||||||
1.625% Series A Convertible Senior Notes due December 2037 (a)
|
1,281
|
—
|
1,281
|
1,261
|
—
|
1,261
|
|||||||||||||||||
1.50% Series B Convertible Senior Notes due December 2037 (a)
|
2,093
|
—
|
2,093
|
2,057
|
—
|
2,057
|
|||||||||||||||||
1.50% Series C Convertible Senior Notes due December 2037 (a)
|
2,014
|
—
|
2,014
|
1,979
|
—
|
1,979
|
|||||||||||||||||
6.80% Senior Notes due March 2038 (a)
|
999
|
—
|
999
|
999
|
—
|
999
|
|||||||||||||||||
Total debt
|
10,442
|
984
|
11,426
|
10,534
|
1,183
|
11,717
|
|||||||||||||||||
Less debt due within one year
|
|||||||||||||||||||||||
ODL Loan Facility
|
10
|
—
|
10
|
10
|
—
|
10
|
|||||||||||||||||
Commercial paper program (a)
|
104
|
—
|
104
|
281
|
—
|
281
|
|||||||||||||||||
6.625% Notes due April 2011 (a)
|
168
|
—
|
168
|
—
|
—
|
—
|
|||||||||||||||||
TPDI Credit Facilities due March 2015
|
—
|
70
|
70
|
—
|
52
|
52
|
|||||||||||||||||
ADDCL Credit Facilities due August 2017
|
—
|
12
|
12
|
—
|
248
|
248
|
|||||||||||||||||
Capital lease contract due August 2029
|
17
|
—
|
17
|
16
|
—
|
16
|
|||||||||||||||||
1.625% Series A Convertible Senior Notes due December 2037 (a)
|
1,281
|
—
|
1,281
|
1,261
|
—
|
1,261
|
|||||||||||||||||
Total debt due within one year
|
1,580
|
82
|
1,662
|
1,568
|
300
|
1,868
|
|||||||||||||||||
Total long-term debt
|
$
|
8,862
|
$
|
902
|
$
|
9,764
|
$
|
8,966
|
$
|
883
|
$
|
9,849
|
(a)
|
Transocean Inc., a wholly owned subsidiary of Transocean Ltd., is the issuer of the notes and debentures, which have been guaranteed by Transocean Ltd. Transocean Ltd. has also guaranteed borrowings under the commercial paper program and the Five-Year Revolving Credit Facility. Transocean Ltd. has no independent assets or operations, its guarantee of debt securities of Transocean Inc. is full and unconditional and its only other subsidiaries not owned indirectly through Transocean Inc. are minor. Transocean Ltd. is not subject to any significant restrictions on its ability to obtain funds from its consolidated subsidiaries or entities accounted for under the equity method by dividends, loans or return of capital distributions.
|
Transocean
Ltd.
and subsidiaries
|
Consolidated
variable
interest
entities
|
Consolidated
total
|
||||||||||
Twelve months ending June 30,
|
||||||||||||
2011
|
$
|
1,595
|
$
|
82
|
$
|
1,677
|
||||||
2012
|
2,218
|
96
|
2,314
|
|||||||||
2013
|
2,969
|
98
|
3,067
|
|||||||||
2014
|
21
|
99
|
120
|
|||||||||
2015
|
23
|
346
|
369
|
|||||||||
Thereafter
|
3,909
|
263
|
4,172
|
|||||||||
Total debt, excluding unamortized discounts, premiums and fair value adjustments
|
10,735
|
984
|
11,719
|
|||||||||
Total unamortized discounts, premiums and fair value adjustments
|
(293
|
)
|
—
|
(293
|
)
|
|||||||
Total debt
|
$
|
10,442
|
$
|
984
|
$
|
11,426
|
June 30, 2010
|
December 31, 2009
|
||||||||||||||||||||||
Principal amount
|
Unamortized discount
|
Carrying amount
|
Principal amount
|
Unamortized discount
|
Carrying amount
|
||||||||||||||||||
Carrying amount of liability component
|
|||||||||||||||||||||||
Series A Convertible Senior Notes due 2037
|
$
|
1,299
|
$
|
(18
|
)
|
$
|
1,281
|
$
|
1,299
|
$
|
(38
|
)
|
$
|
1,261
|
|||||||||
Series B Convertible Senior Notes due 2037
|
2,200
|
(107
|
)
|
2,093
|
2,200
|
(143
|
)
|
2,057
|
|||||||||||||||
Series C Convertible Senior Notes due 2037
|
2,200
|
(186
|
)
|
2,014
|
2,200
|
(221
|
)
|
1,979
|
June 30,
2010
|
December 31,
2009
|
||||||||
Carrying amount of equity component
|
|||||||||
Series A Convertible Senior Notes due 2037
|
$
|
215
|
$
|
215
|
|||||
Series B Convertible Senior Notes due 2037
|
275
|
275
|
|||||||
Series C Convertible Senior Notes due 2037
|
352
|
352
|
Three months ended
June 30,
|
Six months ended
June 30,
|
|||||||||||||||
2010
|
2009
|
2010
|
2009
|
|||||||||||||
Interest expense
|
||||||||||||||||
Series A Convertible Senior Notes due 2037
|
$
|
15
|
$
|
22
|
$
|
30
|
$
|
47
|
||||||||
Series B Convertible Senior Notes due 2037
|
26
|
25
|
52
|
50
|
||||||||||||
Series C Convertible Senior Notes due 2037
|
26
|
25
|
52
|
50
|
Three months ended June 30, 2010
|
Three months ended June 30, 2009
|
|||||||||||||||||||||||||||||||
U.S.
Plans
|
Non-U.S.
Plans
|
OPEB
Plans
|
Total
|
U.S.
Plans
|
Non-U.S.
Plans
|
OPEB
Plans
|
Total
|
|||||||||||||||||||||||||
Net periodic benefit costs
|
||||||||||||||||||||||||||||||||
Service cost
|
$
|
11
|
$
|
4
|
$
|
1
|
$
|
16
|
$
|
11
|
$
|
4
|
$
|
1
|
$
|
16
|
||||||||||||||||
Interest cost
|
14
|
5
|
—
|
19
|
13
|
4
|
—
|
17
|
||||||||||||||||||||||||
Expected return on plan assets
|
(15
|
)
|
(3
|
)
|
—
|
(18
|
)
|
(14
|
)
|
(4
|
)
|
—
|
(18
|
)
|
||||||||||||||||||
Settlements and curtailments
|
2
|
—
|
—
|
2
|
—
|
—
|
—
|
—
|
||||||||||||||||||||||||
Actuarial losses, net
|
3
|
1
|
—
|
4
|
5
|
—
|
—
|
5
|
||||||||||||||||||||||||
Prior service cost, net
|
(1
|
)
|
—
|
—
|
(1
|
)
|
(1
|
)
|
1
|
—
|
—
|
|||||||||||||||||||||
Net periodic benefit costs
|
$
|
14
|
$
|
7
|
$
|
1
|
$
|
22
|
$
|
14
|
$
|
5
|
$
|
1
|
$
|
20
|
||||||||||||||||
Funding contributions
|
$
|
49
|
$
|
4
|
$
|
1
|
$
|
54
|
$
|
45
|
$
|
—
|
$
|
1
|
$
|
46
|
Six months ended June 30, 2010
|
Six months ended June 30, 2009
|
|||||||||||||||||||||||||||||||
U.S.
Plans
|
Non-U.S.
Plans
|
OPEB
Plans
|
Total
|
U.S.
Plans
|
Non-U.S.
Plans
|
OPEB
Plans
|
Total
|
|||||||||||||||||||||||||
Net periodic benefit costs
|
||||||||||||||||||||||||||||||||
Service cost
|
$
|
21
|
$
|
10
|
$
|
1
|
$
|
32
|
$
|
22
|
$
|
8
|
$
|
1
|
$
|
31
|
||||||||||||||||
Interest cost
|
27
|
8
|
1
|
36
|
25
|
8
|
1
|
34
|
||||||||||||||||||||||||
Expected return on plan assets
|
(29
|
)
|
(8
|
)
|
—
|
(37
|
)
|
(27
|
)
|
(7
|
)
|
—
|
(34
|
)
|
||||||||||||||||||
Settlements and curtailments
|
2
|
1
|
—
|
3
|
2
|
—
|
—
|
2
|
||||||||||||||||||||||||
Actuarial losses, net
|
7
|
4
|
—
|
11
|
9
|
—
|
—
|
9
|
||||||||||||||||||||||||
Prior service cost, net
|
(1
|
)
|
—
|
(1
|
)
|
(2
|
)
|
(1
|
)
|
1
|
—
|
—
|
||||||||||||||||||||
Net periodic benefit costs
|
$
|
27
|
$
|
15
|
$
|
1
|
$
|
43
|
$
|
30
|
$
|
10
|
$
|
2
|
$
|
42
|
||||||||||||||||
Funding contributions
|
$
|
51
|
$
|
8
|
$
|
3
|
$
|
62
|
$
|
47
|
$
|
1
|
$
|
2
|
$
|
50
|
§
|
the actual responsibility attributed to us and the other PRPs at the site;
|
§
|
appropriate investigatory or remedial actions; and
|
§
|
allocation of the costs of such activities among the PRPs and other site users.
|
§
|
the volume and nature of material, if any, contributed to the site for which we are responsible;
|
§
|
the numbers of other PRPs and their financial viability; and
|
§
|
the remediation methods and technology to be used.
|
June 30, 2010
|
December 31, 2009
|
||||||||||||||
Carrying
amount
|
Fair
value
|
Carrying
amount
|
Fair
value
|
||||||||||||
Long-term debt, including current maturities
|
$
|
10,442
|
$
|
9,751
|
$
|
10,534
|
$
|
11,218
|
|||||||
Long-term debt of consolidated variable interest entities, including current maturities
|
984
|
997
|
1,183
|
1,178
|
Item 2.
|
Management’s Discussion and Analysis of Financial Condition and Results of Operations
|
§
|
the impact of the Macondo well incident and related matters,
|
§
|
the offshore drilling market, including the impact of the drilling moratorium in the United States (“U.S.”) Gulf of Mexico, supply and demand, utilization rates, dayrates, customer drilling programs, commodity prices, stacking of rigs, reactivation of rigs, effects of new rigs on the market and effects of declines in commodity prices and the downturn in the global economy or market outlook for our various geographical operating sectors and classes of rigs,
|
§
|
customer contracts, including contract backlog, force majeure provisions, contract commencements, contract extensions, contract terminations, contract option exercises, contract revenues, contract awards and rig mobilizations,
|
§
|
newbuild, upgrade, shipyard and other capital projects, including completion, delivery and commencement of operation dates, expected downtime and lost revenue, the level of expected capital expenditures and the timing and cost of completion of capital projects,
|
§
|
liquidity and adequacy of cash flow for our obligations, including our ability and the expected timing to access certain investments in highly liquid instruments,
|
§
|
our results of operations and cash flow from operations, including revenues and expenses,
|
§
|
uses of excess cash, including the payment of dividends and other distributions, debt retirement and share repurchases under our share repurchase program,
|
§
|
the cost and timing of acquisitions and the proceeds and timing of dispositions,
|
§
|
tax matters, including our effective tax rate, changes in tax laws, treaties and regulations, tax assessments and liabilities for tax issues, including those associated with our activities in Brazil, Norway and the U.S.,
|
§
|
legal and regulatory matters, including results and effects of legal proceedings and governmental audits and assessments, outcomes and effects of internal and governmental investigations, customs and environmental matters,
|
§
|
insurance matters, including adequacy of insurance, renewal of insurance, insurance proceeds and cash investments of our wholly owned captive insurance company,
|
§
|
debt levels, including impacts of the financial and economic downturn,
|
§
|
effects of accounting changes and adoption of accounting policies, and
|
§
|
investments in recruitment, retention and personnel development initiatives, pension plan and other postretirement benefit plan contributions, the timing of severance payments and benefit payments.
|
§ “anticipates”
|
§ “estimates”
|
§ “may”
|
§ “projects”
|
§ “believes”
|
§ “expects”
|
§ “might”
|
§ “scheduled”
|
§ “budgets”
|
§ “forecasts”
|
§ “plans”
|
§ “should”
|
§ “could”
|
§ “intends”
|
§ “predicts”
|
§
|
those described under “Item 1A. Risk Factors” included herein and in our annual report on Form 10-K for the year ended December 31, 2009,
|
§
|
the adequacy of and access to sources of liquidity,
|
§
|
our inability to obtain contracts for our rigs that do not have contracts,
|
§
|
the cancellation of contracts currently included in our reported contract backlog,
|
§
|
the effect and results of litigation, tax audits and contingencies, and
|
§
|
other factors discussed in this quarterly report and in our other filings with the U.S. Securities and Exchange Commission (“SEC”), which are available free of charge on the SEC website at www.sec.gov.
|
2010
|
2011
|
2012
|
2013
|
|||||||||
Uncommitted fleet rate
|
||||||||||||
High-Specification Floaters
|
8
|
%
|
20
|
%
|
36
|
%
|
48
|
%
|
||||
Midwater Floaters
|
30
|
%
|
60
|
%
|
80
|
%
|
95
|
%
|
||||
High-Specification Jackups
|
46
|
%
|
52
|
%
|
81
|
%
|
100
|
%
|
||||
Standard Jackups
|
52
|
%
|
72
|
%
|
87
|
%
|
95
|
%
|
Three months ended
June 30,
|
Six months ended
June 30,
|
||||||||||||||||||||||||||
2010
|
2009
|
Change
|
2010
|
2009
|
Change
|
||||||||||||||||||||||
Performance indicators
|
|||||||||||||||||||||||||||
Average daily revenue (a)(b)
|
$
|
284,200
|
$
|
255,900
|
$
|
28,300
|
$
|
291,300
|
$
|
256,200
|
$
|
35,100
|
|||||||||||||||
Utilization (b)(c)
|
64
|
%
|
84
|
%
|
n/a
|
65
|
%
|
87
|
%
|
n/a
|
|||||||||||||||||
Statement of operations data
|
|||||||||||||||||||||||||||
Operating revenues
|
$
|
2,505
|
$
|
2,882
|
$
|
(377
|
)
|
$
|
5,107
|
$
|
6,000
|
$
|
(893
|
)
|
|||||||||||||
Operating and maintenance expense
|
1,358
|
1,277
|
81
|
2,554
|
2,448
|
106
|
|||||||||||||||||||||
Operating income
|
957
|
1,121
|
(164
|
)
|
1,883
|
2,440
|
(557
|
)
|
|||||||||||||||||||
Net income attributable to controlling interest
|
715
|
806
|
(91
|
)
|
1,392
|
1,748
|
(356
|
)
|
June 30,
2010
|
December 31,
2009
|
Change
|
||||||||||||
Balance sheet data
|
||||||||||||||
Cash and cash equivalents
|
$
|
2,888
|
$
|
1,130
|
$
|
1,758
|
||||||||
Total assets
|
37,552
|
36,436
|
1,116
|
|||||||||||
Total debt
|
11,426
|
11,717
|
(291
|
)
|
|
“n/a” means not applicable.
|
(a)
|
Average daily revenue is defined as contract drilling revenue earned per revenue earning day. A revenue earning day is defined as a day for which a rig earns dayrate after commencement of operations. Stacking rigs, such as Midwater Floaters, High-Specification Jackups and Standard Jackups, has the effect of increasing the average daily revenue since these rig types are typically contracted at lower dayrates compared to the High-Specification Floaters. Average daily revenue includes our rigs that are operating on standby rates located in the U.S. Gulf of Mexico.
|
(b)
|
Calculation excludes results for Joides Resolution, a drillship engaged in scientific geological coring activities that is owned by an unconsolidated joint venture in which we have a 50 percent interest and for which we apply the equity method of accounting.
|
(c)
|
Utilization is the total actual number of revenue earning days as a percentage of the total number of calendar days in the period. Idle and stacked rigs are included in the calculation and reduce the utilization rate to the extent these rigs are not earning revenues. Newbuilds are included in the calculation upon acceptance by the customer.
|
July 15,
2010
|
March 31,
2010
|
June 30,
2009
|
||||||||||
Contract backlog
|
(in millions)
|
|||||||||||
High-Specification Floaters
|
$
|
22,969
|
$
|
24,293
|
$
|
27,022
|
||||||
Midwater Floaters
|
2,767
|
2,933
|
4,272
|
|||||||||
High-Specification Jackups
|
391
|
315
|
356
|
|||||||||
Standard Jackups
|
1,374
|
1,323
|
2,234
|
|||||||||
Other Rigs
|
62
|
72
|
91
|
|||||||||
Total
|
$
|
27,563
|
$
|
28,936
|
$
|
33,975
|
Three months ended
|
||||||||||||
June 30,
2010
|
March 31,
2010
|
June 30,
2009
|
||||||||||
Average daily revenue
|
||||||||||||
High-Specification Floaters
|
||||||||||||
Ultra-Deepwater Floaters
|
$
|
482,100
|
$
|
486,000
|
$
|
450,500
|
||||||
Deepwater Floaters
|
395,800
|
383,800
|
339,600
|
|||||||||
Harsh Environment Floaters
|
428,500
|
400,100
|
374,500
|
|||||||||
Total High-Specification Floaters
|
447,800
|
443,200
|
397,600
|
|||||||||
Midwater Floaters
|
319,000
|
331,600
|
302,700
|
|||||||||
High-Specification Jackups
|
146,100
|
166,000
|
161,400
|
|||||||||
Standard Jackups
|
117,100
|
133,100
|
149,200
|
|||||||||
Other Rigs
|
72,000
|
72,700
|
48,300
|
|||||||||
Total fleet average daily revenue
|
284,200
|
298,300
|
255,900
|
Three months ended
|
||||||||||||
June 30,
2010
|
March 31,
2010
|
June 30,
2009
|
||||||||||
Utilization
|
||||||||||||
High-Specification Floaters
|
||||||||||||
Ultra-Deepwater Floaters
|
76
|
%
|
88
|
%
|
91
|
%
|
||||||
Deepwater Floaters
|
66
|
%
|
71
|
%
|
82
|
%
|
||||||
Harsh Environment Floaters
|
85
|
%
|
98
|
%
|
93
|
%
|
||||||
Total High-Specification Floaters
|
74
|
%
|
83
|
%
|
88
|
%
|
||||||
Midwater Floaters
|
69
|
%
|
67
|
%
|
84
|
%
|
||||||
High-Specification Jackups
|
70
|
%
|
63
|
%
|
87
|
%
|
||||||
Standard Jackups
|
53
|
%
|
53
|
%
|
82
|
%
|
||||||
Other Rigs
|
50
|
%
|
50
|
%
|
59
|
%
|
||||||
Total fleet average utilization
|
64
|
%
|
66
|
%
|
84
|
%
|
Three months ended June 30,
|
|||||||||||||||||||
2010
|
2009
|
Change
|
% Change
|
||||||||||||||||
(In millions, except day amounts and percentages)
|
|||||||||||||||||||
Revenue earning days
|
8,057
|
10,261
|
(2,204
|
)
|
(21)
|
%
|
|||||||||||||
Utilization
|
64
|
%
|
84
|
%
|
n/a
|
n/m
|
|||||||||||||
Average daily revenue
|
$
|
284,200
|
$
|
255,900
|
$
|
28,300
|
11
|
%
|
|||||||||||
Contract drilling revenues
|
$
|
2,290
|
$
|
2,625
|
$
|
(335
|
)
|
(13)
|
%
|
||||||||||
Contract drilling intangible revenues
|
29
|
75
|
(46
|
)
|
(61)
|
%
|
|||||||||||||
Other revenues
|
186
|
182
|
4
|
2
|
%
|
||||||||||||||
2,505
|
2,882
|
(377
|
)
|
(13)
|
%
|
||||||||||||||
Operating and maintenance expense
|
1,358
|
1,277
|
81
|
6
|
%
|
||||||||||||||
Depreciation, depletion and amortization
|
400
|
360
|
40
|
11
|
%
|
||||||||||||||
General and administrative expense
|
58
|
53
|
5
|
9
|
%
|
||||||||||||||
1,816
|
1,690
|
126
|
7
|
%
|
|||||||||||||||
Loss on impairment
|
—
|
(67
|
)
|
67
|
n/m
|
||||||||||||||
Gain (loss) on disposal of assets, net
|
268
|
(4
|
)
|
272
|
n/m
|
||||||||||||||
Operating income
|
957
|
1,121
|
(164
|
)
|
(15)
|
%
|
|||||||||||||
Other income (expense), net
|
|||||||||||||||||||
Interest income
|
5
|
1
|
4
|
n/m
|
|||||||||||||||
Interest expense, net of amounts capitalized
|
(141
|
)
|
(114
|
)
|
(27
|
)
|
24
|
%
|
|||||||||||
Gain (loss) on retirement of debt
|
—
|
(8
|
)
|
8
|
n/m
|
||||||||||||||
Other, net
|
(3
|
)
|
(8
|
)
|
5
|
63
|
%
|
||||||||||||
Income before income taxes
|
818
|
992
|
(174
|
)
|
(18)
|
%
|
|||||||||||||
Income tax expense
|
98
|
184
|
(86
|
)
|
(47)
|
%
|
|||||||||||||
Net income
|
720
|
808
|
(88
|
)
|
(11)
|
%
|
|||||||||||||
Net income attributable to noncontrolling interest
|
5
|
2
|
3
|
n/m
|
|||||||||||||||
Net income attributable to controlling interest
|
$
|
715
|
$
|
806
|
$
|
(91
|
)
|
(11)
|
%
|
|
“n/a” means not applicable
|
|
“n/m” means not meaningful
|
Six months ended June 30,
|
|||||||||||||||||||
2010
|
2009
|
Change
|
% Change
|
||||||||||||||||
(In millions, except day amounts and percentages)
|
|||||||||||||||||||
Revenue earning days
|
16,241
|
21,311
|
(5,070
|
)
|
(24)
|
%
|
|||||||||||||
Utilization
|
65
|
%
|
87
|
%
|
n/a
|
n/m
|
|||||||||||||
Average daily revenue
|
$
|
291,300
|
$
|
256,200
|
$
|
35,100
|
14
|
%
|
|||||||||||
Contract drilling revenues
|
$
|
4,731
|
$
|
5,459
|
$
|
(728
|
)
|
(13)
|
%
|
||||||||||
Contract drilling intangible revenues
|
62
|
179
|
(117
|
)
|
(65)
|
%
|
|||||||||||||
Other revenues
|
314
|
362
|
(48
|
)
|
(13)
|
%
|
|||||||||||||
5,107
|
6,000
|
(893
|
)
|
(15)
|
%
|
||||||||||||||
Operating and maintenance expense
|
2,554
|
2,448
|
106
|
4
|
%
|
||||||||||||||
Depreciation, depletion and amortization
|
801
|
715
|
86
|
12
|
%
|
||||||||||||||
General and administrative expense
|
121
|
109
|
12
|
11
|
%
|
||||||||||||||
3,476
|
1,690
|
126
|
6
|
%
|
|||||||||||||||
Loss on impairment
|
(2
|
(288
|
)
|
286
|
(99)
|
||||||||||||||
Gain on disposal of assets, net
|
254
|
—
|
254
|
n/m
|
|||||||||||||||
Operating income
|
1,883
|
2,440
|
(557
|
)
|
(23)
|
%
|
|||||||||||||
Other income (expense), net
|
|||||||||||||||||||
Interest income
|
10
|
2
|
8
|
n/m
|
|||||||||||||||
Interest expense, net of amounts capitalized
|
(273
|
)
|
(250
|
)
|
(23
|
)
|
9
|
%
|
|||||||||||
Gain (loss) on retirement of debt
|
2
|
(10
|
)
|
12
|
n/m
|
||||||||||||||
Other, net
|
10
|
—
|
10
|
n/m
|
%
|
||||||||||||||
Income before income taxes
|
1,632
|
2,182
|
(550
|
)
|
(25)
|
%
|
|||||||||||||
Income tax expense
|
227
|
435
|
(208
|
)
|
(48)
|
%
|
|||||||||||||
Net income
|
1,405
|
1,747
|
(342
|
)
|
(20)
|
%
|
|||||||||||||
Net income (loss) attributable to noncontrolling interest
|
13
|
(1
|
)
|
14
|
n/m
|
||||||||||||||
Net income attributable to controlling interest
|
$
|
1,392
|
$
|
1,748
|
$
|
(356
|
)
|
(20)
|
%
|
|
“n/a” means not applicable
|
|
“n/m” means not meaningful
|
Six months ended June 30,
|
||||||||||||||
2010
|
2009
|
Change
|
||||||||||||
Cash flows from operating activities
|
(In millions)
|
|||||||||||||
Net income
|
$
|
1,405
|
$
|
1,747
|
$
|
(342
|
)
|
|||||||
Amortization of drilling contract intangibles
|
(62
|
)
|
(179
|
)
|
117
|
|||||||||
Depreciation, depletion and amortization
|
801
|
715
|
86
|
|||||||||||
Loss on impairment
|
2
|
288
|
(286
|
)
|
||||||||||
Gain on disposal of assets, net
|
(254
|
)
|
—
|
(254
|
)
|
|||||||||
Other non-cash items
|
236
|
218
|
18
|
|||||||||||
Changes in operating assets and liabilities
|
313
|
228
|
85
|
|||||||||||
$
|
2,441
|
$
|
3,017
|
$
|
(576
|
)
|
Six months ended June 30,
|
||||||||||||||
2010
|
2009
|
Change
|
||||||||||||
Cash flows from investing activities
|
(In millions)
|
|||||||||||||
Capital expenditures
|
$
|
(679
|
)
|
$
|
(1,655
|
)
|
$
|
976
|
||||||
Proceeds from disposal of assets, net
|
51
|
8
|
43
|
|||||||||||
Proceeds from insurance recoveries for loss of drilling unit
|
560
|
—
|
560
|
|||||||||||
Proceeds from payments on notes receivable
|
21
|
—
|
21
|
|||||||||||
Proceeds from short-term investments
|
5
|
393
|
(388
|
)
|
||||||||||
Purchases of short-term investments
|
—
|
(234
|
)
|
234
|
||||||||||
Joint ventures and other investments, net
|
(1)
|
—
|
(1
|
)
|
||||||||||
$
|
(43
|
)
|
$
|
(1,488
|
)
|
$
|
1,445
|
Six months ended June 30,
|
||||||||||||||
2010
|
2009
|
Change
|
||||||||||||
Cash flows from financing activities
|
(In millions)
|
|||||||||||||
Change in short-term borrowings, net
|
$
|
(177
|
)
|
$
|
(500
|
)
|
$
|
323
|
||||||
Proceeds from debt
|
54
|
319
|
(265
|
)
|
||||||||||
Repayments of debt
|
(275
|
)
|
(1,410
|
)
|
1,135
|
|||||||||
Payments for warrant exercise, net
|
—
|
(13
|
)
|
13
|
||||||||||
Purchases of shares held in treasury
|
(240
|
)
|
—
|
(240
|
)
|
|||||||||
Proceeds from (taxes paid for) share-based compensation plans, net
|
(1
|
)
|
22
|
(23
|
)
|
|||||||||
Excess tax benefit from share-based compensation plans
|
1
|
1
|
—
|
|||||||||||
Other, net
|
(2
|
)
|
(4
|
)
|
2
|
|||||||||
$
|
(640
|
)
|
$
|
(1,585
|
)
|
$
|
945
|
Total costs through
June 30,
2010
|
Expected costs for the remainder of 2010
|
Estimated
costs
thereafter
|
Total estimated
cost at
completion
|
|||||||||||||
Discoverer Luanda (a)
|
$
|
695
|
$
|
10
|
$
|
—
|
$
|
705
|
||||||||
Discoverer Inspiration (b)
|
674
|
4
|
—
|
678
|
||||||||||||
Dhirubhai Deepwater KG2 (b) (c)
|
674
|
5
|
—
|
679
|
||||||||||||
Discoverer India
|
591
|
139
|
—
|
730
|
||||||||||||
Deepwater Champion (d)
|
583
|
167
|
5
|
755
|
||||||||||||
Capitalized interest
|
230
|
37
|
16
|
283
|
||||||||||||
Mobilization costs
|
55
|
56
|
3
|
114
|
||||||||||||
Total
|
$
|
3,502
|
$
|
418
|
$
|
24
|
$
|
3,944
|
(a)
|
The costs for Discoverer Luanda represent 100 percent of expenditures incurred since inception. Angola Deepwater Drilling Company Limited (“ADDCL”) is responsible for all of these costs. We hold a 65 percent interest in ADDCL, and Angco Cayman Limited holds the remaining 35 percent interest.
|
(b)
|
The accumulated construction costs of these rigs are no longer included in construction work in progress, as their construction projects had been completed as of June 30, 2010.
|
(c)
|
The cost for Dhirubhai Deepwater KG2 represents 100 percent of TPDI’s expenditures, including those incurred prior to our investment in the joint venture. TPDI is responsible for all of these costs. We hold a 50 percent interest in Transocean Pacific Drilling Inc. (“TPDI”), and Pacific Drilling holds the remaining 50 percent interest.
|
(d)
|
These costs include our initial investment in Deepwater Champion of $109 million, representing the estimated fair value of the rig at the time of our merger with GlobalSantaFe in November 2007.
|
Scheduled Maturity Date (a)
|
Fair Value
|
|||||||||||||||
2011
|
2012
|
2013
|
2014
|
2015
|
Thereafter
|
Total
|
6/30/10
|
|||||||||
Total debt
|
||||||||||||||||
Fixed rate
|
$1,561
|
$ 2,288
|
$ 2,289
|
$ 91
|
$ 320
|
$ 3,909
|
$ 10,458
|
$9,547
|
||||||||
Average interest rate
|
2.2%
|
1.6%
|
1.2%
|
3.6%
|
2.7%
|
6.9%
|
3.5%
|
|||||||||
Variable rate
|
$ 116
|
$ 26
|
$ 778
|
$ 29
|
$ 49
|
$ 263
|
$1,261
|
$1,201
|
||||||||
Average interest rate
|
1.0%
|
1.4%
|
3.4%
|
1.4%
|
1.8%
|
2.0%
|
2.5%
|
(a)
|
Expected maturity amounts are based on the face value of debt.
|
|
In preparing the scheduled maturities of our debt, we assume the noteholders will exercise their options to require us to repurchase the 1.625% Series A Convertible Senior Notes, 1.50% Series B Convertible Senior Notes and 1.50% Series C Convertible Senior Notes in December 2010, 2011 and 2012, respectively.
|
|
We have engaged in certain hedging activities designed to reduce our exposure to interest rate risk, and the effect of our derivative instruments is included in the table above (see Notes to Condensed Consolidated Financial Statements—Note 10—Derivatives and Hedging).
|
PART II.
|
OTHER INFORMATION
|
Period
|
(a) Total Number of Shares Purchased (1)
|
(b) Average
Price Paid
Per Share
|
(c) Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs (2)
|
(d) Maximum Number
(or Approximate Dollar Value)
of Shares that May Yet Be Purchased Under the Plans or Programs (2)
(in millions)
|
||||||||
April 2010
|
1,369,233
|
$
|
87.60
|
1,369,000
|
$
|
3,020
|
||||||
May 2010
|
778,198
|
$
|
77.08
|
777,267
|
$
|
2,960
|
||||||
June 2010
|
173
|
$
|
47.70
|
—
|
$
|
2,960
|
||||||
Total
|
2,147,604
|
$
|
83.78
|
2,146,267
|
$
|
2,960
|
(1)
|
Total number of shares purchased in the second quarter of 2010 includes 1,337 shares withheld by us in satisfaction of withholding taxes due upon the vesting of restricted shares granted to our employees under our Long-Term Incentive Plan and 2,146,267 shares repurchased under the share repurchase program described in (2) below.
|
(2)
|
In May 2009, at the annual general meeting of Transocean Ltd., our shareholders approved and authorized our board of directors, at its discretion, to repurchase an amount of our shares for cancellation with an aggregate purchase price of up to CHF 3.5 billion (which is equivalent to approximately U.S. $3.2 billion at an exchange rate as of the close of trading on June 30, 2010 of USD 1.00 to CHF 1.08). On February 12, 2010, our board of directors authorized our management to implement the share repurchase program. We may decide, based upon our ongoing capital requirements, the price of our shares, matters relating to the Macondo well incident, regulatory and tax considerations, cash flow generation, the relationship between our contract backlog and our debt, general market conditions and o
ther factors, that we should retain cash, reduce debt, make capital investments or otherwise use cash for general corporate purposes, and consequently, repurchase fewer or no shares under this program. Decisions regarding the amount, if any, and timing of any share repurchases would be made from time to time based upon these factors. Through June 30, 2010, we have repurchased a total of 2,863,267 of our shares under this share repurchase program at a total cost of $240 million ($83.74 per share). We have agreed not to repurchase any additional shares under our share repurchase program without 30 days notice to the DOJ. See “Part I. Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations—Sources and Uses of Liquidity—Overview.”
|
Number
|
Description
|
|
†
|
3.1
|
Articles of Association of Transocean Ltd.
|
|
† *
|
10.1
|
Drilling Contract between Vastar Resources, Inc. and R&B Falcon Drilling Co. dated December 9, 1998 with respect to the Deepwater Horizon, as amended
|
|
†
|
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
|
|
†
|
101.ins
|
XBRL Instance Document
|
|
†
|
101.sch
|
XBRL Taxonomy Extension Schema
|
|
†
|
101.cal
|
XBRL Taxonomy Extension Calculation Linkbase
|
|
†
|
101.def
|
XBRL Taxonomy Extension Definition Linkbase
|
|
†
|
101.lab
|
XBRL Taxonomy Extension Label Linkbase
|
|
†
|
101.pre
|
XBRL Taxonomy Extension Presentation Linkbase
|
|
†
|
Filed herewith.
|
|
*
|
Compensatory plan or arrangement.
|
Abschnitt
1:
Firma,
Sitz, Zweck und Dauer der Gesellschaft
|
Section
1:
Name,
Place of Incorporation, Purpose and Duration of the
Company
|
||||
Artikel
1
|
Article
1
|
||||
Firma,
Sitz
|
Unter
der Firma
Transocean
Ltd.
(die
Gesellschaft)
besteht
eine Aktiengesellschaft mit Sitz in Steinhausen, Kanton Zug,
Schweiz.
|
Name,
Place of Incorporation
|
Under
the name
Transocean
Ltd.
(the
Company)
there
exists a corporation with its place of incorporation in Steinhausen,
Canton of Zug, Switzerland.
|
||
Zweck
|
Artikel
2
|
Purpose
|
Article
2
|
||
1
|
Zweck
der Gesellschaft ist der Erwerb, das Halten, die Verwaltung, die
Verwertung und die Veräusserung von Beteiligungen an Unternehmen im In-
und Ausland, ob direkt oder indirekt, insbesondere an Unternehmen, die im
Bereich der Erbringung von Dienstleistungen für Offshore Öl-und
Gasbohrungen, einschliesslich Management Dienstleistungen, Bohringenieurs-
und Bohr-Projekt Management-Dienstleistungen für Öl-und Gasbohrungen,
sowie von Öl- und Gas-Exploration und -Produktionsaktivitäten tätig
sind, sowie die Finanzierung dieser Aktivitäten. Die Gesellschaft kann
Grundstücke und gewerbliche Schutzrechte im In- und Ausland erwerben,
halten, verwalten, belasten und verkaufen.
|
1
|
The
purpose of the Company is to acquire, hold, manage, exploit and sell,
whether directly or indirectly, participations in businesses in
Switzerland and abroad, in particular in businesses that are involved in
offshore contract drilling services for oil and gas wells, oil and gas
drilling management services, drilling engineering services and drilling
project management services and oil and gas exploration and production
activities, and to provide financing for this purpose. The
Company may acquire, hold, manage, mortgage and sell real estate and
intellectual property rights in Switzerland and abroad.
|
||
2
|
Die
Gesellschaft kann alle Tätigkeiten ausüben und Massnahmen ergreifen, die
geeignet erscheinen, den Zweck der Gesellschaft zu fördern, oder die mit
diesem zusammenhängen.
|
2
|
The
Company may engage in all types of transactions and may take all measures
that appear appropriate to promote the purpose of the Company or that are
related thereto.
|
||
- 3 -
|
|||||
Artikel
3
|
Article
3
|
||||
Dauer
|
Die
Dauer der Gesellschaft ist unbeschränkt.
|
Duration
|
The
duration of the Company is unlimited.
|
||
Abschnitt
2:
Aktienkapital
|
Section
2:
Share
Capital
|
||||
Artikel
4
|
Article
4
|
||||
Aktienkapital
|
Das
Aktienkapital der Gesellschaft beträgt CHF 5'028'529’470, eingeteilt
in 335'235’298 voll liberierte Namenaktien. Jede Namenaktie hat einen
Nennwert von CHF 15 (jede Namenaktie nachfolgend bezeichnet als Aktie bzw. die Aktien).
|
Share
Capital
|
The
share capital of the Company is CHF 5,028,529,470 and is divided into
335,235,298 fully paid registered shares. Each registered share
has a par value of CHF 15 (each such registered share hereinafter a
Share and
collectively the Shares).
|
||
Artikel
5
|
Article
5
|
||||
Genehmigtes
Kapital
|
1
|
Der
Verwaltungsrat ist ermächtigt, das Aktienkapital jederzeit bis zum 18.
Dezember 2010 im Maximalbetrag von CHF 2’514’264’735 durch Ausgabe
von höchstens 167’617’649 vollständig zu liberierenden Aktien mit einem
Nennwert von je CHF 15 zu erhöhen. Eine Erhöhung (i) auf dem Weg
einer Festübernahme durch eine Bank, ein Bankenkonsortium oder Dritte und
eines anschliessenden Angebots an die bisherigen Aktionäre sowie (ii) in
Teilbeträgen ist zulässig.
|
Authorized
Share Capital
|
1
|
The
Board of Directors is authorized to increase the share capital, at any
time until December 18, 2010, by a maximum amount of
CHF 2,514,264,735 by issuing a
maximum of 167,617,649 fully paid up Shares with a par value of
CHF 15 each. An increase of the share capital (i) by means
of an offering underwritten by a financial institution, a syndicate of
financial institutions or another third party or third parties, followed
by an offer to the then-existing shareholders of the Company, and (ii) in
partial amounts shall be permissible.
|
2
|
Der
Verwaltungsrat legt den Zeitpunkt der Ausgabe, den Ausgabebetrag, die Art,
wie die neuen Aktien zu liberieren sind, den Beginn der
Dividendenberechtigung, die Bedingungen für die Ausübung der Bezugsrechte
sowie die Zuteilung der Bezugsrechte, welche nicht ausgeübt wurden, fest.
Nicht-ausgeübte Bezugsrechte kann der Verwaltungsrat verfallen lassen,
oder er kann diese bzw. Aktien, für welche Bezugsrechte eingeräumt, aber
nicht ausgeübt werden, zu Marktkonditionen platzieren oder anderweitig im
Interesse der Gesellschaft verwenden.
|
2
|
The
Board of Directors shall determine the time of the issuance, the issue
price, the manner in which the new Shares have to be paid up, the date
from which the Shares carry the right to dividends, the conditions for the
exercise of the preemptive rights and the allotment of preemptive rights
that have not been exercised. The Board of Directors may allow
the preemptive rights that have not been exercised to expire, or it may
place such rights or Shares, the preemptive rights of which have not been
exercised, at market conditions or use them otherwise in the interest of
the Company.
|
||
- 4 -
|
|||||
3
|
Der
Verwaltungsrat ist ermächtigt, die Bezugsrechte der Aktionäre zu entziehen
oder zu beschränken und einzelnen Aktionären oder Dritten
zuzuweisen:
(a) wenn
der Ausgabebetrag der neuen Aktien unter Berücksichtigung des Marktpreises
festgesetzt wird; oder
(b) für
die Übernahme von Unternehmen, Unternehmensteilen oder Beteiligungen oder
für die Finanzierung oder Refinanzierung solcher Transaktionen oder die
Finanzierung von neuen Investitionsvorhaben der Gesellschaft;
oder
(c) zum
Zwecke der Erweiterung des Aktionärskreises in bestimmten Finanz- oder
Investoren-Märkten, zur Beteiligung von strategischen Partnern, oder im
Zusammenhang mit der Kotierung von neuen Aktien an inländischen oder
ausländischen Börsen; oder
(d) für
die Einräumung einer Mehrzuteilungsoption (Greenshoe) von bis zu
20% der zu platzierenden oder zu verkaufenden Aktien an die betreffenden
Erstkäufer oder Festübernehmer im Rahmen einer Aktienplatzierung oder
eines Aktienverkaufs; oder
(e) für
die Beteiligung von Mitgliedern des Verwaltungsrates, Mitglieder der
Geschäftsleitung, Mitarbeitern, Beauftragten, Beratern oder anderen
Personen, die für die Gesellschaft oder eine ihrer Tochtergesellschaften
Leistungen erbringen; oder
(f) wenn
ein Aktionär oder eine Gruppe von in gemeinsamer Absprache handelnden
Aktionären mehr als 15% des im Handelsregister
eingetragenen Aktienkapitals der Gesellschaft auf sich
vereinigt hat, ohne den übrigen Aktionären ein vom Verwaltungsrat
empfohlenes Übernahmeangebot zu unterbreiten; oder zur Abwehr eines
unterbreiteten, angedrohten oder potentiellen Übernahmeangebotes, welches
der Verwaltungsrat, nach Konsultation mit einem von ihm beigezogenen
unabhängigen Finanzberater, den Aktionären nicht zur Annahme empfohlen
hat, weil der Verwaltungsrat das Übernahmeangebot in finanzieller Hinsicht
gegenüber den Aktionären nicht als fair beurteilt hat.
|
3
|
The
Board of Directors is authorized to withdraw or limit the preemptive
rights of the shareholders and to allot them to individual shareholders or
third parties:
(a) if the
issue price of the new Shares is determined by reference to the market
price; or
(b) for
the acquisition of an enterprise, part(s) of an enterprise or
participations, or for the financing or refinancing of any of such
transactions, or for the financing of new investment plans of the Company;
or
(c) for
purposes of broadening the shareholder constituency of the Company in
certain financial or investor markets, for purposes of the participation
of strategic partners, or in connection with the listing of new Shares on
domestic or foreign stock exchanges; or
(d) for
purposes of granting an over-allotment option (Greenshoe) of up to 20%
of the total number of Shares in a placement or sale of Shares to the
respective initial purchaser(s) or underwriter(s); or
(e) for
the participation of members of the Board of Directors, members of the
executive management, employees, contractors, consultants or other persons
performing services for the benefit of the Company or any of its
subsidiaries; or
(f) following
a shareholder or a group of shareholders acting in concert having
accumulated shareholdings in excess of 15% of the share capital registered
in the commercial register without having submitted to the other
shareholders a takeover offer recommended by the Board of Directors, or for the defense of
an actual, threatened or potential takeover bid, in relation to which the
Board of Directors, upon consultation with an independent financial
adviser retained by it, has not recommended to the shareholders acceptance
on the basis that the Board of Directors has not found the takeover bid to
be financially fair to the shareholders.
|
||
- 5 -
|
|||||
4
|
Die
neuen Aktien unterliegen den Eintragungsbeschränkungen in das
Aktienbuch von Artikel 7 und 9 dieser Statuten.
|
4
|
The
new Shares shall be subject to the limitations for registration in the
share register pursuant to Articles 7 and 9 of these Articles of
Association.
|
||
Artikel
6
|
Article
6
|
||||
Bedingtes
Aktienkapital
|
1
|
Das
Aktienkapital kann sich durch Ausgabe von höchstens 167’617’649 voll zu
liberierenden Aktien im Nennwert von je CHF 15 um höchstens
CHF 2’514’264’735 erhöhen durch:
(a) die
Ausübung von Wandel-, Tausch-, Options-, Bezugs- oder ähnlichen Rechten
auf den Bezug von Aktien (nachfolgend die Rechte), welche Dritten oder
Aktionären in Verbindung mit auf nationalen oder internationalen
Kapitalmärkten neu oder bereits begebenen Anleihensobligationen, Optionen,
Warrants oder anderen Finanzmarktinstrumenten oder neuen oder bereits
bestehenden vertraglichen Verpflichtungen der Gesellschaft, einer ihrer
Gruppengesellschaften oder einer deren Rechtsvorgänger eingeräumt werden
(nachfolgend zusammen die mit Rechten verbundenen
Obligationen); und/oder
(b) die
Ausgabe von Aktien oder mit Rechten verbundenen Obligationen an Mitglieder
des Verwaltungsrates, Mitglieder der Geschäftsleitung, Arbeitnehmer,
Beauftragte, Berater oder anderen Personen, welche Dienstleistungen für
die Gesellschaft oder ihre Tochtergesellschaften erbringen.
|
Conditional
Share Capital
|
1
|
The
share capital may be increased in an amount not to exceed
CHF 2,514,264,735 through the issuance of up to 167,617,649 fully
paid-up Shares with a par value of CHF 15 per Share
through:
(a) the
exercise of conversion, exchange, option, warrant or similar rights for
the subscription of Shares (hereinafter the Rights) granted to third
parties or shareholders in connection with bonds, options, warrants or
other securities newly or already issued in national or international
capital markets or new or already existing contractual obligations by or
of the Company, one of its group companies, or any of their respective
predecessors (hereinafter collectively, the Rights-Bearing Obligations);
and/or
(b) the
issuance of Shares or Rights-Bearing Obligations granted to members of the
Board of Directors, members of the executive management, employees,
contractors, consultants or other persons providing services to the
Company or its subsidiaries.
|
- 6 -
|
|||||
2
|
Bei
der Ausgabe von mit Rechten verbundenen Obligationen durch die
Gesellschaft, eine ihrer Gruppengesellschaften oder eine deren
Rechtsvorgänger ist das Bezugsrecht der Aktionäre ausgeschlossen. Zum
Bezug der neuen Aktien, die bei Ausübung von mit Rechten verbundenen
Obligationen ausgegeben werden, sind die jeweiligen Inhaber der mit
Rechten verbundenen Obligationen berechtigt. Die Bedingungen der mit
Rechten verbundenen Obligationen sind durch den Verwaltungsrat
festzulegen.
|
2
|
The
preemptive rights of the shareholders shall be excluded in connection with
the issuance of any Rights-Bearing Obligations by the Company, one of its
group companies, or any of their respective predecessors. The
then-current owners of such Rights-Bearing Obligations shall be entitled
to subscribe for the new Shares issued upon conversion, exchange or
exercise of any Rights-Bearing Obligations. The conditions of
the Rights-Bearing Obligations shall be determined by the Board of
Directors.
|
||
3
|
Der
Verwaltungsrat ist ermächtigt, die Vorwegzeichnungsrechte der Aktionäre im
Zusammenhang mit der Ausgabe von mit Rechten verbundenen Obligationen
durch die Gesellschaft oder eine ihrer Gruppengesellschaften zu
beschränken oder aufzuheben, falls (1) die Ausgabe zum Zwecke der
Finanzierung oder Refinanzierung der Übernahme von Unternehmen,
Unternehmensteilen, Beteiligungen oder Investitionen, oder (2) die Ausgabe
auf nationalen oder internationalen Finanzmärkten oder im Rahmen einer
Privatplatzierung erfolgt.
Wird
das Vorwegzeichnungsrecht weder direkt noch indirekt durch den
Verwaltungsrat gewährt, gilt Folgendes:
(a) Die
mit Rechten verbundenen Obligationen sind zu den jeweils marktüblichen
Bedingungen auszugeben oder einzugehen; und
(b) der
Umwandlungs-, Tausch- oder sonstige Ausübungspreis der mit Rechten
verbundenen Obligationen ist unter Berücksichtigung des Marktpreises im
Zeitpunkt der Ausgabe der mit Rechten verbundenen Obligationen
festzusetzen; und
(c) die
mit Rechten verbundenen Obligationen sind höchstens während 30 Jahren ab
dem jeweiligen Zeitpunkt der betreffenden Ausgabe oder des betreffenden
Abschlusses wandel-, tausch- oder ausübbar.
|
3
|
The
Board of Directors shall be authorized to withdraw or limit the advance
subscription rights of the shareholders in connection with the issuance by
the Company or one of its group companies of Rights-Bearing Obligations if
(1) the issuance is for purposes of financing or refinancing the
acquisition of an enterprise, parts of an enterprise, participations or
investments or (2) the issuance occurs in national or international
capital markets or through a private placement.
If the
advance subscription rights are neither granted directly nor indirectly by
the Board of Directors, the following shall apply:
(a) The
Rights-Bearing Obligations shall be issued or entered into at market
conditions; and
(b) the
conversion, exchange or exercise price of the Rights-Bearing Obligations
shall be set with reference to the market conditions prevailing at the
date on which the Rights-Bearing Obligations are issued; and
(c) the
Rights-Bearing Obligations may be converted, exchanged or exercised during
a maximum period of 30 years from the date of the relevant issuance or
entry.
|
||
- 7 -
|
|||||
4
|
Bei
der Ausgabe von Aktien oder mit Rechten verbundenen Obligationen gemäss
Artikel 6 Absatz 1(b) dieser Statuten sind das Bezugsrecht wie auch
das Vorwegzeichnungsrecht der Aktionäre der Gesellschaft ausgeschlossen.
Die Ausgabe von Aktien oder mit Rechten verbundenen Obligationen an die in Artikel
6 Absatz 1(b) dieser Statuten genannten Personen erfolgt gemäss einem
oder mehreren Beteiligungsplänen der Gesellschaft. Die Ausgabe von Aktien
an die Artikel 6 Absatz 1(b) dieser Statuten genannten Personen kann
zu einem Preis erfolgen, der unter dem Kurs der Börse liegt, an der die
Aktien gehandelt werden, muss aber mindestens zum Nennwert
erfolgen.
|
4
|
The
preemptive rights and advance subscription rights of the shareholders
shall be excluded in connection with the issuance of any Shares or
Rights-Bearing Obligations pursuant to Article 6 para 1(b) of
these Articles of Association. Shares or Rights-Bearing
Obligations shall be issued to any of the persons referred to in Article
6 para 1(b) of these Articles of Association in accordance with
one or more benefit or incentive plans of the Company. Shares
may be issued to any of the persons referred to in Article
6 para 1(b) of these Articles of Association at a price lower
than the current market price quoted on the stock exchange on which the
Shares are traded, but at least at par value.
|
||
5
|
Die
neuen Aktien, welche über die Ausübung von mit Rechten verbundenen
Obligationen erworben werden, unterliegen den
Eintragungsbeschränkungen in das Aktienbuch gemäss Artikel 7 und 9
dieser Statuten.
|
5
|
The
new Shares acquired through the exercise of Rights-Bearing Obligations
shall be subject to the limitations for registration in the share register
pursuant to Articles 7 and 9 of these Articles of
Association.
|
||
Artikel
7
|
Article
7
|
||||
Aktienbuch,
Rechtsausübung, Eintragungsbe-schränkungen, Nominees
|
1
|
Die
Gesellschaft oder von ihr beauftragte Dritte führen ein Aktienbuch. Darin
werden die Eigentümer und Nutzniesser der Aktien sowie Nominees mit Namen
und Vornamen, Wohnort, Adresse und Staatsangehörigkeit (bei juristischen
Personen mit Firma und Sitz) eingetragen. Die Gesellschaft oder der von
ihr mit der Aktienbuchführung beauftragte Dritte ist berechtigt, bei
Eintragung im Aktienbuch von der antragstellenden Person einen
angemessenen Nachweis seiner Berechtigung an den Aktien zu verlangen.
Ändert eine im Aktienbuch eingetragene Person ihre Adresse, so hat sie
dies dem Aktienbuchführer mitzuteilen. Solange dies nicht geschehen ist,
gelten alle brieflichen Mitteilungen der Gesellschaft an die im Aktienbuch
eingetragenen Personen als rechtsgültig an die bisher im Aktienbuch
eingetragene Adresse erfolgt.
|
Share
Register, Exercise of Rights, Restrictions on Registration,
Nominees
|
1
|
The
Company shall maintain, itself or through a third party, a share register
that lists the surname, first name, address and citizenship (in the case
of legal entities, the company name and company seat) of the holders and
usufructuaries of the Shares as well as the nominees. The
Company or the third party maintaining the share register on behalf of the
Company shall be entitled to request at the time of the entry into the
share register from the Person requesting such entry appropriate evidence
of that Person's title to the Shares. A person recorded in
the share register shall notify the share registrar of any change in
address. Until such notification shall have occurred, all
written communication from the Company to persons of record shall be
deemed to have validly been made if sent to the address recorded in the
share register.
|
- 8 -
|
|||||
2
|
Ein
Erwerber von Aktien wird auf Gesuch als Aktionär mit Stimmrecht im
Aktienbuch eingetragen, vorausgesetzt, dass ein solcher Erwerber
ausdrücklich erklärt, die Aktien im eigenen Namen und auf eigene Rechnung
erworben zu haben. Der Verwaltungsrat kann Nominees, welche Aktien im
eigenen Namen aber auf fremde Rechnung halten, als Aktionäre mit
Stimmrecht im Aktienbuch der Gesellschaft eintragen. Die an den Aktien
wirtschaftlich Berechtigten, welche die Aktien über einen Nominee halten,
üben Aktionärsrechte mittelbar über den Nominee aus.
|
2
|
An
acquirer of Shares shall be recorded upon request in the share register as
a shareholder with voting rights; provided, however, that
any such acquirer expressly declares to have acquired the Shares in its
own name and for its own account, save that the Board of Directors may
record nominees who hold Shares in their own name, but for the account of
third parties, as shareholders of record with voting rights in the share
register of the Company. Beneficial owners of Shares who hold
Shares through a nominee exercise the shareholders' rights through the
intermediation of such nominee.
|
||
3
|
Der
Verwaltungsrat kann nach Anhörung des eingetragenen Aktionärs dessen
Eintragung im Aktienbuch als Aktionär mit Stimmrecht mit Rückwirkung auf
das Datum der Eintragung streichen, wenn diese durch falsche oder
irreführende Angaben zustande gekommen ist. Der Betroffene muss über die
Streichung sofort informiert werden.
|
3
|
After
hearing the registered shareholder concerned, the Board of Directors may
cancel the registration of such shareholder as a shareholder with voting
rights in the share register with retroactive effect as of the date of
registration, if such registration was made based on false or misleading
information. The relevant shareholder shall be informed
promptly of the cancellation.
|
||
Artikel
8
|
Article
8
|
||||
Form
der Aktien
|
1
|
Die
Gesellschaft gibt Aktien in Form von Einzelurkunden, Globalurkunden oder
Wertrechten aus. Der Gesellschaft steht es im Rahmen der gesetzlichen
Vorgaben frei, ihre in einer dieser Formen ausgegebenen Aktien jederzeit
und ohne Zustimmung der Aktionäre in eine andere Form umzuwandeln. Die
Gesellschaft trägt die Kosten, die bei einer solchen Umwandlung
anfallen.
|
Form of
Shares
|
1
|
The
Company may issue Shares in the form of individual certificates, global
certificates or uncertificated securities. Subject to applicable law, the
Company may convert the Shares from one form into another form at any time
and without the approval of the shareholders. The Company shall bear all
cost associated with any such conversion.
|
- 9 -
|
|||||
2
|
Ein
Aktionär hat keinen Anspruch auf Umwandlung von in bestimmter Form
ausgegebenen Aktien in eine andere Form. Jeder Aktionär kann jedoch
jederzeit die Ausstellung einer Bescheinigung über die von ihm gemäss
Aktienbuch gehaltenen Namenaktien verlangen.
|
2
|
A
shareholder has no right to request a conversion of the Shares from one
form into another form. Each shareholder may, however, at any time request
a written attestation of the number of Shares held by it as reflected in
the share register.
|
||
3
|
Werden
Bucheffekten im Auftrag der Gesellschaft oder des Aktionärs
von einer Verwahrungsstelle, einem Registrar, Transfer Agenten, einer
Trust Gesellschaft, Bank oder einer ähnlichen Gesellschaft verwaltet (die
Verwahrungsstelle), so
setzt Wirksamkeit gegenüber der Gesellschaft voraus, dass diese
Bucheffekten und die damit verbundenen Rechte unter Mitwirkung der
Verwahrungsstelle übertragen oder daran Sicherheiten bestellt
werden.
|
3
|
If
intermediated securities are administered on behalf of the Company or a
shareholder by an intermediary, registrar, transfer agent, trust company,
bank or similar entity (the Intermediary), any
transfer or grant of a security interest in such intermediated securities
and the appurtenant rights associated therewith, in order for such
transfer or grant of a security interest to be valid against the Company,
requires the cooperation of the Intermediary.
|
||
4
|
Für
den Fall, dass die Gesellschaft beschliesst, Aktienzertifikate zu drucken
und auszugeben, müssen die Aktienzertifikate die Unterschrift von zwei
zeichnungsberechtigten Personen tragen. Mindestens eine dieser Personen
muss ein Mitglied des Verwaltungsrates sein. Faksimile-Unterschriften sind
erlaubt.
|
4
|
If the
Company decides to print and deliver share certificates, the share
certificates shall bear the signatures of two duly authorized signatories
of the Company, at least one of which shall be a member of the Board of
Directors. These signatures may be facsimile
signatures.
|
||
Artikel
9
|
Article
9
|
||||
Rechtsausübung
|
1
|
Die
Gesellschaft anerkennt nur einen Vertreter pro Aktie.
|
Exercise
of Rights
|
1
|
The
Company shall only accept one representative per Share.
|
2
|
Stimmrechte
und die damit verbundenen Rechte können der Gesellschaft gegenüber von
einem Aktionär, Nutzniesser der Aktien oder Nominee jeweils nur im Umfang
ausgeübt werden, wie dieser mit Stimmrecht im Aktienbuch eingetragen
ist.
|
2
|
Voting
rights and appurtenant rights associated therewith may be exercised in
relation to the Company by a shareholder, usufructuary of Shares or
nominee only to the extent that such person is recorded in the share
register with the right to exercise his voting rights.
|
||
Abschnitt
3:
Gesellschaftsorgane
A.
Generalversammlung
|
Section
3:
Corporate
Bodies
A.
General Meeting of Shareholders
|
||||
- 10 -
|
|||||
Artikel
10
|
Article
10
|
||||
Zuständigkeit
|
Die
Generalversammlung ist das oberste Organ der Gesellschaft.
|
Authority
|
The
General Meeting of Shareholders is the supreme corporate body of the
Company.
|
||
Artikel
11
|
Article
11
|
||||
Ordentliche
Generalver-sammlung
|
Die
ordentliche Generalversammlung findet alljährlich innerhalb von sechs
Monaten nach Schluss des Geschäftsjahres statt. Spätestens zwanzig
Kalendertage vor der Versammlung sind der Geschäftsbericht und der
Revisionsbericht den Aktionären am Gesellschaftssitz zur Einsicht
aufzulegen. Jeder Aktionär kann verlangen, dass ihm unverzüglich eine
Ausfertigung des Geschäftsberichts und des Revisionsberichts ohne
Kostenfolge zugesandt wird. Die im Aktienbuch eingetragenen Aktionäre
werden über die Verfügbarkeit des Geschäftsberichts und des
Revisionsberichts durch schriftliche Mitteilung
unterrichtet.
|
Annual
General Meeting
|
The
Annual General Meeting shall be held each year within six months after the
close of the fiscal year of the Company. The Annual Report and the
Auditor's Report shall be made available for inspection by the
shareholders at the registered office of the Company no later than twenty
calendar days prior to the Annual General Meeting. Each
shareholder is entitled to request prompt delivery of a copy of the Annual
Report and the Auditor's Report free of charge. Shareholders of
record will be notified of the availability of the Annual Report and the
Auditor's Report in writing.
|
||
Artikel
12
|
Article
12
|
||||
Ausser-ordentliche
Generalversammlung
|
1
|
Ausserordentliche
Generalversammlungen finden in den vom Gesetz vorgesehenen Fällen statt,
insbesondere, wenn der Verwaltungsrat es für notwendig oder angezeigt
erachtet oder die Revisionsstelle dies verlangt.
|
Extraordinary
General Meetings
|
1
|
Extraordinary
General Meetings shall be held in the circumstances provided by law, in
particular when deemed necessary or appropriate by the Board of Directors
or if so requested by the Auditor.
|
2
|
Ausserdem
muss der Verwaltungsrat eine ausserordentliche Generalversammlung
einberufen, wenn es eine Generalversammlung so beschliesst oder wenn ein
oder mehrere Aktionäre, welche zusammen mindestens den zehnten Teil des im
Handelsregister eingetragenen Aktienkapitals vertreten, dies verlangen,
unter der Voraussetzung, dass folgende Angaben gemacht werden:
(a)(1) die Verhandlungsgegenstände, schriftlich unterzeichnet von
dem/den antragstellenden Aktionär(en), (2) die Anträge sowie
(3) der Nachweis der erforderlichen Anzahl der im Aktienbuch
eingetragenen Aktien; und (b) die weiteren Informationen, die von der
Gesellschaft nach den Regeln der U.S. Securities and Exchange Commission
(SEC) in einem
sog. Proxy Statement aufgenommen und
veröffentlicht werden müssen.
|
2
|
An
Extraordinary General Meeting shall further be convened by the Board of
Directors upon resolution of a General Meeting of Shareholders or if so
requested by one or more shareholders who, in the aggregate, represent at
least one-tenth of the share capital recorded in the Commercial Register
and who submit (a)(1) a request signed by such shareholder(s) that
specifies the item(s) to be included on the agenda, (2) the
respective proposals of the shareholders and (3) evidence of the
required shareholdings recorded in the share register and (b) such
other information as would be required to be included in a proxy statement
pursuant to the rules of the U.S. Securities and Exchange Commission
(SEC).
|
||
- 11 -
|
|||||
Artikel
13
|
Article
13
|
||||
Einberufung
|
1
|
Die
Generalversammlung wird durch den Verwaltungsrat, nötigenfalls die
Revisionsstelle, spätestens 20 Kalendertage vor dem Tag der
Generalversammlung einberufen. Die Einberufung erfolgt durch einmalige
Bekanntmachung im Publikationsorgan der Gesellschaft gemäss
Artikel 32 dieser Statuten. Für die Einhaltung der Einberufungsfrist
ist der Tag der Veröffentlichung der Einberufung im Publikationsorgan
massgeblich, wobei der Tag der Veröffentlichung nicht mitzuzählen ist. Die
im Aktienbuch eingetragenen Aktionäre können zudem auf dem ordentlichen
Postweg über die Generalversammlung informiert werden.
|
Notice
of Shareholders' Meetings
|
1
|
Notice
of a General Meeting of Shareholders shall be given by the Board of
Directors or, if necessary, by the Auditor, no later than twenty calendar
days prior to the date of the General Meeting of
Shareholders. Notice of the General Meeting of Shareholders
shall be given by way of a one-time announcement in the official means of
publication of the Company pursuant to Article 32 of these Articles
of Association. The notice period shall be deemed to have been
observed if notice of the General Meeting of Shareholders is published in
such official means of publication, it being understood that the date of
publication is not to be included for purposes of computing the notice
period. Shareholders of record may in addition be informed of
the General Meeting of Shareholders by ordinary mail.
|
2
|
Die
Einberufung muss die Verhandlungsgegenstände sowie die Anträge des
Verwaltungsrates und des oder der Aktionäre, welche die Durchführung einer
Generalversammlung oder die Traktandierung eines Verhandlungsgegenstandes
verlangt haben, und bei Wahlgeschäften die Namen des oder der zur Wahl
vorgeschlagenen Kandidaten enthalten.
|
2
|
The
notice of a General Meeting of Shareholders shall specify the items on the
agenda and the proposals of the Board of Directors and the shareholder(s)
who requested that a General Meeting of Shareholders be held or an item be
included on the agenda, and, in the event of elections, the name(s) of the
candidate(s) that has or have been put on the ballot for
election.
|
||
Artikel
14
|
Article
14
|
||||
Traktandierung
|
1
|
Jeder
Aktionär kann die Traktandierung eines Verhandlungsgegenstandes verlangen.
Das Traktandierungsbegehren muss mindestens 30 Kalendertage vor dem
Jahrestag des sog. Proxy Statements der Gesellschaft,
das im Zusammenhang mit der Generalversammlung im jeweiligen Vorjahr
veröffentlicht und gemäss den anwendbaren SEC Regeln bei der SEC
eingereicht wurde, schriftlich unter Angabe des Verhandlungsgegenstandes
und der Anträge sowie unter Nachweis der erforderlichen Anzahl im
Aktienbuch eingetragenen Aktien eingereicht werden. Falls das Datum der
anstehenden Generalversammlung mehr als 30 Kalendertage vor oder nach dem
Jahrestag der vorangegangenen Generalversammlung angesetzt worden ist, ist
das Traktandierungsbegehren stattdessen spätestens 10 Kalendertage nach
dem Tag einzureichen, an dem die Gesellschaft das Datum der
Generalversammlung öffentlich bekannt gemacht hat.
|
Agenda
|
1
|
Any
shareholder may request that an item be included on the agenda of a
General Meeting of Shareholders. An inclusion of an item on the
agenda must be requested in writing at least 30 calendar days prior to the
anniversary date of the Company's proxy statement in connection with the
previous year's General Meeting of Shareholders, as filed with the SEC
pursuant to the applicable rules of the SEC, and shall specify in writing
the relevant agenda items and proposals, together with evidence of the
required shareholdings recorded in the share register; provided, however, that
if the date of the General Meeting of Shareholders is more than 30
calendar days before or after such anniversary date, such request must
instead be made at least by the 10th
calendar day following the date on which the Company has made public
disclosure of the date of the General Meeting of
Shareholders.
|
- 12 -
|
|||||
2
|
Zu
nicht gehörig angekündigten Verhandlungsgegenständen können keine
Beschlüsse gefasst werden. Hiervon ausgenommen sind jedoch der Beschluss
über den in einer Generalversammlung gestellten Antrag auf
(i) Einberufung einer ausserordentlichen Generalversammlung sowie
(ii) Durchführung einer Sonderprüfung gemäss Artikel 697a des
Schweizerischen Obligationenrechts (OR).
|
2
|
No
resolution may be passed at a General Meeting of Shareholders concerning
an agenda item in relation to which due notice was not
given. Proposals made during a General Meeting of Shareholders
to (i) convene an Extraordinary General Meeting or (ii) initiate
a special investigation in accordance with article 697a of the Swiss
Code of Obligations (CO) are not subject to
the due notice requirement set forth herein.
|
||
3
|
Zur
Stellung von Anträgen im Rahmen der Verhandlungsgegenstände und zu
Verhandlungen ohne Beschlussfassung bedarf es keiner vorgängigen
Ankündigung.
|
3
|
No
prior notice is required to bring motions related to items already on the
agenda or for the discussion of matters on which no resolution is to be
taken.
|
||
Artikel
15
|
Article
15
|
||||
Vorsitz
der Generalver-sammlung, Protokoll, Stimmenzähler
|
1
|
An der
Generalversammlung führt der Präsident des Verwaltungsrates oder, bei
dessen Verhinderung, der Vizepräsident oder eine andere vom Verwaltungsrat
bezeichnete Person den Vorsitz.
|
Acting
Chair, Minutes, Vote Counters
|
1
|
At the
General Meeting of Shareholders the Chairman of the Board of Directors or,
in his absence, the Vice-Chairman or any other person designated by the
Board of Directors, shall take the chair.
|
2
|
Der
Vorsitzende der Generalversammlung bestimmt den Protokollführer und die
Stimmenzähler, die alle nicht Aktionäre sein müssen. Das Protokoll ist vom
Vorsitzenden und vom Protokollführer zu unterzeichnen.
|
2
|
The
acting chair of the General Meeting of Shareholders shall appoint the
secretary and the vote counters, none of whom need be
shareholders. The minutes of the General Meeting of
Shareholders shall be signed by the acting chair and the
secretary.
|
||
- 13 -
|
|||||
3
|
Der
Vorsitzende der Generalversammlung hat sämtliche Leitungsbefugnisse, die
für die ordnungsgemässe Durchführung der Generalversammlung nötig und
angemessen sind.
|
3
|
The
acting chair of the General Meeting of Shareholders shall have all powers
and authority necessary and appropriate to ensure the orderly conduct of
the General Meeting of Shareholders.
|
||
Artikel
16
|
Article
16
|
||||
Recht
auf Teilnahme, Vertretung der Aktionäre
|
Jeder
im Aktienbuch eingetragene Aktionär ist berechtigt, an der
Generalversammlung und deren Beschlüssen teilzunehmen. Ein Aktionär kann
sich an der Generalversammlung vertreten lassen, wobei der Vertreter nicht
Aktionär sein muss. Der Verwaltungsrat regelt die Einzelheiten über die
Vertretung und Teilnahme an der Generalversammlung in
Verfahrensvorschriften.
|
Right
to Participation and Representation
|
Each
shareholder recorded in the share register is entitled to participate at
the General Meeting of Shareholders and in any vote taken. The
shareholders may be represented by proxies who need not be
shareholders. The Board of Directors shall issue the
particulars of the right to representation and participation at the
General Meeting of Shareholders in procedural rules.
|
||
Artikel
17
|
Article
17
|
||||
Stimmrecht
|
Jede
Aktie berechtigt zu einer Stimme. Das Stimmrecht untersteht den
Bedingungen von Artikel 7 und 9 dieser Statuten.
|
Voting
Rights
|
Each
Share shall convey the right to one vote. The right to vote is
subject to the conditions of Articles 7and 9 of these Articles of
Association.
|
||
Artikel
18
|
Article
18
|
||||
Beschlüsse
und Wahlen
|
1
|
Die
Generalversammlung fasst Beschlüsse und entscheidet Wahlen, soweit das
Gesetz oder diese Statuten es nicht anders bestimmen, mit der relativen
Mehrheit der abgegebenen Aktienstimmen (wobei Enthaltungen, sog. Broker
Nonvotes, leere oder ungültige Stimmen für die Bestimmung des Mehrs nicht
berücksichtigt werden).
|
Resolutions
and Elections
|
1
|
Unless
otherwise required by law or these Articles of Association, the General
Meeting of Shareholders shall take resolutions and decide elections upon a
relative majority of the votes cast at the General Meeting of Shareholders
(whereby abstentions, broker nonvotes, blank or invalid ballots shall be
disregarded for purposes of establishing the majority).
|
- 14 -
|
|||||
2
|
Die
Generalversammlung entscheidet über die Wahl von Mitgliedern des
Verwaltungsrates nach dem proportionalen Wahlverfahren, wonach diejenige
Person, welche die grösste Zahl der abgegebenen Aktienstimmen für einen
Verwaltungsratssitz erhält, als für den betreffenden Verwaltungsratssitz
gewählt gilt. Aktienstimmen gegen einen Kandidaten, Stimmenthaltungen,
sog. Broker Nonvotes, ungültige oder leere Stimmen haben für die Zwecke
dieses Artikels 18 Abs. 2 keine Auswirkungen auf die Wahl
von Mitgliedern des Verwaltungsrates.
|
2
|
The
General Meeting of Shareholders shall decide elections of members of the
Board of Directors upon a plurality of the votes cast at the General
Meeting of Shareholders. A plurality means that the individual who
receives the largest number of votes for a board seat is elected to that
board seat. Votes against any candidate, abstentions, broker
nonvotes, blank or invalid ballots shall have no impact on the election of
members of the Board of Directors under this
Article 18 para. 2.
|
||
3
|
Für
die Abwahl von amtierenden Mitgliedern des Verwaltungsrates gilt das
Mehrheitserfordernis gemäss Artikel 20 Abs. 2(e) sowie das
Präsenzquorum von Artikel 21 Abs. 1(a).
|
3
|
For
the removal of a serving member of the Board of Directors, the voting
requirement set forth in Article 20 para. 2(e) and the presence
quorum set forth in Article 21 para. 1(a) shall
apply.
|
||
4
|
Die
Abstimmungen und Wahlen erfolgen offen, es sei denn, dass die
Generalversammlung schriftliche Abstimmung respektive Wahl beschliesst
oder der Vorsitzende dies anordnet. Der Vorsitzende kann Abstimmungen und
Wahlen auch mittels elektronischem Verfahren durchführen
lassen. Elektronische Abstimmungen und Wahlen sind
schriftlichen Abstimmen und Wahlen gleichgestellt.
|
4
|
Resolutions
and elections shall be decided by a show of hands, unless a written ballot
is resolved by the General Meeting of Shareholders or is ordered by the
acting chair of the General Meeting of Shareholders. The acting
chair may also hold resolutions and elections by use of an electronic
voting system. Electronic resolutions and elections shall be
considered equal to resolutions and elections taken by way of a written
ballot.
|
||
5
|
Der
Vorsitzende kann eine offene Wahl oder Abstimmung immer durch eine
schriftliche oder elektronische wiederholen lassen, sofern nach seiner
Meinung Zweifel am Abstimmungsergebnis bestehen. In diesem Fall gilt die
vorausgegangene offene Wahl oder Abstimmung als nicht
geschehen.
|
5
|
The
chair of the General Meeting of Shareholders may at any time order that an
election or resolution decided by a show of hands be repeated by way of a
written or electronic ballot if he considers the vote to be in
doubt. The resolution or election previously held by a show of
hands shall then be deemed to have not taken place.
|
||
- 15 -
|
|||||
Artikel
19
|
Article
19
|
||||
Befugnisse
der Generalver-sammlung
|
Der
Generalversammlung sind folgende Geschäfte vorbehalten:
(a) Die
Festsetzung und Änderung dieser Statuten;
(b) die
Wahl der Mitglieder des Verwaltungsrates und der
Revisionsstelle;
(c) die
Genehmigung des Jahresberichtes und der Konzernrechnung;
(d) die
Genehmigung der Jahresrechnung sowie die Beschlussfassung über die
Verwendung des Bilanzgewinnes, insbesondere die Festsetzung der
Dividende;
(e) die
Entlastung der Mitglieder des Verwaltungsrates;
(f) die
Genehmigung eines Zusammenschlusses mit einem Nahestehenden Aktionär
(gemäss der Definition dieser Begriffe in Artikel 35 dieser
Statuten); und
(g) die
Beschlussfassung über die Gegenstände, die der Generalversammlung durch
das Gesetz oder die Statuten vorbehalten sind oder ihr, vorbehältlich
Artikel 716a OR, durch den Verwaltungsrat vorgelegt
werden.
|
Powers
of the General Meeting of Shareholders
|
The
following powers shall be vested exclusively in the General Meeting of
Shareholders:
(a) The
adoption and amendment of these Articles of Association;
(b) the
election of the members of the Board of Directors and the
Auditor;
(c) the
approval of the Annual Report and the Consolidated Financial
Statements;
(d) the
approval of the Annual Statutory Financial Statements of the Company and
the resolution on the allocation of profit shown on the Annual Statutory
Balance Sheet, in particular the determination of any
dividend;
(e) the
discharge from liability of the members of the Board of
Directors;
(f) the
approval of a Business Combination with an Interested Shareholder (as each
such term is defined in Article 35 of these Articles of Association);
and
(g) the
adoption of resolutions on matters that are reserved to the General
Meeting of Shareholders by law, these Articles of Association or, subject
to article 716a CO, that are submitted to the General Meeting of
Shareholders by the Board of Directors.
|
||
- 16 -
|
|||||
Artikel
20
|
Article
20
|
||||
Besonderes
Quorum
|
1
|
Ein
Beschluss der Generalversammlung, der mindestens zwei Drittel der an der
Generalversammlung vertretenen Stimmen und die absolute Mehrheit der an
der Generalversammlung vertretenen Aktiennennwerte auf sich vereinigt, ist
erforderlich für:
(a) Die
Ergänzung oder Änderung des Gesellschaftszweckes gemäss Artikel 2
dieser Statuten;
(b) die
Einführung und Abschaffung von Stimmrechtsaktien;
(c) die
Beschränkung der Übertragbarkeit der Aktien und die Aufhebung einer solche
Beschränkung;
(d) die
Beschränkung der Ausübung des Stimmrechts und die Aufhebung einer solchen
Beschränkung;
(e) eine
genehmigte oder bedingte Kapitalerhöhung;
(f) die
Kapitalerhöhung (i) aus Eigenkapital, (ii) gegen Sacheinlage oder zwecks
Sachübernahme oder (iii) die Gewährung von besonderen
Vorteilen;
(g) die
Einschränkung oder Aufhebung des Bezugsrechts;
(h) die
Verlegung des Sitzes der Gesellschaft;
(i) die
Umwandlung von Namen- in Inhaberaktien und umgekehrt; und
(j) die
Auflösung der Gesellschaft.
|
Special
Vote
|
1
|
The
approval of at least two-thirds of the votes and the absolute majority of
the par value of Shares, each as represented at a General Meeting of
Shareholders, shall be required for resolutions with respect
to:
(a) The
amendment or modification of the purpose of the Company as described in
Article 2 of these Articles of Association;
(b) the
creation and the cancelation of shares with privileged voting
rights;
(c) the
restriction on the transferability of Shares and the cancelation of such
restriction;
(d) the
restriction on the exercise of the right to vote and the cancelation of
such restriction;
(e) an
authorized or conditional increase in share capital;
(f) an
increase in share capital (i) through the conversion of capital surplus,
(ii) through contribution in kind or for purposes of an acquisition of
assets, or (iii) the granting of special privileges;
(g) the
limitation on or withdrawal of preemptive rights;
(h) the
relocation of the registered office of the Company;
(i) the
conversion of registered shares into bearer shares and vice versa;
and
(j) the
dissolution of the Company.
|
2
|
Ein
Beschluss der Generalversammlung, der mindestens zwei Drittel aller
stimmberechtigten Aktien auf sich vereinigt, ist erforderlich
für:
|
2
|
The
approval of at least two-thirds of the Shares entitled to vote shall be
required for:
|
||
- 17 -
|
|||||
(a) Jede
Änderung von Artikel 14 Abs. 1 dieser Statuten;
|
(a) Any
change to Article 14 para. 1 of these Articles of
Association;
|
||||
(b) jede
Änderung von Artikel 18 dieser Statuten;
|
(b) any
change to Article 18 of these Articles of Association;
|
||||
(c) jede
Änderung dieses Artikels 20 Abs. 2;
|
(c) any
change to this Article 20 para. 2;
|
||||
(d)jede
Änderung von Artikel 21, 22, 23 oder 24 dieser Statuten;
und
|
(d)any
change to Article 21, 22, 23 or 24 of these Articles of Association;
and
|
||||
(e)die
Abwahl eines amtierenden Mitglieds des Verwaltungsrates.
|
(e)a
resolution with respect to the removal of a serving member of the Board of
Directors.
|
||||
3
|
Zusätzlich
zu etwaigen gesetzlich bestehenden Zustimmungserfordernissen ist ein
Beschluss der Generalversammlung mit einer Mehrheit, die mindestens die
Summe von: (i) zwei Drittel aller stimmberechtigten Aktien; zuzüglich
(ii) einer Zahl von stimmberechtigten Aktien, die einem Drittel der
von Nahestehenden Aktionären (wie in Artikel 35 dieser Statuten
definiert) gehaltenen Aktienstimmen entspricht, auf sich vereinigt,
erforderlich für (1) jeden Zusammenschluss der Gesellschaft mit einem
Nahestehenden Aktionär innerhalb eines Zeitraumes von drei Jahren, seitdem
diese Person zu einem Nahestehenden Aktionär wurde, (2) jede Änderung
von Artikel 19(f) dieser Statuten oder (3) jede Änderung von
Artikel 20 Abs. 3 dieser Statuten (einschliesslich der
dazugehörigen Definitionen in Artikel 35 dieser Statuten). Das im
vorangehenden Satz aufgestellte Zustimmungserfordernis ist jedoch nicht
anwendbar falls:
|
3
|
In
addition to any approval that may be required under applicable law, the
approval of a majority at least equal to the sum of: (i) two-thirds of the
Shares entitled to vote; plus (ii) a number of Shares entitled to vote
that is equal to one-third of the number of Shares held by Interested
Shareholders (as defined in Article 35 of these Articles of
Association), shall be required for the Company to (1) engage in any
Business Combination with an Interested Shareholder for a period of three
years following the time that such Person became an Interested
Shareholder, (2) amend Article 19(f) of these Articles of Association
or (3) amend this Article 20 para. 3 of these Articles
of Association (including any of the definitions pertaining thereto as set
forth in Article 35 of these Articles of Association); provided, however, that
the approval requirement in the preceding sentence shall not apply
if:
|
||
- 18 -
|
|||||
(a) der
Verwaltungsrat, bevor diese Person zu einem Nahestehenden Aktionär wurde,
entweder den Zusammenschluss oder eine andere Transaktion genehmigte, als
Folge derer diese Person zu einem Nahestehenden Aktionär
wurde;
|
(a) Prior
to such time that such Person became an Interested Shareholder, the Board
of Directors approved either the Business Combination or the transaction
which resulted in such Person becoming an Interested
Shareholder;
|
||||
(b) nach
Vollzug der Transaktion, als Folge derer diese Person zu einem
Nahestehenden Aktionär wurde, der Nahestehende Aktionär mindestens 85% der
unmittelbar vor Beginn der betreffenden Transaktion allgemein
stimmberechtigten Aktien hält, wobei zur Bestimmung der Anzahl der
allgemein stimmberechtigten Aktien (nicht jedoch zur Bestimmung der durch
den Nahestehenden Aktionär gehaltenen Aktien) folgende Aktien nicht zu
berücksichtigen sind: Aktien, (x) welche von Personen gehalten
werden, die sowohl Verwaltungsrats- wie Geschäftsleitungsmitglieder sind,
und (y) welche für Mitarbeiteraktienpläne reserviert sind, soweit die
diesen Plänen unterworfenen Mitarbeiter nicht das Recht haben, unter
Wahrung der Vertraulichkeit darüber zu entscheiden, ob Aktien, die dem
betreffenden Mitarbeiteraktienplan unterstehen, in einem Übernahme- oder
Austauschangebot angedient werden sollen oder nicht;
|
(b) upon
consummation of the transaction which resulted in such Person becoming an
Interested Shareholder, the Interested Shareholder Owned at least 85% of
the Shares generally entitled to vote at the time the transaction
commenced, excluding for purposes of determining such number of Shares
then in issue (but not for purposes of determining the Shares Owned by the
Interested Shareholder), those Shares Owned (x) by Persons who are both
members of the Board of Directors and officers of the Company and (y) by
employee share plans in which employee participants do not have the right
to determine confidentially whether Shares held subject to the plan will
be tendered in a tender or exchange offer;
|
||||
(c) eine
Person unbeabsichtigterweise zu einem Nahestehenden Aktionär wird und
(x) das Eigentum an einer genügenden Anzahl Aktien sobald als möglich
veräussert, so dass sie nicht mehr länger als Nahestehender Aktionär
qualifiziert und (y) zu keinem Zeitpunkt während der drei dem
Zusammenschluss zwischen der Gesellschaft und dieser Person unmittelbar
vorangehenden Jahren als Nahestehender Aktionär gegolten hätte,
ausgenommen aufgrund des unbeabsichtigten Erwerbs der
Eigentümerschaft.
|
(c) a
Person becomes an Interested Shareholder inadvertently and (x) as soon as
practicable divests itself of Ownership of sufficient Shares so that such
Person ceases to be an Interested Shareholder and (y) would not, at any
time within the three-year period immediately prior to a Business
Combination between the Company and such Person, have been an Interested
Shareholder but for the inadvertent acquisition of Ownership;
|
||||
- 19 -
|
|||||
(d) der
Zusammenschluss vor Vollzug oder Verzicht auf und nach öffentlicher
Bekanntgabe oder der nach diesem Abschnitt erforderlichen Mitteilung (was
auch immer früher erfolgt) eine(r) beabsichtigten Transaktion
vorgeschlagen wird, welche (i) eine der Transaktionen im Sinne des
zweiten Satzes dieses Artikels 20 Abs. 3(d) darstellt;
(ii) mit oder von einer Person abgeschlossen wird, die entweder
während den letzten drei Jahren kein Nahestehender Aktionär war oder zu
einem Nahestehenden Aktionär mit der Genehmigung des Verwaltungsrates
wurde; und (iii) von einer Mehrheit der dannzumal amtierenden Mitglieder
des Verwaltungsrates (aber mindestens einem) genehmigt oder nicht
abgelehnt wird, die entweder bereits Verwaltungsratsmitglieder waren,
bevor in den drei vorangehenden Jahren irgendeine Person zu einem
Nahestehenden Aktionär wurde, oder die auf Empfehlung einer Mehrheit
solcher Verwaltungsratsmitglieder als deren Nachfolger zur Wahl
vorgeschlagen wurden. Die im vorangehenden Satz erwähnten beabsichtigen
Transaktionen sind auf folgende beschränkt: (x) eine Fusion oder
andere Form des Zusammenschlusses der Gesellschaft (mit Ausnahme einer
Fusion, welche keine Genehmigung durch die Generalversammlung der
Gesellschaft voraussetzt); (y) ein Verkauf, eine Vermietung oder
Verpachtung, hypothekarische Belastung oder andere Verpfändung,
Übertragung oder andere Verfügung (ob in einer oder mehreren
Transaktionen), einschliesslich im Rahmen eines Tauschs, von
Vermögenswerten der Gesellschaft oder einer direkten oder indirekten
Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird
(jedoch nicht an eine direkt oder indirekt zu 100% gehaltene
Konzerngesellschaft oder an die Gesellschaft), soweit diese Vermögenswerte
einen Marktwert von 50% oder mehr entweder des auf konsolidierter Basis
aggregierten Marktwertes aller Vermögenswerte der Gesellschaft oder des
aggregierten Marktwertes aller dann ausgegebenen Aktien haben, unabhängig
davon, ob eine dieser Transaktionen Teil einer Auflösung der Gesellschaft
ist oder nicht; oder (z) ein vorgeschlagenes Übernahme- oder
Umtauschangebot für 50% oder mehr der ausstehenden Stimmrechte der
Gesellschaft. Die Gesellschaft muss Nahestehenden Aktionären sowie den
übrigen Aktionären den Vollzug einer der unter (x) oder (y) des zweiten
Satzes dieses Artikels 20 Abs. 3(d) erwähnten Transaktionen
mindestens 20 Kalendertage vorher mitteilen.
|
(d) the
Business Combination is proposed prior to the consummation or abandonment
of and subsequent to the earlier of the public announcement or the notice
required hereunder of a proposed transaction which (i) constitutes
one of the transactions described in the second sentence of this
Article 20 para. 3(d); (ii) is with or by a person who
either was not an Interested Shareholder during the previous three years
or who became an Interested Shareholder with the approval of the Board of
Directors; and (iii) is approved or not opposed by a majority of the
members of the Board of Directors then in office (but not less than one)
who were Directors prior to any person becoming an Interested Shareholder
during the previous three years or were recommended for election to
succeed such Directors by a majority of such Directors. The
proposed transactions referred to in the preceding sentence are limited to
(x) a merger or consolidation of the Company (except for a merger in
respect of which no vote of the Company’s shareholders is required);
(y) a sale, lease, exchange, mortgage, pledge, transfer or other
disposition (in one transaction or a series of transactions), whether as
part of a dissolution or otherwise, of assets of the Company or of any
direct or indirect majority-Owned subsidiary of the Company (other than to
any direct or indirect wholly Owned subsidiary or to the Company) having
an aggregate market value equal to 50% or more of either that aggregate
market value of all of the assets of the Company determined on a
consolidated basis or the aggregate market value of all the issued shares;
or (z) a proposed tender or exchange offer for 50% or more of the
voting shares then in issue. The Company shall give not less
than 20 days' notice to all Interested Shareholders as well as to the
other shareholders prior to the consummation of any of the transactions
described in clause (x) or (y) of the second sentence of this
Article 20 para. 3(d).
|
||||
- 20 -
|
|||||
Artikel
21
|
Article
21
|
||||
Präsenzquorum
|
1
|
Die
nachfolgend aufgeführten Angelegenheiten erfordern zum Zeitpunkt der
Konstituierung der Generalversammlung ein Präsenzquorum von Aktionären
oder deren Vertretern, welche mindestens zwei Drittel des im
Handelsregister eingetragenen Aktienkapitals vertreten, damit die
Generalversammlung beschlussfähig ist:
(a)Die
Beschlussfassung über die Abwahl eines amtierenden
Verwaltungsratsmitglieds; und
(b)die
Beschlussfassung, diesen Artikel 21 oder Artikel 18, 19(f), 20, 22, 23
oder 24 dieser Statuten zu ergänzen, zu ändern, nicht anzuwenden oder
ausser Kraft zu setzen.
|
Presence
Quorum
|
1
|
The
matters set forth below require that a quorum of shareholders of record
holding in person or by proxy at least two-thirds of the share capital
recorded in the Commercial Register are present at the time when the
General Meeting of Shareholders proceeds to business:
(a)the
adoption of a resolution to remove a serving Director; and
(b)the
adoption of a resolution to amend, vary, suspend the operation of,
disapply or cancel this Article 21 or Articles 18, 19(f), 20, 22, 23
or 24 of these Articles of Association.
|
2
|
Jede
andere Beschlussfassung oder Wahl setzt zu ihrer Gültigkeit voraus, dass
zum Zeitpunkt der Konstituierung der Generalversammlung zumindest die
Mehrheit aller stimmberechtigten Aktien anwesend ist. Die Aktionäre können
mit der Behandlung der Traktanden fortfahren, selbst wenn Aktionäre nach
Bekanntgabe des Quorums durch den Vorsitzenden die Generalversammlung
verlassen und damit weniger als das geforderte Präsenzquorum an der
Generalversammlung verbleibt.
|
2
|
The
adoption of any other resolution or election requires that at least a
majority of all the Shares entitled to vote be represented at the time
when the General Meeting of Shareholders proceeds to
business. The shareholders present at a General Meeting of
Shareholders may continue to transact business, despite the withdrawal of
shareholders from such General Meeting of Shareholders following
announcement of the presence quorum at that meeting.
|
||
B.
Verwaltungsrat
|
B.
Board of Directors
|
||||
Artikel
22
|
Article
22
|
||||
Anzahl
der Verwaltungs-räte
|
Der
Verwaltungsrat besteht aus mindestens zwei und höchstens 14
Mitgliedern.
|
Number
of Directors
|
The
Board of Directors shall consist of no less than two and no more than 14
members.
|
||
- 21 -
|
|||||
Artikel
23
|
Article
23
|
||||
Amtsdauer
|
1
|
Die
Verwaltungsräte werden vom Verwaltungsrat in drei Klassen aufgeteilt,
welche als Klasse I, Klasse II und Klasse III bezeichnet werden. An jeder
ordentlichen Generalversammlung soll jede Klasse Verwaltungsräte, deren
Amtsdauer abläuft, für eine Amtsdauer von drei Jahren bzw. bis zur Wahl
eines Nachfolgers in sein Amt gewählt werden. Der Verwaltungsrat legt die
Reihenfolge der Wiederwahl fest, wobei die erste Amtszeit einer Klasse von
Verwaltungsräten auch weniger als drei Jahre betragen kann. Für die Zwecke
dieser Bestimmung ist unter einem Jahr der Zeitabschnitt zwischen zwei
ordentlichen Generalversammlungen zu verstehen.
|
Term of
Office
|
1
|
The
Board of Directors shall divide its members into three classes, designated
Class I, Class II and Class III. At each Annual General
Meeting, each class of the members of the Board of Directors whose term
shall then expire shall be elected to hold office for a three-year term or
until the election of their respective successor in office. The Board of
Directors shall establish the order of rotation, whereby the first term of
office of members of a particular Class may be less than three years. For
purposes of this provision, one year shall mean the period between two
Annual General Meetings of Shareholders.
|
2
|
Wenn
ein Verwaltungsratsmitglied vor Ablauf seiner Amtsdauer aus welchen
Gründen auch immer ersetzt wird, endet die Amtsdauer des an seiner Stelle
gewählten neuen Verwaltungsratsmitgliedes mit dem Ende der Amtsdauer
seines Vorgängers.
|
2
|
If,
before the expiration of his term of office, a Director should be replaced
for whatever reason, the term of office of the newly elected member of the
Board of Directors shall expire at the end of the term of office of his
predecessor.
|
||
Artikel
24
|
Article
24
|
||||
Organisation
des Verwaltungs-rates, Entschädigung
|
1
|
Der
Verwaltungsrat wählt aus seiner Mitte einen Vorsitzenden. Er kann einen
oder mehrere Vizepräsidenten wählen. Er bestellt weiter einen Sekretär,
welcher nicht Mitglied des Verwaltungsrates sein muss. Der Verwaltungsrat
regelt unter Vorbehalt der Bestimmungen des Gesetzes und dieser Statuten
die Einzelheiten seiner Organisation in einem
Organisationsreglement.
|
Organization
of the Board, Remuneration
|
1
|
The
Board of Directors shall elect from among its members a
Chairman. It may elect one or more Vice-Chairmen. It
shall further appoint a Secretary, who need not be a member of the Board
of Directors. Subject to applicable law and these Articles of
Association, the Board of Directors shall establish the particulars of its
organization in organizational regulations.
|
2
|
Die
Mitglieder des Verwaltungsrates haben Anspruch auf Ersatz ihrer im
Interesse der Gesellschaft aufgewendeten Auslagen sowie auf eine ihrer
Tätigkeit und Verantwortung entsprechende Entschädigung, die der
Verwaltungsrat auf Antrag eines Ausschusses des Verwaltungsrates
festlegt.
|
2
|
The
members of the Board of Directors shall be entitled to reimbursement of
all expenses incurred in the interest of the Company, as well as
remuneration for their services that is appropriate in view of their
functions and responsibilities. The amount of the remuneration
shall be determined by the Board of Directors upon recommendation by a
committee of the Board of Directors.
|
||
- 22 -
|
|||||
3
|
Soweit
gesetzlich zulässig, hält die Gesellschaft aktuelle und ehemalige
Mitglieder des Verwaltungsrates und der Geschäftsleitung sowie deren
Erben, Konkurs- oder Nachlassmassen aus Gesellschaftsmitteln für Schäden,
Verluste und Kosten aus drohenden, hängigen oder abgeschlossenen Klagen,
Verfahren oder Untersuchungen zivil-, straf- oder verwaltungsrechtlicher
oder anderer Natur schadlos, welche ihnen oder ihren Erben, Konkurs- oder
Nachlassmassen entstehen aufgrund von tatsächlichen oder behaupteten
Handlungen, Zustimmungen oder Unterlassungen im Zusammenhang mit der
Ausübung ihrer Pflichten oder behaupteten Pflichten oder aufgrund der
Tatsache, dass sie Mitglied des Verwaltungsrates oder der Geschäftsleitung
der Gesellschaft sind oder waren oder auf Aufforderung der Gesellschaft
als Mitglied des Verwaltungsrates, der Geschäftsleitung oder als
Arbeitnehmer oder Agent eines anderen Unternehmens, einer anderen
Gesellschaft, einer nicht-rechtsfähigen Personengesellschaft oder eines
Trusts sind oder waren. Diese Pflicht zur Schadloshaltung besteht nicht,
soweit in einem endgültigen, nicht weiterziehbaren Entscheid eines
zuständigen Gerichts bzw. einer zuständigen Verwaltungsbehörde entschieden
worden ist, dass eine der genannten Personen ihre Pflichten als Mitglied
des Verwaltungsrates oder der Geschäftsleitung absichtlich oder
grobfahrlässig verletzt hat.
|
3
|
The
Company shall indemnify and hold harmless, to the fullest extent permitted
by law, the existing and former members of the Board of Directors and
officers, and their heirs, executors and administrators, out of the assets
of the Company from and against all threatened, pending or completed
actions, suits or proceedings – whether civil, criminal, administrative or
investigative – and all costs, charges, losses, damages and expenses which
they or any of them, their heirs, executors or administrators, shall or
may incur or sustain by or by reason of any act done or alleged to be
done, concurred or alleged to be concurred in or omitted or alleged to be
omitted in or about the execution of their duty, or alleged duty, or by
reason of the fact that he is or was a member of the Board of Director or
officer of the Company, or while serving as a member of the Board of
Director or officer of the Company is or was serving at the request of the
Company as a director, officer, employee or agent of another corporation,
partnership, joint venture, trust or other enterprise; provided, however, that
this indemnity shall not extend to any matter in which any of said persons
is found, in a final judgment or decree of a court or governmental or
administrative authority of competent jurisdiction not subject to appeal,
to have committed an intentional or grossly negligent breach of his
statutory duties as a member of the Board of Director or
officer.
|
||
4
|
Ohne
den vorangehenden Absatz 3 dieses Artikels 24 einzuschränken, bevorschusst
die Gesellschaft Mitgliedern des Verwaltungsrates und der Geschäftsleitung
Gerichts- und Anwaltskosten. Die Gesellschaft kann solche Vorschüsse
zurückfordern, wenn ein zuständiges Gericht oder eine zuständige
Verwaltungsbehörde in einem endgültigen, nicht weiterziehbaren Urteil bzw.
Entscheid zum Schluss kommt, dass eine der genannten Personen ihre
Pflichten als Mitglied des Verwaltungsrates oder der Geschäftsleitung
absichtlich oder grobfahrlässig verletzt hat.
|
4
|
Without
limiting the foregoing paragraph 3 of this Article 24, the Company
shall advance court costs and attorneys' fees to the existing and former
members of the Board of Directors and officers. The Company may
however recover such advanced costs if any of said persons is found, in a
final judgment or decree of a court or governmental or administrative
authority of competent jurisdiction not subject to appeal, to have
committed an intentional or grossly negligent breach of his statutory
duties as a Director of officer.
|
||
- 23 -
|
|||||
|
Artikel
25
|
Article
25
|
|||
Befugnisse
des Verwaltungs-rates
|
1
|
Der
Verwaltungsrat hat die in Artikel 716a OR statuierten unübertragbaren
und unentziehbaren Aufgaben, insbesondere:
(a)die
Oberleitung der Gesellschaft und die Erteilung der nötigen
Weisungen;
(b)die
Festlegung der Organisation; und
(c)die
Oberaufsicht über die mit der Geschäftsführung betrauten Personen,
namentlich im Hinblick auf die Befolgung der Gesetze, Statuten, Reglemente
und Weisungen.
|
Specific
Powers
of the Board
|
1
|
The
Board of Directors has the non-delegable and inalienable duties as
specified in Article 716a CO, in particular:
(a)the
ultimate direction of the business of the Company and the issuance of the
required directives;
(b)the
determination of the organization of the Company; and
(c)the
ultimate supervision of the persons entrusted with management duties, in
particular with regard to compliance with law, these Articles of
Association, regulations and directives.
|
2
|
Der
Verwaltungsrat kann überdies in allen Angelegenheiten Beschluss fassen,
die nicht nach Gesetz oder Statuten der Generalversammlung zugeteilt
sind.
|
2
|
In
addition, the Board of Directors may pass resolutions with respect to all
matters that are not reserved to the General Meeting of Shareholders by
law or under these Articles of Association.
|
||
3
|
Der
Verwaltungsrat kann Beteiligungspläne der Gesellschaft der
Generalversammlung zur Genehmigung vorlegen.
|
3
|
The
Board of Directors may submit benefit or incentive plans of the Company to
the General Meeting of Shareholders for approval.
|
||
Artikel
26
|
Article
26
|
||||
Übertragung
von Befugnissen
|
Der
Verwaltungsrat kann unter Vorbehalt von Artikel 25 Abs. 1
dieser Statuten sowie der Vorschriften des OR die Geschäftsführung nach
Massgabe eines Organisationsreglements ganz oder teilweise an eines oder
mehrere seiner Mitglieder, an einen oder mehrere Ausschüsse des
Verwaltungsrates oder an Dritte übertragen.
|
Delegation
of Powers
|
Subject
to Article 25 para. 1 of these Articles of Association and the
applicable provisions of the CO, the Board of Directors may delegate the
management of the Company in whole or in part to individual directors, one
or more committees of the Board of Directors or to persons other than
Directors pursuant to organizational regulations.
|
||
- 24 -
|
|||||
Artikel
27
|
Article
27
|
||||
Sitzungen
des Verwaltungsrats
|
1
|
Sofern
das vom Verwaltungsrat erlassene Organisationsreglement nichts anderes
festlegt, ist zur gültigen Beschlussfassung über Geschäfte des
Verwaltungsrates die Anwesenheit einer Mehrheit der Mitglieder des
gesamten Verwaltungsrates notwendig. Kein Präsenzquorum ist erforderlich
für die Statutenanpassungs- und Feststellungsbeschlüsse des
Verwaltungsrates im Zusammenhang mit Kapitalerhöhungen.
|
Meeting
of the Board of Directors
|
1
|
Except
as otherwise set forth in organizational regulations of the Board of
Directors, the attendance quorum necessary for the transaction of the
business of the Board of Directors shall be a majority of the whole Board
of Directors. No attendance quorum shall be required for
resolutions of the Board of Directors providing for the confirmation of a
capital increase or for the amendment of the Articles of Association in
connection therewith.
|
2
|
Der
Verwaltungsrat fasst seine Beschlüsse mit einer Mehrheit der von den
anwesenden Verwaltungsräten abgegebenen Stimmen, vorausgesetzt, das
Präsenzquorum von Absatz 1 dieses Artikels 27 ist erfüllt. Der
Vorsitzende hat bei Stimmengleichheit keinen
Stichentscheid.
|
2
|
The
Board of Directors shall pass its resolutions with the majority of the
votes cast by the Directors present at a meeting at which the attendance
quorum of para. 1 of this Article 27 is
satisfied. The Chairman shall have no casting
vote.
|
||
Artikel
28
|
Article
28
|
||||
Zeichnungs-berechtigung
|
Die
rechtsverbindliche Vertretung der Gesellschaft durch Mitglieder des
Verwaltungsrates und durch Dritte wird in einem Organisationsreglement
festgelegt.
|
Signature
Power
|
The
due and valid representation of the Company by members of the Board of
Directors and other persons shall be set forth in organizational
regulations.
|
||
C.
Revisionsstelle
|
C.
Auditor
|
||||
Artikel
29
|
Article
29
|
||||
Amtsdauer,
Befugnisse und Pflichten
|
1
|
Die
Revisionsstelle wird von der Generalversammlung gewählt und es obliegen
ihr die vom Gesetz zugewiesenen Befugnisse und Pflichten.
|
Term,
Powers and Duties
|
1
|
The
Auditor shall be elected by the General Meeting of Shareholders and shall
have the powers and duties vested in it by law.
|
- 25 -
|
|||||
2
|
Die
Amtsdauer der Revisionsstelle beträgt ein Jahr, beginnend am Tage der Wahl
an einer ordentlichen Generalversammlung und endend am Tage der nächsten
ordentlichen Generalversammlung.
|
2
|
The
term of office of the Auditor shall be one year, commencing on the day of
election at an Annual General Meeting of Shareholders and terminating on
the day of the next Annual General Meeting of
Shareholders.
|
||
Abschnitt
4:
Jahresrechnung,
Konzernrechnung und Gewinnverteilung
|
Section
4:
Annual
Statutory Financial Statements, Consolidated Financial Statements and
Profit Allocation
|
||||
Artikel
30
|
Article
30
|
||||
Geschäftsjahr
|
Der
Verwaltungsrat legt das Geschäftsjahr fest.
|
Fiscal
Year
|
The
Board of Directors determines the fiscal year.
|
||
Artikel
31
|
Article
31
|
||||
Verteilung
des Bilanzgewinns, Reserven
|
1
|
Über
den Bilanzgewinn verfügt die Generalversammlung im Rahmen der anwendbaren
gesetzlichen Vorschriften. Der Verwaltungsrat unterbreitet ihr seine
Vorschläge.
|
Allocation
of Profit Shown on the Annual Statutory Balance Sheet,
Reserves
|
1
|
The
profit shown on the Annual Statutory Balance Sheet shall be allocated by
the General Meeting of Shareholders in accordance with applicable
law. The Board of Directors shall submit its proposals to the
General Meeting of Shareholders.
|
2
|
Neben
der gesetzlichen Reserve können weitere Reserven geschaffen
werden.
|
2
|
Further
reserves may be taken in addition to the reserves required by
law.
|
||
3
|
Dividenden,
welche nicht innerhalb von fünf Jahren nach ihrem Auszahlungsdatum bezogen
werden, fallen an die Gesellschaft und werden in die allgemeinen
gesetzlichen Reserven verbucht.
|
3
|
Dividends
that have not been collected within five years after their payment date
shall enure to the Company and be allocated to the general statutory
reserves.
|
||
Abschnitt
5:
Auflösung
und Liquidation
|
Section
5:
Winding-up
and Liquidation
|
||||
Artikel
32
|
Article
32
|
||||
Auflösung
und Liquidation
|
1
|
Die
Generalversammlung kann jederzeit die Auflösung und Liquidation der
Gesellschaft nach Massgabe der gesetzlichen und statutarischen
Vorschriften beschliessen.
|
Winding-up
and Liquidation
|
1
|
The
General Meeting of Shareholders may at any time resolve on the winding-up
and liquidation of the Company pursuant to applicable law and the
provisions set forth in these Articles of Association.
|
- 26 -
|
|||||
2
|
Die
Liquidation wird durch den Verwaltungsrat durchgeführt, sofern sie nicht
durch die Generalversammlung anderen Personen übertragen
wird.
|
2
|
The
liquidation shall be effected by the Board of Directors, unless the
General Meeting of Shareholders shall appoint other persons as
liquidators.
|
||
3
|
Die
Liquidation der Gesellschaft erfolgt nach Massgabe der gesetzlichen
Vorschriften.
|
3
|
The
liquidation of the Company shall be effectuated pursuant to the statutory
provisions.
|
||
4
|
Nach
erfolgter Tilgung der Schulden wird das Vermögen unter die Aktionäre nach
Massgabe der eingezahlten Beträge verteilt, soweit diese Statuten nichts
anderes vorsehen.
|
4
|
Upon
discharge of all liabilities, the assets of the Company shall be
distributed to the shareholders pursuant to the amounts paid in, unless
these Articles of Association provide otherwise.
|
||
Abschnitt
6:
Bekanntmachungen,
Mitteilungen
|
Section
6:
Announcements,
Communications
|
||||
Artikel
33
|
Article
33
|
||||
Bekannt-machungen,
Mitteilungen
|
1
|
Publikationsorgan
der Gesellschaft ist das Schweizerische Handelsamtsblatt.
|
Announcements,
Communications
|
1
|
The
official means of publication of the Company shall be the Swiss Official
Gazette of Commerce.
|
2
|
Soweit
keine individuelle Benachrichtigung durch das Gesetz, börsengesetzliche
Bestimmungen oder diese Statuten verlangt wird, gelten sämtliche
Mitteilungen an die Aktionäre als gültig erfolgt, wenn sie im
Schweizerischen Handelsamtsblatt veröffentlicht worden sind. Schriftliche
Bekanntmachungen der Gesellschaft an die Aktionäre werden auf dem
ordentlichen Postweg an die letzte im Aktienbuch verzeichnete Adresse des
Aktionärs oder des bevollmächtigten Empfängers geschickt. Finanzinstitute,
welche Aktien für wirtschaftlich Berechtigte halten und als solches im
Aktienbuch eingetragen sind, gelten als bevollmächtigte
Empfänger.
|
2
|
To the
extent that individual notification is not required by law, stock exchange
regulations or these Articles of Association, all communications to the
shareholders shall be deemed valid if published in the Swiss Official
Gazette of Commerce. Written communications by the Company to
its shareholders shall be sent by ordinary mail to the last address of the
shareholder or authorized recipient recorded in the share
register. Financial institutions holding Shares for beneficial
owners and recorded in such capacity in the share register shall be deemed
to be authorized recipients.
|
||
Abschnitt
7:
Verbindlicher
Originaltext
|
Section
7:
Original
Language
|
||||
- 27 -
|
|||||
Artikel
34
|
Article
34
|
||||
Verbindlicher
Originaltext
|
Falls
sich zwischen der deutschen und englischen Fassung dieser Statuten
Differenzen ergeben, hat die deutsche Fassung Vorrang.
|
Original
Language
|
In the
event of deviations between the German and English version of these
Articles of Association, the German text shall prevail.
|
||
Abschnitt
8:
Definitionen
|
Section
8:
Definitions
|
||||
Artikel
35
|
Article
35
|
||||
Aktie(n)
|
1
|
Der
Begriff Aktie(n)
hat die in Artikel 4 dieser Statuten aufgeführte
Bedeutung.
|
Share(s)
|
1
|
The
term Share(s) has
the meaning assigned to it in Article 4 of these Articles of
Association.
|
Eigentümer
|
2
|
Eigentümer(in), unter
Einschluss der Begriffe Eigentum, halten, gehalten, Eigentümerschaft oder
ähnlicher Begriffe, bedeutet, wenn verwendet mit Bezug auf Aktien, jede
Person, welche allein oder zusammen mit oder über Nahestehende
Gesellschaften oder Nahestehende Personen:
|
Owner
|
2
|
Owner, including the
terms Own, Owned and Ownership when used with
respect to any Shares means a Person that individually or with or through
any of its Affiliates or Associates:
|
(a) wirtschaftliche
Eigentümerin dieser Aktien ist, ob direkt oder indirekt;
|
(a) beneficially
Owns such Shares, directly or indirectly;
|
||||
(b) (1) das
Recht hat, aufgrund eines Vertrags, einer Absprache oder einer anderen
Vereinbarung, oder aufgrund der Ausübung eines Wandel-, Tausch-, Bezugs-
oder Optionsrechts oder anderweitig Aktien zu erwerben (unabhängig davon,
ob dieses Recht sofort ausübbar ist oder nur nach einer gewissen Zeit);
vorausgesetzt, dass eine Person nicht als Eigentümerin derjenigen Aktien
gelten soll, die im Rahmen eines Übernahme- oder Umtauschangebots, das
diese Person oder eine dieser Person Nahestehende Gesellschaft oder
Nahestehende Person eingeleitet hat, angedient werden, bis diese Aktien
zum Kauf oder Tausch akzeptiert werden; oder (2) das Recht hat, die
Stimmrechte dieser Aktien aufgrund eines Vertrags, einer Absprache oder
einer anderen Vereinbarung auszuüben; vorausgesetzt, dass eine Person
nicht als Eigentümerin von Aktien gilt infolge des Rechts, das Stimmrecht
auszuüben, soweit der diesbezügliche Vertrag, die diesbezügliche Absprache
oder die diesbezügliche andere Vereinbarung nur aufgrund einer
widerruflichen Vollmacht (proxy) oder Zustimmung
zustande gekommen ist, und diese Vollmacht (proxy) oder Zustimmung
in Erwiderung auf eine an 10 oder mehr Personen gemachte diesbezügliche
Aufforderung ergangen ist; oder
|
(b) has
(1) the right to acquire such Shares (whether such right is exercisable
immediately or only after the passage of time) pursuant to any agreement,
arrangement or understanding, or upon the exercise of conversion rights,
exchange rights, warrants or options, or otherwise; provided, however, that
a Person shall not be deemed the Owner of Shares tendered pursuant to a
tender or exchange offer made by such Person or any of such Person's
Affiliates or Associates until such tendered Shares are accepted for
purchase or exchange; or (2) the right to vote such Shares pursuant to any
agreement, arrangement or understanding; provided, however, that
a Person shall not be deemed the Owner of any Shares because of such
Person's right to vote such Shares if the agreement, arrangement or
understanding to vote such Shares arises solely from a revocable proxy or
consent given in response to a proxy or consent solicitation made to 10 or
more Persons; or
|
||||
- 28 -
|
|||||
(c) zwecks
Erwerbs, Haltens, Stimmrechtsausübung (mit Ausnahme der
Stimmrechtsausübung aufgrund einer widerruflichen Vollmacht (proxy) oder Zustimmung
wie in Artikel 35 Abs. 2(b)(ii)(2) umschrieben) oder
Veräusserung dieser Aktien mit einer anderen Person in einen Vertrag, eine
Absprache oder eine andere Vereinbarung getreten ist, die direkt oder
indirekt entweder selbst oder über ihr Nahestehende Gesellschaften oder
Nahestehende Personen wirtschaftlich Eigentümerin dieser Aktien
ist.
|
(c) has
any agreement, arrangement or understanding for the purpose of acquiring,
holding, voting (except voting pursuant to a revocable proxy or consent as
described in Article 35 para. 2(b)(ii)(2)), or disposing of
such Shares with any other Person that beneficially Owns, or whose
Affiliates or Associates beneficially Own, directly or indirectly, such
Shares.
|
||||
Gesellschaft
|
3
|
Der
Begriff
Gesellschaft hat die in Artikel 1 dieser Statuten aufgeführte
Bedeutung.
|
Company
|
3
|
The
term Company has
the meaning assigned to it in Article 1 of these Articles of
Association.
|
Kontrolle
|
4
|
Kontrolle,
einschliesslich die Begriffe kontrollierend, kontrolliert von und
unter gemeinsamer
Kontrolle mit, bedeutet die Möglichkeit, direkt oder indirekt auf
die Geschäftsführung und die Geschäftspolitik einer Person Einfluss zu
nehmen, sei es aufgrund des Haltens von Stimmrechten, eines Vertrags oder
auf andere Weise. Eine Person, welche 20% oder mehr der ausgegebenen oder
ausstehenden Stimmrechte einer Kapitalgesellschaft, rechts- oder
nicht-rechtsfähigen Personengesellschaft oder eines anderen Rechtsträgers
hält, hat mangels Nachweises des Gegenteils unter Anwendung des
Beweismasses der überwiegenden Wahrscheinlichkeit der Beweismittel
vermutungsweise Kontrolle über einen solchen Rechtsträger. Ungeachtet des
Voranstehenden gilt diese Vermutung der Kontrolle nicht, wenn eine Person
in Treu und Glauben und nicht zur Umgehung dieser Bestimmung Stimmrechte
als Stellvertreter (agent), Bank,
Börsenmakler (broker), Nominee,
Depotbank (custodian) oder Treuhänder
(trustee) für
einen oder mehrere Eigentümer hält, die für sich allein oder zusammen als
Gruppe keine Kontrolle über den betreffenden Rechtsträger
haben.
|
Control
|
4
|
Control, including the
terms controlling,
controlled by and under common control
with, means the possession, direct or indirect, of the power to direct or
cause the direction of the management and policies of a Person, whether
through the Ownership of voting shares, by contract, or
otherwise. A Person who is the Owner of 20% or more of the
issued or outstanding voting shares of any corporation, partnership,
unincorporated association or other entity shall be presumed to have
control of such entity, in the absence of proof by a preponderance of the
evidence to the contrary. Notwithstanding the foregoing, a presumption of
control shall not apply where such Person holds voting shares, in good
faith and not for the purpose of circumventing this provision, as an
agent, bank, broker, nominee, custodian or trustee for one or more Owners
who do not individually or as a group have control of such
entity.
|
- 29 -
|
|||||
Nahestehender
Aktionär
|
5
|
Nahestehender Aktionär
bedeutet jede Person (unter Ausschluss der Gesellschaft oder jeder
direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der
Gesellschaft gehalten wird), (i) die Eigentümerin von 15% oder mehr der
ausgegebenen Aktien ist, oder (ii) die als Nahestehende Gesellschaft oder
Nahestehende Person anzusehen ist und irgendwann in den drei unmittelbar
vorangehenden Jahren vor dem Zeitpunkt, zu dem bestimmt werden muss, ob
diese Person ein Nahestehender Aktionär ist, Eigentümerin von 15% oder
mehr der ausgegebenen Stimmrechte gewesen ist, ebenso wie jede
Nahestehende Gesellschaft und Nahestehende Person dieser Person;
vorausgesetzt, dass eine Person nicht als Nahestehender Aktionär
gilt, die aufgrund von Handlungen, die ausschliesslich der Gesellschaft
zuzurechnen sind, Eigentümerin von Aktien in Überschreitung der
15%-Beschränkung ist; wobei jedoch jede solche Person dann als
Nahestehender Aktionär gilt, falls sie später zusätzliche Aktien erwirbt,
ausser dieser Erwerb erfolgt aufgrund von weiteren
Gesellschaftshandlungen, die weder direkt noch indirekt von dieser Person
beeinflusst werden. Zur Bestimmung, ob eine Person ein Nahestehender
Aktionär ist, sind die als ausgegeben geltenden Aktien unter Einschluss
der von dieser Person gehaltenen Aktien (unter Anwendung des Begriffs
"gehalten" wie in Artikel 35 Abs. 2 dieser Statuten
definiert) zu berechnen, jedoch unter Ausschluss von nichtausgegebenen
Aktien, die aufgrund eines Vertrags, einer Absprache oder einer anderen
Vereinbarung, oder aufgrund der Ausübung eines Wandel-, Bezugs- oder
Optionsrechts oder anderweitig ausgegeben werden können;
|
Interested
Shareholder
|
5
|
Interested Shareholder
means any Person (other than the Company or any direct or indirect
majority-Owned subsidiary of the Company) (i) that is the Owner of 15% or
more of the issued Shares of the Company or (ii) that is an Affiliate or
Associate of the Company and was the Owner of 15% or more of the issued
Shares at any time within the three-year period immediately prior to the
date on which it is sought to be determined whether such Person is an
Interested Shareholder, and also the Affiliates and Associates of such
Person; provided,
however, that the term Interested Shareholder shall not include any
Person whose Ownership of Shares in excess of the 15% limitation is the
result of action taken solely by the Company; provided that such Person
shall be an Interested Shareholder if thereafter such Person acquires
additional Shares, except as a result of further corporate action not
caused, directly or indirectly, by such Person. For the purpose
of determining whether a Person is an Interested Shareholder, the Shares
deemed to be in issue shall include Shares deemed to be Owned by the
Person (through the application of the definition of Owner in
Article 35 para. 2 of these Articles of Association) but
shall not include any other unissued Shares which may be issuable pursuant
to any agreement, arrangement or understanding, or upon exercise of
conversion rights, warrants or options, or otherwise.
|
Nahestehende
Gesellschaft
|
6
|
Nahestehende
Gesellschaft bedeutet jede Person, die direkt oder indirekt über
eine oder mehrere Mittelspersonen eine andere Person kontrolliert, von
einer anderen Person kontrolliert wird, oder unter gemeineinsamer
Kontrolle mit einer anderen Person steht.
|
Affiliate
|
6
|
Affiliate means a Person
that directly, or indirectly through one or more intermediaries, controls,
or is controlled by, or is under common control with, another
Person.
|
Nahestehende
Person
|
7
|
Nahestehende Person
bedeutet, wenn verwendet zur Bezeichnung einer Beziehung zu einer Person,
(i) jede Kapitalgesellschaft, rechts- oder nicht-rechtsfähige
Personengesellschaft oder ein anderer Rechtsträger, von welcher diese
Person Mitglied des Leitungs- oder Verwaltungsorgans, der Geschäftsleitung
oder Gesellschafter ist oder von welcher diese Person, direkt oder
indirekt, Eigentümerin von 20% oder mehr einer Kategorie von Aktien oder
anderer Anteilsrechte ist, die ein Stimmrecht vermitteln, (ii) jedes
Treuhandvermögen (Trust) oder jede andere
Vermögenseinheit, an der diese Person wirtschaftlich einen Anteil von 20%
oder mehr hält oder in Bezug auf welche diese Person als Verwalter (trustee) oder in
ähnlich treuhändischer Funktion tätig ist, und (iii) jeder Verwandte,
Ehe- oder Lebenspartner dieser Person, oder jede Verwandte des Ehe- oder
Lebenspartners, jeweils soweit diese den gleichen Wohnsitz haben wie diese
Person.
|
Associate
|
7
|
Associate, when used to
indicate a relationship with any Person, means (i) any corporation,
partnership, unincorporated association or other entity of which such
Person is a director, officer or partner or is, directly or indirectly,
the Owner of 20% or more of any class of voting shares, (ii) any
trust or other estate in which such Person has at least a 20% beneficial
interest or as to which such Person serves as trustee or in a similar
fiduciary capacity, and (iii) any relative or spouse of such Person,
or any relative of such spouse, who has the same residence as such
Person.
|
- 30 -
|
|||||
OR
|
8
|
Der
Begriff OR hat die
in Artikel 14 Abs. 2 dieser Statuten aufgeführte
Bedeutung.
|
CO
|
8
|
The
term CO has the
meaning assigned to it in Article 14 para. 2 of these
Articles of Association.
|
Person
|
9
|
Person bedeutet jede
natürliche Person, Kapitalgesellschaft, rechts- oder nicht-rechtsfähige
Personengesellschaft oder jeder andere Rechtsträger;
|
Person
|
9
|
Person means any
individual, corporation, partnership, unincorporated association or other
entity.
|
Rechte
|
10
|
Der
Begriff Rechte hat
die in Artikel 6 Abs. 1 dieser Statuten aufgeführte
Bedeutung.
|
Rights
|
10
|
The
term Rights has
the meaning assigned to it in Article 6 para. 1 of these
Articles of Association.
|
Mit
Rechten verbundenen Obligationen
|
11
|
Der
Begriff mit Rechten
verbundenen Obligationen hat die in Artikel 6 Abs. 1
dieser Statuten aufgeführte Bedeutung.
|
Rights-Bearing
Obligations
|
11
|
The
term Rights-Bearing
Obligations has the meaning assigned to it in
Article 6 para. 1 of these Articles of
Association.
|
SEC
|
12
|
Der
Begriff SEC hat
die in Artikel 12 Abs. 2 dieser Statuten aufgeführte
Bedeutung.
|
SEC
|
12
|
The
term SEC has the
meaning assigned to it in Article 12 para. 2 of these
Articles of Association.
|
Transfer
Agent
|
13
|
Der
Begriff Transfer
Agent hat die in Artikel 8 Abs. 3 dieser Statuten
aufgeführte Bedeutung.
|
Transfer
Agent
|
13
|
The
term Transfer
Agent has the meaning assigned to it in
Article 8 para. 3 of these Articles of
Association.
|
Zusammenschluss
|
14
|
Zusammenschluss
bedeutet, wenn im Rahmen dieser Statuten in Bezug auf die Gesellschaft
oder einen Nahestehenden Aktionär der Gesellschaft
verwendet:
|
Business
Combination
|
14
|
Business Combination,
when used in these Articles of Association in reference to the Company and
any Interested Shareholder of the Company, means:
|
(a) Jede
Fusion oder andere Form des Zusammenschlusses der Gesellschaft oder einer
direkten oder indirekten Tochtergesellschaft, die zur Mehrheit von der
Gesellschaft gehalten wird, mit (1) dem Nahestehenden Aktionär oder
(2) einer anderen Kapitalgesellschaft, rechts- oder
nicht-rechtsfähigen Personengesellschaft oder einem anderen Rechtsträger,
soweit diese Fusion oder andere Form des Zusammenschlusses durch den
Nahestehenden Aktionär verursacht worden ist und als Folge dieser Fusion
oder anderen Form des Zusammenschlusses Artikel 19(f) und
Artikel 20 Abs. 3 dieser Statuten (sowie jede der dazu
gehörigen Definition in Artikel 35 dieser Statuten) oder im
Wesentlichen gleiche Bestimmungen wie Artikel 19(f), Artikel
20 Abs. 3 (und die dazugehörigen Definitionen in Artikel 35
dieser Statuten auf den überlebenden Rechtsträger) nicht anwendbar
sind;
|
(a) Any
merger or consolidation of the Company or any direct or indirect
majority-Owned subsidiary of the Company with (1) the Interested
Shareholder or (2) with any other corporation, partnership, unincorporated
association or other entity if the merger or consolidation is caused by
the Interested Shareholder and as a result of such merger or consolidation
Article 19(f) and Article 20 para. 3 of these Articles
of Association (including the relevant definitions in Article 35 of
these Articles of Association pertaining thereto) or a provision
substantially the same as such Article 19(f) and
Article 20 para. 3 (including the relevant definitions in
Article 35) are not applicable to the surviving entity;
|
||||
(b) jeder
Verkauf, Vermietung oder Verpachtung, hypothekarische Belastung oder
andere Verpfändung, Übertragung oder andere Verfügung (ob in einer oder
mehreren Transaktionen), einschliesslich im Rahmen eines Tauschs, von
Vermögenswerten der Gesellschaft oder einer direkten oder indirekten
Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird,
an einen Nahestehenden Aktionär (ausser soweit der Zuerwerb unter einer
der genannten Transaktionen proportional als Aktionär erfolgt), soweit
diese Vermögenswerte einen Marktwert von 10% oder mehr entweder des auf
konsolidierter Basis aggregierten Marktwertes aller Vermögenswerte der
Gesellschaft oder des aggregierten Marktwertes aller dann ausgegebenen
Aktien haben, unabhängig davon, ob eine dieser Transaktionen Teil einer
Auflösung der Gesellschaft ist oder nicht;
|
(b) any
sale, lease, exchange, mortgage, pledge, transfer or other disposition (in
one transaction or a series of transactions), except proportionately as a
shareholder, to or with the Interested Shareholder, whether as part of a
dissolution or otherwise, of assets of the Company or of any direct or
indirect majority-Owned subsidiary of the Company which assets have an
aggregate market value equal to 10% or more of either the aggregate market
value of all the assets of the Company determined on a consolidated basis
or the aggregate market value of all the Shares then in
issue;
|
||||
- 31 -
|
|||||
(c) jede
Transaktion, die dazu führt, dass die Gesellschaft oder eine direkte oder
indirekte Tochtergesellschaft, die zur Mehrheit von der Gesellschaft
gehalten wird, Aktien oder Tochtergesellschafts-Aktien an den
Nahestehenden Aktionär ausgibt oder überträgt, es sei denn
(1) aufgrund der Ausübung, des Tauschs oder der Wandlung von
Finanzmarktinstrumenten, die in Aktien oder Aktien einer direkten oder
indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft
gehalten wird, ausgeübt, getauscht oder gewandelt werden können,
vorausgesetzt, die betreffenden Finanzmarktinstrumente waren zum
Zeitpunkt, in dem der Nahestehende Aktionär zu einem solchem wurde,
bereits ausgegeben; (2) als Dividende oder Ausschüttung an alle
Aktionäre, oder aufgrund der Ausübung, des Tauschs oder der Wandlung von
Finanzmarktinstrumenten, die in Aktien oder Aktien einer direkten oder
indirekten Tochtergesellschaft, die zur Mehrheit von der Gesellschaft
gehalten wird, ausgeübt, getauscht oder gewandelt werden können,
vorausgesetzt, diese Finanzinstrumente werden allen Aktionäre
anteilsmässig ausgegeben, nachdem der Nahestehende Aktionär zu einem
solchem wurde; (3) gemäss einem Umtauschangebot der Gesellschaft,
Aktien von allen Aktionären zu den gleichen Bedingungen zu erwerben; oder
(4) aufgrund der Ausgabe oder der Übertragung von Aktien durch die
Gesellschaft; vorausgesetzt, dass in keinem der unter (2) bis (4)
genannten Fällen der proportionale Anteil des Nahestehenden Aktionärs an
den Aktien erhöht werden darf;
|
(c) any
transaction which results in the issuance or transfer by the Company or by
any direct or indirect majority-Owned subsidiary of the Company of any
Shares or shares of such subsidiary to the Interested Shareholder, except
(1) pursuant to the exercise, exchange or conversion of securities
exercisable for, exchangeable for or convertible into Shares or the shares
of a direct or indirect majority-Owned subsidiary of the Company which
securities were in issue prior to the time that the Interested Shareholder
became such; (2) pursuant to a dividend or distribution paid or made, or
the exercise, exchange or conversion of securities exercisable for,
exchangeable for or convertible into Shares or the shares of a direct or
indirect majority-Owned subsidiary of the Company which security is
distributed, pro rata, to all shareholders subsequent to the time the
Interested Shareholder became such; (3) pursuant to an exchange offer by
the Company to purchase Shares made on the same terms to all holders of
said Shares; or (4) any issuance or transfer of Shares by the Company;
provided,
however, that in no case under (2)–(4) above shall there be an
increase in the Interested Shareholder's proportionate interest in the
Shares;
|
||||
(d) jede
Transaktion, in welche die Gesellschaft oder eine direkte oder indirekte
Tochtergesellschaft, die zur Mehrheit von der Gesellschaft gehalten wird,
involviert ist, und die direkt oder indirekt dazu führt, dass der
proportionale Anteil der vom Nahestehenden Aktionär gehaltenen Aktien, in
Aktien wandelbare Obligationen oder Tochtergesellschafts-Aktien erhöht
wird, ausser eine solche Erhöhung ist nur unwesentlich und die Folge eines
Spitzenausgleichs für Fraktionen oder eines Rückkaufs oder einer Rücknahme
von Aktien, soweit diese(r) weder direkt noch indirekt durch den
Nahestehenden Aktionär verursacht wurde; oder
|
(d) any
transaction involving the Company or any direct or indirect majority-Owned
subsidiary of the Company which has the effect, directly or indirectly, of
increasing the proportionate interest in the Shares, or securities
convertible into the Shares, or in the shares of any such subsidiary which
is Owned by the Interested Shareholder, except as a result of immaterial
changes due to fractional share adjustments or as a result of any purchase
or redemption of any Shares not caused, directly or indirectly, by the
Interested Shareholder; or
|
||||
- 32 -
|
|||||
(e) jede
direkte oder indirekte Gewährung von Darlehen, Vorschüssen, Garantien,
Bürgschaften, oder garantieähnlicher Verpflichtungen, Pfändern oder
anderen finanziellen Begünstigungen (mit Ausnahme einer solchen, die
gemäss den Unterabschnitten (a) – (d) dieses
Artikels 35 Abs. 14 ausdrücklich erlaubt ist sowie einer
solchen, die proportional an alle Aktionäre erfolgt) durch die oder über
die Gesellschaft oder eine direkte oder indirekte Tochtergesellschaft, die
zur Mehrheit von der Gesellschaft gehalten wird, an den Nahestehenden
Aktionär.
|
(e) any
receipt by the Interested Shareholder of the benefit, directly or
indirectly (except proportionately as a shareholder), of any loans,
advances, guarantees, pledges or other financial benefits (other than
those expressly permitted in subsections (a)–(d) of this
Article 35 para. 14) provided by or through the Company or
any direct or indirect majority-Owned subsidiary of the
Company.
|
||||
Abschnitt
9:
Übergangsbestimmungen
|
Section
9:
Transitional
Provisions
|
||||
Artikel
36
|
Article
36
|
||||
Sacheinlage
|
Die
Gesellschaft übernimmt bei der Kapitalerhöhung vom 19. Dezember 2008
von der Transocean Inc. in Grand Cayman, Cayman Islands (Transocean Inc.), gemäss
Sacheinlagevertrag per 18. Dezember 2008 (Sacheinlagevertrag)
319’228’632 Aktien (ordinary shares) der
Transocean Inc. Diese Aktien werden zu einem Übernahmewert von insgesamt
CHF 16'476'107'961.80 übernommen. Als Gegenleistung für diese
Sacheinlage gibt die Gesellschaft einem Umtauschagenten, handelnd auf
Rechnung der Aktionäre der Transocean Inc. im Zeitpunkt unmittelbar vor
Vollzug des Sacheinlagevertrages und im Namen und auf Rechnung der
Transocean Inc., insgesamt 335'228’632 voll einbezahlte Aktien mit einem
Nennwert von insgesamt CHF 5'028'429’480 aus. Die Gesellschaft weist
die Differenz zwischen dem totalen Nennwert der ausgegebenen
Aktien und dem Übernahmewert der Sacheinlage im Gesamtbetrag von
CHF 11'447'678'481.80 den Reserven der Gesellschaft
zu.
|
Contribution
in Kind
|
In
connection with the capital increase of December 19, 2008, and in
accordance with the contribution in kind agreement as of December 18, 2008
(the Contribution in Kind
Agreement), the Company acquires 319,228,632 ordinary shares of
Transocean Inc., Grand Cayman, Cayman Islands (Transocean
Inc.). The shares of Transocean Inc. are acquired for a
total value of CHF 16,476,107,961.80. As consideration for this
contribution, the Company issues to an exchange agent, acting for the
account of the holders of ordinary shares of Transocean Inc. outstanding
immediately prior to the completion of the Contribution in Kind Agreement
and in the name and the account of Transocean Inc, a total of 335,228,632
fully paid Shares with a total par value of CHF
5,028,429,480. The difference between the aggregate par value
of the issued Shares and the total value of CHF 11,447,678,481.80 is
allocated to the reserves of the
Company.
|
Zug,
14. Mai 2010
|
Zug,
May 14, 2010
|
DRILLING CONTRACT
|
|
between
|
|
VASTAR RESOURCES, INC.
|
|
and
|
|
R&B FALCON DRILLING CO.
|
|
DATED DECEMBER 9, 1998
|
|
for
|
|
“RBS-8D”
|
|
“Deepwater Horizon”
|
|
CONTRACT NO. 980249
|
|
D-1-87.1
|
|
DISTRIBUTION:
|
|
Houston Legal Files - Signed Original
|
|
Houston Distribution (2)
|
|
Vern Buzard
|
CONTRACT NO. 980249
|
DATE: DECEMBER 9, 1998
|
ARTICLE 1-
|
TERM
|
2
|
ARTICLE 2-
|
DAYRATES
|
4
|
ARTICLE 3-
|
PERSONNEL AND PAYMENTS
|
7
|
ARTICLE 4-
|
OTHER PAYMENTS
|
8
|
ARTICLE 5-
|
DRILLING UNIT MODIFICATIONS
|
9
|
ARTICLE 6-
|
OTHER REIMBURSEMENTS
|
9
|
ARTICLE 7-
|
MATERIALS, SUPPLIES, EQUIPMENT, AND SERVICES TO BE FURNISHED BY CONTRACTOR
|
10
|
ARTICLE 8-
|
MATERIALS, SUPPLIES, EQUIPMENT, AND SERVICES TO BE FURNISHED BY COMPANY
|
11
|
ARTICLE 9-
|
PAYMENTS
|
11
|
ARTICLE 10-
|
PAYMENT OF CLAIMS
|
12
|
ARTICLE 11-
|
TAXES AND FEES
|
13
|
ARTICLE 12-
|
COMPANY’S RIGHT TO QUESTION INVOICES AND AUDIT
|
14
|
ARTICLE 13-
|
DEPTH
|
14
|
ARTICLE 14-
|
DRILLING UNIT
|
14
|
ARTICLE 15-
|
PERFORMANCE OF DRILLING OPERATIONS
|
16
|
ARTICLE 16-
|
INSPECTION OF MATERIALS
|
18
|
ARTICLE 17-
|
SAFETY
|
18
|
ARTICLE 18-
|
PERFORMANCE OF THE WORK
|
19
|
ARTICLE 19-
|
RECORDS TO BE FURNISHED BY CONTRACTOR
|
21
|
ARTICLE 20-
|
INSURANCE
|
22
|
ARTICLE 21-
|
INDEMNITY FOR PERSONAL INJURY OR DEATH
|
22
|
ARTICLE 22-
|
RESPONSIBILITY FOR LOSS OF OR DAMAGE TO THE EQUIPMENT
|
22
|
ARTICLE 23-
|
LOSS OF HOLE OR RESERVOIR
|
24
|
ARTICLE 24-
|
POLLUTION
|
25
|
ARTICLE 25-
|
INDEMNITY OBLIGATION
|
26
|
ARTICLE 26-
|
LAWS, RULES, AND REGULATIONS
|
27
|
ARTICLE 27-
|
TERMINATION
|
28
|
ARTICLE 28-
|
FORCE MAJEURE
|
29
|
ARTICLE 29-
|
CONFIDENTIAL INFORMATION, LICENSE AND PATENT INDEMNITY
|
30
|
ARTICLE 30-
|
ASSIGNMENT OF CONTRACT
|
32
|
ARTICLE 31-
|
INGRESS AND EGRESS OF LOCATION
|
33
|
ARTICLE 32-
|
COMPANY POLICIES
|
33
|
ARTICLE 33-
|
NOTICES
|
34
|
ARTICLE 34-
|
CONSEQUENTIAL DAMAGES
|
35
|
ARTICLE 35-
|
WAIVERS AND ENTIRE CONTRACT
|
35
|
EXHIBIT A:
|
Dayrates
|
Tab A
|
EXHIBIT B-1:
|
Drilling Unit Specifications
|
Tab B
|
EXHIBIT B-2:
|
Material Equipment List
|
Tab B
|
EXHIBIT B-3:
|
Consumable Material and Equipment List
|
Tab B
|
EXHIBIT C:
|
Insurance Requirements
|
Tab C
|
EXHIBIT D:
|
Safety, Health, and Environmental Management System
|
Tab D
|
EXHIBIT E:
|
Termination Payment Schedule
|
Tab E
|
EXHIBIT F-1:
|
Rig Manning
|
Tab F
|
EXHIBIT F-2:
|
Cost of Additional Personnel
|
Tab F
|
EXHIBIT G:
|
Vessel/Equipment Performance/Acceptance Test
|
Tab G
|
EXHIBIT H:
|
Project Execution Plan
|
Tab H
|
Exhibit A:
|
Dayrates
|
|
Exhibit B-1:
|
Drilling Unit Specifications
|
|
Exhibit B-2:
|
Material Equipment List
|
|
Exhibit B-3:
|
Consumable Material and Equipment List
|
|
Exhibit C:
|
Insurance Requirements
|
|
Exhibit D:
|
Safety, Health, and Environmental Management System
|
|
Exhibit E:
|
Termination Payment Schedules
|
|
Exhibit F-1:
|
Rig Manning
|
|
Exhibit F-2:
|
Cost of Additional Personnel
|
|
Exhibit G:
|
Vessel/Equipment Performance/Acceptance Test
|
|
Exhibit H:
|
Project Execution Plan
|
R&B Falcon Drilling Co.
|
Vastar Resources, Inc.
|
||||
BY:
|
/s/ Paul B. Loyd, Jr.
|
By
|
/s/ Charles D. Davidson
|
||
Paul B. Loyd, Jr.
|
Charles D. Davidson
|
||||
TITLE:
|
Attorney-in-Fact
|
TITLE:
|
President and CEO
|
||
(Chairman R&B Falcon Corporation)
|
|||||
RATES PER 24 HOUR DAY
|
||||
Three (3) Year Option
|
Five (5) Year Option
|
|||
Operating Rate
|
$199,950.00 per day
|
$189,200.00 per day
|
||
Moving Rate
|
$199,950.00 per day
|
$189,200.00 per day
|
||
Standby Rate With Crews
|
$199,950.00 per day
|
$189,200.00 per day
|
||
Standby Rate Without Crews
|
$199,950.00 per day less documented cost savings
|
$189,200.00 per day less documented cost savings
|
||
Stack Rate With Crews
|
$199,950.00 per day less documented cost savings
|
$189,200.00 per day less documented cost savings
|
||
Stack Rate Without Crews
|
$199,950.00 per day less documented cost savings
|
$189,200.00 per day less documented cost savings
|
||
Equipment Repair Rate
|
$ -0- per day
|
$ -0- per day
|
||
Hurricane Evacuation Rate
|
Standby Rates without crews plus documented expenses of evacuated crew
|
Standby Rates without crews plus documented expenses of evacuated crew
|
Metric Units
|
U.S. Units
|
||||
Overall Structure
|
|||||
Length (overall)
|
120.7 m
|
396.00 ft.
|
|||
Breadth (overall)
|
78.0 m
|
255.91 ft.
|
|||
Upper Hull
|
|||||
Length
|
81.5 m
|
267.40 ft.
|
|||
Breadth
|
61.0 m
|
200.13 ft.
|
|||
Depth
|
8.5 m
|
27.89 ft.
|
|||
Main Deck
|
|||||
Length
|
84.1 m
|
275.93 ft.
|
|||
Breadth
|
61.0 m
|
200.13 ft.
|
|||
Pontoons (two each)
|
|||||
Length
|
114.0 m
|
373.96 ft.
|
|||
Breadth (amidship)
|
13.4 m
|
43.96 ft.
|
|||
Breadth (ends)
|
16.5 m
|
54.13 ft.
|
|||
Depth
|
9.10 m
|
29.86 ft.
|
|||
Corner Radius
|
3.00 m
|
9.84 ft.
|
|||
Transverse Distance (c. to c.)
|
61.5 m
|
201.77 ft.
|
Columns (four each)
|
|||||
Horizontal Section (Lx B)
|
|||||
17.0 m x l6.5 m (@ WL
|
)
|
55.8 ft. x 54.l ft.
|
|||
14.0 m x 16.5 m (bottom
|
)
|
45.93 ft. x 54.13 ft.
|
|||
Corner Radius
|
3.00 m
|
9.84 ft.
|
|||
Vertical Height
|
23.9 m
|
78.41 ft.
|
|||
Longitudinal Distance (c. to c.)
|
60.0 m
|
196.85 ft.
|
|||
Transverse Distance (c. to c.) at Top
|
46.00 m
|
150.92 ft.
|
|||
at Bottom
|
61.5 m
|
201.77 ft.
|
|||
Transverse Braces (two each)
|
|||||
Length
|
45.0 m
|
147.64 ft.
|
|||
Breadth
|
6.0 m
|
19.68 ft.
|
|||
Depth
|
3.00 m
|
9.84 ft.
|
|||
Corner Radius
|
0.60 m
|
1.97 ft.
|
|||
Longitudinal Distance (c. to c.)
|
68.0 m
|
223.10 ft.
|
|||
Centerline Elevation
|
1.5 m
|
4.92 ft.
|
|||
Diagonal Braces (four each)
|
|||||
Diameter
|
3.0 m
|
9.84 ft.
|
|||
Centerline Elevation
|
1.5 m
|
4.92 ft.
|
|||
Elevations
|
|||||
Drill Floor
|
46.0 m
|
150.92 ft.
|
|||
Main Deck (at sides)
|
41.5 m
|
136.15 ft.
|
|||
Second Deck
|
38.0 m
|
124.67 ft.
|
|||
Third Deck (Inner bottom Top)
|
34.5 m
|
113.19 ft.
|
|||
Upper Hull Bottom
|
33.0 m
|
108.27 ft.
|
|||
Lower Hull Top
|
9.1 m
|
29.86 ft.
|
|||
Draft
|
|||||
Operating Condition (G.O.M.)
|
23.00 m
|
75.46 ft.
|
|||
Severe Storm Condition (G.O.M.)
|
16.50 m
|
54.13 ft.
|
|||
Transit Condition
|
8.80 m
|
28.87 ft.
|
Metric Units
|
U.S. Units
|
|||
Pipe Racks
|
871 m2
|
9,376 ft2
|
||
Riser (90’ joints)
|
3,048.5 m
|
10,000 ft
|
||
Total Open Deck
|
2,005 m2
|
21,578 ft2
|
||
Bulk Cement
|
232 m3
|
8,205 ft3
|
||
Bulk Barite
|
387 m3
|
13,675 ft3
|
||
Cement Day Tank
|
62 m3
|
2,200 ft3
|
||
Barite Day Tank
|
68 m3
|
2,400 ft3
|
||
Total Bulk Storage
|
750 m3
|
26,480 ft3
|
||
Sack Storage
|
10,000 Sx
|
10,000 Sx
|
||
Drilling Mud Deck
|
750 m3
|
4,434 bbl.
|
||
Drilling Mud (Column)
|
908 m3
|
5,710 bbl.
|
||
Base Oil
|
480 m3
|
3,019 bbl
|
||
Column Brine Storage
|
480 m3
|
3,019 bbl.
|
||
Pontoon Brine Storage *)
|
3,975 m3
|
25,000 bbl.
|
||
DW-Col.
|
1,736 m3
|
10,918 bbl.
|
||
DW-pontoons
|
1424 m3
|
8,956 bbl.
|
||
Fuel Oil
|
3,468 m3
|
21,811 bbl
|
||
Potable Water
|
644 m3
|
4,050 bbl
|
||
Helicopter Fuel
|
TBD
|
TBD
|
||
Refrigeration Storage
|
45 m2
|
484 ft.2
|
||
Dry Storage
|
60 m2
|
646 ft. 2
|
||
SWB — pontoons *)
|
16,308 m3
|
102,565 bbl
|
||
Quarters
|
130 Persons
|
130 Persons
|
||
Heliport
|
S-61, Super Puma
|
S-61, Super Puma
|
OPERATION
(DP Mode)
|
SURVIVAL
(transit / future moored)
|
|||||
Condition
|
Drilling
|
Moored
|
Vessel
|
|||
Item
|
10 Year Eddy +
10 year Tropical
Storm
|
20Year Tropical +
10 Year Eddy
(API Criteria)
|
100 Year Tropical
Storm
(ABS/API)
|
|||
Wind (1 hour)
|
26.1 m/s
(50.8 kn)
|
30.5 rn/s
(59.2 kn)
|
44.9 m/s
(87.2 kn)
|
|||
Wind (1 min.)
|
30.9 m/s
(60 kn)
|
36.0 m/s
(70 kn)
|
53.1 m/s
(103 kn)
|
|||
Wind (3 sec.)
|
35.8 m/s
(69.5 kn)
|
41.7 m/s
(81.0 kn)
|
61.7 m/s
(120 kn)
|
|||
Wave Hgt. Significant
|
7.9 m (26.0 ft)
|
9.4 m (31.0 ft)
|
12.5 m (41.0 ft)
|
|||
Peak Period
|
(PMS)
|
12.0 sec.
|
15.0 sec.
|
|||
Wave Height Maximum
|
14.7 m
(48.2 ft)
|
17.5 m
(57.3 ft)
|
22.0 m
(72.2 ft)
|
|||
Current:
|
||||||
Surface
|
1.8 m/s, (3.5 kn)
|
1.8 m/s, (3.5 kn)
|
1.0 m/s (1.9 kn)
|
|||
100 ft.
|
1.7 m/s, (3.4 kn)
|
1.7 m/s, (3.4 kn)
|
||||
200 ft.
|
1.2 m/s (2.4 kn)
|
1.2 m/s (2.4 kn)
|
||||
400 ft.
|
1.0 M/s (2.0 kn)
|
1.0 m/s (2.0 kn)
|
||||
1000 ft.
|
0.5 m/s (1.0 kn)
|
0.5 m/s (1.0 kn)
|
||||
2000 ft.
|
0.3 m/s (0.5 kn)
|
0.3 m/s (0.5 kn)
|
||||
Seafloor
|
0.1 m/s, (0.1 kn)
|
0.1 m/s, (0.1 kn)
|
Item
|
Division
|
Operation
Condition
|
KG (m)
(Operating)
|
Survival
Condition
|
Transit
Condition
|
Remark
|
||||||
MT
|
(m)
|
MT
|
MT
|
|||||||||
Light Ship
|
22,325
|
26.15
|
22,325
|
22,325
|
||||||||
VDL (Variable Dlg. Loads)
|
Upper Hull & Abv.
|
5,596
|
37.40
|
5,596
|
(note 1)
|
|||||||
Columns
|
2,057
|
22.85
|
2,057
|
|||||||||
VDL Total
|
(Dk. + Col.)
|
7,653
|
33.49
|
7,653
|
7,450
|
|||||||
Pontoon Loads:
Drill Water, Potable Water, Water, Fuel Oil, Lube Oil, and Ballast Water
|
17,530
|
5.57
|
10,722
|
2,984
|
||||||||
Displacement (MT)
|
47,509
|
19.68
|
40,700
|
32,759
|
Item
|
Division
|
Operation
Condition
|
KG (m)
(Operating)
|
Survival
Condition
|
Transit
Condition
|
Remark
|
||||||
MT
|
(m)
|
MT
|
MT
|
|||||||||
Light Ship
|
22,325
|
26.15
|
22,325
|
22,325
|
||||||||
Mooring Load
|
2,135
|
22.00
|
2,135
|
1,784
|
||||||||
VDL (Variable Dlg. Loads)
|
Upper Hull & Abv.
|
5,596
|
37.40
|
5,596
|
(note 1)
|
|||||||
Columns
|
2,057
|
22.85
|
2,057
|
|||||||||
VDL Total
|
(Dk. + Col.)
|
7,653
|
33.49
|
7,653
|
5,696
|
(note 2)
|
||||||
Pontoon Loads:
Drill Water, Potable Water, Water, Fuel Oil, Lube Oil, and Ballast Water
|
15,395
|
5.55
|
8,587
|
2,984
|
||||||||
Displacement (MT)
|
47,509
|
20.49
|
40,700
|
32,759
|
Item
|
M. Tonnes
|
L. Tons
|
|||
HSW
|
13,603
|
13,390
|
|||
BFE
|
3,433
|
3,379
|
|||
OFE
|
4,619
|
4,547
|
|||
<SUBTOTAL>
|
<21,655
|
>
|
<21,316
|
>
|
|
OTHERS
|
220
|
218
|
|||
MARGIN
|
450
|
443
|
|||
TOTAL
|
22,325
|
21,977
|
SECTION A - UNIT SPECIFICATIONS
|
|
Al
|
Main Dimensions/Technical Description
|
A2
|
Storage Capacities
|
A3
|
Propulsion/Thrusters
|
A4
|
Operational Capabilities
|
A5
|
Variable Loading
|
A6
|
Environmental Limits
|
A7
|
Mooring System
|
A8
|
Marine Loading Hoses
|
A9
|
Cranes, Hoists, and Materials Handling
|
A10
|
Helicopter Landing Deck
|
A11
|
Auxiliary Equipment
|
SECTION B - GENERAL RIG SPECIFICATIONS
|
|
B1
|
Derrick and Substructure
|
B2
|
Drawworks and Associated Equipment
|
B3
|
Derrick Hoisting Equipment
|
B4
|
Rotating System
|
SECTION C - POWER SUPPLY SYSTEMS
|
|
C1
|
Rig Power Plant
|
C2
|
Emergency Generator
|
C3
|
Primary Electric Motors
|
SECTION D - DRILLSTRING EQUIPMENT
|
|
D1
|
Tubulars
|
D2
|
Handling Tools
|
D3
|
Fishing Equipment
|
SECTION E - WELL CONTROL/SUBSEA EQUIPMENT
|
|
El
|
Lower Riser Diverter Assembly
|
E2
|
Primary BOP Stack
|
E3
|
Primary Lower Marine Riser Package
|
E4
|
Annular Gas Handler
|
E5
|
Secondary Lower Marine Riser Package
|
E6
|
Primary Marine Riser System
|
E7
|
Secondary Marine Riser System
|
E8
|
Diverter BOP
|
E9
|
Subsea Support System
|
El0
|
BOP Control System
|
E11
|
Subsea Control System
|
E12
|
Acoustic Emergency BOP Control System
|
E13
|
Subsea Auxiliary Equipment
|
E14
|
Choke Manifold
|
E15
|
Hydraulic BOP Test Pump
|
E16
|
Wellhead Running/Retrieving/Testing Tools
|
SECTION F - MUD SYSTEM/BULK SYSTEM
|
|
Fl
|
High Pressure Mud System
|
F2
|
Low Pressure Mud System
|
F3
|
Bulk System
|
SECTION G - CASING/CEMENTING EQUIPMENT
|
|
G1
|
Casing Equipment
|
G2
|
Cement Equipment
|
SECTION H - INSTRUMENTATION/COMMUNICATION
|
|
H1
|
Drilling Instrumentation at Driller’s Position
|
H2
|
Drilling Parameter Recorder
|
H3
|
Instrumentation at Choke Manifold
|
H4
|
Standpipe Pressure Gauge
|
H5
|
Deviation Equipment
|
H6
|
Calibrated Pressure Gauges
|
H7
|
Rig Communication System
|
H8
|
Environmental Instrumentation
|
H9
|
Additional MODU Specific Instrumentation
|
H10
|
Radio Equipment
|
SECTION I - PRODUCTION TEST EQUIPMENT
|
|
11
|
Burners
|
12
|
Burner Booms
|
13
|
Lines Required on Burner Booms
|
14
|
Sprinkler System
|
15
|
Fixed Lines for Well Tesing
|
16
|
Power Requirement
|
SECTION J - WORKOVER TOOLS
|
|
SECTION K - ACCOMMODATION
|
|
K1
|
Offices
|
K2
|
Living Quarters
|
SECTION L - SAFETY EQUIPMENT
|
|
L1
|
General Safety Equipment
|
L2
|
Gas Detection
|
L3
|
Fire Fighting Equipment
|
L4
|
Breathing Apparatus
|
L5
|
Emergency First Aid Equipment
|
L6
|
Helideck Rescue Equipment
|
L7
|
Rig Safety Store
|
L8
|
Emergency Warning Alarms
|
L9
|
Survival Equipment
|
SECTION M - POLLUTION PREVENTION EQUIPMENT
|
|
Ml
|
Sewage Treatment
|
M2
|
Garbage Compaction
|
M3
|
Garbage Disposal/Grinder
|
SECTION N - THIRD PARTY EQUIPMENT (SPACE PROVIDED)
|
A. UNIT SPECIFICATIONS
|
|||
GENERAL
|
|||
Unit Name
|
:
|
RBS8-D
|
|
Rig Type
|
:
|
SEMISUBMERSIBLE
|
|
Unit/design/shape
|
IHI - RBF Exploration
|
||
Unit flag
|
:
|
UNITED STATES
|
|
Unit classification
|
:
|
ABS
|
|
IMO Certification (yes/no)
|
:
|
YES
|
|
Which code version
|
:
|
1989 as ammended 1991
|
|
Year of construction
|
:
|
2,000
|
|
Construction yard
|
:
|
HYUNDAI
|
|
Type of Positioning system (anchor/dp/c
|
:
|
DPS-3
|
|
A.1 MAIN DIMENSIONS/TECHNICAL
|
|||
DESCRIPTION
|
|||
Weight (light ship)
|
lt:
|
21,977
|
|
Overall width
|
ft:
|
255.9
|
|
Overall length
|
ft:
|
396
|
|
Main deck width
|
ft:
|
200.1
|
|
Main deck length
|
ft:
|
275.9
|
|
Main deck depth
|
ft:
|
27.9
|
|
Number of main columns/diameter
|
No x ft:
|
4 x 55.8 x 54.1 (WL) 45.9 x 54.1 (Bottom)
|
|
Number of small columns/diameter
|
No x ft
|
0
|
|
Drilling draft/related displacement
|
ft - lt:
|
75.5 / 46,767
|
|
Transit draft/related displacement
|
ft - lt:
|
28.9 / 32,247
|
|
Survival draft/related displacement
|
ft - lt:
|
54 / 40,064
|
|
Moon pool dimensions
|
ft x ft:
|
21 X 93
|
|
Maximum opening through spider deck
|
ft - lt:
|
N/A
|
|
Pontoon length
|
ft - lt:
|
374
|
|
Pontoon breadth (ends / middle)
|
54.1 / 44.0
|
||
Pontoon height
|
ft - lt:
|
29.9
|
|
Accommodation for maximum no. of persons
|
:
|
130
|
|
A.2 STORAGE CAPACITIES
|
|||
Fuel
|
bbls:
|
21,811
|
|
Drilling water
|
bbls:
|
19,874
|
|
Potable water
|
bbl:
|
4050
|
|
Active liquid mud (see F.2)
|
bbl:
|
4434 (100%)
|
|
Mud processing tank (see F.2)
|
bbl:
|
450 (100%)
|
|
Reserve liquid mud (see F.2)
|
bbl:
|
5710 (100%)
|
|
Bulk bentonite/barite (see F.3)
|
cu ft:
|
13,675 (100%)
|
|
Bulk cement (see F.3)
|
cu ft:
|
11000 (100%)
|
|
Sack storage
|
No. or ft2:
|
10000 sxs
|
|
Pipe racks area
|
ft2:
|
9,376
|
|
Load bearing capacity
|
lb/ft2:
|
500
|
|
Riser racks area
|
ft:
|
10,000
|
|
Load bearing capacity
|
lb/ft2:
|
300
|
|
Miscellaneous storage area
|
ft2:
|
See Drawing
|
|
Brine storage (Column)
|
bbls:
|
3019 (100%)
|
Brine storage (Pontoon)
|
bbls:
|
25,000 (100%)
|
|
Base oil mud storage
|
bbls:
|
3019 (100%)
|
|
Ballast system
|
bbls:
|
102,565
|
|
A.3 PROPULSION/THRUSTERS
|
|||
Thrusters\Type (azimuth/in line)
|
:
|
AZIMUTH - FULL 360
|
|
Quantity
|
:
|
8
|
|
Location (aft, opposite corners, 4 corners
|
:
|
FOUR CORNERS
|
|
Driven by electric motor (yes/no)
|
:
|
YES - VARIABLE SPEED DRIVE
|
|
Make/type
|
:
|
Kamewa
|
|
Power output (HP ea)
|
:
|
6633
|
|
Propeller type (fixed/variable pitch)
|
:
|
FIXED
|
|
Nozzled (yes/no)
|
:
|
YES
|
|
Thruster power (HP total)
|
:
|
53064
|
|
DP SYSTEM
|
:
|
||
Class III Dynamic Positioning System in accordance with ABS DPS-3 requirements and recommendations. System to consist of a main triple redundant dynamic positioning system and shall accept inputs from the team selected and proven state of the art Acoustic Positioning System, two differential GPS (DGPS) based on correction signal inputs from different sources, (3) three gyrocompass, (3) three vertical reference units with redundant feeds to the DP system, and three wind sensors, as well as operator input and input from the ERA (Electrical Riser Angle) system. The system shall be powered from a redundant UPS. A single dynamic positioning system of similar design as the main DP system, will accept inputs from the APS, the two DGPS’s, the ERA system, one gyrocompass, one vertical reference unit, and one wind sensor. The system contains the
Power Management System and is interfaced with the Integrated Alarm and Control System. The system shall be powered from a dedicated UPS.
|
|||
Position reference
|
:
|
HYDRO ACOUSTIC & GLOBAL POSITIONING
|
|
Integrated Alarm And Control System:
|
The IACS will operate as the Sys.Control and Data acquisition sys. for the MODU. The IACS will perform several different functions including: Power Management Sys., Machinery Monitoring and Control, Manual Thruster Control and Autopilot, Dynamic Positioning Control, Ballast / Bunker Monitoring and Control, Bulk Storage Sys. Monitoring and Control.
|
||
A.4 OPERATIONAL CAPABILITIES
|
|||
Maximum designed water depth capability
|
ft:
|
10000
|
|
Outfitted max. water depth capability
|
ft:
|
8000
|
|
Normal min. water depth cpability
|
ft:
|
250
|
|
Drilling depth capability (rated)
|
ft:
|
30000
|
|
Transit speed towed (historical avg)
|
knots:
|
4.5
|
Transit speed self propelled (historical avg)
|
knots:
|
7.5
|
|
A.5 VARIABLE LOADING (VL)
|
|||
Transit VL
|
mt
|
See B-1
|
|
Drilling VL
|
mt
|
See B-1
|
|
Survival VL
|
mt
|
See B-1
|
|
A.6 ENVIRONMENTAL LIMITS
|
|||
Drilling (including station keeping)
|
See Exhibit B-1
|
||
Air gap
|
ft:
|
32.8
|
|
Sign. Wave Height
|
ft:
|
26
|
|
Max. wave height
|
ft:
|
48.2
|
|
Spec. peak period
|
sec:
|
PMS
|
|
Max. wind velocity
|
knots:
|
60 ( 1 min.)
|
|
Max. current velocity
|
knots:
|
See B-1
|
|
Max. heave
|
ft:
|
N/A
|
|
Max. pitch
|
degrees:
|
N/A
|
|
Max. roll
|
degrees:
|
N/A
|
|
Survival (excluding station keeping)
|
|||
Air gap
|
ft:
|
54.2
|
|
Sig. Wave height
|
ft:
|
41
|
|
Max. wave height
|
ft:
|
72.2
|
|
Spec. peak period
|
sec:
|
15
|
|
Max. wind velocity
|
knots:
|
103 ( 1 min.)
|
|
Max. current velocity
|
knots:
|
1.9
|
|
Max. heave
|
ft:
|
N/A
|
|
Max. pitch
|
degrees:
|
N/A
|
|
Max. roll
|
degrees:
|
N/A
|
|
Transit (field move)
|
|||
Air gap
|
ft:
|
79.4
|
|
Max. wave height
|
ft:
|
30-40
|
|
Max. wave period
|
sec:
|
8-12
|
|
Max. wind velocity
|
knots:
|
60-70
|
|
Max. current velocity
|
knots:
|
2-3
|
|
Max. heave
|
ft:
|
N/A
|
|
Max. pitch
|
degrees:
|
N/A
|
|
Max. roll
|
degrees:
|
N/A
|
|
A.7 MOORING SYSTEM
|
MOD’S REQ’D FOR THE FUTURE INSTALLATION OF OPERATOR FURNISHED CHAIN WINDLASSES WILL BE PERFORMED DURING THE CONSTRUCTION PHASE AT THE SHIPYARD INCLUDING FOUNDATIONS / PRIMARY PIPING & WIRING.
|
||
A.7.1 ANCHOR WINCHES
|
|||
Quantity
|
no.:
|
N/A
|
|
Make
|
|||
Type (electric/hydraulic/diesel)
|
:
|
||
Rated pull
|
mt
|
||
Speed low gear
|
ft/m:
|
Test load
|
:
|
||
Control locations (local/remote/both)
|
:
|
||
Emergency release (type/location)
|
:
|
||
A.7.2 FAIRLEADS
|
Foundations to be installed in shipyard
|
||
Quantity
|
no:
|
||
Make
|
:
|
||
Free rotating range
|
degrees:
|
||
A.7.3 ANCHORS
|
Company Supplied
|
||
A.7.3.1 ANCHORS - Primary
|
Company Supplied
|
||
A.7.3.2 ANCHORS - Spare
|
Company Supplied
|
||
A.7.4 ANCHOR LINES
|
Company Supplied to be installed at later date
|
||
A.7.5 ANCHOR LINE RUNNING / RETRIE’
|
N/A
|
||
A.7.5.1 PENNANT LINES
|
N/A
|
||
A.7.5.2 ANCHOR BUOYS
|
N/A
|
||
A.7.5.3 CHASER
|
N/A
|
||
A.7.6 TOWING GEAR
|
|||
Towing bridle size
|
inches:
|
Installation of a tow bridle will be evaluated by the team.
|
|
Hook-up system
|
:
|
||
Rating
|
lt:
|
||
Power required for infield tow
|
bollard pull lt:
|
N/A
|
|
Power required for ocean tow
|
bollard pull lt:
|
N/A
|
|
Spare bridle
|
yes/no:
|
yes
|
|
A.7.7 SUPPLY VESSEL MOORING LINES
|
:
|
||
Quantity
|
no.:
|
4
|
|
System
|
mt:
|
TO BE EVALUATED BY TEAM
|
|
Rating
|
lt:
|
TBA
|
|
A.8 MARINE LOADING HOSES
|
|||
Location of loading manifolds (port/stbd
|
:
|
BOTH
|
|
A.8.1 POTABLE WATER HOSE
|
|||
Quantity
|
no.:
|
2 x 150’
|
|
Size
|
inch:
|
3
|
|
Make/Type
|
:
|
TBA
|
|
Color coding
|
yes/no:
|
YES
|
|
Make/Type/Connection
|
TBA
|
||
A.8.2 DRILLING WATER HOSE
|
|||
Quantity
|
no.:
|
2 x 150’
|
|
Size
|
inch:
|
4
|
|
Make/Type
|
:
|
TBA
|
|
Color coding
|
yes/no:
|
YES
|
|
Make/Type connection
|
:
|
TBA
|
|
A.8.3 GAS OIL HOSE
|
|||
Quantity
|
no.:
|
2 x 150’
|
|
Size
|
inch:
|
4
|
Make/Type
|
:
|
TBA
|
||||
Color coding
|
yes/no:
|
yes
|
||||
Make/Type connection
|
:
|
TBA
|
||||
PRESSURE RATING
|
p.s.i
|
150 wp
|
||||
A.8.4 MUD CHEMICAL HOSE
|
||||||
Quantity
|
no.:
|
2 x 150’
|
||||
Size
|
inch:
|
5
|
||||
Make/Type
|
:
|
TBA
|
||||
Color coding
|
yes/no:
|
YES
|
||||
Make/Type connection
|
:
|
TBA
|
||||
A.8.5 CEMENT HOSE
|
||||||
Quantity
|
no.:
|
2 x 150’
|
||||
Size
|
inch:
|
5
|
||||
Make/ Type
|
:
|
TBA
|
||||
Color coding
|
yes/no:
|
YES
|
||||
Make/Type connection
|
:
|
TBA
|
||||
A.8.6 BASE OIL HOSE
|
||||||
Quantity
|
no.:
|
2 x 150’
|
||||
Size
|
inch:
|
4
|
||||
Make/Type
|
:
|
TBA
|
||||
Color coding
|
yes/no:
|
YES
|
||||
Make/Type connection
|
:
|
TBA
|
||||
Pressure Rating
|
150 psi wp
|
|||||
A.8.7 BRINE HOSE
|
||||||
Quantity
|
no.:
|
2 x 150’
|
||||
Size
|
inch:
|
4
|
||||
Make/Type
|
:
|
TBA
|
||||
Color coding
|
yes/no:
|
YES
|
||||
Make/Type connection
|
:
|
TBA
|
||||
A. 9 CRANES, HOISTS, AND MATERIALS HANDLING
|
||||||
A. 9.1 CRANES, REVOLVING, MAIN
|
||||||
Quantity
|
no.:
|
2
|
||||
Specification (API, etc.)
|
ABS /US-DEN
|
|||||
Make
|
:
|
LIEBHERR
|
||||
Type
|
:
|
PEDESTAL
|
||||
Location (stbd, port, aft, frwd)
|
:
|
PORT & STBD
|
||||
Maximum rated capacity (main hook)
|
mt
|
100
|
||||
Maximum rated capacity (whip hook)
|
mt
|
15
|
||||
Boom length
|
ft:
|
150
|
||||
Line length (no Boom
|
ft:
|
1893
|
||||
Main Hoist
|
ft:
|
1920
|
||||
Whip line
|
ft:
|
475
|
||||
Maximum capacity and hoisting speeds
|
||||||
Radius
|
Metric
|
|||||
Main Hoist
|
Platform Lift
|
4 lines
|
Meters
|
Tons
|
||
6.6
|
92
|
|||||
10
|
92
|
||||
11
|
92
|
||||
15
|
84.7
|
||||
20
|
71.8
|
||||
25
|
62.8
|
||||
30
|
55.6
|
||||
35
|
47.2
|
||||
40
|
39.7
|
||||
45
|
33.8
|
||||
48
|
31.1
|
||||
No Load
|
|||||
Radius
|
Metric
|
||||
Main Hoist
|
Seastate Lift
|
4 lines
|
Meters
|
Tons
|
|
6.6
|
51.5
|
||||
10
|
46
|
||||
11
|
44.8
|
||||
15
|
40.7
|
||||
20
|
36.8
|
||||
25
|
33.5
|
||||
30
|
30.6
|
||||
35
|
26.4
|
||||
40
|
22.4
|
||||
45
|
19.4
|
||||
48
|
18
|
||||
No load
|
|||||
Radius
|
Metric
|
||||
Main Hoist
|
Platform Lift
|
2 lines
|
Meters
|
Tons
|
|
6.6
|
50
|
||||
10
|
50
|
||||
11
|
50
|
||||
15
|
50
|
||||
20
|
50
|
||||
25
|
50
|
||||
30
|
50
|
||||
35
|
47.2
|
||||
40
|
39.7
|
||||
45
|
33.8
|
||||
48
|
31.1
|
||||
No load
|
|||||
Radius
|
Metric
|
||||
Main Hoist
|
Seastate Lift
|
2 lines
|
Meters
|
Tons
|
|
6.6
|
31.9
|
||||
10
|
31.9
|
||||
11
|
31.9
|
||||
15
|
31.9
|
||||
20
|
31.9
|
||||
25
|
31.9
|
||||
30
|
30.6
|
35
|
26.4
|
||||
40
|
22.4
|
||||
45
|
19.4
|
||||
48
|
18
|
||||
No Load
|
|||||
Radius
|
Metric
|
||||
Meters
|
Tons
|
||||
Whip Line
|
Platform Lift
|
51
|
15
|
||
Seastate lift
|
51
|
10
|
|||
No Load
|
|||||
Hook load indicator automatically corrected for boom angle
|
yes/no:
|
YES
|
|||
Alarm (audible, visual, both)
|
:
|
BOTH
|
|||
Automatic brake
|
yes/no:
|
YES
|
|||
Safety latch on hooks
|
yes/no:
|
YES
|
|||
Crown saver (limit switch)
|
yes/no:
|
YES
|
|||
Boom illumination
|
yes/no:
|
YES
|
|||
Baskets for personnel transfer
|
no.:
|
2
|
|||
A. 9.2 CRANES, REVOLVING, SECONDARY
|
|||||
Quantity
|
no.:
|
1
|
|||
Specification (API, etc.)
|
:
|
API
|
|||
Make
|
:
|
OUT REACH
|
|||
Type
|
:
|
KNUCKLEBOOM
|
|||
Location (stbd, port, aft, frwd)
|
:
|
FORWARD
|
|||
Maximum rated capacity (main hook)
|
lt:
|
3.57
|
|||
Maximum rated capacity (whip hook)
|
lt:
|
N/A
|
|||
Boom length
|
ft:
|
68
|
|||
Line length (nominal)
|
ft:
|
N/A
|
|||
A. 9.3 FORKLIFTS
|
|||||
Quantity
|
no.:
|
1
|
|||
Make/Type
|
:
|
TBA
|
|||
Rated capacity
|
lt:
|
TBA
|
|||
Explosion proof
|
yes/no:
|
YES
|
|||
A. 9.4 MONORAIL OVERHEAD CRANES
|
|||||
Quantity
|
no.:
|
1
|
|||
Make
|
:
|
MARITIME HYDRAULICS
|
|||
Type
|
:
|
GANTRY TYPE
|
|||
Rated capacity
|
mt
|
36
|
|||
Location
|
:
|
AFT RISER DECK
|
|||
A. 9.5 BOP HANDLING SYSTEM
|
|||||
Make/Type
|
HYDRALIFT BRIDGE CRANE
|
||||
Rated capacity (5 Ram Stack =551,300 lbs (250mt)) 310 T
|
|||||
BOP CARRIER
|
|||||
Make/Type
|
Hydralift “C” Cart complete with false rotary deck.
|
||||
Rated Capacity
|
310 Tons
|
A. 9.6 AIR HOISTS/DERRICK WINCHES
|
|||
A. 9.6.1 RIG FLOOR WINCHES (Non man-riding)
|
|||
Quantity
|
no.:
|
4
|
|
Make
|
:
|
INGERSAL RAND
|
|
Type
|
:
|
HYDRAULIC
|
|
Rated capacity
|
st:
|
5.5
|
|
Wire diameter
|
inch:
|
0.75
|
|
Automatic brakes
|
yes/no:
|
YES
|
|
Overload protection
|
yes/no:
|
NO
|
|
Automatic spooling
|
yes/no:
|
YES
|
|
A. 9.6.2 MONKEY BOARD WORK WINCH
|
|||
Quantity
|
no.:
|
1
|
|
Make
|
:
|
IR
|
|
Type
|
:
|
||
Rated capacity
|
st:
|
0.25
|
|
Wire diameter
|
yes/no:
|
3/8”
|
|
Automatic brakes
|
yes/no:
|
YES
|
|
Overload protection
|
yes/no:
|
NO
|
|
A. 9.6.3 RIG FLOOR “MAN-RIDING” WINCH
|
|||
Quantity
|
no.:
|
2
|
|
Make
|
:
|
Ingersoll Rand
|
|
Type
|
:
|
Hydraulic
|
|
Rated capacity
|
st:
|
0.25
|
|
Wire diameter/non-twist wire
|
inch:
|
3/8”
|
|
Automatic brakes
|
yes/no:
|
Yes
|
|
Overload protection
|
yes/no:
|
No
|
|
Automatic spooling
|
yes/no:
|
Yes
|
|
Certified for man-riding
|
yes/no:
|
Yes
|
|
A. 9.6.4 UTILITY WINCH (i.e. Deck Winch)
|
N/A
|
||
A. 9.6.5 CELLAR DECK WINCH
|
|||
Quantity
|
no.:
|
4
|
|
Make
|
:
|
Ingersoll Rand
|
|
Type
|
:
|
Air
|
|
Rated capacity
|
st:
|
5.5
|
|
Wire diameter
|
inch:
|
.75
|
|
Automatic brakes
|
yes/no:
|
No
|
|
Overload protection
|
yes/no:
|
No
|
|
Automatic spooling
|
yes/no:
|
Yes
|
|
Man -riding
|
:
|
2
|
|
A.10 HELICOPTER LANDING DECK
|
|||
Location
|
PORT/FWD. MAIN DECK
|
||
Dimensions
|
ft. x ft.:
|
72.8 X 72.8
|
|
Perimeter safety net
|
yes/no:
|
YES
|
|
Load capacity
|
lt:
|
9.15
|
Designed for helicopter type
|
:
|
SIKORSKY S-61
|
||||
Tie down points
|
yes/no:
|
YES
|
||||
Covered by foam fire system (See L.36)
|
yes/no:
|
YES
|
||||
A.10.1 HELICOPTER REFUELING SYSTEM
|
||||||
Fuel storage capacity
|
U.S. gals:
|
1440
|
||||
Jettisonable
|
yes/no:
|
NO
|
||||
Fuel transport containers
|
qty:
|
2
|
||||
Volume (ea)
|
:
|
720
|
||||
Covered by foam fire system (See L.3.5)
|
yes/no:
|
YES
|
||||
A.11 AUXILIARY EQUIPMENT
|
||||||
A.11.1 WATER DISTILLATION
|
||||||
Quantity
|
no.:
|
4
|
||||
Make/Type
|
Alfa Laval or equivalent
|
|||||
Capacity (each/total)
|
cu. ft./day:
|
26 Metric Ton each (Depending on engine utilization)
|
||||
A.11.2 BROILERS
|
N/A
|
|||||
A.11.3 AIR CONDITIONING
|
||||||
Quantity
|
no.:
|
5
|
||||
Make/Type
|
:
|
|||||
Capacity (total system)
|
tons:
|
|||||
A.11.4 ELECTRIC WELDING SETS
|
||||||
Quantity
|
no.:
|
3
|
||||
Current capacity
|
amp:
|
400
|
||||
Make/Type
|
:
|
Lincoln S-7046 SAE 400
|
||||
A.11.5 HIGH PRESSURE CLEANER
|
||||||
Quantity
|
no.:
|
1
|
||||
Make/Type
|
:
|
Weatherford
|
||||
Electric/pneumatic
|
:
|
Electric
|
||||
Max delivered pressure
|
psi:
|
2700
|
||||
Ring Main
|
yes/no
|
Yes
|
||||
Outlets
|
Number
|
6
|
||||
B. GENERAL RIG SPECIFICATIONS
|
||||||
B.1 DERRICK AND SUBSTRUCTURE
|
||||||
B.1.1. DERRICK/MAST
|
||||||
Make/Type
|
:
|
DRECO
|
||||
Rated for wind speed:
|
||||||
With full set back
|
knots:
|
100
|
||||
With no set back
|
knots:
|
100
|
||||
Height
|
ft:
|
210 estimated. Final height to be evaluated by Dreco.
|
||||
Dimensions of base
|
ft x ft:
|
48X48
|
||||
Dimensions of crown
|
ft x ft:
|
18x18
|
||||
Gross nominal capacity
|
st.:
|
1250
|
||||
Maximum Number of lines
|
no.:
|
14
|
||||
Ladders with safety cages and rests
|
yes/no:
|
yes
|
|
Platform for crown sheave access
|
yes/no:
|
yes
|
|
Counter balance, system for rig tongs and pipe spinning tong
|
yes/no:
|
yes
|
|
Lighting system explosion proof
|
yes/no:
|
yes
|
|
(adjustable fingers on the right hand side can have any one of the casing below racked back at any one time, but not all)
|
Unit is capable of field transiting with 238 stands of drillpipe without exceeding rated design loads of derrick.
|
||
Make/Type
|
:
|
Varco
|
|
Racking platform total capacity with 5-1
|
ft:
|
31,000 (nominal)
|
|
Fixed Fingers (on left side of derrick) - u
|
ft:
|
20000 (nominal)
|
|
Adjustable fingers (on right side) - 7” Ca
|
ft:
|
11000 (nominal)
|
|
or
|
|||
Adjustable fingers (on right side) - 9-5/8
|
ft:
|
11000 (nominal)
|
|
or
|
|||
Adjustable fingers (on right side) - 13-3/
|
ft:
|
9500 (nominal)
|
|
Racking platform capacity of 8” - 9” DC
|
no.:
|
8
|
|
Auxiliary Derrick (Moonpool)
|
|||
Make / Type
|
Dreco
|
||
Capacity
|
300 Tons
|
||
B.1.3 AUTOMATIC PIPE RACKER
|
|||
Make/Type
|
:
|
2 - Varco PRS-6 Pipe Rackers
|
|
Pipe racker on forward side to be capable of handling 20”, 16”, 13-3/8”, 11-3/4”, 9-7/8”, 7-5/8”, and 7” casing
|
|||
B.1.4 CASING STABBING BOARD
|
|||
Make/Type
|
:
|
Dreco / Hyd.
|
|
Adjustable from/to height above R/table
|
ft/ft:
|
Adjustable Casing Stabbing Basket - 45’ reach
|
|
Auxiliary Pipe Handler (Moonpool)
|
|||
Make / Type
|
National
|
||
B.1.5 SUBSTRUCTURE
|
|||
Make/Type
|
:
|
H.H.I
|
|
Height
|
ft :
|
14.75’
|
|
Width
|
ft:
|
80
|
|
Length
|
ft:
|
71
|
|
Setback capacity
|
st:
|
1000
|
|
Hookload
|
st
|
1000
|
|
Simultaneous setback-hookload capacity
|
st:
|
2000
|
|
Tensioner capacity
|
st
|
1750
|
|
Clear height below R/table beams (from
|
ft:
|
29.5
|
|
B.1.6 WEATHER PROOFING
|
|||
Rig floor windbreaks height
|
ft:
|
10
|
|
Derrickman windbreaks height
|
ft:
|
15
|
B.1.7 DERRICK TV CAMERA SYSTEM
|
|||
Camera located at
|
:
|
Monkey Board/ Crown
|
|
Make/Type
|
:
|
Color
|
|
Zoom/Pan/Tilt-function
|
yes/no:
|
yes
|
|
Monitor located at
|
:
|
Driller’s House
|
|
B.2 DRAWWORKS AND ASSOCIATED EQUIPMENT
|
|||
B.2.1 DRAWWORKS
|
|||
Make/Type
|
:
|
Dreco/Hitec
|
|
Drum type
|
:
|
Lebus Grooving, 2” drill line
|
|
Spinning cathead type
|
:
|
Refer D 2.1.7
|
|
Breakout cathead type
|
:
|
N/A
|
|
Crown block safety device
|
:
|
YES
|
|
Make
|
:
|
||
Model
|
:
|
||
Rated input power continuous
|
hp:
|
6900
|
|
Rated input power maximum
|
hp:
|
8400
|
|
Drum Diameter
|
inches:
|
73.5
|
|
Maximum line pull 14 lines
|
st:
|
1000
|
|
Maximum line pull 12 Lines
|
|||
Maximum line pull 10 lines
|
st:
|
600
|
|
Maximum line pull 8 lines
|
st:
|
||
Independent fresh water cooling system for
|
|||
drawworks
|
yes/no:
|
yes
|
|
B.2.2 DRAWWORKS POWER
|
|||
Number of electric motors
|
no.:
|
8
|
|
Make
|
:
|
General Electric
|
|
Model
|
:
|
GEB 22A1
|
|
Output power continuous
|
hp:
|
1150
|
|
Output power intermittent (max.)
|
hp:
|
1400
|
|
B.2.3 AUXILIARY BRAKE
|
|||
Make
|
:
|
Hitec
|
|
Model
|
:
|
Regenerative AC braking,
|
|
Independent back-up system type
|
:
|
Failsafe disc brakes
|
|
B.2.4 SANDLINE
|
NA
|
||
B.2.5 AUTOMATIC DRILLER
|
|||
Make/Type
|
:
|
Hitec
|
|
AUXILIARY DRAWWORKS (Moonpool)
|
|||
Make / Type
|
National / AC
|
||
Lift Capacity
|
300 Tons
|
||
Input HP
|
1,000
|
B.3 DERRICK HOISTING EQUIPMENT
|
|||
B.3.1 CROWN BLOCK
|
|||
Make/Type
|
:
|
Dreco
|
|
Rated capacity
|
st:
|
1000
|
|
No. of sheaves
|
no.:
|
7
|
|
Sheave diameter
|
inches:
|
72
|
|
Sheave grooved for line size
|
inches:
|
2
|
|
AUXILIARY CROWN BLOCK (Moonpool)
|
|||
Make / Type
|
Dreco
|
||
Rated Capacity
|
300 Tons
|
||
B.3.2 TRAVELING BLOCK
|
|||
Make/Type
|
:
|
Dreco
|
|
Rated capacity
|
st:
|
1000
|
|
No. of sheaves
|
no.:
|
7
|
|
Sheave diameter
|
inches:
|
72
|
|
Sheave grooved for line size
|
inch:
|
2
|
|
AUXILIARY TRAVELING BLOCK
|
|||
Make / Type
|
Dreco
|
||
Rated Capacity
|
300 Tons
|
||
B.3.3 HOOK
|
N/A
|
||
Make/Type
|
:
|
||
Rated capacity
|
st:
|
||
Complete with spring assembly/hook loc
|
yes/no:
|
||
B.3.4 SWIVEL
|
|||
Make/Type
|
:
|
None
|
|
Rated capacity
|
st:
|
||
Test/working pressure
|
psi/psi:
|
||
Gooseneck and washpipe minimum ID >
|
yes/no:
|
||
Left hand pin connection size
|
inches:
|
||
Access fitting for wireline entry on top o
|
yes/no:
|
||
B.3.5 DRILLING LINE
|
|||
Diameter
|
inch:
|
2”
|
|
Type
|
:
|
6 x 26 EIPS, IWRC
|
|
Length (original)
|
ft:
|
12500
|
|
Support frame for drum/cover
|
yes/no:
|
yes
|
|
Drilling line drum power driven
|
yes/no:
|
yes
|
|
Spare reel drilling line
|
yes/no:
|
no
|
|
Location (rig, shore, etc.)
|
:
|
||
B.3.6 ANCHOR DEAD LINE
|
|||
Make/Type
|
:
|
Dreco
|
|
Weight sensor
|
yes/no:
|
yes
|
|
B.3.7 DRILL STRING MOTION COMPENSATOR
|
|||
Make/Type
|
:
|
Hitec ASA Active Heave Comp.
|
|
Stroke
|
ft:
|
14.5
|
Capacity - compensated
|
st:
|
500
|
||
Capacity - locked
|
st:
|
1000
|
||
B.3.8 BLOCK GUIDANCE SYSTEM
|
||||
Make/Type
|
:
|
DRECO
|
||
B.3.9 RETRACTION SYSTEM FOR TRAVELING BLOCK
|
||||
Make/Type
|
:
|
Varco/Retrac. Dolly
|
||
B.4 ROTATING SYSTEM
|
||||
B.4.1 ROTARY TABLE
|
||||
Make/Type
|
:
|
Varco
|
||
Maximum opening
|
inches:
|
60
|
||
Rated capacity
|
st:
|
1000
|
||
Static load capacity
|
st:
|
1000
|
||
Rotating load capacity
|
st @ rpm:
|
TBA
|
||
Two speed gearbox
|
yes/no:
|
No
|
||
Max RPM @t Max Torque
|
RPM/ Ft lbs
|
17/48000
|
||
Emergency chain drive
|
yes/no:
|
no
|
||
Driven by an independent electric motor
|
yes/no:
|
No
|
||
Electric motor type/make
|
:
|
Hydraulic x 4
|
||
Maximum continuous torque
|
ft/lbs:
|
48000
|
||
Drip pan/mud collection system
|
yes/no:
|
yes
|
||
B 4.2 ROTARY TABLE ADAPTER BUSHING
|
||||
Size
|
“
|
60 1/2 x 49 1/2
|
||
Quanity
|
:
|
1
|
||
Size
|
“
|
49 1/2 x 37 1/2
|
||
Quanty
|
:
|
|||
B.4.3 MASTER BUSHING
|
||||
Make/Type
|
:
|
Varco MPCH
|
||
Size
|
inch:
|
37-1/2
|
||
Inset Bushings
|
#’s
|
3,2,1
|
||
B.4.4 KELLY BUSHING
|
||||
B.4.5 TOP DRIVE
|
||||
Make
|
:
|
National or Varco
|
||
Type (electric/hydraulic)
|
:
|
Electric
|
||
Rated capacity
|
st:
|
1000 or 750 (if 750 parking system to be supplied)
|
||
Test/working pressure
|
psi/psi:
|
11250 / 7500
|
||
Remote operated kelly cock
|
yes/no:
|
YES
|
||
If driven by electric motor
|
||||
Make/Type
|
:
|
GE GEB-20AC
|
||
Output power
|
hp:
|
1150
|
||
Output torque
|
ft lbs:
|
Per Manufacturers rating
|
||
Max Torque @ Max RPM
|
Ft lb/s RPM
|
Per Manufacturers rating
|
||
Two speed gearbox
|
yes/no:
|
No
|
||
Maximum rotary speed
|
rpm:
|
270
|
||
Cooling system type
|
:
|
AIR
|
||
B.4.6 TOP DRIVE MAKEOUT/BREAKOUT SYSTEM
|
|||
Make
|
:
|
National or Varco
|
|
Model
|
:
|
||
Type
|
:
|
HYDRAULIC
|
|
Max. breakout torque that can be applied
|
ft/lbs:
|
100000
|
|
B.4.7 RAISED BACKUP SYSTEM
|
|||
Make
|
:
|
Varco
|
|
Model
|
:
|
RBS 4
|
|
Torque rating
|
:
|
100,000 Ft Lb
|
|
Vertical Travel
|
:
|
10 Ft
|
|
Pipe range
|
:
|
4 3/4” to 8 1/4”
|
|
C. POWER SUPPLY SYSTEMS
|
|||
C.1 RIG POWER PLANT
|
|||
C.1.1 DIESEL ENGINES
|
|||
Quantity
|
no.:
|
6
|
|
Make/Type
|
:
|
18V32
|
|
Maximum continuous power
|
hp:
|
7290
|
|
At rotation speed of
|
rpm:
|
720
|
|
Equipped with spark arrestors
|
yes/no:
|
YES
|
|
Mufflers installed
|
yes/no:
|
YES
|
|
Total fuel consumption, drilling (average
|
bbl/day:
|
Av 375. Estimate only, based on GOM weather and will vary depending on operations
|
|
C.1.2 DC - GENERATOR
|
Type:
|
N/A
|
|
C.1.3 AC-GENERATOR
|
|||
Quantity
|
no.:
|
6
|
|
Make/Type
|
:
|
TBA
|
|
Continuous power
|
kw:
|
7000
|
|
At rotation speed of
|
rpm:
|
720
|
|
Output volts
|
volts:
|
42,000 kw
|
|
Quantity
|
no.:
|
||
Make/Type
|
:
|
||
Continuous power
|
kw:
|
||
At rotation speed of
|
rpm:
|
||
Output volts
|
volts:
|
||
C.1.4 VARIABLE FREQUENCY DRIVES
|
|||
Number of Inverters
|
no.:
|
19 INVERTERS
|
|
Make/Type
|
:
|
TBA
|
|
Maximum continuous power (total)
|
kw:
|
15130 KW
|
|
Output volts
|
volts:
|
0-600AC
|
|
C.1.5 TRANSFORMER SYSTEM
|
|||
Quantity
|
no.:
|
8 THRUSTER TRANSFORMERS
|
|
Make/Type
|
:
|
TBA
|
|
Continuous power (each)
|
KVA:
|
5000 KVA
|
Output volts
|
volts:
|
2300
|
|
Frequency
|
Hz:
|
60
|
|
Quantity
|
no.:
|
6 DRILLING TRANSFORMERS
|
|
Make/Type
|
:
|
TBA
|
|
Continuous power (each)
|
KVA:
|
2500
|
|
Output volts
|
volts:
|
600
|
|
Frequency
|
Hz:
|
60
|
|
C.1.6 EMERGENCY SHUTDOWN
|
|||
Emer. shutdown switches for complete power sys.
|
CENTRAL CONTROL ROOM
|
||
(AC and DC), located at the following points
|
:
|
RIG FLOOR
|
|
ENGINE CONTROL ROOM
|
|||
C.1.7 AUXILIARY POWER SUPPLY
|
|||
Power supply for a mud logging unit
|
yes/no:
|
YES
|
|
Power supply available:
|
|||
Output volts
|
volts:
|
480
|
|
Frequency
|
Hz:
|
60
|
|
Current
|
amps:
|
100
|
|
Phase
|
single/three
|
THREE
|
|
C.1.8 COMPRESSED AIR SYSTEMS
|
|||
Air Compressors - High Pressure:
|
|||
Quantity
|
no:
|
2
|
|
Make
|
:
|
Hamworthy
|
|
Model
|
:
|
w1234
|
|
Rated capacity
|
cu ft/hr:
|
65 cfm
|
|
Working press
|
psi:
|
5000
|
|
Prime mover (electric/diesel)
|
hp:
|
Electrical
|
|
Continuous power
|
hp:
|
60
|
|
Air dryers
|
|||
Quantity
|
no.:
|
2
|
|
Make/Type
|
:
|
Hamworthy Regenerative Tower (Dual)
|
|
Rated Capacity
|
cu ft/min:
|
||
Air Compressors - Medium Pressure (rig air):
|
|||
Quantity
|
no:
|
3
|
|
Make
|
:
|
Gardner Denver
|
|
Model
|
:
|
EGQSP Rotary Screw
|
|
Rated capacity
|
cu ft/hr:
|
750 SCFM
|
|
Working press
|
psi:
|
125 psi
|
|
Prime mover (electric/diesel)
|
hp:
|
Electric
|
|
Continuous power
|
hp:
|
200
|
|
Air dryers
|
|||
Quantity
|
no.:
|
3
|
|
Make/Type
|
:
|
Dessicant Domnick Hunter / DX110 Heatless
|
|
Rated Capacity
|
cu ft/min:
|
1080 scfm
|
|
Air Compressors - Low Pressure (bulk air):
|
None - Reducing Stations
|
||
Quantity
|
no:
|
2
|
|
Make
|
:
|
Kimray
|
|
Model
|
:
|
Reducing Valve / Back Pressure Valve ABY / AAU 3”
|
|
Rated capacity
|
cu ft/hr:
|
10,600 Each
|
|
Working press
|
psi:
|
60
|
C.2 EMERGENCY GENERATOR - Emergency Generator not required due to power system design
|
||||
C.2.1 ENGINE
|
||||
AUXILIARY POWER PLANT
|
||||
C.2.1 ENGINE
|
Data, for Anchored ver.may change for RBS8-D
|
|||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
CATERPILLAR 3508B
|
||
Maximum output
|
kw:
|
500
|
||
At rotation speed
|
rpm:
|
1200
|
||
Starting methods (automatic, manual, air
|
:
|
AUTOMATIC
|
||
Max. angle of operation
|
degrees:
|
22.5 PER ABS
|
||
C.2.2 AC-GENERATOR
|
||||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
CATERPILLAR SR4
|
||
Maximum output
|
kw:
|
500
|
||
At rotation speed
|
rpm:
|
1200
|
||
Output volts
|
volts:
|
480
|
||
Capable of back-feeding to main bus
|
yes/no:
|
YES - TO 480V BUS
|
||
C.3 PRIMARY ELECTRIC MOTORS
|
||||
C.3.1 PROPULSION MOTORS
|
Type:
|
See Thruster Motors
|
||
C.3.2 THRUSTER MOTORS
|
||||
Quantity
|
no.:
|
8
|
||
Type (AC/DC)
|
:
|
TBA
|
||
Power of each
|
MW
|
5.5
|
||
Total power
|
MW
|
|||
D. DRILLSTRING EQUIPMENT
|
||||
D.1 TUBULARS
|
||||
D.1.1 KELLIES
|
||||
D.1.2 TOP DRIVE SAVER SUBS
|
||||
Quantity
|
no.:
|
2
|
||
Connection type
|
:
|
HT 55
|
||
API classification
|
:
|
8 C
|
||
Protector
|
yes/no:
|
No
|
||
Quantity
|
no.:
|
2
|
||
Connection type
|
:
|
4 1/2 IF
|
||
API classification
|
:
|
8 C
|
||
Protector
|
yes/no:
|
No
|
D.1.3 DRILL PIPE
|
||||
Drill pipe OD
|
inch:
|
5.5
|
||
Grade
|
:
|
S135
|
||
Total length
|
ft:
|
22000
|
||
Range
|
:
|
3
|
||
Weight
|
lbs/ft:
|
21.9 Nonimal
|
||
Tensile yield strength Premium
|
lbs:
|
621000
|
||
Internally plastic coated
|
yes/no:
|
Yes,TK-34
|
||
Tool joint OD/ID
|
inch/inch:
|
71 /4” x 4” provisional
|
||
Make up torque
|
Ftt/lbs
|
46300
|
||
Tool joint pin length
|
inch:
|
10
|
||
Tapered shoulder tool joints
|
degree:
|
18
|
||
Connection type
|
:
|
HT 55
|
||
Type of hardfacing
|
:
|
Armacor M
|
||
API classification
|
:
|
PREMIUM
|
||
Thread protectors
|
yes/no:
|
Yes
|
||
Drill pipe OD
|
inch:
|
5
|
||
Grade
|
:
|
S-135
|
||
Total length
|
ft:
|
8000
|
||
Range
|
:
|
3
|
||
Weight
|
lbs/ft:
|
19.5 Nominal
|
||
Tensile yield strength Premium
|
lbs
|
560000
|
||
Internally plastic coated
|
yes/no:
|
Yes TK-34
|
||
Tool joint OD/ID
|
inch/inch:
|
6 5/8” x 3 1 1/6”
|
||
make up Torque
|
Ft/lbs
|
32900
|
||
Tool joint pin length
|
inch:
|
9”
|
||
Tapered shoulder tool joints
|
degree:
|
18
|
||
Connection type
|
:
|
4 1/2 “IF
|
||
Type of hardfacing
|
:
|
Armacor M
|
||
API classification
|
:
|
PREMIUM
|
||
Thread protectors
|
yes/no:
|
Yes
|
||
Drill pipe OD
|
inch:
|
5.5
|
||
Grade
|
:
|
S-135
|
||
Total length
|
ft:
|
8000
|
||
Range
|
:
|
3
|
||
Weight
|
lbs/ft:
|
38
|
||
Tensile yield s Premium
|
lbs
|
1170600
|
||
Internally plastic coated
|
yes/no:
|
Yes
|
||
Tool Joint OD/ID
|
inch/inch:
|
7 1/8 x 3 3/4 Provisional
|
||
Tool joint pin length
|
inch:
|
10
|
||
Tapered shoulder tool joints
|
degree:
|
18
|
||
Connection type
|
:
|
HT 55
|
||
Type of hardfacing
|
:
|
Armacor M
|
||
API classification
|
:
|
Premium
|
||
Thread protectors
|
yes/no:
|
Yes
|
||
D.1.4 DRILL PIPE PUP JOINTS ( Integral)
|
||||
O.D
|
5.5”
|
|||
Grade/Yield
|
:
|
4145 H Equiv. To 120K
|
Tool joint OD/ID
|
inch/inch:
|
7 1/4 x 3 3/4 ”
|
||
Weight
|
LB/FT
|
40
|
||
Connection type
|
HT-55
|
|||
Stress relief pin groove
|
:
|
No
|
||
Boreback on box
|
:
|
No
|
||
Internally plastic coated
|
yes/no:
|
No
|
||
Thread protectors
|
yes/no:
|
Yes,
|
||
Length
|
ft:
|
10
|
||
Quantity
|
no:
|
1
|
||
Length
|
ft:
|
15
|
||
Quantity
|
no:
|
2
|
||
Length
|
ft:
|
20
|
||
Quantity
|
1
|
|||
O.D
|
:
|
5”
|
||
Grade/ Yield
|
:
|
4145 H equiv to 120 K
|
||
Tool joint OD/ID
|
inch/inch:
|
6 5/8” x 2 3/4 ”
|
||
Grade
|
:
|
4145 H Equiv. To 120K
|
||
Weight
|
LB/FT
|
TBA
|
||
Connection type
|
4 1/2” IF
|
|||
Stress relief pin groove
|
:
|
Yes
|
||
Boreback on box
|
:
|
Yes
|
||
Internally plastic coated
|
yes/no:
|
No
|
||
Thread protectors
|
yes/no:
|
Yes
|
||
Length
|
ft:
|
10
|
||
Quantity
|
no:
|
1
|
||
Length
|
ft:
|
15
|
||
Quantity
|
no:
|
2
|
||
Length
|
ft:
|
20
|
||
Quantity
|
1
|
|||
Thread protectors
|
yes/no:
|
yes
|
||
D.1.5 DRILL PIPE PUP JOINT:
|
Size:
|
N/A
|
||
D 1.6 HEAVY WEIGHT DRILL PIPE (Integral)
|
||||
Quantity
|
no.:
|
30
|
||
Nominal size OD
|
inch:
|
5”
|
||
Weight
|
lbs/ft:
|
49.1 Nonimal
|
||
Range
|
:
|
2
|
||
Tool joint OD
|
inch:
|
6 5/8”
|
||
Tool joint ID
|
inch:
|
3 1/16”
|
||
Pin Stress relief groove
|
yes/no
|
yes
|
||
Box , Bore back
|
yes/no
|
yes
|
||
Type of hardfacing
|
:
|
Pinnchrome ( team to review)
|
||
Internally plastic coated
|
yes/no:
|
No
|
||
Connection type
|
:
|
4 1/2 IF
|
||
Thread protectors
|
yes/no:
|
Yes, Bale type
|
||
Quantity
|
no.:
|
30
|
||
Nominal size OD
|
inch:
|
5 1/2”
|
||
Weight
|
lbs/ft:
|
58” Nonimal
|
||
Range
|
:
|
2
|
Tool joint OD
|
inch:
|
7 1/4”
|
||
Tool joint ID
|
inch:
|
3 3/4”
|
||
Pin Stress relief groove
|
yes/no
|
No
|
||
Box , Bore back
|
yes/no
|
No
|
||
Type of hardfacing
|
:
|
Pinnchrome ( Team to review)
|
||
Internally plastic coated
|
yes/no:
|
No
|
||
Connection type
|
:
|
HT 55
|
||
Thread protectors
|
yes/no:
|
yes, Bale type
|
||
D.1.7 DRILL COLLARS
|
||||
Quantity
|
no.:
|
15
|
||
OD body
|
inches:
|
9.5
|
||
ID body
|
inches:
|
3”
|
||
Nominal Length of each joint
|
ft:
|
31.5 Nominal
|
||
Drill collar body (slick/spiral)
|
:
|
SPIRAL
|
||
Recess for “zip” elevator
|
yes/no:
|
yes
|
||
Recess for slips
|
yes/no:
|
yes
|
||
Stress relief pin groove
|
yes/no:
|
YES
|
||
Boreback on box
|
yes/no:
|
YES
|
||
B.S.R
|
2.72
|
|||
Connection type
|
:
|
7 5/8”reg
|
||
Thread protectors
|
yes/no:
|
yes, Bale type
|
||
Quantity
|
no.:
|
15
|
||
OD body
|
inches:
|
8 1/4”
|
||
ID body
|
inches:
|
2 13/16”
|
||
Nominal Length of each joint
|
ft:
|
31.5 Ft Nomimal
|
||
Drill collar body (slick/spiral)
|
:
|
SPIRAL
|
||
Recess for “zip” elevator
|
yes/no:
|
yes
|
||
Recess for slips
|
yes/no:
|
yes
|
||
Stress relief pin groove
|
yes/no:
|
YES
|
||
Boreback on box
|
yes/no:
|
YES
|
||
B.S.R.
|
2.93
|
|||
Connection type
|
yes/no:
|
6 5/8” reg
|
||
Thread protectors
|
yes/no:
|
yes, Bale type
|
||
Quantity
|
no.:
|
30
|
||
OD body
|
inches:
|
6 1/2
|
||
ID body
|
inches:
|
2 1/2”
|
||
Nominal Length of each joint
|
ft:
|
31.5 Ft Nominal
|
||
Drill collar body (slick/spiral)
|
:
|
SPIRAL
|
||
Recess for “zip” elevator
|
yes/no:
|
YES
|
||
Recess for slips
|
yes/no:
|
YES
|
||
Stress relief pin groove
|
yes/no:
|
YES
|
||
Boreback on box
|
yes/no:
|
YES
|
||
B.S.R
|
2.73
|
|||
Connection type
|
yes/no:
|
4 ” IF
|
||
Thread protectors
|
yes/no:
|
yes, Bale type
|
||
D.1.8 SHORT DRILL COLLARS
|
Company Supplied
|
|||
D.1.9 NON-MAGNETIC DRILL COLLARS
|
Company Supplied
|
|||
D.1.10 CORE BARRELS
|
Company Supplied
|
D.1.11 STABILIZERS
|
Company Supplied
|
|||
D.1.12 ROLLER REAMERS
|
Company Supplied
|
|||
D.1.13 SHOCK ABSORBERS (Damping Sub)
|
Company Supplied
|
|||
D.1.14 DRILLING JARS
|
Company Supplied
|
|||
D.1.15 INSIDE BOP VALVE
|
||||
Quantity
|
no.:
|
2
|
||
Make
|
:
|
SMF (provisional)
|
||
OD
|
inch:
|
TBA
|
||
Connection type
|
:
|
HT 55
|
||
Working pressure rating
|
psi:
|
15000
|
||
Quantity
|
no.:
|
2
|
||
Make
|
:
|
SMF (provisional)
|
||
OD
|
inch:
|
6 5/8”
|
||
Connection Type
|
4 1/2 IF
|
|||
Working Pressure
|
psi
|
15000
|
||
D.1.16 FULL OPENING SAFETY VALVE
|
||||
Quanty
|
2
|
|||
Make
|
:
|
SMF ( provisional)
|
||
O.D/ I.D
|
no.:
|
TBA ( Team to review & advise )
|
||
Connection type
|
:
|
HT 55
|
||
Working Pressure
|
15000
|
|||
Quanty
|
2
|
|||
Make
|
:
|
SMF ( provisional)
|
||
O.D/ I.D
|
no.:
|
6 5/8” / 2 13/16”
|
||
Connection type
|
:
|
4 1/2 IF
|
||
Working Pressure
|
15000
|
|||
D.1.17 CIRCULATION HEAD
|
N/A
|
|||
D.1.18 TOP DRIVE VALVES
|
||||
Upper
|
||||
Quantity
|
no.:
|
2
|
||
Make/Type
|
:
|
Varco
|
||
Working pressure
|
psi:
|
15000
|
||
Max. OD body
|
inch:
|
TBA
|
||
Min. ID body
|
inch:
|
TBA
|
||
Connection type
|
:
|
7 5/8 Reg
|
||
Lower
|
||||
Quantity
|
no.:
|
2
|
||
Make/Type
|
:
|
Varco
|
||
Working pressure
|
psi:
|
15000
|
||
Max. OD body
|
inch:
|
TBA
|
||
Min. ID body
|
inch:
|
TBA
|
||
Connection type
|
:
|
7 5/8 Reg
|
||
D.1.19 CIRCULATION SUBS
|
Company Supplied
|
|||
D.1.20 CUP TYPE TESTERS
|
Company Supplied
|
|||
D.1.21 PLUG TYPE TESTERS
|
Company Supplied
|
|||
D.1.22 DROP-IN VALVES
|
Company Supplied
|
D.1.23 NEAR-BIT SUBS (Box-Box)
|
||||
Quantity
|
no.:
|
2
|
||
OD size
|
inch:
|
9 1/2”
|
||
ID size
|
inch:
|
3”
|
||
Top connection
|
inch:
|
7 5/8 Reg
|
||
Boreback
|
Yes/No
|
Yes
|
||
BSR
|
:
|
2.25. - 3
|
||
Bottom connection
|
inch:
|
7 5/8 REG
|
||
Boreback
|
Yes/No
|
No
|
||
Bored for float valve
|
yes/no:
|
yes
|
||
Float size
|
inch:
|
5F-6R
|
||
Quantity
|
no.:
|
2
|
||
OD size
|
inch:
|
9 1/2”
|
||
ID size
|
inch:
|
2 13/16”
|
||
Top connection
|
inch:
|
7 5/8 REG
|
||
Boreback
|
Yes/No
|
Yes
|
||
BSR
|
:
|
2.25 - 3
|
||
Bottom connection
|
inch:
|
6 5/8 REG
|
||
Boreback
|
Yes/No
|
No
|
||
Bored for float valve
|
yes/no:
|
YES
|
||
Float size
|
inch:
|
5F-6R
|
||
Quantity
|
no.:
|
2
|
||
OD size
|
inch:
|
8 1/4”
|
||
ID size
|
inch:
|
2 13/16”
|
||
Top connection
|
inch:
|
6 5/8 Reg
|
||
Boreback
|
Yes/No
|
Yes
|
||
BSR
|
:
|
2.25 - 3
|
||
Bottom connection
|
inch:
|
6 5/8 Reg
|
||
Boreback
|
Yes/No
|
No
|
||
Bored for float valve
|
yes/no:
|
YES
|
||
Float size
|
inch:
|
5F-6R
|
||
Quantity
|
no.:
|
2
|
||
OD
|
inch:
|
6 1 /2
|
||
ID
|
inch:
|
2 1/2”
|
||
Top connection
|
inch:
|
4 1/2 XH
|
||
Boreback
|
Yes/No
|
Yes
|
||
BSR
|
:
|
2.25 - 3
|
||
Bottom connection
|
inch:
|
4 1/2 Reg
|
||
Boreback
|
Yes/No
|
No
|
||
Bored for float valve
|
yes/no:
|
YES
|
||
Float size
|
inch:
|
4 R
|
||
D.1.24 CROSSOVER SUBS
|
||||
Quantity
|
no.:
|
2
|
||
OD size
|
inch:
|
8 1/4” x 9 1/2”
|
||
Top connection size
|
inch:
|
6 5/8 REG
|
||
Type (pin/box)
|
:
|
BOX
|
||
I.D
|
:
|
2 13/16”
|
||
B.S.R
|
:
|
2.25 - 3
|
||
Boreback
|
Yes/No
|
Yes
|
||
Bottom connection size
|
inch:
|
7 5/8 REG
|
||
Type (pin/box)
|
:
|
PIN
|
I.D
|
:
|
3”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove
|
Yes/No
|
Yes
|
|
Quantity
|
no.:
|
2
|
|
OD size
|
inch:
|
7 1/4” x 8 1/4”
|
|
Top connection size
|
inch:
|
HT 55
|
|
Type (pin/box)
|
:
|
BOX
|
|
ID
|
inch:
|
3”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Boreback
|
Yes/No
|
No
|
|
Bottom connection size
|
inch:
|
6 5/8 Reg
|
|
Type (pin/box)
|
:
|
PIN
|
|
I.D
|
:
|
3”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove
|
Yes/No
|
Yes
|
|
Quantity
|
no.:
|
2
|
|
OD
|
inch:
|
7 1/4” x 6 1/2”
|
|
Top connection size
|
inch:
|
HT 55
|
|
Type (pin/box)
|
:
|
BOX
|
|
ID
|
inch:
|
2 1/2”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Boreback
|
Yes/No
|
No
|
|
Bottom connection size
|
inch:
|
4 1/2 XH (NC 46)
|
|
Type (pin/box)
|
:
|
PIN
|
|
I.D
|
:
|
2 1/2”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove
|
Yes/No
|
Yes
|
|
Quantity
|
no.:
|
2
|
|
OD size
|
inch:
|
6 1/2” x 8 1/2”
|
|
Top connection size
|
inch:
|
4 IF (NC 46)
|
|
Type (pin/box)
|
:
|
BOX
|
|
ID
|
inch:
|
2 1/2”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Boreback
|
Yes/No
|
Yes
|
|
Bottom connection
|
inch:
|
6 5/8 Reg
|
|
Type (pin/box)
|
:
|
PIN
|
|
ID
|
inch:
|
2 1/2”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove
|
Yes/No
|
Yes
|
|
Quantity
|
no.:
|
2
|
|
OD size
|
inch:
|
7 1/4 x 6 5/8
|
|
Top connection size
|
inch:
|
HT55
|
|
Type (pin/box)
|
:
|
Box
|
|
ID size
|
inch:
|
2 13/16”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Boreback
|
Yes/No
|
No
|
|
Bottom connection size
|
inch:
|
4 1/2 IF (NC 50)
|
|
Type (pin/box)
|
:
|
Pin
|
|
ID size
|
inch:
|
2 13/16”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove:
|
Yes/No
|
Yes
|
|
Quantity
|
no.:
|
2
|
OD size
|
inch:
|
6 5/8 x 6 5/8
|
|
Top connection size
|
inch:
|
4 1/2 IF (NC 50)
|
|
Type (pin/box)
|
:
|
Box
|
|
ID size
|
inch:
|
2 1/2”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Boreback
|
Yes/No
|
Yes
|
|
Bottom connection size
|
inch:
|
4 IF (NC 46)
|
|
Type (pin/box)
|
:
|
Pin
|
|
ID size
|
inch:
|
2 1/2”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove
|
Yes/No
|
Yes
|
|
Quantity
|
no.:
|
2
|
|
OD size
|
inch:
|
6 5/8 x 8 1/4
|
|
Top connection size
|
inch:
|
4 1/2 IF
|
|
Type (pin/box)
|
:
|
Box
|
|
ID size
|
inch:
|
2 13/16”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Boreback
|
Yes/No
|
YES
|
|
Bottom connection size
|
inch:
|
6 5/8 Reg
|
|
Type (pin/box)
|
:
|
Pin
|
|
ID size
|
inch:
|
2 13/16”
|
|
B.S.R
|
:
|
2.25 - 3
|
|
Relief Groove
|
Yes/No
|
Yes
|
|
D 1.25 STABBING SUBS - Approximately 9” long
|
|||
Quantity
|
no.:
|
1
|
|
OD size
|
inch:
|
9.5
|
|
ID size
|
inch:
|
3
|
|
Top connection size
|
inch:
|
HT 55
|
|
Type (pin/box)
|
:
|
Box
|
|
Bottom connection size
|
inch:
|
7 5/8 Reg
|
|
Type (pin/box)
|
:
|
PIN
|
|
Quantity
|
no.:
|
1
|
|
OD size
|
inch:
|
9.5
|
|
Top connection size
|
inch:
|
4 1/2 IF
|
|
Type (pin/box)
|
:
|
Box
|
|
ID size
|
inch:
|
3
|
|
Bottom connection size
|
inch:
|
7 5/8 Reg
|
|
Type (pin/box)
|
:
|
PIN
|
|
Quantity
|
no.:
|
1
|
|
OD size
|
inch:
|
8.25
|
|
ID size
|
inch:
|
2 13 /16
|
|
Top connection size
|
inch:
|
HT 55
|
|
Type (pin/box)
|
:
|
BOX
|
|
Bottom connection size
|
inch:
|
6 5/8 REG
|
|
Type (pin/box)
|
:
|
PIN
|
|
Quantity
|
no.:
|
1
|
|
OD size
|
inch:
|
6.5
|
|
ID size
|
inch:
|
2.8125
|
|
Top connection size
|
inch:
|
HT 55
|
|
Type (pin/box)
|
:
|
BOX
|
|
Bottom connection size
|
inch:
|
4 IF
|
Type (pin/box)
|
:
|
PIN
|
|
D.1.26 PUMP IN / TESTING SUBS
|
|||
Quantity
|
Pin/Box
|
1
|
|
Connection
|
HT 55 Box
|
||
Union type
|
2” 1502 Female
|
||
Quantity
|
1
|
||
Connection
|
Pin/Box
|
HT 55 Pin
|
|
Union Type
|
2” 1502 Female
|
||
Quantity
|
1
|
||
Connection
|
Pin/Box
|
4 1/2 IF Box
|
|
Union type
|
2” 1502 Female
|
||
Quantity
|
1
|
||
Connection
|
Pin/Box
|
4 1/2 IF Pin
|
|
Union type
|
2” 1502 Female
|
||
Quantity
|
1
|
||
Connection
|
Pin/Box
|
7 5/8 Reg Pin
|
|
Union Type
|
2” 1502 Female
|
||
D 1.27. SIDE ENTRY SUBS
|
|||
Quantity
|
1
|
||
Top Connection
|
Box/Pin
|
HT 55 Box
|
|
Lower connection
|
HT 55 Pin
|
||
Outlet size and type
|
2” 1502 Female
|
||
Quantity
|
1
|
||
Top Connection
|
Box/Pin
|
4 1/2 IF Box
|
|
Lower connection
|
4 1/2 IF Pin
|
||
Outlet size and type
|
2” 1502 Female
|
||
D.1.28 DRILLING BUMPER SUBS
|
Company Supplied
|
||
D.1.29 HOLE OPENERS
|
Company Supplied
|
||
D.1.30 UNDERREAMERS
|
Company Supplied
|
||
D.2 HANDLING TOOLS
|
|||
D.2.1 DRILL PIPE ELEVATORS
|
|||
Quantity
|
:
|
2
|
|
Make
|
:
|
Varco
|
|
Model
|
st:
|
BX 475
|
|
Drill Collars inserts 150 Ton
|
6 1/2” , 8 1/4” , 9 1/2”
|
||
Casing inserts 350 Ton
|
“
|
Company Supplied
|
|
Drill pipe Inserts 500 Ton
|
5 , 5 1/2”
|
||
Elevators 750 Ton
|
5”, 5-1/2”
|
||
BOP handling elevators
|
st:
|
1000 Refer E 6.10
|
|
D.2.2 DRILL COLLAR ELEVATORS
|
|||
Size
|
inch:
|
N/A
|
|
Quantity
|
no.:
|
||
Make
|
:
|
||
Model
|
:
|
||
Rated capacity
|
st:
|
Size
|
inch:
|
N/A
|
||
Quantity
|
no.:
|
|||
Make
|
:
|
|||
Model
|
:
|
|||
Rated capacity
|
st:
|
|||
Size
|
inch:
|
N/A
|
||
Quantity
|
no.:
|
|||
Make
|
:
|
|||
Model
|
:
|
|||
Rated capacity
|
st:
|
|||
Size
|
inch:
|
N/A
|
||
Quantity
|
no.:
|
|||
Make
|
:
|
|||
Model
|
:
|
|||
Rated capacity
|
st:
|
|||
D.2.3 TUBING ELEVATORS
|
Type:
|
Company Supplied
|
||
D.2.4 DRILL PIPE HAND SLIPS
|
||||
Size
|
inch
|
5 1/2 ”
|
||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
VARCO / SDXL
|
||
Size
|
inch
|
5
|
||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
VARCO / SDXL
|
||
D.2.5 POWER SLIPS
|
||||
Make/Type
|
Varco PS 30
|
|||
Quantity
|
1
|
|||
Slip assembly
|
20” to 18 5/8”
|
1
|
||
Slip Assmebly
|
16 ” to 6 5/8
|
1
|
||
Slip Assembly
|
2 3/8 to 10 3/4”
|
1
|
||
Insert carriers Drillpipe
|
:
|
5 ”, 5 1/2” ,
|
||
Insert Carriers Drill collars
|
6 1/2, 8 1/4,9 1/2
|
|||
Insert carriers Casing
|
Company supplied
|
|||
Die sets for 13 3/8” 9 5/8 & 7” carriers
|
Company supplied
|
|||
MOUSEHOLE SLIPS
|
Varco 18” Power Slips.
|
|||
D.2.6 DRILL COLLAR SLIPS
|
||||
Size
|
inch:
|
9.5
|
||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
VARCO / DCS-L
|
||
Size
|
inch:
|
8.25
|
||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
VARCO / DCS-L
|
||
Size
|
inch:
|
6.1/2
|
||
Quantity
|
no.:
|
1
|
||
Make/Type
|
:
|
VARCO / DCS-R
|
||
D.2.7 DRILL COLLAR SAFETY CLAMPS
|
||||
Quantity
|
no.:
|
1
|
||
Model
|
MP-L
|
||
Range
|
:
|
19 3/8” to 4 1/2 “
|
|
D.2.8 TUBING SLIPS
|
:
|
Company Supplied
|
|
D.2.9 TUBING SPIDER
|
:
|
Company Supplied
|
|
D.2.10 DRILL COLLAR LIFTSUBS
|
:
|
As needed
|
|
D.2.11 DC LIFTING PLUGS
|
:
|
n/a
|
|
D.2.12 BIT BREAKER
|
|||
Quantity
|
no.:
|
1
|
|
For bit size
|
inch:
|
26
|
|
Quantity
|
no.:
|
1
|
|
For bit size
|
inch:
|
17.1/2”
|
|
Quantity
|
no.:
|
1
|
|
For bit size
|
inch:
|
14 3/4”
|
|
Quantity
|
no.:
|
1
|
|
For bit size
|
inch:
|
12. 1/4
|
|
Quantity
|
no.:
|
1
|
|
For bit size
|
inch:
|
8.1/2
|
|
D.2.13. GAUGE RINGS
|
|||
Sizes
|
26, 17 1/2, 14 3/4, 12 1/4, 8 1/2
|
||
D.2.14 ELEVATOR LINKS
|
|||
Quantity of sets
|
no.:
|
1
|
|
Make/Type
|
:
|
VARCO
|
|
Size
|
inch:
|
3.5
|
|
Length
|
ft:
|
11
|
|
Rated capacity
|
st:
|
500
|
|
Quantity of sets
|
no.:
|
1
|
|
Make/Type
|
:
|
VARCO
|
|
Size
|
inch:
|
4 3/4”
|
|
Length
|
ft:
|
22
|
|
Rated capacity
|
st:
|
750
|
|
Quantity of sets
|
no.:
|
1
|
|
Make/Type
|
:
|
VARCO
|
|
Size
|
inch:
|
4 3/4”
|
|
Length
|
ft:
|
22
|
|
Rated capacity
|
st:
|
1000
|
|
D.2.15 DRILL PIPE SPINNER
|
Type:
|
Varco SSW-40
|
|
D.2.16 MUD SAVER BUCKET
|
|||
Make
|
:
|
Dreco
|
|
Size
|
inch:
|
9 3/4 to 3 1/2”
|
|
Operation
|
:
|
Remote from DWS
|
|
D.2.17 EZY TORGUE
|
|||
Make/Type
|
:
|
Varco
|
|
Maximum linepull
|
lb:
|
31000
|
|
Quantity
|
2
|
D.2.18 ROTARY RIG TONGS
|
|||
Quantity
|
no.:
|
2
|
|
Make/Type
|
:
|
Varco HT 100
|
|
Size range (max OD/min OD)
|
inch/inch:
|
17 to 4
|
|
Torque rating
|
ft lbs:
|
Max 100,000, reduces depending on size
|
|
Quantity
|
no.:
|
2
|
|
Make/Type
|
:
|
Varco HT 50
|
|
Size range (max OD/min OD)
|
:
|
17 1/4 to 20”
|
|
Torque rating
|
Ft/lb:
|
50000
|
|
D.2.19 TUBING TONGS (MANUAL)
|
|||
D.2.20 TUBING TONGS (POWER)
|
|||
D.2.21 IRON ROUGHNECK
|
|||
Make/Type
|
:
|
VARCO / AR3200
|
|
Size range (max OD/min OD) Drill Coll inch/inch:
|
4 “ to - 9 1/2”
|
||
Size range (max OD/min OD) Drillpipe
|
3 1/2” to 6 5/8
|
||
D.3 FISHING EQUIPMENT
|
|||
D.3.1 OVERSHOTS
|
|||
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
F.S
|
|
Top sub connection type
|
:
|
6 5/8 Reg
|
|
Overshot OD
|
inch:
|
11 3/4”
|
|
Max catch size
|
inch:
|
9 1/2”
|
|
To catch size Spiral grapple
|
inch:
|
9.1/2
|
|
9 3/8,8 1/2,8 3/8,8 1/4,8 1/8,7 1/4,7 1/8,7, 6 7/8, 6 5/8,6
|
|||
To catch size Basket grapple
|
inch:
|
1/2, 6 3/8, 5 1/2, 5
|
|
Control rings
|
For above grapples
|
||
Extension sub length
|
ft:
|
2.5
|
|
Lipped guide (oversize, regular)
|
“:
|
113/4,15, 21
|
|
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA S.H Series 150
|
|
Top sub connection type
|
:
|
4 IF
|
|
Overshot OD
|
inch:
|
8.3/8
|
|
Max catch size
|
inch:
|
7 1/4”
|
|
To catch size Spiral grapple
|
inch:
|
7 1/4, 7 1/8, 7, 6 7/8,
|
|
To catch size Basket grapple
|
inch:
|
6 5/8, 6 1/2, 6 3/8, 5 1/2, 5
|
|
Control rings
|
For above grapples
|
||
Extension sub length
|
ft:
|
2.5
|
|
Lipped guide (oversize, regular)
|
:
|
8 3/8, 11,
|
|
D.3.2 HYDRAULIC FISHING JAR
|
Company Supplied
|
||
D.3.3 JAR INTENSIFIER
|
Company Supplied
|
||
D.3.4 SURFACE JAR
|
Company Supplied
|
||
D.3.5 FISHING BUMPERSUBS
|
|||
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA
|
|
OD body
|
inch:
|
8
|
|
Min.ID
|
inch:
|
3.5
|
Stroke
|
inch:
|
20
|
|
Connection type
|
:
|
6 5/8 Reg
|
|
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA
|
|
OD body
|
inch:
|
6.25
|
|
Min. ID
|
inch:
|
2.25
|
|
Stroke
|
inch:
|
20
|
|
Connection type
|
:
|
4 IF
|
|
D.3.6 SAFETY JOINTS
|
Company Supplied
|
||
D.3.7 JUNK BASKETS (REVERSE CIRC.)
|
Company Supplied
|
||
D.3.8 JUNK SUBS
|
Company Supplied
|
||
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA
|
|
For hole size
|
inch:
|
17.5
|
|
Boot OD
|
inch:
|
12.875
|
|
Connection type
|
:
|
7 5/8 Reg
|
|
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA
|
|
For hole size
|
inch:
|
12.25
|
|
Boot OD
|
inch:
|
9.625
|
|
Connection type
|
:
|
6 5/8 Reg
|
|
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA
|
|
For hole size
|
inch:
|
8.5
|
|
Boot OD
|
inch:
|
6.625
|
|
Connection type
|
:
|
4 1/2 Reg
|
|
D.3.9 FLAT BOTTOM JUNK MILL
|
Company Supplied
|
||
D.3.10 MAGNET FISHING TOOL
|
|||
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
TBA/ Flush guide
|
|
OD body
|
inch:
|
16
|
|
Hole size
|
inch:
|
17.5
|
|
Connection type
|
:
|
6 5/8 reg
|
|
D.3.11 TAPER TAPS
|
Company Supplied
|
||
D.3.12 DIE COLLARS
|
Company Supplied
|
||
E. WELL CONTROL/SUBSEA EQUIPMENT
|
|||
E.1 LOWER RISER DIVERTER ASSY
|
N/A
|
||
E.2 PRIMARY BOP STACK (from bottom to top)
|
|||
Stack complete with:
|
|||
· guide frame
|
yes/no:
|
YES
|
|
· pick up attachment
|
yes/no:
|
YES
|
|
· transport base
|
yes/no:
|
YES
|
|
Size (bore)
|
inch:
|
18.75
|
|
Working pressure
|
psi:
|
15000
|
|
H2S service
|
yes/no:
|
YES
|
E.2.1 ALTERNATE HYDRAULIC CONNECT N/A
|
|||
E.2.2 HYDRAULIC WELLHEAD CONNECTOR
|
|||
Size
|
inch:
|
18-3/4”
|
|
Make/Type
|
:
|
Vetco SD H-4
|
|
Working pressure
|
psi:
|
15000
|
|
Hot tap for underwater intervention ROV
|
yes/no:
|
YES
|
|
Spare connector same type
|
yes/no:
|
NO
|
|
Hydrate seal
|
yes/no:
|
Yes (1 oring & 1 Lip seal Option as STD.)
|
|
Glycol Injection ( ROV)
|
yes/no:
|
yes (4 x 1” Npt @ 90 deg increments
|
|
Pilot Operated check Valve, close function
|
Yes/No:
|
Yes
|
|
E.2.3 RAM TYPE PREVENTERS
|
|||
Preventers:
|
|||
Quantity
|
no.:
|
5
|
|
Bore size
|
inch:
|
18.3/4”
|
|
Working Pressure
|
psi:
|
15000
|
|
Make
|
:
|
CAMERON or equivalent
|
|
Model
|
:
|
TYPE T1
|
|
Type (single/double)
|
:
|
Double x2 , Single x 1
|
|
Stack Configuration
|
:
|
Al, A2, CL, SSCSR BSR,VBR,VBR,LFPR,CH
|
|
Ram locks
|
yes/no:
|
YES
|
|
Preventer connection type - top
|
:
|
CX18 (BX-164 Option Available)
|
|
Preventer connection type - bottom
|
:
|
CX18 (BX-164 Option Available)
|
|
Side oultlets
|
yes/no:
|
YES
|
|
Size
|
inch:
|
3.1/16
|
|
Connection type
|
:
|
No. 6 CAMERON CLAMP AX GROOVE
|
|
Super/Shear rams:
|
Less than or equal to 13-5/8”
|
||
Quantity
|
no.:
|
1 set
|
|
Blind/Shear rams:
|
|||
Quantity
|
no.:
|
1 set
|
|
Variable rams:
|
|||
Quantity
|
no.:
|
1 set
|
|
Size range (max/min)
|
inch/inch:
|
Customer to advise
|
|
Quantity
|
no.:
|
1 set
|
|
Size range (max/min)
|
inch-inch:
|
Customer to advise
|
|
Pipe rams:
|
|||
Quantity
|
no.:
|
1 set
|
|
Size
|
inch:
|
Customer to advse
|
|
E.2.4 STACK CONFIGURATION
|
|||
(Blind/Shear/Pipe/Variable)
|
|||
Upper Shear ra Cavity 5
|
SSCSR (Less than or equal to 13-5/8”)
|
||
Lower shear ra Cavity 4
|
:
|
BSR
|
|
Middle Upper Cavity 3
|
:
|
VBR
|
|
Middle Lower Cavity 2
|
:
|
VBR
|
|
Lower rams Cavity 1
|
:
|
LFPR
|
|
Position of side outlets - kill
|
|||
Upper
|
:
|
Below BSR (Cavity #4)
|
|
Lower
|
:
|
Below LFPR (Cavity #1)
|
Position of side outlets - choke
|
|||
LMRP
|
Below upper Annular (Al)
|
||
Stack
|
Below Top VBR (Cavity #3)
|
||
Stack
|
:
|
Below Bottom VBR (Cavity #2)
|
|
E.2.5 ANNULAR TYPE PREVENTER ON STACK
|
|||
Size
|
inch:
|
n/a
|
|
Working pressure
|
psi:
|
n/a
|
|
Make/Type
|
:
|
n/a
|
|
E.2.6 MANDREL
|
|||
Make/Type
|
:
|
Cameron 18-3/4 10 HC
|
|
Size
|
inch:
|
18.75
|
|
E.2.7 FAIL-SAFE HYDRAULIC VALVES
|
|||
(Kill and Choke)
|
|||
Quantity on each side outlet
|
no.:
|
2
|
|
Size (ID)
|
inch:
|
42430
|
|
Make/Type
|
:
|
Cameron MCS
|
|
Working pressure
|
psi:
|
15000
|
|
Solid block
|
yes/no:
|
YES
|
|
E.2.8 SUBSEA ACCUMULATORS
|
|||
(See also E.7.1 - Surface Accummulator Unit)
|
|||
Quantity
|
no.:
|
17 ( team to evaluate)
|
|
Useful capacity per accumulator (w/o prUS gallons
|
:
|
13.1
|
|
Bottle working pressure
|
psi:
|
5000 (team to evaluate)
|
|
E.2.9 HYDRAULIC CONTROL POD/RECEPTACLES
|
|||
Quantity
|
no.:
|
2
|
|
Redundancy
|
%:
|
100
|
|
Color Coded
|
yes/no:
|
YES
|
|
Remote regulation of operating pressure for
|
|||
functions requiring lower operating press
|
yes/no:
|
YES
|
|
Spare control pod
|
yes/no:
|
NO
|
|
Deadman system
|
yes/no:
|
YES
|
|
Pressure & tempreture Sensor’s LMRP
|
yes/no:
|
YES
|
|
E.3 PRIMARY LOWER MARINE RISER PACKAGE
|
|||
(From Bottom To Top)
|
|||
E.3.1 HYDRAULIC CONNECTOR
|
|||
Make/Type
|
:
|
Cameron 18-3/4-10 HC or equivalent
|
|
Size
|
inch:
|
18.75
|
|
Working pressure
|
psi:
|
10000
|
|
Hot tap for underwater intervention
|
yes/no:
|
YES
|
|
Spare connector same type
|
yes/no:
|
NO
|
|
E.3.2 ANNULAR TYPE PREVENTER (LMRP)
|
|||
Size
|
inch:
|
18-3/4”
|
|
Qty.
|
no:
|
2
|
|
Working pressure
|
psi:
|
10000
|
|
Make/Type (2*70.5=141” Total Heigl
|
:
|
CAMERON TYPE DL
|
E.3.3 FLEX JOINT
|
|||
Make/Type
|
:
|
Oil States 18-3/4”
|
|
Size
|
inch:
|
21
|
|
Max deflection
|
degrees:
|
20 (10 from vertical)
|
|
E.3.4 RISER ADAPTER
|
|||
Make/Type
|
:
|
Vetco HMF-class H
|
|
Size
|
inch:
|
21
|
|
E.3.5 CONNECTION LINES TO RISER
|
|||
Type (rigid loops, coflexip, etc.)
|
Make:
|
COFLEXIP
|
|
Size:
|
3-1/16
|
||
WP:
|
15,000 psi
|
||
Collapse Psi
|
12,7l0psi
|
||
E.3.6 RISER CENTRALIZER
|
Hydralift
|
||
E.4 ANNULAR GAS HANDLER
|
|||
Make / Type
|
Supplied by Company at later date. Hard piping and control functions to be supplied by Contractor
|
||
Rating
|
1,500 psi
|
||
Number Outlets
|
2
|
||
Number Valves
|
4
|
||
E.5 SECONDARY LOWER MARINE RISER P N/A
|
|||
E.6 PRIMARY MARINE RISER SYSTEM
|
|||
E.6.1 MARINE RISER JOINTS
|
To be designed for 10,000’ wd
|
||
Make/Model
|
:
|
Vetco or equivalent (HMF-class H)
|
|
OD
|
inch
|
To be determined by final riser analysis
|
|
ID
|
inch
|
To be determined by final riser analysis
|
|
Wall thickness
|
inch:
|
To be determined by final riser analysis
|
|
Average length of each joint
|
ft:
|
90
|
|
62,311 for 5k buoancy, 54,424 for 3k buoancy, 31,620
|
|||
Weight of one complete joint (in air)
|
Ibs:
|
for 3/4” Slick, 36,900 1” slick
|
|
Quantity
|
no.:
|
Sufficient for 8,000 ft. water depth
|
|
Pipe material
|
grade:
|
API 5L Grade X80 Mod.
|
|
Minimum yield strength
|
psi:
|
80KSI
|
|
Type riser connectors
|
:
|
HMF- class H
|
|
Dogs
|
no.:
|
To be determined by final riser analysis
|
|
Pup joints:
|
|||
Quantity
|
no.:
|
1
|
|
Length
|
ft:
|
45.0’
|
|
Quantity
|
no.:
|
1
|
|
Length
|
ft:
|
37.5’
|
|
Quantity
|
no.:
|
1
|
|
Length
|
ft:
|
30.0’
|
|
Quantity
|
no.:
|
1
|
|
Length
|
ft:
|
22.5’
|
Quantity
|
no.:
|
1
|
|
Length
|
ft:
|
15’
|
|
E.6.2 TELESCOPIC JOINT
|
|||
Make/Type
|
:
|
Vetco
|
|
Size (ID)
|
inch:
|
19.25
|
|
Stroke
|
ft:
|
65
|
|
Double Seals
|
yes/no:
|
YES
|
|
Working pressure
|
psi
|
500
|
|
Spare telescoping joint
|
yes/no:
|
no
|
|
Location
|
:
|
N/A
|
|
Rotating support ring for riser tensioners
|
type:
|
Vetco SDC
|
|
Connection points
|
no.:
|
6
|
|
E.6.3 KILL/CHOKE LINES
|
|||
Quantity
|
no.:
|
2
|
|
Outside diameter
|
inch:
|
6.5
|
|
Inside diameter
|
inch:
|
4.5
|
|
Working pressure
|
psi:
|
15000
|
|
LMRP Isolation valves
|
YES/NO
|
YES. Fail Close
|
|
E.6.4 BOOSTER LINES (If Fitted)
|
|||
Quantity
|
no.:
|
1
|
|
Outside diameter
|
inch:
|
4.5
|
|
Inside diameter
|
inch:
|
3.83
|
|
Working pressure
|
psi:
|
6000
|
|
LMRP Isolation valve
|
YES/NO
|
YES
|
|
E.6.5 HYDRAULIC SUPPLY LINES
|
|||
Quantity
|
no.:
|
1
|
|
Outside Diameter
|
inch:
|
3.5
|
|
Inside Diameter
|
inch:
|
2.62
|
|
Working pressure
|
psi:
|
5000
|
|
E.6.6 UPPER BALL (FLEX) JOINT
|
|||
Make/Type
|
:
|
Oilstates Diverter 3
|
|
Size
|
inch:
|
21-1/4
|
|
Maximum deflection
|
deg.:
|
30 (15 from vertical)
|
|
Spare upper ball (flex) joint
|
yes/no.:
|
NO
|
|
E.6.7 BUOYANCY MODULES (If Fitted)
|
|||
Make
|
:
|
To be determined by riser analysis
|
|
Quantity of buoyed riser joints
|
no.:
|
To be determined by riser analysis
|
|
OD of buoyed riser joints
|
inch:
|
To be determined by riser analysis
|
|
Length of each module
|
ft:
|
To be determined by riser analysis
|
|
Volume of each module
|
ft3:
|
To be determined by riser analysis
|
|
Buoyancy in seawater
|
st/ft3:
|
To be determined by riser analysis
|
|
Rated water depth
|
ft:
|
To be determined by riser analysis
|
|
Make
|
:
|
To be determined by riser analysis
|
|
Quantity of buoyed riser joints
|
no.:
|
To be determined by riser analysis
|
|
OD of buoyed riser joints
|
inch:
|
To be determined by riser analysis
|
Length of each module
|
ft:
|
To be determined by riser analysis
|
|
Volume of each module
|
ft3:
|
To be determined by riser analysis
|
|
Buoyancy in seawater
|
st/ft3:
|
To be determined by riser analysis
|
|
Rated water depth
|
ft:
|
To be determined by riser analysis
|
|
E.6.8 MARINE RISER SPIDER
|
|||
Make/Type
|
:
|
VETCO / HYDRAULIC
|
|
E.6.9 Marine Riser Gimbal
|
|||
Make/Type
|
:
|
VETCO
|
|
E.6.10 RISER HANDLING TOOLS
|
|||
Tool, riser lifting
|
no.:
|
3
|
|
1000 ton Solid Body Elevators
|
no :
|
1 set ( team to evaluate)
|
|
Type
|
:
|
HMF- Class h
|
|
Torque Wrenches
|
:
|
2 - dual speed
|
|
E.6.11 RISER TEST TOOLS
|
|||
Quantity
|
no.:
|
2
|
|
Type
|
:
|
HMF- Class H Hydraulic Test Tool
|
|
E.6.12 INSTRUMENTED RISER JT
|
:
|
N/A
|
|
E.7 SECONDARY MARINE RISER
|
:
|
N/A
|
|
E.8 DIVERTER BOP
|
|||
(For installation in fixed bell nipple)
|
|||
Make/Type
|
:
|
Hydril 60
|
|
Max Bore Size
|
inch:
|
21-1/4
|
|
Working pressure
|
psi:
|
500
|
|
Number of diverter outlets
|
no.:
|
2
|
|
Outlet OD
|
inch:
|
14
|
|
Insert packer size ID
|
inch:
|
N/A CSO
|
|
Element type.
|
:
|
Nitrile rubber
|
|
Running from diverter to
|
:
|
Overboard , port/ starb./ Poorboy MGS
|
|
E.8.1 DIVERTER FLOWLINE
|
|||
Quantity
|
no.:
|
1
|
|
I.D of flowline
|
inch:
|
16” Nominal
|
|
Valve types
|
:
|
Diverter Sleeve
|
|
Size
|
inch:
|
16
|
|
Working pressure
|
psi:
|
500
|
|
Control valve type (air/hydraulic/etc.)
|
:
|
HYDRAULIC
|
|
Remote controlled from
|
location:
|
DRILLERS WORKSTATION
|
|
E.8.2 DIVERTER CONTROL PANELS
|
|||
Driller’s panel
|
|||
Make
|
:
|
CAMERON OR EQUIVALENT
|
|
Model
|
:
|
MULTIPLEX
|
|
Location
|
:
|
DRILLERS WORKSTATION
|
|
Locking/unclocking control
|
yes/no:
|
YES
|
Remote panel
|
|||
Make
|
: CAMERON
|
||
Model
|
: MULTIPLEX
|
||
Location
|
: CONTROL ROOM
|
||
Locking/unclocking control
|
yes/no
|
: YES
|
|
E.9 SUBSEA SUPPORT SYSTEM
|
|||
E.9.1 RISER TENSIONERS
|
Ability To Skid Tensioners From Well Centerline
|
||
Quantity
|
no.:
|
6
|
|
Make/Type
|
:
|
HYDRALIFT - INLINE
|
|
Capacity each tensioner
|
st:
|
800 kips
|
|
Maximum stroke
|
ft:
|
50
|
|
Wireline size
|
inch:
|
N/A (9” ROD)
|
|
Line travel
|
ft:
|
N/A (9” ROD)
|
|
Independent air compressors
|
yes/no:
|
YES
|
|
Independent air drying unit
|
yes/no:
|
YES
|
|
Riser Recoil System
|
yes/no:
|
yes
|
|
E.9.2 GUIDELINE SYSTEM
|
N/A
|
||
E.9.3 REMOTE GUIDELINE REPL. TOOL
|
N/A
|
||
E.9.4 REMOTE GUIDELINE CUTTING TOOL
|
N/A
|
||
E.9.5 POD LINE TENSIONERS
|
TURN DOWN SHEAVE’S COMPLETE WITH STORM LOOP WITHIN MOONPOOL INCLUDED WITHIN DESIGN LAYOUT
|
||
E.9.6 TENSIONER/COMPENSATOR AIR PRESSURE VESSELS
|
|||
Quantity
|
no.:
|
30
|
|
Total capacity
|
ft3:
|
2747
|
|
Rated working pressure
|
psi:
|
3000
|
|
Pressure relief valve installed
|
yes/no:
|
YES
|
|
E.10 BOP CONTROL SYSTEM
|
|||
Cameron or equivalent Mux system including: 2 each remote control panels, one located in driller’s house and one in the control room, both panels incorporate full function and monitoring system for BOP’s and diverter system. 1 each pod test stand and Mux system analyzer consisting of test stand and portable computer test set. 2 each Mux cable reels complete with 11,000’ of Multiplex cable, one reel blue and one reel yellow for functioning yellow and blue pods plus one spare. 2 each stack mounted pods, complete with subsea electronics
|
|||
E.10.1 SURFACE ACCUMULATOR UNIT
|
|||
(See also E.2.8 & E.4.8 - Subsea Accumulators)
|
|||
Make
|
:
|
CAMERON or equivalent
|
|
Model/Type
|
:
|
MUX
|
|
Location
|
:
|
ACCUMULATOR ROOM
|
|
Soluble oil reservoir capacity
|
US gallons:
|
300
|
|
Oil/water mix.capacity
|
US gals/min:
|
838
|
|
Glycol reservoir capacity
|
US gallons:
|
1000
|
No. of bottles installed
|
no.:
|
38 team to evaluate bottles required for 10,000’
|
|
Useful cap. per accum. (w/o pre-charge)US gallons
|
:
|
40
|
|
Bottle working pressure
|
psi:
|
5000
|
|
Control manifold model
|
:
|
MULTIPLEX
|
|
Regulator type
|
:
|
PRESSURE SWITCH / RELIEF VALVES
|
|
Total useful accumulator volume (surface and stack)
|
|||
Equals all preventer opening and closing
|
yes/no:
|
YES
|
|
Plus percent additional volume
|
%:
|
50
|
|
E.10.2 ACCUMULATOR HYDRAULIC PUMPS
|
|||
Electric Driven
|
|||
Quantity
|
no.:
|
2
|
|
Power source
|
:
|
From BUS A
|
|
Make
|
:
|
US Motors
|
|
Model
|
:
|
||
Each driven by motor of power
|
hp:
|
100
|
|
Flow rate of each pump
|
US gals/min:
|
26
|
|
At minimum operating pressure
|
psi:
|
5000
|
|
Secondary
|
|||
Quantity
|
no.:
|
1
|
|
Power source
|
:
|
From BUS B
|
|
Make
|
:
|
US Motors
|
|
Model
|
:
|
||
Each driven by motor of power
|
hp:
|
100
|
|
Flow rate of each pump
|
US gals/min:
|
26
|
|
At minimum operating pressure
|
psi:
|
5000
|
|
E.10.3 DRILLER’S CONTROL PANEL
|
|||
Graphic control panel at driller’s position showing subsea functions with controls for the following functions of the BOP stack Location.
|
Driller Work Station.
|
||
Boost Line Control Valve
|
yes/no:
|
YES
|
|
Marine riser connector
|
yes/no:
|
YES
|
|
All annular type BOP’s
|
yes/no:
|
YES
|
|
All ram type BOP’s
|
yes/no:
|
YES
|
|
Lock for ram type BOPs
|
yes/no:
|
YES
|
|
Wellhead and LMRP connector
|
yes/no:
|
YES
|
|
Inner and outer kill and choke line valve:
|
yes/no:
|
YES
|
|
Low acc. pressure warning
|
yes/no:
|
YES
|
|
Low reservoir level warning
|
yes/no:
|
YES
|
|
Low rig air pressure warning
|
yes/no:
|
YES
|
|
Pressure regulator for annular
|
yes/no:
|
YES
|
|
Flowmeter
|
yes/no:
|
YES
|
|
Quantity of pressure gauges
|
no.:
|
7+
|
|
Emergency push button for automatic riser disconnection
|
:
|
YES
|
|
Other control functions
|
yes/no:
|
YES
|
|
Control panel make
|
:
|
CAMERON
|
|
Control panel model
|
:
|
MULTIPLEX
|
E.10.4 REMOTE CONTROL PANELS
|
|||
Ability to operate main closing unit valv
|
yes/no:
|
NO
|
|
Quantity
|
no.:
|
2
|
|
Make/Model
|
:
|
CAMERON / MULTIPLEX
|
|
Locations
|
:
|
DRILLERS WORK STATION & CONTROL ROOM
|
|
Operating System Routing (Direct/via Primary Control Panel)
|
:
|
DIRECT DUAL BUS
|
|
E.11 SUBSEA CONTROL SYSTEM
|
|||
E.11.1 HOSE REELS
|
|||
Quantity
|
no.:
|
2 Bop Control (MUX)
|
|
Location
|
:
|
MOONPOOL
|
|
Make/Type
|
:
|
CAMERON
|
|
Maximum storage length each
|
ft:
|
11000
|
|
Drive motor type
|
:
|
AIR
|
|
Quantity
|
no.:
|
1 HOTLINE
|
|
Location
|
:
|
MOONPOOL
|
|
Make/Type
|
:
|
SYNFLEX (KEVLAR)
|
|
Maximum storage length each
|
ft:
|
11,000
|
|
Drive motor type
|
:
|
AIR
|
|
E.11.2 POD HOSE
|
|||
E.11.3 POD HOSE MANIFOLD
|
|||
Make/Model
|
:
|
NONE
|
|
Surface test stump
|
yes/no:
|
YES
|
|
E.11.4 SURFACE TEST POD
|
yes/no:
|
N/A
|
|
E.12 ACOUSTIC EMER. BOP CONTROL SYS
|
:
|
N/A
|
|
E.13 SUBSEA AUXILARY EQUIPMENT
|
|||
E.13.1 HOLE POSITION INDICATOR
|
|||
Make/Type
|
:
|
Simrad
|
|
Quantity of monitors
|
no.:
|
2 (Blue pod / Yellow pod)
|
|
Monitor location
|
:
|
Drillers Work station
|
|
Monitor location
|
:
|
Control Room
|
|
Recorder
|
yes/no:
|
no
|
|
E.13.2 RISER ANGLE INDICATOR
|
|||
Make/Type
|
:
|
To be incorporated into Mux system
|
|
Quantity of monitors
|
no.:
|
2 (Blue pod / Yellow pod)
|
|
Monitor location
|
:
|
Drillers Work station
|
|
Monitor location
|
:
|
Control Room
|
|
Recorder
|
yes/no:
|
no
|
|
Location
|
Flex joint neck
|
||
E.13.3 SLOPE INDICATORS
|
|||
Make
|
:
|
RECAN
|
Quantity
|
no.:
|
3
|
|
Provision for installation on
|
|||
BOP
|
yes/no:
|
YES
|
|
Pin Connector
|
yes/no:
|
NO
|
|
Other
|
:
|
LOWER STACK, LMRP & RISER
|
|
E.13.5 ROV System
|
Power and foundations supplied
|
||
E.14 CHOKE MANIFOLD
|
Per Drawing # D-233669
|
||
E.14.1 CHOKE MANIFOLD (For Instrumentation, see H.3)
|
|||
Make
|
:
|
CONTROL FLOW
|
|
Minimum ID
|
inch:
|
3-1/16
|
|
Maximum WP
|
psi:
|
15000
|
|
H2S service
|
yes/no:
|
YES
|
|
Quantity of fixed chokes
|
no.:
|
n/a
|
|
Make
|
:
|
n/a
|
|
Model
|
:
|
n/a
|
|
Size (ID)
|
inch:
|
n/a
|
|
Quantity of adjustable chokes
|
no.:
|
n/a
|
|
Make
|
:
|
n/a
|
|
Model
|
:
|
n/a
|
|
Size (ID)
|
inch:
|
n/a
|
|
Quantity of power chokes
|
no.:
|
3 ( team to evaluate)
|
|
Make
|
:
|
CONTROL FLOW
|
|
Model
|
:
|
15000
|
|
Size (ID)
|
inch:
|
2 Team to evaluate
|
|
Power choke remote control panel
|
yes/no:
|
YES
|
|
Make
|
:
|
Houston Digital
|
|
Model
|
:
|
CPU 27” MONITOR AND MANUAL HYD. BACK-UP.
|
|
Location
|
:
|
DRILLERS WORKSTATION / CHOKE MANIFOLD
|
|
Glycol injection
|
yes/no:
|
NO
|
|
E.14.2 FLEXIBLE CHOKE AND KILL LINES (Connecting Riser to Drilling Unit)
|
|||
Quantity
|
no.:
|
2
|
|
Make/Type
|
:
|
Coflexip
|
|
ID
|
inch:
|
3 ( team to review)
|
|
Working pressure/test pressure
|
psi/psi:
|
15000 / 22500
|
|
Quantity
|
no.:
|
n/a
|
|
Make/Type
|
:
|
n/a
|
|
ID
|
inch:
|
n/a
|
|
Working pressure/test pressure
|
psi/psi:
|
n/a
|
|
E.15 BOP TESTING EQUIPMENT
|
|||
E.15.1 HYDRAULIC BOP TEST PUMP
|
|||
Make
|
:
|
SHAFFER
|
|
Model/Type
|
:
|
ELECTRO HYDRAULIC VARIABLE SPEED 5 GPM
|
|
Pressure rating
|
psi:
|
22500
|
Chart recorder
|
yes/no:
|
0-5000 0-30000
|
|
E.15.2 BOP TEST STUMP
|
|||
Quantity
|
no.:
|
1
|
|
Test pressure
|
psi:
|
15000
|
|
Type
|
:
|
VETCO / CAMERON
|
|
Size
|
:
|
18.75
|
|
Connected to deck (welded/bolted)
|
:
|
BOLTED
|
|
E.16 WELLHEAD RUNNING/RETRIEVING/TESTING TOOLS (RT/RRT/TT)
|
|||
E.16.1 RT’s FOR CASING INSTALLATION
|
Company Supplied
|
||
E.16.2 RRT’s FOR CASING INSTALLATION
|
Company Supplied
|
||
E.16.3 MISCELLANEOUS TOOLS
|
Company Supplied
|
||
E.16.4 DP HANG-OFF SUBS
|
Company Supplied
|
||
E.16.5 MINI HOSE BUNDLE FOR HYD. R. TOOLS
|
Company Supplied
|
||
E.16.6 EMERGENCY BOP RECOVER
|
yes/no:
|
yes
|
|
Make/type
|
:
|
CAMERON
|
|
F.1 HIGH PRESSURE MUD SYSTEM
|
|||
System working pressure
|
psi:
|
7500
|
|
System test pressure
|
psi:
|
11250
|
|
Built to which design standard
|
:
|
ANSI, API
|
|
F.1.1 MUD PUMPS
|
|||
Quantity
|
no.:
|
4
|
|
Make
|
:
|
National
|
|
Model
|
:
|
14P-220
|
|
Type (Triplex/Duplex)
|
:
|
Triplex
|
|
Liner sizes available
|
inch:
|
5” - 9”
|
|
Mud pump drive motors
|
no.:
|
2
|
|
Motor type
|
:
|
AC
|
|
Continuous power rating per motor
|
hp:
|
1150
|
|
Fluid end
|
type:
|
Two piece
|
|
Maximum working pressure
|
psi:
|
7500
|
|
Test pressure
|
psi:
|
11250
|
|
Pump stroke counter
|
type:
|
Hitec
|
|
Supercharging pump
|
type:
|
Halco
|
|
Driven by motor of power
|
bp:
|
100
|
|
Discharge/Suction line ID
|
inch/inch
|
5” / 10”
|
|
M.P. Pulsation Dampener
|
type:
|
White Rock
|
|
Soft Pump
|
:
|
I system
|
|
Reset Relief Valve
|
type:
|
TBA
|
|
Working flowrate per pump at 90% of max spm
|
|||
Maximum SPM
|
:
|
105 SPM @ 100%
|
F.1.2 TRANSFER PUMPS/MIXING PUMPS (centrifugal)
|
|||
Treatment pumps (Desilter/Desander)
|
|||
Quantity
|
4
|
||
Make
|
Halco
|
||
Model
|
2500
|
||
Drive motor type
|
Electric
|
||
Power output
|
100 hp
|
||
Impeller
|
14”
|
||
Impeller speed
|
1200 rpm
|
||
Packing type
|
Mechanical seal
|
||
Mixing Pumps
|
|||
Quantity
|
no.:
|
2
|
|
Make
|
:
|
Halco
|
|
Model
|
:
|
2500
|
|
Drive motor type
|
:
|
Electric /Belt
|
|
Power output
|
hp:
|
100
|
|
Impeller
|
:
|
14”
|
|
Impeller speed
|
RPM:
|
1200
|
|
Packing type
|
;
|
Mechanical seal
|
|
Shearing Pumps
|
|||
Quantity
|
no.:
|
2
|
|
Make
|
:
|
Halco
|
|
Model
|
:
|
T 6550
|
|
Drive motor type
|
:
|
Electric /Belt
|
|
Power output
|
hp:
|
100
|
|
Impeller
|
:
|
Shearing type
|
|
Impeller speed
|
RPM:
|
1800
|
|
Packing type
|
;
|
Mechanical seal
|
|
Charging Pumps
|
|||
Quantity
|
no.:
|
4
|
|
Make
|
:
|
Halco
|
|
Model
|
:
|
2500
|
|
Drive motor type
|
:
|
Electric /Belt
|
|
Power output
|
hp:
|
100
|
|
Impeller
|
:
|
14”
|
|
Impeller speed
|
RPM:
|
1200
|
|
Packing type
|
;
|
Mechanical seal
|
|
Column Transfer
|
|||
Quantity
|
no.:
|
4
|
|
Make
|
:
|
Halco
|
|
Model
|
:
|
2500
|
|
Drive motor type
|
:
|
Electric /Belt
|
|
Power output
|
hp:
|
125
|
|
Impeller
|
:
|
12
|
|
Impeller speed
|
RPM:
|
1800
|
|
Packing type
|
;
|
Mechanical seal
|
|
F.1.3 BOOSTER PUMP
|
|||
Quantity
|
no.:
|
Rig Mud pump
|
|
Make/Type
|
:
|
||
Pumping capacity (each)
|
US gals/min:
|
Drive motor type
|
:
|
||
Power output
|
hp:
|
||
F.1.4 STANDPIPE MANIFOLD
|
|||
Quantity of standpipes
|
no.:
|
2 @ 7500 psi wp
|
|
Standpipes ID
|
inch:
|
5
|
|
H-Type standpipe manifold
|
yes/no:
|
yes
|
|
Kill line outlet
|
yes/no:
|
yes
|
|
Fill-up/bleed-off line outlet
|
yes/no:
|
yes
|
|
Outlets (total)
|
no.:
|
4
|
|
ID
|
inch:
|
5 & 3
|
|
Type connections
|
:
|
Weco
|
|
Dimensions OD x ID
|
inch x inch:
|
6 x 5
|
|
Design standard
|
:
|
ANSI, API
|
|
F.1.5 ROTARY HOSES
|
|||
Quantity
|
no.:
|
2 @ 7500 psi wp
|
|
Make/Type
|
:
|
Beattie
|
|
ID x length
|
inch x ft:
|
4 x 88
|
|
Snubbing lines
|
yes/no:
|
yes
|
|
F.1.6 CEMENTING HOSE
|
|||
Type (i.e. Coflexip)
|
:
|
Beattie
|
|
Length
|
ft:
|
85
|
|
ID
|
inch:
|
3
|
|
Working pressure
|
psi:
|
15000
|
|
F.1.7 CHIKSAN STEEL HOSES
|
|||
Integral non-screwed
|
yes/no:
|
yes
|
|
Make/type
|
:
|
TBA / 1502
|
|
ID Nonimal
|
inch:
|
2”
|
|
Section length
|
ft:
|
||
Quantity
|
no.:
|
||
Section length
|
ft:
|
||
Quantity
|
no.:
|
||
Sweep swivels, make/type
|
:
|
||
Nom. size ID
|
inch:
|
||
Fittings, non-screwed type
|
yes/no:
|
Yes
|
|
Suitable for H2S service
|
yes/no:
|
||
F.2 LOW PRESSURE MID SYSTEM
|
|||
F.2.1 MUD TANKS
|
|||
Quantity
|
no.:
|
15
|
|
Column Tanks
|
|||
Quanity
|
:
|
4
|
|
Capacity 85%
|
4600
|
||
Surface Tanks
|
Quanity
|
10
|
||
Capacity 85%
|
4000
|
||
Capacity, tank No. 1
|
bbls:
|
460
|
|
Type (active/reserve)
|
:
|
Active
|
|
Capacity, tank No. 2
|
bbls:
|
460
|
|
Type (active/reserve)
|
:
|
Active
|
|
Capacity, tank No. 3
|
bbls:
|
460
|
|
Type (active/reserve)
|
:
|
Active
|
|
Capacity, tank No. 4
|
bbls:
|
650
|
|
Type (active/reserve)
|
:
|
Active
|
|
Capacity, tank No. 5
|
bbls:
|
650
|
|
Type (active/reserve)
|
:
|
Active
|
|
Capacity, tank No. 6
|
bbls:
|
680
|
|
Type (active/reserve)
|
:
|
Active
|
|
Capacity, tank No. 7
|
bbls:
|
160
|
|
Type (active/reserve)
|
:
|
Chemical
|
|
Capacity, tank No. 8
|
bbls:
|
160
|
|
Type (active/reserve)
|
:
|
Chemical
|
|
Capacity, tank No. 9
|
bbls:
|
160
|
|
Type (active/reserve)
|
:
|
Chemical
|
|
Capacity, tank No. 10
|
bbls:
|
160
|
|
Type (active/reserve)
|
:
|
Chemical
|
|
Mixer in each tank
|
yes/no:
|
Yes
|
|
Mud guns in each tank
|
yes/no:
|
Yes
|
|
F.2.2 PROCESSING TANKS
|
|||
Quantity
|
no.:
|
6
|
|
Total capacity (@ 100%)
|
bbls:
|
450
|
|
Capacity Sand Trap tank
|
bbls:
|
75
|
|
Capacity degasser tank
|
bbls:
|
75
|
|
Capacity desander tank
|
bbls:
|
75
|
|
Capacity desilter tank
|
bbls:
|
75
|
|
Capacity desilter tank
|
bbls:
|
75
|
|
Capacity treated mud tank
|
bbls:
|
75
|
|
F.2.3 PILL/SLUG TANK
|
|||
Capacity (@ 100%)
|
bbls:
|
150
|
|
Mud agitator
|
yes/no:
|
yes
|
|
Mud guns
|
yes/no:
|
yes
|
|
F.2.4 TRIP TANK
|
|||
Capacity (@ 100%)
|
bbls:
|
100 2 x 50
|
|
Capacity/foot
|
bbls/ft:
|
TBA
|
|
Level indicator
|
yes/no:
|
yes
|
|
Electric pump make
|
Halco x 2
|
||
Model/type
|
:
|
Cent.
|
|
Motor output
|
hp:
|
30
|
|
Facility for casing fill-up
|
yes/no:
|
no
|
|
Alarm and strip chart recorder (See H.1.;11)
|
yes/no:
|
Yes
|
F.2.5 STRIPPING TANK
|
|||
Capacity (@100%)
|
bbls:
|
10 Approx
|
|
Capacity/foot
|
bbls/ft:
|
TBA
|
|
Equalizing facility with triptank
|
yes/no:
|
Yes
|
|
Transfer pump
|
yes/no:
|
No
|
|
Alarm and strip chart recorder (See H.1.
|
yes/no:
|
Yes
|
|
F.2.6 CHEMICAL MIXING TANK
|
Separate mixing tank above for mixing caustic
|
||
Capacity
|
bbls:
|
See F.2.1 Tks. 7- 10
|
|
Chemical mixer type
|
:
|
||
F.2.7 SHALE SHAKERS
|
|||
Primary:
|
|||
Quantity
|
no.:
|
7
|
|
Make/Model
|
:
|
Brandt/LCM-2D CS
|
|
Type
|
:
|
Linear Motion/ Cascading
|
|
Driven by no. of electric motors
|
no.:
|
3
|
|
Design flowrate
|
bbl/min:
|
Depending on Mud Characteristics
|
|
Cascading:
|
|||
Quantity
|
no.:
|
See Above
|
|
Make/Model
|
:
|
||
Type
|
:
|
||
Driven by no. of electric motors
|
no.:
|
||
Design flowrate
|
bbl/min:
|
||
F.2.8 DESANDER
|
|||
Quantity
|
no.:
|
Desander cones over one cascading shale shaker
|
|
Make/Model
|
:
|
Brandt
|
|
Type
|
:
|
||
Number of cones x sizes
|
no. x inch:
|
6 X 12” w/ discharge overboard
|
|
Type/size centrifugal pump
|
:
|
||
Driven by electric motor of
|
hp:
|
||
Is pump dedicated to desander
|
yes/no:
|
||
Max. flowrate
|
bbl/min:
|
||
F.2.9 DESILTER
|
|||
Quantity
|
no.:
|
Desilter cones over one cascading shale shaker
|
|
Make/Model
|
:
|
Brandt
|
|
Type
|
:
|
||
Number of cones x sizes
|
no. x inch:
|
40 X 4” W/ discharge over shaker or overboard
|
|
Type/size centrifugal pump
|
:
|
||
Driven by electric motor of
|
hp:
|
||
Is pump dedicated to desilter
|
yes/no:
|
||
Max. flowrate
|
bbl/min:
|
||
F.2.10 MUD CLEANER
|
|||
Quantity
|
no.:
|
N/A
|
|
Make/Model
|
:
|
||
Type
|
:
|
||
Number of cones x sizes
|
no. x inch:
|
Type/size centrifugal pump
|
:
|
||
Driven by electric motor of
|
hp:
|
||
Is pump dedicated to mud cleaner
|
yes/no:
|
||
Max. flowrate
|
bbl/min:
|
||
Inlet and outlet for centrifuge to be provided
|
|||
F.2.11 MUD/GAS SEPARATOR (Poor Boy)
|
Shall be capable to direct flow from flowline to MGS
|
||
Make/Type
|
:
|
Swaco
|
|
Gas discharge line ID
|
inch:
|
12” nominal
|
|
Gas discharge location, primary
|
Top
|
||
Can discharge be tied into burner system
|
yes/no:
|
no
|
|
Mud seal height
|
:
|
20
|
|
Calculated gas throughput
|
mmscf:
|
20
|
|
Dimensions
|
OAL 41.5 ft. X 6 ft.
|
||
F.2.12 DEGASSER
|
|||
Quanty
|
2
|
||
Make/Type
|
:
|
Burgess/1500
|
|
Capacity
|
:
|
1000 GPM x 2
|
|
Type/size centrifugal pump
|
:
|
N/A
|
|
Driven by electric motor of power
|
hp:
|
N/A
|
|
Discharge line running to
|
:
|
6”
|
|
Vacuum pump make
|
:
|
Internal
|
|
Type
|
:
|
||
F.2.13 MUD AGITATORS
|
|||
Quantity
|
no.:
|
6
|
|
Make/Model
|
:
|
Philadelphia
|
|
Driven by motor of power
|
hp
|
15
|
|
Located in tanks (See F.2.1 for tank numbers)
|
8, 9, & 10
|
||
Quantity
|
no.:
|
3
|
|
Make/Model
|
:
|
Philadelphia
|
|
Driven by motor of power
|
hp
|
5
|
|
Located in tanks (See F.2.1 for tank numbers)
|
Shaker Tanks
|
||
Quantity
|
no.:
|
4
|
|
Make/Model
|
:
|
Philadelphia
|
|
Driven by motor of power
|
hp
|
10
|
|
Located in tanks (See F.2.1 for tank numbers)
|
1, 2, 3, & 4
|
||
Quantity
|
no.:
|
3
|
|
Make/Model
|
:
|
Philadelphia
|
|
Driven by motor of power
|
hp
|
40
|
|
Located in tanks (See F.2.1 for tank numbers)
|
5, 6, & 7
|
||
F.2.14 MUD CENTRIFUGE
|
|||
Quantity
|
no.:
|
Power and space for 2
|
|
F.2.15 MUD HOPPER
|
|||
Quantity
|
no.:
|
2
|
|
Make/Model
|
:
|
Halco
|
Feed pump make/model
|
:
|
Mixing pumps
|
|
F.2.16 SHEARING HOPPERS
|
|||
Quantity
|
no.:
|
2
|
|
Make/Model
|
:
|
Halco/105-15
|
|
Feed pump make/model
|
:
|
Mixing pumps
|
|
F.2.17 DECK HOPPER
|
|||
Quantity
|
no.:
|
1
|
|
Make/Model
|
:
|
Halco
|
|
Feed pump make/model
|
:
|
Mixing pumps
|
|
F.3 BULK SYSTEM
|
|||
F.3.1 BARITE/BENTONITE SILOS
|
|||
Quantity
|
no.:
|
5
|
|
Capacity of each silo
|
C.F.:
|
2500
|
|
Locations
|
:
|
Columns
|
|
Type weight loadcell
|
:
|
Hydraulic
|
|
Manufacturer
|
:
|
Martin Decker
|
|
Pressure rating
|
65
|
||
Relief valve(s) installed
|
yes/no:
|
yes
|
|
F.3.2 BARITE DAY TANKS
|
|||
Quantity
|
2
|
||
Capacity of each silo
|
C.F:
|
1200
|
|
Locations
|
:
|
Moonpool
|
|
Type weight loadcell
|
:
|
Hydraulic
|
|
Manufacturer
|
:
|
Martin Decker
|
|
Pressure rating
|
psi:
|
65
|
|
Relief valve(s) installed
|
yes/no:
|
yes
|
|
F.3.3 SURGE TANK FOR BARITE
|
|||
Quantity
|
no.:
|
2
|
|
Capacity of each tank
|
It:
|
70
|
|
Type weight loadcell
|
:
|
Hydraulic
|
|
Manufacturer
|
:
|
Martin Decker
|
|
Pressure rating
|
psi:
|
65
|
|
Relief valve(s) installed
|
yes/no:
|
yes
|
|
F.3.4 CEMENT SILOS
|
|||
Quantity
|
3
|
||
Capacity of each silo
|
C.F:
|
2800
|
|
Locations
|
:
|
Columns
|
|
Type weight loadcell
|
:
|
Hydraulic
|
|
Manufacturer
|
:
|
Martin Decker
|
|
Pressure rating
|
psi:
|
65
|
|
Relief valve(s) installed
|
yes/no:
|
yes
|
|
Separate mud/cement loading facilities
|
yes/no:
|
yes
|
|
Discharge line for cement independent from
|
barite/bentonite discharge line
|
yes/no:
|
Yes
|
|
F.3.5 CEMENT DAY TANKS
|
|||
Quantity
|
2
|
||
Capacity of each silo
|
C.F:
|
1100
|
|
Locations
|
:
|
Cement Room
|
|
Type weight loadcell
|
:
|
Hydraulic
|
|
Manufacturer
|
:
|
Martin Decker
|
|
Pressure rating
|
psi:
|
65
|
|
Relief valve(s) installed
|
yes/no:
|
yes
|
|
F.3.6 SURGE TANK FOR CEMENT
|
Third party
|
||
F.3.7 BULK TRANSFER SYSTEM (See also C.1.8 - Compressed Air Systems)
|
|||
Independent air system for the silos and surge tanks consisting of a high-volume low-pressure compressor and air drier
|
yes/no:
|
no
|
|
Air reduced from main air supply through pressure regulators
|
yes/no:
|
yes
|
|
Separate volume tank and drier
|
yes/no:
|
no
|
|
G. CASING/CEMENTING EQUIPMENT
|
Company Supplied
|
||
G.1 CASING EQUIPMENT
|
Company Supplied
|
||
G.1.1 API CASING DRIFT
|
Company Supplied
|
||
G.1.2 CLAMP-ON CSG THREAD PROT’S
|
Company Supplied
|
||
G.1.3 CASING ELEVATOR
|
|||
Manufacturer
|
Company Supplied
|
||
Type
|
|||
Capacity
|
st:
|
||
Inserts for
|
inch:
|
||
G.1.3 SIDE DOOR CASING ELEVATOR
|
Company Supplied
|
||
G.1.4 SINGLE JOINT CASING ELEVATOR
|
Company Supplied
|
||
G.1.5 SLIP TYPE ELEVATOR/SPIDERS
|
|||
Quantity
|
no.:
|
Company Supplied
|
|
G.1.6 CASING SLIPS (Hand)
|
|||
Quantity
|
no.:
|
Company Supplied
|
|
Make/Type
|
:
|
||
For OD casing
|
inch:
|
||
Quantity
|
no.:
|
||
Make/Type
|
:
|
||
For OD casing
|
inch:
|
||
Quantity
|
no.:
|
||
Make/Type
|
:
|
||
For OD casing
|
inch:
|
||
G.1.7 CASING BOWLS
|
|||
Quantity
|
no.:
|
Company Supplied
|
Make/Type
|
:
|
||
For OD casing (max/min)
|
inch/inch:
|
||
Quantity
|
no.:
|
||
Make/Type
|
:
|
||
For OD casing (max/min)
|
inch/inch:
|
||
Quantity
|
no.:
|
||
Make/Type
|
:
|
||
For OD casing (max/min)
|
inch/inch:
|
||
G.1.8 CASING TONGS
|
Company Supplied
|
||
G.1.9 POWER CASING TONGS
|
Company Supplied
|
||
G.1.10 POWER UNIT FOR CASING AND TUBING TONGS
|
|||
Quantity
|
no.:
|
1 Central Hydraulic unit
|
|
Driven by electric motor
|
yes/no:
|
YES
|
|
G.1.11 CASING CIRCULATING HEAD (Swedge)
|
Company Supplied
|
||
G.1.12 CASING SPEARS (Internal)
|
Company Supplied
|
||
G.1.13 CASING CUTTERS (Internal)
|
Company Supplied
|
||
G.1.14 CROSSOVER CASING TO DRILL PIPE
|
Company Supplied
|
||
G.1.15 CASING SCRAPERS
|
Company Supplied
|
||
G.2 CEMENTING EQUIPMENT
|
|||
G.2.1 CEMENT UNIT
|
Company Supplied
|
||
G.2.2 CEMENTING MANIFOLD
|
|||
Discharge manifold working pressure
|
psi:
|
15000
|
|
Cement pump discharge lines min. ID
|
inch:
|
3 Nonimal
|
|
Cement pump discharge lines working p
|
psi:
|
15000
|
|
G.2.3 CEMENT KELLY
|
N/A
|
||
G.2.4 CEMENTING TUBING
|
N/A
|
||
H. INSTRUMENTATION/COMMUNICATION
|
|||
H.1 DRILLING INSTRUMENTATION AT DRILLER’S POSITION
|
|||
H.1.1 WEIGHT INDICATOR
|
|||
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Sensor type
|
:
|
ELECTRONIC DEADEND
|
|
Calibrated for number of lines strung (6, 8, 10, 12, etc.)
|
no.:
|
USER SELECTABLE
|
|
H.1.2 STANDPIPE PRESSURE GAUGES
|
|||
Quantity
|
no.:
|
TBA
|
|
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Pressure range (maximum)
|
psi:
|
TBA
|
|
H.1.3 CHOKE MANIFOLD PRESSURE GAUGE
|
|||
Quantity
|
no.:
|
2
|
|
Make/Type
|
HITEC SMART DRILLING INSTRUMENTATION
|
||
Pressure range (maximum)
|
psi:
|
0 - 15,000
|
H.1.4 ROTARY SPEED TACHOMETER
|
|||
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Capacity range (maximum)
|
rpm:
|
0 - 200
|
|
H.1.5 ROTARY TORQUE INDICATOR
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
H.1.6 MOTION COMPENSATOR INSTRUMENTS
|
|||
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Hook position indicator
|
yes/no:
|
YES
|
|
Lock/unlock indicator
|
yes/no:
|
YES
|
|
H.1.7 PUMP STROKE COUNTERS
|
|||
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
One pump stroke indicator and one cumulative pump stroke counter for each pump.
|
yes/no:
|
YES
|
|
H.1.8 TONG TORQUE INDICATOR
|
|||
Make/Type
|
:
|
||
Capacity range (maximum)
|
ft lbs:
|
||
H.1.9 PIT VOLUME TOTALIZER
|
|||
Make/Model
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Floats in active mud tanks
|
yes/no:
|
YES
|
|
Floats in reserve mud tanks
|
yes/no:
|
YES
|
|
Loss/Gain indicator
|
yes/no:
|
YES
|
|
Alarm (audio and visual)
|
yes/no:
|
YES
|
|
H.1.10 MUD FLOW INDICATOR
|
|||
Make/Model
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
High/low alarm (audio and visual)
|
yes/no:
|
YES
|
|
H.1.11 TRIP TANK INDICATOR
|
|||
Make/Model
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Chart recorder
|
yes/no:
|
DATA LOGGING
|
|
Alarm
|
yes/no:
|
YES
|
|
H.1.12 GENERAL ALARM SYS.
|
yes/no:
|
YES
|
|
H.1.13 AUTOMATIC DRILLER
|
|||
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
H.1.14 REMOTE CHOKE CONTROL UNIT (See E.14.1)
|
|||
Make/Model
|
:
|
Houston Digital
|
|
H.2 DRILLING PARAMETER RECORDER
|
|||
Quantity
|
no.:
|
USER DEFINED ELECT. DATA ACQUISITION
|
|
Location - 1
|
:
|
DRILLERS HOUSE
|
|
Location - 2
|
:
|
||
Make/Type
|
:
|
HITEC SMART DRILLING INSTRUMENTATION
|
|
Quantity of pens
|
no.:
|
USER DEFINED ELECT. DATA ACQUISITION
|
|
Parameter recorded
|
:
|
”
|
|
Parameter recorded
|
:
|
”
|
|
Parameter recorded
|
:
|
”
|
Parameter recorded
|
:
|
”
|
|
Parameter recorded
|
:
|
”
|
|
Parameter recorded
|
:
|
”
|
|
Parameter recorded
|
:
|
”
|
|
Parameter recorded
|
:
|
”
|
|
H.3 INSTRUMENTATION AT CHOKE MANIFOLD
|
|||
H.3.1 STANDPIPE PRESSURE GAUGE
|
|||
Make/Type
|
:
|
Strain gauge
|
|
Pressure range (maximum)
|
psi:
|
0-10,000
|
|
H.3.2 CHOKE MANIFOLD PRESSURE GAUGE
|
|||
Make/Type
|
:
|
Strain gauge
|
|
Pressure range
|
psi:
|
0-15,000
|
|
H.3.1 and H.3.2 combined on one panel
|
yes/no:
|
yes
|
|
Visible from choke operating position
|
yes/no:
|
yes
|
|
H.4 STANDPIPE PRESSURE GAUGE
|
Strain Gauges
|
||
Make/Type
|
:
|
OTECO
|
|
Pressure range
|
psi:
|
0-10,000
|
|
Visible from driller’s position
|
yes/no:
|
No
|
|
H.5 DEVIATION EQUIPMENT
|
|||
H.5.1 MEASURING DEVICE
|
|||
Quantity
|
no.:
|
1
|
|
Make/Type
|
:
|
Totco
|
|
Deviation range
|
degree:
|
0 - 8 / 0-12
|
|
H.5.2 WIRELINE WINCH
|
|||
Make/Model
|
:
|
Mathey
|
|
Wire length (nominal)
|
ft:
|
25000
|
|
Depth counter
|
yes/no:
|
yes
|
|
Wire size
|
inch:
|
3/16
|
|
Pull indicator
|
Ibs:
|
yes
|
|
H.6 CALIBRATED PRESS. GAUGES
|
:
|
Strain Gauges
|
|
H.7 RIG COMMUNICATION SYSTEM
|
|||
H.7.1 TELEPHONE SYSTEM
|
|||
No. of stations
|
no.:
|
120
|
|
Make/Type
|
:
|
Mitel Exchange
|
|
Explosion proof
|
yes/no:
|
AS REQ’D.
|
|
No. of stations
|
no.:
|
||
Make/Type
|
:
|
||
Explosion proof
|
yes/no:
|
||
H.7.2 PUBLIC ADDRESS SYSTEM
|
|||
Can be combined with above
|
yes/no:
|
YES
|
Make/Type
|
:
|
Akusta
|
|
Explosion proof
|
yes/no:
|
AS REQ’D.
|
|
H.7.3 DRILL FLOOR - DERRICKMAN’S TALKBACK (For Intercom System)
|
|||
No. of stations
|
no.:
|
14
|
|
Location
|
:
|
DWS - 2 / PHS
|
|
Location
|
:
|
CCR / ECR
|
|
Location
|
:
|
FLOOR, ROV, CP AREA, MONKEY BD., MP ROOM, MOONPOOL, SHAKERS, CROWN
|
|
Make/Type
|
:
|
AKUSTA
|
|
Explosion proof
|
yes/no:
|
AS REQ’D.
|
|
H.7.4 HAND-HELD VHF RADIOS
|
|||
Quantity
|
12 MIN.
|
||
Make/Type
|
Earmark VOX 130
|
||
H.8 ENVIRONMENTAL INSTRUMENTATION
|
|||
H.8.1 TEMPERATURE INDICATORS
|
|||
Air temperature
|
Yes
|
||
Make/Model
|
Kongsberg
|
||
Sea water temperature
|
TBA
|
||
Make/Model
|
:
|
TBA
|
|
Recorder
|
yes/no:
|
Yes
|
|
H.8.2 BAROMETRIC PRESSURE
|
yes/no:
|
Yes
|
|
Make/Model
|
Kongsberg
|
||
Recorder
|
Yes
|
||
H.8.3 HUMIDITY SENSING INDICATOR
|
Yes
|
||
Make/Model
|
Kongsberg
|
||
Recorder
|
No
|
||
H.8.4 WIND SPEED/DIRECTION
|
Yes - QTY. 2
|
||
Make/Model
|
Kongsberg
|
||
Recorder
|
Yes
|
||
H.8.5 WAVE PROFILE RECORDER
|
No
|
||
H.9 ADDITIONAL MODULE SPECIFIC INSTRUMENTATION
|
|||
H.9.1 ROLL, PITCH AND HEAVE INDICATOR
|
|||
Make/Type
|
Kongsberg
|
||
Recorder
|
|||
H.9.2 GYRO COMPASS
|
|||
Make/Model
|
C. Plath / Navagat X
|
||
Located at
|
CCR ELECT. SPACE
|
||
H.9.3 ECHO SOUNDER
|
Yes
|
||
Make/Model
|
Skipper
|
||
Located at
|
Bridge
|
Recorder
|
No
|
||
H.9.4 CURRENT INDICATOR
|
Doppler Current Profiler
|
||
Make/Model
|
TBA
|
||
Located at
|
Lower Hull Penetration
|
||
Recorder
|
TBA
|
||
H.9.5 WEATHER FACSIMILE RECOI
|
Yes
|
||
Make/Model
|
:
|
JRC / JAX - 9A
|
|
Located at
|
:
|
Radio Room
|
|
Recorder
|
yes/no:
|
Yes
|
|
H.9.6 RADAR
|
YES
|
Yes
|
|
Quantity
|
1
|
1
|
|
Make/Model
|
Norcontrol / Databridge 2000 BL
|
||
Located at
|
Bridge
|
||
Bandwidth
|
cm:
|
X-Band
|
|
Quantity
|
no.:
|
1
|
|
Make/Model
|
:
|
Norcontrol / Databridge 2000 BL
|
|
Located at
|
:
|
Bridge
|
|
Bandwidth
|
cm:
|
S-Band
|
|
H.10 RADIO EQUIPMENT
|
|||
H.10.1 SSB TRANSCEIVER
|
|||
Quantity
|
1
|
||
Make/Model
|
Sailor / RE2100
|
||
Power
|
watts:
|
600
|
|
Frequency ranges
|
hz:
|
100 khz - 30 MHz
|
|
(Synthesized/crystal)
|
:
|
Synthesized
|
|
Facsimile capable
|
No
|
||
Telex capable
|
N/A
|
||
H.10.2 E.P.I.R.B’s
|
|||
Quantity
|
2
|
||
Make/Model
|
:
|
COSPAS / SARSAT / TRON 30S MK II
|
|
H.10.3 VHF RADIO TELEPHONE
|
|||
Quantity
|
5
|
||
Make/Model
|
Norcontrol - Sailor / RT 2048 W/ DSC
|
||
Power
|
watts:
|
25 W
|
|
Channels
|
|||
H.10.4 VHF RADIO TRANSCEIVER
|
|||
Quantity
|
no.:
|
3
|
|
Make/Model
|
:
|
Norcontrol - Sailor / RT 2048
|
|
Power
|
watts:
|
25 W
|
|
H.10.5 RADIO BEACON TRANSM
|
|||
Quantity
|
1
|
||
Make/Model
|
:
|
Southern Avionics / SA 100
|
|
Power
|
watts:
|
100 W
|
H.10.6 AEORNAUTICAL VHF TRANS
|
||||
Quantity
|
1
|
|||
Make/Model
|
:
|
Jotron
|
||
Power
|
watts:
|
40 W PEP
|
||
Frequency range
|
hz:
|
118 - 137
|
||
(Synthesized/crystal)
|
:
|
|||
H.10.7 WATCH RECEIVER
|
||||
Quantity
|
1
|
|||
Make/Model
|
:
|
Sailor / R501
|
||
Frequency
|
khz:
|
2182
|
||
H.10.8 SCRAMBLER
|
||||
Quantity
|
no.:
|
No
|
||
Make/Model
|
:
|
|||
H.10.9 TELEX
|
||||
Quantity
|
no.:
|
N/A
|
||
Make/Model
|
:
|
|||
H.10.10 SATELLITE COMM. SYS
|
||||
Make/Model
|
:
|
NERA / C-10-0
|
/ NERA / H2095 B
|
|
Type
|
:
|
Type B
|
/ Type C
|
|
Facsimile link
|
Yes
|
|||
Telex link
|
Yes
|
|||
Telephone link
|
Data Link (9.6 K bits / Message Terminal
|
|||
Other capabilities
|
:
|
|||
1. PRODUCTION TEST EQUIPMENT
|
||||
1.1 BURNERS
|
N/A
|
|||
1.2 BURNER BOOMS
|
Foundations Only
|
|||
1.3 LINES ON BURNER BOOMS
|
N/A
|
|||
1.3.1 OIL LINE
|
||||
OD
|
inch:
|
4”
|
||
Working pressure
|
psi:
|
1480 psi
|
||
Connection type at burner end
|
:
|
Suitable to connect to well test equipment
|
||
H2S
|
yes/no:
|
Yes
|
||
Pressure gauge connection at barge end
|
inch:
|
Provided by well test company
|
||
1.3.2 GAS LINE
|
||||
OD
|
inch:
|
3”
|
||
Working pressure
|
psi:
|
1480 psi
|
||
Extended beyond burner by
|
ft:
|
Provided by well test company
|
||
Connection type at burner end
|
type:
|
Suitable to connect to well test equipment
|
||
H2S
|
yes/no:
|
Yes
|
||
Pressure gauge connection at barge end
|
inch:
|
Provided by well test company
|
||
1.3.3 WATER LINE
|
||||
OD
|
inch:
|
Seawater - 1-1/2”
|
||
Working pressure
|
psi:
|
285 psi
|
Connection type at burner end
|
type:
|
Suitable to connect to well test equipment
|
|
Pressure gauge connection at barge end
|
inch:
|
Provided by well test company
|
|
I.3.4 AIR LINE
|
|||
OD
|
inch:
|
4”
|
|
Working pressure
|
psi:
|
285 psi
|
|
Connection type at burner end
|
type:
|
Suitable to connect to well test equipment
|
|
Pressure gauge connection at barge end
|
inch:
|
Provided by well test company
|
|
I.3.5 PILOT GASLINE
|
|||
ID
|
inch:
|
Provided by well test company
|
|
Working pressure
|
psi:
|
||
Connection type at burner end
|
type:
|
||
Pressure gauge connection at rig end
|
inch:
|
||
I.4 SPRINKLER SYSTEM
|
|||
Sufficient to give protection to rig and personnel against heat radiation damage from the b
|
yes/no:
|
Provided by well test company
|
|
1.5 FIXED LINES FOR WELL TESTING
|
|||
1.5.1 DRILL FLOOR TO SEPARATOR AREA
|
|||
Type (Screwed/welded, both)
|
Tested and certified flexible flowlines provided by well
|
||
:
|
test co. for connecting from rig floor to well test equip.
|
||
1.5.2 SEPARATOR AREA TO BOTH BURNER BOOMS
|
|||
Type (screwed/welded, both.)
|
:
|
Welded
|
|
Quantity
|
no.:
|
2 ea. / one oil / one gas
|
|
Size OD
|
inch:
|
3” Gas / 4” Oil
|
|
Working pressure
|
psi:
|
1480 psi
|
|
Connection type at separator
|
type:
|
Suitable for connecting to well test company
|
|
Connection type at boom
|
type:
|
As above
|
|
Number of valves/lines
|
no.:
|
Provided by well test company
|
|
Size of valves
|
inch:
|
Provided by well test company
|
|
H2S
|
yes/no:
|
Yes
|
|
Valves installed near separator area for switching gas to either burner.
|
yes/no:
|
Yes
|
|
I.53 MUD PUMPS TO 2-BURNER
|
:
|
N/A
|
|
I.5.4 RIG AIR SYSTEM TO BOTH BURNER BOOMS
|
|||
Type (screwed/welded, both)
|
:
|
Welded
|
|
Quantity
|
no.:
|
1 ea. Port and Starboard
|
|
Size OD
|
inch:
|
4”
|
|
Working pressure
|
psi:
|
||
Non-return valves fitted
|
yes/no:
|
Yes
|
|
I.5.5 OIL STORAGE TANK TO OVERBOARD
|
|||
Type (screwed/welded, both)
|
:
|
Provided by well test company
|
|
Quantity
|
no.:
|
||
Size ID
|
inch:
|
Working pressure
|
psi:
|
||
Height above water level
|
ft:
|
||
Connection type at separator area
|
type:
|
||
I.5.6 SEPARATOR TO VENTSTACK OF RIG
|
|||
Type (screwed/welded, both)
|
:
|
No vent from separator. Relief to flair
|
|
Quantity
|
no.:
|
||
Size ID
|
inch:
|
||
Working pressure
|
psi:
|
||
Connection type at separator area
|
type:
|
||
I.6 AUXILIARY POWER AVAILABILITY
|
|||
I.6.1 FOR FIELD LABORATORY
|
|||
Quantity
|
kw
|
2 - 480 volt boxes
|
|
Volts
|
v:
|
||
Frequency
|
hz:
|
||
I.6.2 FOR CRUDE TRANSFER PUMP
|
|||
Quantity
|
kw:
|
Yes, as above
|
|
volts
|
v:
|
||
Frequency
|
hz:
|
||
I.6.3 FOR ELECTRIC HEATERS
|
|||
Quantity
|
kw:
|
Yes, as above
|
|
Volts
|
v:
|
||
Frequency
|
hz:
|
||
J. WORKOVER TOOLS
|
Company Supplied
|
||
K. ACCOMMODATION
|
|||
K.1 OFFICES
|
|||
K.1.1 CO. REP.’S OFFICE
|
|||
Quantity
|
3
|
||
Complete with desk, filing cabinet(s) and other necessary furniture
|
YES
|
||
Unrestricted view to drill floor
|
NO(CCTV MONITOR)
|
||
K.1.2 CONT. REP.’S OFFICE
|
|||
Quantity
|
3
|
||
Unrestricted view to drill floor
|
NO(CCTV MONITOR)
|
||
K.1.3 RADIO ROOM
|
YES
|
||
Quantity
|
1
|
||
K.1.4 HOSPITAL ROOM
|
|||
Number of beds/bunks
|
2 Beds
|
||
Wash basin
|
YES
|
||
Medical cabinet
|
YES
|
||
Dangerous drugs locker
|
YES
|
K.1.5 MUD LABORATORY AND FACILITIES
|
|||
Separate room
|
yes/no:
|
YES
|
|
Equippped with:
|
|||
Mud balance
|
yes/no:
|
YES
|
|
Marsh funnel
|
yes/no:
|
YES
|
|
Filtration kit
|
yes/no:
|
YES
|
|
Sand content kit
|
yes/no:
|
YES
|
|
Stopwatch
|
yes/no:
|
YES
|
|
K.2 LIVING QUARTERS
|
|||
K.2.1 TOTAL PERSONS ACCOMODATED
|
|||
Quantity
|
130
|
||
K.2.2 ACCOMODATION FOR COMPANY’S PERSONNEL
|
|||
Total quantity
|
60
|
||
Quantity of single bed rooms
|
2
|
||
C/W attached toilet
|
YES
|
||
Quantity of two bed rooms
|
30
|
||
C/W attached toilet
|
YES
|
||
Quantity of four bed rooms
|
0
|
||
C/W attached toilet
|
N/A
|
||
K.2.3 ACCOMODATION FOR CONTRACTOR’S PERSONNEL
|
|||
Total quantity
|
70
|
||
Quantity of single bed rooms
|
7
|
||
C/W attached toilet
|
YES
|
||
Quantity of two bed rooms
|
30
|
||
C/W attached toilet
|
YES
|
||
Quantity of four bed rooms
|
O
|
||
C/W attached toilet
|
N/A
|
||
K.2.4 GALLEY
|
|||
Quantity
|
1
|
||
K.2.5 MESS SEATING CAPACITY
|
|||
Main mess
|
60
|
||
Aux. mess
|
N/A
|
||
K.2.6 MEETING ROOMS
|
|||
Quantity
|
1
|
||
K.2.7 RECREATION ROOMS
|
|||
Quantity
|
2
|
||
Recreation facilities:
|
YES
|
||
TV
|
YES
|
||
VCR
|
YES
|
||
Pool Table
|
NO
|
||
Ping Pong Table
|
YES
|
||
Computer
|
NO
|
||
Other
|
DARTS/CARDS/READING
|
.2.8 OTHER ROOMS
|
|||
Laundry
|
1 + 2 In change room for dirty clothes
|
||
Dry food store
|
1
|
||
Refrigerator
|
3
|
||
Change Rooms
|
4
|
||
Prayer Room
|
NO
|
||
Cinema
|
NO
|
||
Workout/Weight Room
|
YES
|
||
L. SAFETY EQUIPMENT
|
|||
L.1 GENERAL SAFETY EQUIPMENT
|
|||
L.1.1 GENERAL PERSONNEL PROTECTIVE GEAR
|
|||
Safety bats (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Safety boots (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Safety clothing (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Ear protection (contractor only/everyone/not supplied
|
:
|
EVERYONE
|
|
Rubber gloves (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Rubber aprons (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Fullface visors (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Eye shields (for grinding machines, etc.)
(Contractor only/everyone/not supplied
|
:
|
CONTRACTOR ONLY
|
|
Dust masks (contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Rubber gloves - elbow length for chemical handling
(Contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Explosion proof handtorches c/w batteries
(Contractor only/everyone/not supplied
|
:
|
CONTACTOR ONLY
|
|
Safety belts c/w lines (contractor only/everyone/not supplied
|
:
|
CONTRACTOR ONLY
|
|
L.1.2 EYE WASH STATIONS
|
|||
Quantity
|
no.:
|
3
|
|
Make/model
|
:
|
TBA
|
|
Located at
|
pot water
|
MUD PROCESS ROOM
|
|
Located at
|
piping
|
DRILL FLOOR
|
|
Located at
|
:
|
MUD MIXING ROOM
|
|
L.1.3 DERRICK SAFETY EQUIPMENT
|
|||
Derrick escape chute (rem chute)
|
no.:
|
N/A
|
|
Make/Type
|
:
|
||
Derrick safety belts
|
no.:
|
2 W/ INERTIA REEL
|
|
Make/Type
|
:
|
TBA
|
|
L.1.4 DERRICK CLIMBING ASSISTANT
|
|||
Make/Type
|
|||
L.1.5 FRESH AIR BLOWERS (Bug Blowers)
|
|||
Quantity
|
:
|
3
|
|
Make/Type
|
:
|
||
Located at
|
:
|
Rig Floor
|
|
Located at
|
:
|
L.2 GAS/FIRE/SMOKE DETECTION
|
|||
L.2.1 H2S MONITORING SYSTEM
|
|||
Make/Type
|
:
|
TBA
|
|
Sampling points at:
|
|||
Bellnipple
|
yes/no:
|
YES
|
|
Drillfloor
|
yes/no:
|
YES
|
|
Shale shaker
|
yes/no:
|
YES
|
|
Mud tanks
|
yes/no:
|
YES
|
|
Ventilation system into living quarters
|
yes/no:
|
YES
|
|
Other
|
:
|
YES
|
|
General alarm
|
yes/no:
|
||
Alarm types (audible, visual, both) at:
|
|||
Driller’s console
|
:
|
BOTH
|
|
Engine room
|
:
|
BOTH
|
|
Mud room
|
:
|
BOTH
|
|
Living quarters each level
|
:
|
AUDIBLE
|
|
Central area each structural level
|
:
|
BOTH
|
|
Other
|
:
|
BOTH
|
|
Central alarm panel
|
yes/no:
|
YES
|
|
Located at
|
:
|
CCR
|
|
L.2.2 COMBUSTIBLE GAS MONITORING SYSTEM
|
|||
Make/Type
|
:
|
Simrad Integrated Alarm and Control System
|
|
Sampling points at:
|
yes/no:
|
||
Bellnipple
|
yes/no:
|
YES
|
|
Drill floor
|
yes/no:
|
YES
|
|
Shale Shaker
|
yes/no:
|
YES
|
|
Mud tanks
|
yes/no:
|
YES
|
|
Ventilation system into living quarters
|
yes/no:
|
YES
|
|
Other
|
:
|
YES
|
|
General alarm
|
yes/no:
|
||
Alarm types (audible, visual, both) at:
|
|||
Driller’s console
|
:
|
BOTH
|
|
Other
|
:
|
BOTH
|
|
YES
|
|||
L.2.3 H2S DETECTORS (Portable)
|
|||
Quantity
|
no.:
|
TBA
|
|
Make/Type
|
:
|
||
Phials for H2S: measuring range
|
|||
from 1 to 20 ppm
|
no.:
|
||
from 100 to 600 ppm
|
no.:
|
||
L.2.4 CO2 GAS DETECTORS (Portable)
|
|||
Quantity
|
no.:
|
TBA
|
|
Make/Type
|
:
|
||
Phials for CO2: measuring range
|
|||
from 1 to 20 ppm
|
no.:
|
||
from 20 to 200 ppm
|
no.:
|
||
om 250-3000 ppm
|
no:
|
||
L.2.5 EXPLOSIMETERS
|
|||
Quantity
|
no.:
|
TBA
|
|
Make/Type
|
:
|
L.2.6 FIRE/SMOKE DETECTORS IN ACCOMODATION
|
||||
Make/type
|
:
|
THERMAL
|
||
Fire detection
|
yes/no:
|
YES
|
||
Smoke detection
|
yes/no:
|
YES
|
||
Central alarm panel
|
yes/no:
|
YES
|
||
Location
|
:
|
CCR
|
||
L.3 FIRE FIGHTING EQUIPMENT
|
||||
L.3.1 FIRE PUMPS
|
||||
Quantity
|
no.:
|
2
|
||
Make/Model
|
:
|
Patterson
|
||
Type
|
:
|
CENTRIFUGAL
|
||
Output
|
US gals/min:
|
550
|
||
All offtake points supplied by each pump
|
yes/no:
|
YES
|
||
Location of pumps
|
:
|
AUX. MACHINE ROOM PORT
|
||
Location of pumps
|
:
|
AUX. MACHINE ROOM FWD.
|
||
Fire fighting water delivery conforms to
|
yes/no:
|
YES
|
||
MODU spec version
|
:
|
|||
L 3.2 HYDRANTS AND HOSES
|
||||
Hydrants positioned such that any point may be reached
|
||||
by a single hose length from two separate hydrants
|
yes/no:
|
YES
|
||
Quantity of hydrants
|
no.:
|
48
|
||
Hose connections/hydrant
|
no.:
|
46 X 1
|
||
Hose max. diam.
|
inch:
|
2.5” OD
|
||
Length
|
ft:
|
50’
|
||
L.3.3 PORTABLE FIRE EXTINGUISHERS
|
||||
Quantity (total)
|
no.:
|
70
|
||
Type 1- CO2
|
no./lbs:
|
2 @ 4
|
||
no./lbs:
|
37 @ 15
|
|||
no./lbs:
|
2 @ 150
|
|||
Type 2 - Dry chemical
|
no./lbs:
|
17 @ 5
|
||
no./lbs:
|
9 @ 10
|
|||
no./lbs:
|
3 @ 50
|
|||
Type 3 - Foam
|
no./lbs:
|
0
|
||
no./lbs:
|
0
|
|||
no./lbs:
|
0
|
|||
Mounted adjacent to access ways and escape routes
|
yes/no:
|
yes
|
||
L.3.4 FIRE BLANKETS
|
||||
Location
|
:
|
RIG FLOOR, GALLEY, HELICOPTER BOX
|
||
Quantity
|
no.:
|
3
|
||
L.3.5 FIXED FOAM SYSTEM
|
||||
Automatically injected into fixed fire water system at central point with remote manual control
|
yes/no:
|
YES
|
||
Make/Type
|
:
|
Patterson
|
||
Quantity foam stored on site
|
GALLONS
|
700 GPM
|
||
Inductor tube
|
yes/no:
|
YES
|
|
Foam nozzles
|
no.:
|
4
|
|
Located at
|
:
|
HELIPORT -3 TURRET MOUNTED
|
|
Located at
|
:
|
HELIPORT -1 HOSE REELS
|
|
Located at
|
:
|
||
L.3.6 HELIDECK FOAM SYSTEM
|
|||
Dedicated system adequate for at least 10 minutes fire fighting at the rate quoted in the IMO MODU code
|
yes/no:
|
YES
|
|
IMO MODU code version
|
:
|
TBA
|
|
Make/Type
|
:
|
DOOLY
|
|
Quantity of monitors
|
no.:
|
3
|
|
Foam type
|
:
|
TBA
|
|
Rate
|
US gals/min:
|
350 gal. min. each
|
|
L.3.7 FIXED FIRE EXTINGUISHING SYSTEM
|
|||
Protected spaces
|
|||
Engine room, type (Halon/CO2)
|
CO2
|
||
Paint locker, type (Halon/CO2)
|
CO2
|
||
Emergency generator, type (Halon/CO2)
|
CO2
|
||
SCR room, type (Halon/CO2)
|
CO2
|
||
Other (specify location & type)
|
CO2 IN MUD PUMP ROOM
|
||
Alarms (audible, visual or both)
|
:
|
||
Automatic shutting of mechanical ventilation in protected spaces
|
yes/no:
|
YES
|
|
Remote manual release located at
|
:
|
||
Remote manual release located at
|
:
|
||
Remote manual release located at
|
:
|
||
L.3.8 MANUAL WATER DELUGE SYSTEM
|
yes/no:
|
YES
|
|
Protected spaces
|
:
|
DRILL FLOOR, LIFEBOATS
|
|
Protected spaces
|
:
|
LIFERAFTS, MOONPOOL
|
|
Water supplied from fire main line
|
yes/no:
|
YES MAIN SALT WATER RING
|
|
L.3.9 WATER SPRINKLER SYSTEM IN ACCOMODATION
|
|||
Automatic
|
yes/no:
|
YES
|
|
Working pressure
|
psi:
|
130
|
|
Pressurized tank capacity
|
ft3:
|
53.47
|
|
L.4 BREATHING APPARATUS
|
:
|
TBA
|
|
L.5 EMERGENCY FIRST AID EQUIPMENT
|
|||
L.5.1 FIRST AID KITS
|
|||
Quantity
|
no.:
|
TBA
|
|
L.5.2 BURN KITS
|
|||
Quantity
|
no.:
|
TBA
|
|
L.5.3 RESUSCITATORS
|
|||
Quantity
|
no.:
|
TBA
|
Charged (spare) oxygen cylinders
|
no.:
|
||
L.5.4 STRETCHERS
|
|||
Quantity
|
no.:
|
TBA
|
|
Type
|
:
|
||
Located at
|
:
|
||
L.6 HELIDECK RESCUE EQUIPMENT
|
|||
L.6.1 STORAGE BOXES
|
|||
Quantity
|
no.:
|
TBA
|
|
Construction material
|
:
|
FIBERGLASS
|
|
Max height open
|
inch:
|
TBA
|
|
L.6.2 EQUIPMENT
|
|||
Aircraft axe
|
yes/no:
|
YES
|
|
Large firemans rescue axe
|
yes/no:
|
YES
|
|
Crowbar
|
yes/no:
|
YES
|
|
Heavy duty hacksaw
|
yes/no:
|
YES
|
|
Spare blades
|
yes/no:
|
YES
|
|
Grapnel hook
|
yes/no:
|
NO
|
|
Length of wire rope attached
|
ft:
|
||
Quick release knife
|
yes/no:
|
YES
|
|
Bolt croppers
|
yes/no:
|
YES
|
|
L.7 RIG SAFETY STORE
|
|||
Equipment to repair, recharge and restock
|
R&BF will carry all spares necessary to ensure an efficient and safe operation.
|
||
L.8 EMERGENCY WARNING ALARMS
|
|||
Approved system to give warning of different emergencies
|
yes/no:
|
YES
|
|
L.9 SURVIVAL EQUIPMENT
|
|||
L.9.1 LIFEBOATS
|
|||
Make/Type
|
:
|
TBA
|
|
Quantity
|
no.:
|
2
|
|
Capacity
|
person/craft:
|
65
|
|
Locations (fore, apt, port, stbd)
|
:
|
2 FORE
|
|
Fire protection
|
yes/no:
|
YES
|
|
Radios
|
yes/no:
|
YES
|
|
Flares
|
yes/no:
|
YES
|
|
Food
|
yes/no:
|
YES
|
|
First aid kits
|
yes/no:
|
YES
|
|
Maker/Type
|
:
|
TBA
|
|
Quantity
|
no.:
|
2
|
|
Capacity
|
person/craft:
|
65
|
|
Locations (fore, apt, port, stbd)
|
:
|
AFT
|
|
Fire protection
|
yes/no:
|
YES
|
|
Radios
|
yes/no:
|
YES
|
|
Flares
|
yes/no:
|
YES
|
Food
|
yes/no:
|
YES
|
|
First aid kits
|
yes/no:
|
YES
|
|
L.9.2 LIFERAFTS
|
|||
Make/Type
|
:
|
TBA
|
|
Quantity
|
no.:
|
3
|
|
Capacity
|
person/craft:
|
30
|
|
Davit launched
|
yes/no:
|
YES & FLOAT FREE
|
|
Locations (fore, apt, port, stbd)
|
:
|
FORE
|
|
Fire protection
|
yes/no:
|
||
Radios
|
yes/no:
|
TBA
|
|
Flares
|
yes/no:
|
YES
|
|
Food
|
yes/no:
|
YES
|
|
First aid kits
|
yes/no:
|
YES
|
|
Make/Type
|
:
|
TBA
|
|
Quantity
|
no.:
|
2
|
|
Capacity
|
person/craft:
|
30
|
|
Davit launched
|
yes/no:
|
YES
|
|
Locations (fore, apt, port, stbd)
|
:
|
AFT
|
|
Fire protection
|
yes/no:
|
||
Radios
|
yes/no:
|
TBA
|
|
Flares
|
yes/no:
|
YES
|
|
Food
|
yes/no:
|
YES
|
|
First aid kits
|
yes/no:
|
YES
|
|
L.9.3 RESCUE BOAT
|
|||
Make/Type
|
:
|
Port Fwd lifeboat is designated as a rescue boat
|
|
Engine power
|
hp:
|
||
L.9.4 LIFE JACKETS
|
|||
Make/Type
|
TBA
|
||
Quantity
|
no.:
|
163
|
|
L.9.5 LIFE BUOYS
|
|||
Make/Type
|
:
|
TBA
|
|
Quantity
|
no.:
|
10
|
|
L.9.6 WORK VESTS
|
|||
Make/Type
|
:
|
TBA
|
|
Quantity
|
no:
|
25
|
|
L.9.7 ESCAPE LADDERS/NETS
|
|||
Make/Type
|
:
|
PERMANENT LADDERS
|
|
Quantity
|
no.:
|
4, 1 PER CORNER COL.
|
|
L.9.8 DISTRESS SIGNALS
|
|||
Type
|
:
|
TBA
|
|
Quantity
|
no.:
|
1 SET
|
|
M. POLLUTION PREVENTION EQUIPMENT
|
|||
M.1 SEWAGE TREATMENT
|
Make/Model
|
:
|
HAMMWORTHY (USCG APPROVED)
|
|
System type
|
:
|
BIOLOGICAL
|
|
Conforms to (Marpol annex IV, etc.)
|
:
|
YES
|
|
M.2 GARBAGE COMPACTION
|
|||
Make/Model
|
:
|
To be provided
|
|
System type
|
:
|
||
Conforms to (Marpol annex IV, etc.)
|
:
|
||
Make/Model
|
:
|
||
System type
|
:
|
||
Conforms to (Marpol annex IV, etc.)
|
:
|
||
M.3 GARBAGE DISPOSAL/GRINDER
|
|||
Make/Model
|
:
|
To be provided
|
|
System type
|
:
|
||
Conforms to (Marpol annex IV, etc.)
|
:
|
||
N.1 THIRD PARTY EQUIPMENT
|
|||
Mud Loggers (available sq feet)
|
555 sq. ft.
|
||
MWD / LWD (available sq feet)
|
555 sq. ft.
|
||
Cement Unit (available sq. feet)
|
1,087 sq. ft.
|
||
ROV (available sq. feet)
|
1184 sq. ft.
|
||
Electric Log (available sq. feet)
|
895 sq. ft.
|
Categories:
|
I. Furnished by CONTRACTOR, paid by CONTRACTOR.
|
II. Furnished by COMPANY, paid by COMPANY.
|
|
III. Furnished by CONTRACTOR, paid by COMPANY.
|
1.1
|
Fuel storage.
|
|
1.2
|
Lube oils and greases.
|
|
1.3
|
Tool joint lubricant for CONTRACTOR’S drill string.
|
|
1.4
|
Replacement screens on shale shaker for screen sizes 84 mesh and coarser.
|
|
1.5
|
Replacement screens for mud cleaner(s) for screen sizes 150 mesh and coarser.
|
|
1.6
|
Initial set of rig hoses for receiving or discharge of liquid and bulk consumables from workboats.
|
|
1.7
|
Initial installation and utility provision for AC drive cementing unit and cement mixing pumps in shipyard. (rental only - as provided in Rental Agreement).
|
|
1.8
|
Initial installation for ROV unit and installation of ROV cursor system. Provision of utilities for electric motor generator for ROV main power.
|
|
1.9
|
Welding services with welder in CONTRACTOR’S crew (overtime not included).
|
|
1.10
|
Except as otherwise provided in Exhibit “B-2” herein rig and equipment maintenance, running supplies, spares and replacement parts, and services for continuous operation of CONTRACTOR’S equipment.
|
|
1.11
|
Towing bridle and replacement of same from Drilling Unit to towing vessel(s) during all rig moves.
|
|
1.12
|
Supply vessel mooring system at Drilling Unit.
|
|
1.13
|
Labor on the Drilling Unit to load and unload all CONTRACTOR’S and COMPANY’S equipment, materials and supplies between supply vessels and Drilling Unit.
|
|
1.14
|
CONTRACTOR’S Shore Base.
|
|
1.15
|
Medical doctor on notice in the Operating Area for emergency treatment of CONTRACTOR’S personnel injured aboard the Drilling Unit.
|
|
1.16
|
Meals, bunk and accommodations, including medical services, on board Drilling Unit for all CONTRACTOR’S personnel and an average of ten (10) COMPANY and COMPANY third party personnel per day.
|
|
1.17
|
Personnel for Drilling Unit and shore base as set out in Exhibit “F”.
|
|
1.18
|
Disposal of all liquids and other waste generated by CONTRACTOR including drum disposal.
|
1.19
|
Complement of personal protective equipment required to handle completion brines and synthetic base mud for those crew members with potential exposure.
|
|
1.20
|
Blowout preventers, choke and kill lines, ring gaskets, controls, handling, testing tools and spare parts as required set out in Exhibit “B-2”.
|
|
1.21
|
Wellhead connector and spare parts as required in Exhibit “B-2” to adapt CONTRACTOR’S BOP stack to COMPANY’S wellhead.
|
|
1.22
|
All other well control equipment components and replacement parts, including failsafe valves, riser, choke and kill lines and choke manifold. All replacement parts shall be Original Manufacturer’s Equipment.
|
|
1.23
|
Initial set of ram packer elements, annular elements, top seals, related equipment as required in Exhibit “B-2” CONTRACTOR’S BOP EQUIPMENT. All elements, packers, seals and related rubber goods shall be Original Manufacturer’s Equipment and oil mud compatible.
|
|
1.24
|
Manifolding and piping as required to flare burners for oil, gas, water and air.
|
|
1.25
|
CONTRACTOR shall conduct a drillpipe inspection on all drillpipe, drill collars, subs, rotary and handling tools prior to spudding the first well under this CONTRACT. A specified inspection including all optional inspections as specified by API-RP7G, such as; Transverse Defect inspection using induction coils and a magnetic particle inspection of tube ends, couplings, and verification of defects found by gamma ray wall thickness inspection. Drillpipe must satisfy criteria as new or premium drillpipe to be used on COMPANY’S wells.
|
|
1.26
|
CONTRACTOR shall conduct an inspection on all drillpipe after every 100,000’ drilled or 1500 rotating hours (whichever is less). Inspection type will satisfy criteria spelled out in API-IADC specified inspection for used drillpipe. Inspection will include all operational inspections in same API criteria along with magnetic particle for tube ends and couplings. Drillpipe must satisfy criteria as new or premium drillpipe to be used on COMPANY’S wells.
|
|
1.27
|
CONTRACTOR shall conduct an inspection on topdrive valves and subs, all drill collars, subs and related bottom hole assembly components every 250 rotating hours. All bottom hole assembly components shall meet a bending strength ratio of 2.25 to 3.00.
|
|
1.28
|
Living Quarters to accommodate 130 personnel minimum. Must have separate facilities for up to 10 women.
|
|
1.29
|
Three COMPANY designated offices. One for COMPANY’S drilling supervisors, one for COMPANY’S third partys and one for COMPANY’S geologists. All offices complete with intercom system, television, VCR’s, surge suppression for up to 4 computers, 2 desks and file cabinets.
|
|
1.30
|
All equipment shall comply with MMS regulations.
|
|
1.31
|
Spare parts inventory for surface and subsurface BOP equipment as per CONTRACTOR BOP EQUIPMENT LIST, Exhibit B-2. Spare parts inventory list to be provided to and agreed by COMPANY.
|
|
1.32
|
Supply labor required to test, service, and maintain, all surface, and subsurface BOP and well control equipment and tools including COMPANY’S wellhead running tools.
|
|
1.33
|
Mud pump liners and pistons for two (2) sizes as specified by COMPANY.
|
|
1.34
|
Fishing tools to include overshots, grapples, and crossover subs required to catch all contractor supplied drill string and bottom hole assembly components
|
listed in Exhibit “B-2”.
|
||
1.35
|
Diver services and equipment as required by CONTRACTOR.
|
|
1.36
|
Mud bucket for each size of CONTRACTOR supplied drill pipe.
|
|
1.37
|
Outside pipe wipers for each size of CONTRACTOR supplied drill pipe.
|
|
1.38
|
Pressure washer for rig floor and maintaining same.
|
|
1.39
|
Mud vacuum system for rig floor clean up and maintenance.
|
|
1.40
|
Space and utilities for the following COMPANY’S third party equipment: electric wireline logging unit, MWD/LWD logging unit, mud logging unit and two (2) centrifuges.
|
|
1.41
|
Space or accommodation for COMPANY’S warehouse.
|
|
Category II
Furnished by COMPANY, paid by COMPANY
|
||
2.1
|
Thread compound for COMPANY’S connectors and casing.
|
|
2.2
|
Potable and fresh water for drilling, cementing and wash down of CONTRACTOR’S equipment and for personnel use but with respect to the latter only in excess of the capacity of the distillation unit.
|
|
2.3
|
Diesel fuel.
|
|
2.4
|
Drill sites, location surveys, marker buoys.
|
|
2.5
|
All permits and licenses required for the drilling site and to permit access thereto and egress therefrom.
|
|
2.6
|
Weather forecast service.
|
|
2.7
|
Stabilizers, including sleeves and spare parts and maintenance.
|
|
2.8
|
Core heads, core catchers and coring service charges.
|
|
2.9
|
Drilling bits, bit breakers (not supplied per Exhibit B-2), underreamers, hole openers, shock subs, wall scrapers, and other down hole tools, plus maintenance and repairs.
|
|
2.10
|
Water based mud, chemicals and additives.
|
|
2.11
|
Synthetic oil base mud, oil emulsion and other special drilling and completion fluids for completing wells.
|
|
2.12
|
Mud engineering services, and other mud supervision.
|
|
2.13
|
Mud centrifuge.
|
|
2.14
|
Pumping and blowing of bulk materials from work boats to Drilling Unit and between workboats and dock storage facilities.
|
|
2.15
|
All completion and production equipment, including hangers, packers, liners, floats, centralizers, scratchers, casing shoes, float collars, wellheads, spacer spools, Christmas trees including ring gaskets, valves, well connections and all necessary tools and equipment for installation.
|
|
2.16
|
Wellhead running retrieving, handling and testing tools.
|
|
2.17
|
Cementing unit and cement mixing pumps.
|
|
2.18
|
Cement and cement services, including special rental charge.
|
|
2.19
|
Electric logging unit, services and related tools.
|
|
2.20
|
Gun perforating and related services.
|
|
2.21
|
Mud logging unit and related services.
|
2.22
|
Whipstocks, directional drilling tools and services.
|
|
2.23
|
All surface and down hole survey equipment and services, except for drift indicators and slick line unit as described in Exhibit “B-2”.
|
|
2.24
|
Drill stem, formation testing tools and services.
|
|
2.25
|
Test tanks and accessories for production testing.
|
|
2.26
|
Well test burner equipment, burners, separators, flow meters, any other well testing equipment, including installation costs and well testing services.
|
|
2.27
|
All permanent or special installations and services, including services for controlling blowouts and fires.
|
|
2.28
|
Diver, ROV services and equipment as required by COMPANY.
|
|
2.29
|
Additional welding services required by COMPANY.
|
|
2.30
|
Spare parts and operating supplies for COMPANY’S tools and equipment.
|
|
2.31
|
All transportation required for CONTRACTOR’S and COMPANY’S equipment, supplies, drilling and potable water and personnel between shore and Drilling Unit.
|
|
2.32
|
Transportation from base of operations to Drilling Unit by sea, air and/or helicopter.
|
|
2.33
|
Anchor handling vessels and crews to deploy and recover mooring system at COMPANY’S drilling location.
|
|
2.34
|
Dock and dockside facilities, including cranes and trucks, labor equipment for loading and unloading CONTRACTOR’S and COMPANY’S equipment, materials and supplies at COMPANY’S shore base, port charges, pilot fees, canal fees, wharfage, agent fees and related costs for movement of equipment and material at COMPANY’S shore base and dock facilities.
|
|
2.35
|
Any radio equipment required by COMPANY in excess of those described in Exhibit “B-2”, and maintenance of such radio equipment.
|
|
2.36
|
All radio permits and licenses for COMPANY’S radios.
|
|
2.37
|
Disposal of all liquid and other waste generated by COMPANY including drum disposal.
|
|
2.38
|
Disposal of cuttings, mud materials from the well, if required.
|
|
2.39
|
Wellhead, wellhead gasket, wear bushing and bore protectors. All other gaskets and bore protectors for CONTRACTOR’S account.
|
|
2.40
|
Casing and or tubing tools and crews not listed in Exhibit “B-2”.
|
|
2.41
|
All casing, tubing and accessories.
|
|
2.42
|
Casing cutting tools.
|
|
2.43
|
Drill pipe, drill collars and accessories other than that furnished by CONTRACTOR listed in Exhibit “B-2”.
|
3.1
|
Special safety equipment required other than as described in Exhibit “D”.
|
|
3.2
|
Replacement screens on shale shakers for screen sizes finer than 84 mesh.
|
|
3.3
|
Replacement screens on mud cleaners for screen sizes finer than 150 mesh.
|
|
3.4
|
Welding consumables for welding COMPANY furnished equipment.
|
|
3.5
|
Additional off tour labor authorized by COMPANY for mixing cement, moving mud materials, COMPANY’S tubulars, etc.
|
|
3.6
|
Overtime beyond normal work schedule and extra CONTRACTOR personnel requested by COMPANY.
|
|
3.7
|
Replacement of CONTRACTOR supplied supply vessel mooring system ropes.
|
|
3.8
|
Replacement set of ram packer elements, top seals and annular elements. All elements, packers, seals and related rubber goods shall be Original Equipment Manufacturer equipment and oil mud compatible.
|
|
3.9
|
Replacement of CONTRACTOR supplied hoses for receiving and discharge of liquid and bulk consumables from workboats.
|
|
3.10
|
Meals and accommodations on board the Drilling Unit for COMPANY and COMPANY’S third party personnel in excess of an average of ten (10) per day calculated over a period of one (1) calendar month will be billed at CONTRACTOR’S actual cost.
|
Name:
|
Ron Tafery
|
|
Title:
|
Vice President
|
|
Signature:
|
/s/ Ron Tafery
|
|
Date:
|
December 9, 1998
|
(1)
|
The repayment will be reduced by the eighty percent (80%) of the fixed cost not already paid by COMPANY.
|
|
(2)
|
The repayment will be reduced by an amount equal to five percent (5%) as an incentive for CONTRATOR to actively market the Drilling Unit.
|
|
(3)
|
Repayments by CONTRACTOR to COMPANY shall never exceed Contract Rate.
|
Drill Crew
|
Total
|
On Board
|
Remarks
|
|||
Drilling Rig Supt
|
2
|
1
|
||||
Toolpusher
|
4
|
2
|
||||
Driller
|
4
|
2
|
||||
Asst. Driller
|
8
|
4
|
||||
Pumpman
|
4
|
2
|
||||
Floorman
|
12
|
6
|
||||
Maintenance Supervisor (Electrical)
|
2
|
1
|
||||
Electrician
|
4
|
2
|
||||
Assistant Electrician
|
2
|
1
|
||||
Electronic Technician
|
4
|
2
|
||||
Mechanic
|
4
|
2
|
||||
Assistant Mechanic
|
2
|
1
|
||||
Welder
|
2
|
1
|
||||
Sub Sea Engineer
|
2
|
1
|
||||
Assistant Sub Sea
|
2
|
1
|
||||
Crane Operator
|
4
|
2
|
||||
Roustabout
|
16
|
8
|
||||
RTSC
|
2
|
1
|
||||
Medic
|
2
|
1
|
||||
Materialsman
|
4
|
2
|
||||
Captain/OIM
|
2
|
1
|
||||
Chief Officer
|
2
|
1
|
||||
D.P. Operator
|
4
|
2
|
||||
Assist. D.P. Operator
|
4
|
2
|
||||
A.B. Seaman/Painters
|
6
|
3
|
||||
Chief Engineer
|
2
|
1
|
||||
First Engineer
|
2
|
1
|
||||
2nd Engineer
|
4
|
2
|
||||
Oiler/Motorman
|
4
|
2
|
||||
Boatswain
|
2
|
1
|
||||
Galley
|
As Needed
|
|||||
Total:
|
118
|
59
|
a)
|
Galley crew ratio of one to every 10 persons on board.
|
|
b)
|
A mutually agreed pre-commencement manning schedule shall be attached.
|
|
c)
|
Contractor may, with Company approval, reduce the marine crew manning based upon Coast Guard requirements, when available.
|
Title
|
Total
|
On
Drilling
Rig
|
Regular
Hourly
Rate ($)
|
Overtime
Rate with
Burden
|
Daily Rate
Per Man (w/
Burden)
|
||||||
Drilling Rig Supt
|
2
|
1
|
34.83
|
75.76
|
831.81
|
||||||
Toolpusher
|
4
|
2
|
30.48
|
66.29
|
736.47
|
||||||
Driller
|
4
|
2
|
25.69
|
55.88
|
637.43
|
||||||
Asst. Driller
|
8
|
4
|
17.85
|
38.83
|
465.29
|
||||||
Pumpman
|
4
|
2
|
13.50
|
29.36
|
369.78
|
||||||
Floorman
|
12
|
6
|
13.00
|
28.28
|
358.80
|
||||||
Maintenance Supervisor (Electrical)
|
2
|
1
|
26.12
|
56.81
|
641.12
|
||||||
Electrician
|
4
|
2
|
21.77
|
47.36
|
551.36
|
||||||
Assistant Electrician
|
2
|
1
|
16.50
|
35.89
|
435.65
|
||||||
Electronic Technician
|
4
|
2
|
22.86
|
49.72
|
575.30
|
||||||
Mechanic
|
4
|
2
|
21.77
|
47.36
|
551.36
|
||||||
Assistant Mechanic
|
2
|
1
|
16.50
|
35.89
|
435.65
|
||||||
Welder
|
2
|
1
|
15.75
|
34.26
|
419.18
|
||||||
Sub Sea Engineer
|
2
|
1
|
25.44
|
55.33
|
631.95
|
||||||
Assistant Sub Sea
|
2
|
1
|
21.77
|
47.36
|
551.36
|
||||||
Crane Operator
|
4
|
2
|
16.55
|
36.00
|
436.75
|
||||||
Roustabout
|
16
|
8
|
11.00
|
23.93
|
314.88
|
||||||
RTSC
|
2
|
1
|
17.85
|
38.83
|
465.29
|
||||||
Medic
|
2
|
1
|
15.67
|
34.09
|
417.42
|
||||||
Materialsman
|
4
|
2
|
15.02
|
32.67
|
398.00
|
||||||
Captain/OIM
|
2
|
1
|
35.70
|
77.65
|
850.88
|
||||||
Chief Officer
|
2
|
1
|
26.12
|
56.81
|
641.12
|
||||||
D.P. Operator
|
4
|
2
|
29.17
|
63.45
|
707.86
|
||||||
Assist. D.P. Operator
|
4
|
2
|
22.64
|
49.24
|
570.47
|
||||||
A.B. Seaman/Painters
|
6
|
3
|
11.00
|
23.93
|
314.88
|
||||||
Chief Engineer
|
2
|
1
|
28.30
|
61.55
|
688.79
|
||||||
First Engineer
|
2
|
1
|
22.64
|
49.24
|
570.47
|
||||||
2nd Engineer
|
4
|
2
|
19.59
|
42.62
|
503.50
|
||||||
Oiler/Motorman
|
4
|
2
|
14.00
|
30.45
|
380.76
|
||||||
Boatswain
|
2
|
1
|
17.42
|
37.89
|
455.85
|
||||||
Galley
|
As Needed
|
||||||||||
Total:
|
118
|
59
|
·
|
Vessel / equipment acceptance / seatrials procedures:
|
one (1) month prior to delivery
|
·
|
DP/power systems FMEA and fault tree analysis:
|
two (2) month after final design
|
·
|
BOP mux control system FMEA and fault tree analysis:
|
two (2) month after final design
|
·
|
Project Goals/Operating Principles
|
·
|
Project Organization
|
· |
Roles/Responsibilities/Accountabilities
|
·
|
Project Description/Schedule/Milestones
|
·
|
Overall Assurance Plan
|
·
|
Safety
|
·
|
Interface Coordination Plan (Communication)
|
·
|
Quality Plan
|
·
|
Document Control
|
·
|
Approval Process
|
·
|
Change Control Procedures
|
·
|
Management of Change
|
·
|
Meeting/Presentation Schedule
|
·
|
Risk Management Register
|
·
|
Cost Control
|
a. Labor (all inclusive)
|
U.S.$21,420 \ Day
|
b. Catering
|
U.S.$2,364 \ Day
|
c. Spare Parts & Supplies
|
PPI Code No. 1191.02 Base = 133.8 (Preliminary - December, 1998) -
|
d. Insurance
|
U.S.$2,660 \ Day
|
Title
|
Hrly Rate Shown
|
Correct Hrly Rate
|
|||||||
Drilling Rig Supt
|
$
|
34.83
|
Should be
|
$
|
35.70
|
||||
Captain/OIM
|
$
|
35.70
|
Should be
|
$
|
34.83
|
||||
Chief Officer
|
$
|
26.12
|
Should be
|
$
|
27.43
|
||||
D. P. Operator
|
$
|
29.17
|
Should be
|
$
|
23.08
|
||||
Assist D. P. Operator
|
$
|
22.64
|
Should be
|
$
|
20.90
|
Sincerely yours,
|
|
R&B Falcon Drilling Co.
|
|
/s/ W.L. Ellis
|
|
W.L. Ellis
|
|
Regional Operations Manager
|
Exchange Rate: US $1.00 =1 U.S. $
|
[03PAY]
|
Total Per Employee
|
|||||||||||||||||||
Budgeted
|
Budgeted
|
Annual
|
Regular
|
Regular
|
Regular
|
Regular
|
Payroll/
|
Payroll
|
|||||||||||
On Board
|
Total
|
Work
|
Monthly
|
Monthly
|
Monthly
|
Annual
|
Calenday
|
Per
|
|||||||||||
Rig-based
|
Expats
|
Expats
|
Days
|
Base
|
Travel Pay
|
Total
|
Total
|
Day
|
Work Day
|
||||||||||
Asst. Superintendent*
|
1.00
|
2.00
|
182.50
|
8,000
|
8,000
|
96,000
|
263
|
526
|
|||||||||||
Toolpusher
|
2.00
|
4.00
|
182.50
|
7,000
|
7,000
|
84,000
|
230
|
460
|
|||||||||||
Tourpusher
|
0
|
0
|
|||||||||||||||||
Barge Engineer*
|
6,000
|
6,000
|
72.000
|
||||||||||||||||
Asst. Barge Engineer*
|
4,800
|
4,800
|
57,600
|
||||||||||||||||
Maintenance Supervisor*
|
1.00
|
2.00
|
182.50
|
6,000
|
6,000
|
72,000
|
197
|
395
|
|||||||||||
Driller
|
2.00
|
4.00
|
182.50
|
5,900
|
5,900
|
70,800
|
194
|
388
|
|||||||||||
Alternate Driller
|
4.00
|
8.00
|
182.50
|
5,000
|
5,000
|
60,000
|
164
|
329
|
|||||||||||
Alternate Driller Trainee
|
0
|
0
|
|||||||||||||||||
Derrickman
|
3,330
|
3,330
|
39,960
|
||||||||||||||||
Pumpman
|
2.00
|
4.00
|
182.50
|
3,101
|
250
|
3,351
|
40,212
|
110
|
220
|
||||||||||
Motorman
|
3,215
|
3,215
|
38,580
|
||||||||||||||||
Welder
|
1.00
|
2.00
|
182.50
|
3,617
|
3,617
|
43,404
|
119
|
238
|
|||||||||||
Crane Operator
|
2.00
|
4.00
|
182.50
|
3,800
|
3,800
|
45,600
|
125
|
250
|
|||||||||||
Heavy Lift Crane Operator**
|
0
|
0
|
|||||||||||||||||
Barge Captain
|
0
|
0
|
|||||||||||||||||
Asst. Barge Captain
|
0
|
0
|
|||||||||||||||||
Control Room Operator*
|
4,500
|
4,500
|
54,000
|
||||||||||||||||
Asst. Control Room Operator*
|
3,600
|
3,600
|
43,200
|
||||||||||||||||
Mechanic
|
2.00
|
4.00
|
182.50
|
5,000
|
5,000
|
60,000
|
164
|
329
|
|||||||||||
Asst. Mechanic
|
1.00
|
2.00
|
182.50
|
3,790
|
3,790
|
45,480
|
125
|
249
|
|||||||||||
Mechanic Helper
|
0
|
0
|
|||||||||||||||||
Electronic Technician*
|
2.00
|
4.00
|
182.50
|
5,250
|
5,250
|
63,000
|
173
|
345
|
|||||||||||
Electrician
|
2.00
|
4.00
|
182.50
|
5,000
|
5,000
|
60,000
|
164
|
329
|
|||||||||||
Asst. Electrician
|
1.00
|
2.00
|
182.50
|
3,790
|
3,790
|
45,480
|
125
|
249
|
|||||||||||
Electrician Helper
|
0
|
0
|
|||||||||||||||||
Subsea Engineer*
|
1.00
|
2.00
|
182.50
|
7,000
|
7,000
|
84,000
|
230
|
460
|
|||||||||||
Asst. Subsea Engineer*
|
1.00
|
2.00
|
182.50
|
5,000
|
5,000
|
60,000
|
164
|
329
|
|||||||||||
Materialsman
|
0
|
0
|
|||||||||||||||||
Storekeeper
|
2.00
|
4.00
|
182.50
|
3,450
|
3,450
|
41,400
|
113
|
227
|
|||||||||||
Medic
|
1.00
|
2.00
|
182.50
|
3,450
|
3,450
|
41,400
|
113
|
227
|
|||||||||||
Radio Operator
|
3,101
|
3,101
|
37,212
|
||||||||||||||||
Floorman
|
6.00
|
12.00
|
182.50
|
2,986
|
250
|
3,236
|
38,832
|
106
|
213
|
||||||||||
Lead Roustabout
|
0
|
0
|
|||||||||||||||||
Roustabout
|
8.00
|
16.00
|
182.50
|
2,526
|
250
|
2,776
|
33,312
|
91
|
183
|
||||||||||
Paint Foreman
|
0
|
0
|
|||||||||||||||||
Painter
|
2,124
|
2,124
|
25,488
|
||||||||||||||||
Captain/Master***
|
1.00
|
2.00
|
182.50
|
8,000
|
8,000
|
96,000
|
263
|
526
|
|||||||||||
Chief Officer***
|
1.00
|
2.00
|
182.50
|
6,300
|
6,300
|
75,600
|
207
|
414
|
|||||||||||
First Officer***
|
5,300
|
5,300
|
63,600
|
||||||||||||||||
Second Officer***
|
4,800
|
4,800
|
57,600
|
||||||||||||||||
Third Officer***
|
4,200
|
4,200
|
50,400
|
||||||||||||||||
Chief Engineer***
|
1.00
|
2.00
|
182.50
|
6,500
|
6,500
|
78,000
|
214
|
427
|
|||||||||||
First Engineer***
|
1.00
|
2.00
|
182.50
|
6,000
|
6,000
|
72,000
|
197
|
395
|
|||||||||||
Second Engineer***
|
2.00
|
4.00
|
182.50
|
5,200
|
5,200
|
62,400
|
171
|
342
|
|||||||||||
Bosun***
|
1.00
|
2.00
|
182.50
|
4,000
|
4,000
|
48,000
|
132
|
263
|
|||||||||||
Deck Supervisor***
|
4,000
|
4,000
|
48,000
|
||||||||||||||||
D.P. Operator***
|
2.00
|
4.00
|
182.50
|
5,300
|
5,300
|
63,000
|
174
|
348
|
|||||||||||
Asst. D.P. Operator***
|
2.00
|
4.00
|
182.50
|
4,800
|
4,800
|
57,600
|
158
|
316
|
|||||||||||
Oiler***
|
2.00
|
4.00
|
182.50
|
3,215
|
250
|
3,465
|
41,580
|
114
|
228
|
||||||||||
Able Seaman***
|
3.00
|
6.00
|
182.50
|
2,526
|
250
|
2,776
|
33,312
|
91
|
183
|
||||||||||
Rig Safety & Training Coordinator
|
1.00
|
2.00
|
182.50
|
4,100
|
4,100
|
49,200
|
135
|
270
|
|||||||||||
Other
|
0
|
0
|
|||||||||||||||||
Total
|
59.00
|
118.00
|
Overtime Wages Total
|
0
|
|||||||||||||||
OIM Premium ($4,800 if applicable)
|
4.800
|
||||||||||||||||||
Total Annual Expatriate Payroll
|
6,257,544
|
||||||||||||||||||
Total Per Day Expatriate Payroll
|
17,144
|
(Posts to Rig Payroll)
|
* Semisubmersibles Only
|
|||||||||||||||||||
** Super Tenders Only
|
Total Payroll Burden Per Day
|
20
|
%
|
3,429
|
(Posts to Payroll Burden)
|
Exchange Rate: US $1.00 =1 U.S. $
|
[09XPTTRN]
|
Employee Name
|
Employee
Position
|
Name of
School
|
School Location
|
# of
Days
|
Training
Wages
Per Day
|
Outside
Tuition
|
International
Airfare
|
Domestic/
Charter
|
Hotel
Per Day
|
Meals
Per Day
|
Other
|
||||||||||||
T.B.A.
|
Various
|
Well Control
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Cyberchair
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Varco
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
PM
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
GE
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Burgess
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Brandt
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Fire Fighting
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Sea Survival
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Wartslia
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Kamewa
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Simrad
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
High Voltage
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Alborg
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Bridge Mgn
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Radar
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
GMDSS
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
HLO
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
Crane Ops
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
AWC
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
STOP / H2S
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
EPT
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
T.B.A.
|
Various
|
DGPS
|
10
|
75
|
2,500
|
300
|
100
|
35
|
20
|
||||||||||||||
230
|
1,725
|
57,500
|
6,900
|
0
|
2,300
|
805
|
460
|
||||||||||||||||
Total Training Wages
|
17,250
|
||||||||||||||||||||||
Total Outside Tuition
|
57,500
|
||||||||||||||||||||||
Total Training Travel
|
38,410
|
||||||||||||||||||||||
Total Training Costs
|
113,160
|
||||||||||||||||||||||
Per Day Training Costs
|
310
|
(Posts to Training Costs)
|
Exchange Rate: US $1.00 =1 U.S. $
|
[15EXTRAV]
|
Annual
|
Cost Per Trip
|
Total
|
Round
|
||||||||||||||||||
Airport of Origin
|
Total
Personnel
|
Roundtrips
Per Emp.
|
International
Airfare
|
Domestic/
Charter
|
Hotel
|
Meals
|
Other
|
Annual
costs
|
Commuter
Schedule
|
Trips
Per Year
|
|||||||||||
East Coast
|
12
|
8.69
|
300
|
75
|
35
|
20
|
44,840
|
7x7
|
26.07
|
||||||||||||
West Coast
|
12
|
8.69
|
300
|
75
|
35
|
20
|
44,840
|
14x14
|
13.04
|
||||||||||||
North Central
|
12
|
8.69
|
200
|
75
|
35
|
20
|
34,412
|
21x21
|
8.69
|
||||||||||||
Texas
|
12
|
8.69
|
100
|
75
|
35
|
20
|
23,984
|
28x28
|
6.52
|
||||||||||||
Louisana
|
12
|
8.69
|
100
|
75
|
35
|
20
|
23,984
|
35x35
|
5.21
|
||||||||||||
Mississippi
|
12
|
8.69
|
100
|
75
|
35
|
20
|
23,984
|
42x42
|
4.35
|
||||||||||||
Other
|
4
|
0
|
56x56
|
3.26
|
|||||||||||||||||
0
|
14x7
|
17.38
|
|||||||||||||||||||
0
|
21x14
|
10.43
|
|||||||||||||||||||
0
|
28x14
|
8.69
|
|||||||||||||||||||
0
|
56x28
|
4.35
|
|||||||||||||||||||
0
|
112x56
|
2.17
|
|||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
0
|
|||||||||||||||||||||
Expatriate Commuters
|
76
|
Total Annual Expatriate Commuter Travel
|
196.046
|
||||||||||||||||||
Expat Cost / Man / Calendar Day
|
7.07
|
||||||||||||||||||||
Total Annual Expatriate Operationl Travel
|
196,046
|
||||||||||||||||||||
Total Per Day Expatriate Operational Travel
|
537
|
(Posts to Operational Travel)
|
Exchange Rate: US $1.00 =1 U.S. $
|
[12CAT]
|
Category
|
Personnel
On
Board
|
Manday
Rate
|
Total/Day
Per
Category
|
Annual
Catering
Costs
|
|||||
Expatriate
|
59.00
|
34.26
|
2,021
|
737,789
|
|||||
TCN
|
0.00
|
34.26
|
0
|
0
|
|||||
National
|
0.00
|
34.26
|
0
|
0
|
|||||
Total Regular Crews
|
59.00
|
2,021
|
737,789
|
||||||
AVG OPERATOR ON BOARD
|
30.00
|
34.26
|
1,028
|
375,147
|
|||||
OPERATOR RECHARGE
|
(20.00
|
)
|
(34.26
|
)
|
(685
|
)
|
(250,098
|
)
|
|
NET OPERATOR CATERING
|
10.00
|
Office Staff
|
0.00
|
34.26
|
0
|
0
|
|||||||
Crew Change
|
0.00
|
34.26
|
0
|
0
|
|||||||
Other Mandays
|
0.00
|
34.26
|
0
|
0
|
|||||||
Total Other Mandays
|
0.00
|
0
|
0
|
||||||||
Other Annual Amounts
|
0
|
||||||||||
Other Annual Amounts
|
0
|
||||||||||
Total Annual Catering Cost
|
862,838
|
||||||||||
Daily Personnel On Board
|
89.00
|
Total Per Day Catering Cost
|
2,364
|
(Posts to Catering)
|
Year
|
Jan
|
Feb
|
Mar
|
Apr
|
May
|
Jun
|
Jul
|
Aug
|
Sep
|
Oct
|
Nov
|
Dec
|
Ann
|
||||||||||||||
1989
|
96.9
|
97.1
|
97.2
|
97.1
|
97.6
|
97.6
|
97.6
|
98.4
|
98.6
|
99.3
|
99.5
|
99.5
|
98.0
|
||||||||||||||
1990
|
99.6
|
99.6
|
99.2
|
99.2
|
99.3
|
99.9
|
100.2
|
101.5
|
105.8
|
106.2
|
106.6
|
106.6
|
102.0
|
||||||||||||||
1991
|
106.7
|
107.7
|
108.7
|
108.8
|
110.0
|
110.0
|
110.0
|
110.0
|
110.0
|
110.0
|
110.1
|
110.1
|
109.3
|
||||||||||||||
1992
|
110.1
|
110.1
|
110.1
|
110.1
|
110.2
|
110.4
|
110.6
|
110.6
|
110.6
|
110.8
|
112.4
|
112.5
|
110.7
|
||||||||||||||
1993
|
112.8
|
112.9
|
113.3
|
112.1
|
112.0
|
112.2
|
112.3
|
112.3
|
113.4
|
113.4
|
113.4
|
114.6
|
112.9
|
||||||||||||||
1994
|
114.6
|
114.6
|
114.6
|
114.6
|
114.7
|
114.9
|
115.4
|
115.4
|
115.9
|
117.8
|
117.8
|
117.8
|
115.7
|
||||||||||||||
1995
|
118.3
|
118.6
|
119.2
|
119.2
|
119.3
|
119.6
|
120.4
|
120.4
|
120.4
|
122.0
|
122.2
|
122.2
|
120.1
|
||||||||||||||
1996
|
124.0
|
124.0
|
124.0
|
124.3
|
124.2
|
124.8
|
125.3
|
125.3
|
125.3
|
126.2
|
126.6
|
127.1
|
125.1
|
||||||||||||||
1997
|
127.7
|
127.9
|
128.6
|
129.1
|
129.2
|
129.3
|
129.3
|
129.5
|
129.7
|
130.3
|
131.4
|
132.0
|
129.5
|
||||||||||||||
1998
|
133.1
|
132.9
|
133.1
|
133.0
|
133.0
|
133.0
|
132.9
|
132.9
|
132.9
|
133.6
|
133.6
|
133.8
|
(P)
|
133.2
|
(P)
|
||||||||||||
1999
|
134.0
|
(P)
|
133.9
|
(P)
|
133.9
|
(P)
|
Data Home Page
|
BLS Home Page
|
|
Memo
|
To:
|
John Luedtke
|
Date:
|
August 3, 1998
|
From:
|
Robert B. Carvell
|
||
Subject:
|
Estimated Annual Premium
|
||
RBS-8 M
|
|||
Effective 15 March 1998
|
CONFIDENTIAL
|
|||
I.
|
Coverage:
|
All Risk Hull & Machinery
|
|
Insured Value:
|
$325,000,000
|
||
Deductible:
|
$250,000 Per Occurrence
|
||
NET ANNUAL PREMIUM:
|
$528,996.80
|
||
II.
|
Coverage:
|
Loss of Hire
|
|
Daily Indemnity:
|
$189,000
|
||
Policy Limits:
|
180 Days
|
||
Deductible Period
|
21 Days
|
||
NET ANNUAL PREMIUM
|
$232,867
|
||
III.
|
Coverage:
|
Primary Marine Protection & Indemnity
|
|
Policy Limits:
|
$1,000,000 Per Occurrence
|
||
Deductible:
|
$100,000 Per Occurrence
|
||
NET ANNUAL PREMIUM (U.S. WATERS)
|
$182,000.00
|
||
NET ANNUAL PREMIUM (FOREIGN WATERS)
|
$ 78,000.00
|
||
IV.
|
Coverage:
|
Excess Liability
|
|
Policy Limits:
|
$400,000,000
|
||
Deductible:
|
XS of Primary Marine P&I
|
||
NET ANNUAL PREMIUM
|
$6,795.00
|
V.
|
Coverage:
|
Contingent Energy Exploration & Development
|
|||
Policy Limits:
|
$100,000,000
|
||||
Deductible
|
$250,000 Per Occurrence
|
||||
NET ANNUAL PREMIUM
|
$704.76
|
||||
VI.
|
U.S. Brokers:
|
Aon Risk Services, Inc.
|
|||
ANNUAL FEE
|
$19,379.85
|
||||
TOTAL ANNUAL PREMIUM:
|
(U.S. Waters)
|
$970,743.41
|
|||
(Foreign Waters)
|
$866,743.41
|
Mike Roth
MARKETING MANAGER NAR
|
R & B FALCON DRILLNG CO.
311 BROADFIELD BLVD., SUITE 400
HOUSTON, TEXAS 77084
|
Attn:
|
Mr. Don Weisinger
|
Re:
|
Vastar Resources Inc. (“Vastar”) & R & B Falcon Drilling Company (“R &B”)
Drilling Contract — RBS-8D — Deepwater Horizon (“Rig”) (hereinafter referred to as the “Contract”)
Deepwater Horizon Contract Amendment — Additional Personnel
|
Title
|
Total
|
On
Rig
|
Overtime Rate
(per person per
hour) with Burden
|
Daily Rate
(per person)
with Burden
|
Total Day Rate
with Burden
|
|||||||||
Asst. Pumpman
|
4
|
2
|
$
|
27.18
|
$
|
368.30
|
$
|
736.60
|
||||||
Solid Control Tech
|
4
|
2
|
$
|
27.18
|
$
|
368.30
|
$
|
736.60
|
||||||
Deck Foreman
|
2
|
1
|
$
|
38.14
|
$
|
478.93
|
$
|
478.93
|
||||||
Roustabout
|
4
|
2
|
$
|
23.08
|
$
|
332.89
|
$
|
665.78
|
||||||
TOTAL ADDITIONAL PERSONNEL
|
14
|
7
|
$
|
2,617.91
|
PHONE: 281-647-8518
|
FAX: 281-647-8754
|
EMAIL:mroth@deepwater.com
|
VASTAR RESOURCES, INC.
|
|
Deepwater Horizon Contract Amendment – Additional Personnel
|
June 26, 2001
|
TSF File #01-063
|
/s/ Mike Roth
|
|
Mike Roth
|
SIGNED
|
/s/ Don Weisinger
|
|
PRINTED
|
Don Weisinger
|
|
TITLE
|
Drilling Team Leader
|
TERRY BONNO
|
R & B FALCON DRILLING COMPANY
|
|
SR. MARKETING REPRESENTATIVE
|
311 BROADFIELD BLVD., SUITE 400
|
|
HOUSTON, TEXAS 77084
|
Reference:
|
Drilling Contract No. 980249 between Vastar Resources Inc. , predecessor in interest to BP America Production Company (“BP”) and R&B Falcon Drilling Company (“R&B”) dated December 9, 1998 for RBS-8D (now known as the Deepwater Horizon), as amended (the “Contract”)
|
Subject:
|
Letter of Agreement for Cost Escalation and Naming Convention Adjustments
|
|
|
2.3.2a
|
The Base Labor cost adjustment will be an increase of $6,876 from the baseline of $21,420 with a new total of $28,296. Labor will also increase by $239 on the additional personnel to a new total of $2,613.
|
2.3.2b
|
Contractor’s cost of catering has decreased by ($541) to a new total of $2,067 under the baseline of $2,608.
|
|
|
PHONE: 281-675-8848
|
FAX: 281-647-8754
|
EMAIL:tbonno@deepwater.com
|
BP America Production Company
|
||||
Deepwater Horizon Contract - Cost Escalation
|
||||
TSF File #01-063
|
2.3.2c
|
Based on the initial base Spare Parts/Supplies Element of $12,692, there will be an increase of $1,159 to a new baseline of $13,851.
|
2.3.2d
|
The insurance element has decreased by $861 over the baseline figure of $2,660 and the new Total Base Insurance Cost will be $1,799.
|
|
|
Paragraph
|
2.3.2a
|
$
|
6,876
|
||||
Paragraph
|
2.3.2a
|
239
|
(additional personnel)
|
||||
Paragraph
|
2.3.2b
|
(541
|
)
|
||||
Paragraph
|
2.3.2c
|
1,159
|
|||||
Paragraph
|
2.3.2d
|
(861
|
)
|
||||
Total
|
$
|
6,872
|
Sincerely,
|
|
/s/ Terry Bonno
|
|
Terry Bonno
|
|
Sr. Marketing Representative
|
|
On Behalf of R & B Falcon Drilling Co.
|
SIGNED
|
/s/ R. Kevin Guerre
|
|
PRINTED
|
R. Kevin Guerre
|
|
TITLE
|
TL - SCM
|
Drill Crew
|
Total
|
On Board
|
|||
Drilling Rig Supt/OIM
|
2
|
1
|
|||
Toolpusher
|
4
|
2
|
|||
Driller
|
4
|
2
|
|||
Asst. Driller
|
8
|
4
|
|||
Pumphand
|
4
|
2
|
|||
Floorhand Roughneek
|
12
|
6
|
|||
Maintenance Electrical Supervisor (Electrical)
|
2
|
1
|
|||
Chief Electrician
|
4
|
2
|
|||
Assistant Electrician
|
2
|
1
|
|||
Chief Electronic Technician
|
4
|
2
|
|||
Chief Mechanic
|
4
|
2
|
|||
Assistant Mechanic
|
2
|
1
|
|||
Welder
|
2
|
1
|
|||
Sub Sea Supervisor Engineer
|
2
|
1
|
|||
Assistant Sub Sea
|
2
|
1
|
|||
Crane Operator
|
4
|
2
|
|||
Roustabout
|
16
|
8
|
|||
Rig Safety & Training Coordinator Officer
|
2
|
1
|
|||
Medic
|
2
|
1
|
|||
Materialsman Materials Coordinator
|
4
|
2
|
|||
Captain Master/OIM
|
2
|
1
|
|||
Chief Mate Officer
|
2
|
1
|
|||
D. P. Operator
|
4
|
2
|
|||
Assist. D.P. Operator
|
4
|
2
|
|||
A.B. Seaman/Painters
|
6
|
3
|
|||
Chief Engineer
|
2
|
1
|
|||
First Asst. Engineer
|
2
|
1
|
|||
2ndAsst. Engineer
|
4
|
2
|
|||
Motorhand
|
4
|
2
|
|||
Beatswain Bosun
|
2
|
1
|
|||
Galley
|
As Needed
|
||||
Tota1:
|
118
|
59
|
a)
|
Galley crew ratio of one to every 10 persons on board.
|
b)
|
A mutually agreed pre-commencement manning schedule shall be attached.
|
c)
|
Contractor may, with Company approval, reduce the marine crew manning based upon Coast Guard requirements, when available.
|
Contract No. 980249
|
Per Baseline
|
||||||||||
Costs Plus
|
2001
|
|||||||||
July 24, 2001 Letter
|
Sept. 2001
|
Variance
|
||||||||
Base Labor Cost:
|
||||||||||
Labor & Burden (per schedule)
|
$
|
20,573
|
25,476
|
4,903
|
||||||
Training & Transportation Costs
|
847
|
2,820
|
1,973
|
|||||||
Total Base Labor Cost
|
$
|
21,420
|
$
|
28,296
|
$
|
6,876
|
||||
Percentage Increase
|
32
|
%
|
||||||||
Additional Crew Increase per agreement dated July 24, 2001
|
||||||||||
Labor & Burden (per schedule)
|
2,163
|
2,278
|
115
|
|||||||
Training & Transportation Costs
|
$
|
211
|
335
|
124
|
||||||
Total Additional Personnel Cost
|
$
|
2,374
|
$
|
2,613
|
$
|
239
|
||||
Percentage Increase
|
10
|
%
|
||||||||
Base Catering Cost:
|
||||||||||
59 Combined Personnel @ $ 27.20
|
$
|
2,021
|
$
|
1,605
|
(417
|
)
|
||||
7 Additional Personnel @ $ 27.20
|
$
|
244
|
$
|
190
|
(53
|
)
|
||||
10 Company Personnel @ $ 27.20
|
$
|
343
|
$
|
272
|
(71
|
)
|
||||
Total Base Catering Costs
|
$
|
2,608
|
$
|
2,067
|
$
|
(541
|
)
|
|||
Percentage Increase
|
-21
|
%
|
||||||||
Base Insurance Cost
|
$
|
2,660
|
$
|
1,799
|
$
|
(861
|
)
|
|||
Percentage Increase
|
-32
|
%
|
||||||||
Base Repair and Maintenance Cost
|
$
|
12,692
|
$
|
13,851
|
$
|
1,159
|
||||
Percentage Increase
|
9
|
%
|
||||||||
Total Baseline Operating Costs
|
$
|
41,754
|
$
|
48,626
|
$
|
6,872
|
Horizon Cost Escalations
|
A
|
B
|
C
|
D
|
|||||||||||||
Gulf of Mexico Crew Complement
|
GOM Base Labor w/Burden
|
GOM Overtime Rates
|
||||||||||||||
No. of Personnel
|
Daily Rate
|
Total Daily
|
Daily
|
Hourly
|
||||||||||||
JOB
|
On
|
Assigned
|
(per person)
|
On Board
|
Rate
|
Rate
|
||||||||||
CODE
|
Board
|
To Rig
|
JOB CLASSIFICATION
|
w/ Burden*
|
Cost**
|
w/ Burden**
|
w/ Burden**
|
|||||||||
1
|
2
|
Offshore Installation Manager
|
930.23
|
855.23
|
Salaried
|
|||||||||||
2
|
4
|
Toolpusher
|
761.90
|
1,373.80
|
Salaried
|
|||||||||||
2
|
4
|
Driller
|
650.87
|
1,151.74
|
650.12
|
54.18
|
||||||||||
4
|
8
|
Assistant Driller
|
493.35
|
1,673.41
|
462.88
|
38.57
|
||||||||||
2
|
4
|
Pumphand
|
408.82
|
667.65
|
362.40
|
30.20
|
||||||||||
10
|
20
|
Floorhand
|
395.57
|
3,205.71
|
346.65
|
28.89
|
||||||||||
10
|
20
|
Roustabout
|
353.97
|
2,789.67
|
297.20
|
24.77
|
||||||||||
1
|
2
|
Welder
|
475.62
|
400.62
|
441.80
|
36.82
|
||||||||||
2
|
4
|
Crane Operator
|
493.35
|
836.70
|
462.88
|
38.57
|
||||||||||
2
|
4
|
Chief Mechanic
|
581.84
|
1,013.67
|
568.06
|
47.34
|
||||||||||
1
|
2
|
Mechanic
|
471.20
|
396.20
|
436.55
|
36.38
|
||||||||||
2
|
4
|
Motor Operator
|
395.97
|
641.93
|
347.12
|
28.93
|
||||||||||
1
|
2
|
Electrical Supervisor
|
663.46
|
588.46
|
Salaried
|
|||||||||||
2
|
4
|
Chief Electrician
|
581.84
|
1,013.67
|
568.06
|
47.34
|
||||||||||
1
|
2
|
Electrician
|
471.20
|
396.20
|
436.55
|
36.38
|
||||||||||
2
|
4
|
Chief Electronic Technician
|
590.67
|
1,031.34
|
578.56
|
48.21
|
||||||||||
1
|
2
|
Senior Sub Sea Supervisor
|
768.23
|
693.23
|
Salaried
|
|||||||||||
1
|
2
|
Assistant Sub Sea Supervisor
|
546.43
|
471.43
|
525.97
|
43.83
|
||||||||||
2
|
4
|
Materials Coordinator
|
435.79
|
721.58
|
394.46
|
32.87
|
||||||||||
1
|
2
|
Master
|
810.10
|
735.10
|
Salaried
|
|||||||||||
1
|
2
|
Chief Mate
|
675.99
|
600.99
|
679.98
|
56.66
|
||||||||||
1
|
2
|
Chief Engineer
|
751.42
|
676.42
|
Salaried
|
|||||||||||
1
|
2
|
1st Assist. Engineer
|
634.12
|
559.12
|
630.21
|
52.52
|
||||||||||
2
|
4
|
2nd Assist. Engineer
|
599.57
|
1,049.14
|
589.14
|
49.10
|
||||||||||
2
|
4
|
Dynamic Position Operator
|
546.43
|
942.86
|
525.97
|
43.83
|
||||||||||
2
|
4
|
Assistant Dynamic Position Operator
|
457.95
|
765.89
|
420.79
|
35.07
|
||||||||||
1
|
2
|
Deck Pusher
|
512.80
|
437.80
|
486.00
|
40.50
|
||||||||||
1
|
2
|
Bosun
|
457.95
|
382.95
|
420.79
|
35.07
|
||||||||||
3
|
6
|
Able Bodied Seaman
|
413.70
|
1,016.11
|
368.20
|
30.68
|
||||||||||
1
|
2
|
Rig & Safety Training Technician*
|
466.78
|
391.78
|
431.29
|
35.94
|
||||||||||
1
|
2
|
Rig Medic/Clerk
|
348.23
|
273.23
|
290.38
|
24.20
|
||||||||||
66
|
132
|
Total Base Labor Costs =
|
$
|
27,753.63
|
||||||||||||
*
|
Does include catering, transportation, or training expense.
|
|
**
|
Does NOT include catering transportation, or training expense.
|
|
Notes:
|
1)
|
The figures in column “A” are to be used as the basis for adding personnel to the permanent crew and for determining the credit for crew members short.
|
2)
|
The figures in column “B” are the product of multiplying the number of “on board” personnel by the “Daily Rate w/ Burden” in column “A”. The Sum of column “B” is the “Total Base Labor Cost” per day.
|
|
3)
|
The figures in columns “C” and “D” are the basis for charging the Operator for overtime hours worked at the request of the Operator.
|
Bureau of Labor Statistics Data
|
Bureau of Labor Statistics
U.S. Department of Labor
|
|||
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|
Year
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Jan
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Feb
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Mar
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Apr
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May
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Jun
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Jul
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Aug
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Sep
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Oct
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Nov
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Dec
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Ann
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||||||||||||||
1992
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110.1
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110.1
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110.1
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110.1
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110.2
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110.4
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110.6
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110.6
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110.6
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110.8
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112.4
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112.5
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110.7
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||||||||||||||
1993
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112.8
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112.9
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113.3
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112.1
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112.0
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112.2
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112.3
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112.3
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113.4
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113.4
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113.4
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114.6
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112.9
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||||||||||||||
1994
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114.6
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114.6
|
114.6
|
114.6
|
114.7
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114.9
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115.4
|
115.4
|
115.9
|
117.8
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117.8
|
117.8
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115.7
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||||||||||||||
1995
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118.3
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118.6
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119.2
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119.2
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119.3
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119.6
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120.4
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120.4
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120.4
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122.0
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122.2
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122.2
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120.1
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||||||||||||||
1996
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124.0
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124.0
|
124.0
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124.3
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124.2
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124.8
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125.3
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125.3
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125.3
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126.2
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126.6
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127.1
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125.1
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||||||||||||||
1997
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127.7
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127.9
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128.6
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129.1
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129.2
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129.3
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129.3
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129.5
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129.7
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130.3
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131.4
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132.0
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129.5
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||||||||||||||
1998
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133.1
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132.9
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133.1
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133.0
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133.0
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133.0
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132.9
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132.9
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132.9
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133.6
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133.6
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133.6
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133.1
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||||||||||||||
1999
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133.8
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133.7
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133.7
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133.9
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133.9
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134.0
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134.0
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133.7
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133.7
|
133.7
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134.4
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134.6
|
133.9
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||||||||||||||
2000
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134.9
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136.3
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136.3
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136.3
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136.5
|
136.5
|
136.5
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136.6
|
136.7
|
138.7
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138.7
|
138.7
|
136.9
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||||||||||||||
2001
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143.5
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143.9
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144.0
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144.0
|
144.0
|
145.5
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145.6
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145.8
|
145.7
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146.1
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146.1
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146.1
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145.0
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||||||||||||||
2002
|
146.2
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146.0
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(P)
|
146.7
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(P)
|
146.7
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(P)
|
146.5
|
(P)
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Security Statement · Accessibility Information
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Search: GO
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Advanced Search
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Bureau of Labor Statistics
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Phone: (202) 691-5200
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Square Building
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Fax-on-demand: (202) 691-6325
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2 Massachusetts Ave., NE
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Data questions: blsdata_staff@bls.gov
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Washington, DC 20212-0001
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Technical (web) questions: webmaster@bls.gov
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Other comments: feedback@bls.gov
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Memo
|
|||||
To:
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Terry Bonno
|
Date:
|
December 6, 2001
|
|||
From:
|
James Mitchell, Director of Risk Management
|
|||||
Subject:
|
Estimated Annual Premium – Deepwater Horizon
|
Coverage:
Insured Value:
Deductible:
NET ANNUAL PREMIUM:
|
All Risk Hull & Machinery
$350,000,000
($5MM/$7.5MM/$7.5MM/$10MM aggregate layers)
$470,329
|
|
Coverage:
Policy Limits:
Deductible:
NET ANNUAL PREMIUM (US WATERS):
NET ANNUAL PREMIUM (FOREIGN WATERS):
|
Primary Marine Protection & Indemnity
$1,000,000 per occurrence
$250,000 Per Occurrence
$125,352
$53,796
|
|
Coverage:
Insured Value:
Deductible:
NET ANNUAL PREMIUM:
|
Excess Liability
$452,000,000
XS of Primary Marine P&I
$26,334
|
|
U.S. BROKERS:
ANNUAL FEE
|
McGriff Seibels & Williams, Inc.
$34,454
|
|
TOTAL ANNUAL PREMIUM: (U.S. WATERS)
|
$656,469
|
|
TOTAL ANNUAL PREMIUM: (FOREIGN WATERS)
|
$584,913
|
Rig Name
Contractor & No.
|
Effective Date
|
Commence
Date
|
Duration
Mos. &
|
Last
Update/
|
Reoccurrence
Timing
|
Reoccurrence
Condition
|
|||||||
Horizon(2)
Vastar (BP)
01-063
|
Dec. 8, 1998
|
Sept. 1, 2001
|
Annually
|
=> 5%
|
12/8/98
Baselines
|
9/1/01
Costs
|
|||||||||||
A. Baseline Labor
|
$
|
21,420
|
$
|
28,296
|
32.10
|
%
|
$
|
6,876
|
||||
Addtl Personnel
|
$
|
2,374
|
$
|
2,613
|
$
|
239
|
||||||
Total Labor
|
$
|
23,794
|
$
|
30,909
|
$
|
7,115
|
||||||
B. Catering
|
$
|
2,608
|
$
|
2,067
|
$
|
-541
|
||||||
C. Cost of R&M
|
$
|
12,692
|
$
|
13,851
|
$
|
1,159
|
||||||
BLS Indices
|
133.6
|
145.8
|
9.13
|
%
|
||||||||
D. Insurance Premiums
|
$
|
2,660
|
1,799.00
|
$
|
-861
|
|||||||
$
|
41,754
|
$
|
48,626
|
$
|
6,872
|
|||||||
16
|
%
|
R & B FALCON DRILLNG CO.
|
||
1311 BROADFIELD BLVD., SUITE 400
HOUSTON, TEXAS 77084
|
||
JOHN KEETON
RIG MANAGER
|
|
Reference: Deepwater Horizon Letter Agreement — Additional Personnel for Mad Dog Project CONTRACTOR-5121-2002-005
|
PHONE: 832-587-8533
|
FAX: 832-587-8754
|
EMAIL:JKeeton@houston.deepwater.com
|
VASTAR RESOURCES INC
|
||||
Deepwater Horizon Letter Agreement - Additional Personnel
|
||||
CONTRACTOR File #01-063
|
Sincerely,
|
|
/s/ John Keeton
|
|
John Keeton
|
|
R & B Falcon Drilling Co.
|
SIGNED
|
/s/ Allen Cook
|
|
PRINTED
|
Allen Cook
|
|
TITLE
|
MD Well Delivery TL
|
R & B FALCON DRILLNG CO.
|
||
1311 BROADFIELD BLVD., SUITE 400
HOUSTON, TEXAS 77084
|
||
TERRY BONNO
|
||
SR. MARKETING REPRESENTATIVE
|
|
Attn: Mr. Jon Sprague
|
|
Mr. Charles Taylor
|
|
Reference: Deepwater Horizon Letter Agreement — Additional Personnel for Deepwater Horizon CONTRACTOR-5121-2002-006
|
|
In a recent survey of crewing levels on similar Drilling Units in our fleet the following results were obtained:
|
|
|
Horizon
|
Nautilus
|
Marianas
|
|||||
Crew Total
|
72
|
88
|
96
|
Title
|
Total
|
On
Rig
|
Overtime Rate (per
person per hour)
with Burden
|
Daily Rate (per
person) with
Burden
|
Total Day Rate
with Burden
|
|||||||||
Toolpusher
|
2
|
1
|
N/A
|
$
|
761.90
|
$
|
761.90
|
|||||||
Floorhand
|
4
|
2
|
$
|
28.89
|
$
|
395.57
|
$
|
791.14
|
||||||
Crane Operator
|
4
|
2
|
$
|
38.57
|
$
|
493.35
|
$
|
986.70
|
||||||
Roustabout
|
8
|
4
|
$
|
24.77
|
$
|
353.97
|
$
|
1,415.88
|
||||||
TOTAL ADDITIONAL PERSONNEL
|
18
|
9
|
$
|
3,955.62
|
PHONE: 832-587-8848
|
FAX: 832-587-8754
|
EMAIL:tbonno@houston.deepwater.com
|
VASTAR RESOURCES INC
|
||||
Deepwater Horizon Letter Agreement - Additional Personnel
|
||||
CONTRACTOR File #01-063
|
Title
|
Total
|
On
Rig
|
Overtime Rate (per
person per hour)
with Burden
|
Daily Rate (per
person) with
Burden
|
Total Day Rate
with Burden
|
|||||||||
Driller
|
2
|
1
|
$
|
54.18
|
$
|
650.87
|
$
|
650.87
|
||||||
Welder
|
2
|
1
|
$
|
36.82
|
$
|
475.62
|
$
|
475.62
|
||||||
TOTAL ADDITIONAL PERSONNEL
|
4
|
2
|
$
|
1,126.49
|
Sincerely,
|
|
/s/ Terry Bonno
|
|
Terry Bonno
|
|
R & B Falcon Drilling Co.
|
SIGNED
|
/s/ R Kevin Guerre
|
|
PRINTED
|
R Kevin Guerre
|
|
TITLE
|
TL-SCM
|
|
R & B FALCON DRILLNG CO.
1311 BROADFIELD BLVD., SUITE 400
HOUSTON, TEXAS 77084
|
Reference:
|
Deepwater Horizon Letter Agreement – Cameron Variable Bore Rams Deepwater Horizon
|
|
CONTRACTOR-5121-2002-007
|
|
1. The Equipment is limited to the following components
|
Description
|
Quantity
|
|
Variable Bore Ram 18-3/4” 15M BOP, 3-1/2” X 6-5/8” OD Pipe, API 16A, ABS and DNV Certification
|
2
|
|
Ram Wear Pad, Right Side 18-3/4” BOP
|
2
|
|
Ram Wear Pad, Left Side 18-3/4” BOP
|
2
|
|
Screw, Ram Wear Pads
|
8
|
|
|
|
2. Company has authorized Contractor to purchase Equipment and has agreed to a dayrate reimbursement fee of $125.00 per day to be paid over the remainder of the Contract on the Deepwater Horizon. Dayrate reimbursement fee shall commence on June 13, 2002.
|
|
|
|
3. If the Contract is terminated prior to September 18, 2004, Company shall reimburse Contractor via a lump sum payment of $125.00 per day times the days remaining in contract after termination date. Such payment shall be due within thirty days after presentation of an invoice to Company.
|
|
|
|
4. The Equipment provided under this agreement shall become part of Contractor’s equipment and incorporated into Exhibit B-2 of the Contract.
|
|
|
|
All other terms and conditions of the referenced Contract, as amended, shall remain in full force and effect.
|
|
|
PHONE: 832-587-8848
|
FAX: 832-587-8754
|
EMAIL:tbonno@houston.deepwater.com
|
Sincerely,
|
|
/s/ Terry Bonno
|
|
Terry Bonno
|
|
R & B Falcon Drilling Co.
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
|
R & B FALCON DRILLNG CO.
1311 BROADFIELD BLVD., SUITE 400
HOUSTON, TEXAS 77084
|
Reference:
|
Deepwater Horizon Letter Agreement -
|
|
CONTRACTOR-5121-2002-010
|
Yours very truly,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
R & B Falcon Drilling Co.
|
PHONE: 832-587-8506
|
FAX: 832-587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
|
R&B FALCON DRILLING COMPANY
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Attn: Mr. Randy Rhoads
|
Re:
|
Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
|
|
Subject:
|
Letter of Agreement for adding Deck Pusher
|
|
CONTRACTOR-5121-2002-011
|
|
|
Title
|
On Board
|
Assigned
to Rig
|
Daily Rate per
Person w/ Burden
|
Hourly Overtime
Rate w/Burden
|
|||||||
Deck Pusher
|
1
|
2
|
$
|
512.80
|
$
|
40.50
|
|||||
Sincerely,
|
||
/s/ Christopher S. Young
|
||
Christopher S. Young
|
||
Sr. Marketing Representative
|
||
On Behalf of R & B Falcon Drilling Co.
|
PHONE: (832) 587 8506
|
FAX: (832) 587 8754
|
EMAIL:cyoung@houston.deepwater.com
|
BP
|
||
Horizon – Escalation 2002
|
||
TSF File #01-063
|
AGREED AND ACCEPTED THIS 2ND DAY OF DECEMBER, 2002
|
|||
BP AMERICA PRODUCTION COMPANY
|
|||
SIGNED
|
/s/ Jerry R Rhoads
|
||
PRINTED
|
Jerry R Rhoads
|
||
TITLE
|
Contracts Specialist
|
A
|
B
|
C
|
D
|
|||||||||||||
Gulf of Mexico Crew Complement
|
GOM Base Labor w/Burden
|
GOM Overtime Rates
|
||||||||||||||
No. of Personnel
|
Daily Rate
|
Total Daily
|
Daily
|
Hourly
|
||||||||||||
JOB
|
On
|
Assigned
|
(per person)
|
On Board
|
Rate
|
Rate
|
||||||||||
CODE
|
Board
|
To Rig
|
JOB CLASSIFICATION
|
w/ Burden*
|
Cost* *
|
w/ Burden* *
|
w/ Burden* *
|
|||||||||
1883
|
1
|
2
|
Offshore Installation Manager
|
930.23
|
855.23
|
Salaried
|
||||||||||
1276
|
3
|
6
|
Toolpusher
|
761.90
|
2,060.70
|
Salaried
|
||||||||||
1295
|
2
|
4
|
Driller
|
650.87
|
1,151.74
|
650.12
|
54.18
|
|||||||||
1302
|
4
|
8
|
Assistant Driller
|
493.35
|
1,673.41
|
462.88
|
38.57
|
|||||||||
1845
|
2
|
4
|
Pumphand
|
408.82
|
667.65
|
362.40
|
30.20
|
|||||||||
1296
|
12
|
24
|
Floorhand
|
395.57
|
3,846.86
|
346.65
|
28.89
|
|||||||||
1297
|
14
|
28
|
Roustabout
|
353.97
|
3,905.54
|
297.20
|
24.77
|
|||||||||
799
|
1
|
2
|
Welder
|
475.02
|
400.02
|
441.00
|
36.82
|
|||||||||
1289
|
4
|
8
|
Crane Operator
|
493.35
|
1,673.41
|
462.88
|
38.57
|
|||||||||
1381
|
2
|
4
|
Chief Mechanic
|
581.84
|
1,013.67
|
568.06
|
47.34
|
|||||||||
1286
|
1
|
2
|
Mechanic
|
471.20
|
396.20
|
436.55
|
36.38
|
|||||||||
1305
|
2
|
4
|
Motor Operator
|
395.97
|
641.93
|
347.12
|
28.93
|
|||||||||
1355
|
1
|
2
|
Electrical Supervisor
|
663.46
|
588.46
|
Salaried
|
||||||||||
1345
|
2
|
4
|
Chief Electrician
|
581.84
|
1,013.67
|
568.06
|
47.34
|
|||||||||
1280
|
1
|
2
|
Electrician
|
471.20
|
396.20
|
436.55
|
36.38
|
|||||||||
1387
|
2
|
4
|
Chief Electronic Technician
|
590.67
|
1,031.34
|
578.56
|
48.21
|
|||||||||
1388
|
1
|
2
|
Senior Sub Sea Supervisor
|
768.23
|
693.23
|
Salaried
|
||||||||||
1372
|
1
|
2
|
Assistant Sub Sea Supervisor
|
546.43
|
471.43
|
525.97
|
43.83
|
|||||||||
394
|
2
|
4
|
Materials Coordinator
|
435.79
|
721.58
|
394.46
|
32.87
|
|||||||||
1668
|
1
|
2
|
Master
|
810.10
|
735.10
|
Salaried
|
||||||||||
1299
|
1
|
2
|
Chief Mate
|
675.99
|
600.99
|
679.98
|
56.66
|
|||||||||
1539
|
1
|
2
|
Chief Engineer
|
751.42
|
676.42
|
Salaried
|
||||||||||
0
|
1
|
2
|
1st Assist. Engineer
|
634.12
|
559.12
|
630.21
|
52.52
|
|||||||||
0
|
2
|
4
|
2nd Assist. Engineer
|
599.57
|
1,049.14
|
589.14
|
49.10
|
|||||||||
1688
|
2
|
4
|
Dynamic Position Operator
|
546.43
|
942.86
|
525.97
|
43.83
|
|||||||||
1323
|
2
|
4
|
Assistant Dynamic Position Operator
|
457.95
|
765.89
|
420.79
|
35.07
|
|||||||||
1238
|
2
|
4
|
Deck Pusher
|
512.80
|
875.60
|
486.00
|
40.50
|
|||||||||
1298
|
1
|
2
|
Bosun
|
457.95
|
382.95
|
420.79
|
35.07
|
|||||||||
1300
|
3
|
6
|
Able Bodied Seaman
|
413.70
|
1,016.11
|
368.20
|
30.68
|
|||||||||
1608
|
1
|
2
|
Rig & Safety Training Technician*
|
466.78
|
391.78
|
431.29
|
35.94
|
|||||||||
1677
|
1
|
2
|
Rig Medic/Clerk
|
351.73
|
276.73
|
294.53
|
24.54
|
|||||||||
76
|
152
|
Total Base Labor Costs =
|
$
|
31,475.54
|
||||||||||||
*
|
Does include catering, transportation, or training expense.
|
||
* *
|
Does NOT include catering transportation, or training expense.
|
||
Notes:
|
1)
|
The figures in column “A” are to be used as the basis for adding personnel to the permanent crew and for determining the credit for crew members short.
|
|
2)
|
The figures in column “B” are the product of multiplying the number of “on board” personnel by the “Daily Rate w/ Burden” in column “A”. The Sum of column “B” is the “Total Base Labor Cost” per day.
|
||
3)
|
The figures in columns “C” and “D” are the basis for charging the Operator for overtime hours worked at the request of the Operator.
|
|
1.0 Effective at midnight October 31, 2002, RBFDC assigns to THI all of RBFDC’s rights and obligations under the Drilling Contract, and THI accepts the assignment and agrees to assume and perform all the said obligations under the Drilling Contract.
|
|
2.0 RBFDC agrees to notify and provide reasonably requested documentation to the other party to the Drilling Contract to effect the assignment.
|
|
3.0 Written notice to a Party under this Agreement will be considered to be properly served if received at the Party’s address appearing above by personal delivery or registered mail.
|
|
|
|
4.0 Any failure by a Party to enforce the terms of this Agreement or to exercise any rights will not constitute a waiver of those terms or rights, nor will it constitute any precedence.
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5.0 This Agreement is to be governed by and construed in accordance with the governing law provisions of the Drilling Contract.
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R&B FALCON DRILLING CO.
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TRANSOCEAN HOLDINGS INC.
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By:
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/s/ Jean P. Cahuzac
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By:
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/s/ Eric B. Brown
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Name: Jean P. Cahuzac
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Name: Eric B. Brown
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Title: Vice President
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Title: Vice President
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TRANSOCEAN OFFSHORE DEEPWATER DRILLING INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
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Re: Drilling Contract No. 980249 dated December 9, 1998 (“Contract”) by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings, Inc,(“Contractor or TODDI”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)<
/div>
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Subject:
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Letter of Agreement for 6 5/8” Drill Pipe Rental
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CONTRACTOR-5121-2002-011
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1. TODDI shall purchase the following pipe and rent it to Company over the remaining term of the Contract referenced above. Specifications of the pipe are as follows:
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Footage
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18,000
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Joints
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439
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Pipe OD
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6 5/8”
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Connection
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6 5/8 FH
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Weight
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34.01
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OD
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8 1/4”
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Grade
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S-135
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ID
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4 1/4”
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Upset
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IEU
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Pin Tong
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10”
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Range
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3
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Box Tong
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13”
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Internal Coating
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TK 34 XT*
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Hardfacing Pin
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None
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Inspection
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Truscope AS
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Hardfacing Box
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Armacor M
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Delivery
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16 weeks*
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|||||
Make & Break & 95% wall included
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2. Tooljoints (Pin & Box) shall be manufactured long enough to provide for a minimum of two full recuts and still have sufficient tong space excluding proud hardbanded area. Company’s coating, hardbanding and make & break specifications are attached and made a part of this Agreement.
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PHONE: (832) 587-8506
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FAX: (832) 587-8754
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EMAIL:cyoung@houston.deepwater.com
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3. The rental rate will be approximately $3,000/day assuming that 18 months will be remaining on the contract at time of pipe delivery and that the total cost of the pipe is approximately $1.29 million. The exact calculation will be made when the pipe is delivered and the total cost (based on good footage) and the remaining number of days in the term are known. The total rental amount to be recovered will be calculated at 1.27418155 times the total cost of the pipe. The total cost of the pipe will include inspection and transportation.
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4. The rental rate shall begin upon delivery of the pipe to TODDI following acceptance in accordance with Company’s QA/QC specifications and inspection criteria. These specifications and criteria are made a part of this Agreement. The rental rate shall cease when the total rental paid equals 1.27418155 times the final cost of the pipe. The rental agreement will continue as long the Contract is in force however the rental rate will be zero after the total rental paid equals 1.27418155 times the final cost of the pipe.
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5. Contractor shall furnish all handling equipment required for this pipe during the term of the rental at no cost to Company.
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6. Initial inspection is included in the cost of the pipe. Company reserves the right to re-inspect the pipe at Company’s cost. Company will be responsible for all inspections during the term of the rental.
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7. The pipe shall be treated as Contractor’s in-hole equipment per Article 22.3 of the Contract except for the cost of inspections.
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8. During the term of the rental, Company will have the option of moving the pipe to another Transocean Rig at Company’s option and expense.
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/s/ Christopher S. Young
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Christopher S. Young
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Sr. Marketing Representative
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SIGNED
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/s/ Jerry R Rhoads
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PRINTED
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Jerry R Rhoads
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TITLE
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Contracts Specialist
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INTERNAL PLASTIC COATING OF
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Procedure: BP-DEIP-IPC001
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Revision: 1
|
||
DRILL PIPE AND WORKSTRINGS
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Date: 6/6/02
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Page: 1 Of: 7
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Approved By:
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Date:
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1.0 Scope.
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1.1 This procedure details the BP GoM requirements for internal plastic coating of both new and used drill pipe, workstrings and pup joints. Additionally, this procedure details the BP GoM minimum requirements for used internal plastic coatings.
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1.2 This procedure includes a visual examination of all threaded connections after internal blasting at final inspection. All workstring tubing, and workstring tubing pup joints will be full length drifted at final inspection.
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2.0 Referenced Documents.
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2.1 The following documents are used as references for establishing this procedure.
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2.1.1 NACE TM-01-70
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2.1.2 NACE TM-03-89
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2.1.3 BP GoM OCTG Inspection Procedures and Requirements.
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2.1.4 The Coating Contractor’s Standard Operating Procedures manual for the application and inspection of internal coatings.
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3.0 Contractors Internal Coating Operating Procedures And Equipment Capabilities.
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3.1 The coating Contractor shall provide to BP for approval, complete standard operating procedures and equipment capabilities applicable to the individual pieces of equipment utilized for this process. The procedures will be of sufficient detail to enable the operator to perform required setup, calibration and adjustments to the equipment for preparation, application and inspection of the coatings.
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4.0 Requirements For Material And Equipment.
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4.1 All material, equipment, tools and supplies furnished by the Contractor shall be of good quality and adequate design, shall be maintained in good condition during use, shall conform to the requirements described in the Contractor’s Specifications and Standard Operating Procedures and shall be subject to BP’s approval.
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5.0 Preparation.
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5.1 Thread protectors shall be removed cleaned and stored until they are re-applied after final inspection.
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5.2 All threaded connections shall be cleaned with steam cleaners, soapy water, varsol or other mineral spirits.
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5.3 The material will then be visually examined internally for obvious defects, such as ridges or rough surfaces that would limit the coat-ability of the material. Rejected lengths will be identified, marked, segregated from the prime material and BP will be notified. No attempt will be made to coat these lengths until corrections have been made. Material with uncorrectable damage will be classified as “not suitable for coating” (NSC).
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5.4 The material will undergo a thermal cleaning by prebaking the material at 600° – 800° F (pipe temperature) for a minimum period of 2 hours or as agreed to by BP. Longer prebake periods may be required depending upon the characteristics of the material being processed.
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5.5 In order to insure that the proper oven temperatures are maintained, the BP QA/QC Inspector will be given a copy of the heat charts. These heat charts will be included with the BP QA/QC Inspector’s final job report. Additionally, at BP’s request the contractor will satisfactorily demonstrate to the BP QA/QC Inspector that the surface temperature of the pipe meets but does not exceed the established temperature limitations during the thermal cleaning, regardless of the method by which the material is heated (i.e., conveyor system or batch ovens).
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5.6 After thermal cleaning is completed, the material will be internally blasted “to white metal” with an abrasive material to thoroughly clean and roughen the metal surface in order to form a suitable anchor pattern for coating.
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5.7 The abrasive blasting operation will be repeated until the proper “white metal” surface condition is achieved.
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5.8 The Material must be dry before abrasive blasting begins.
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5.9 The compressed air used for abrasive blasting shall be free of water and oil. At the beginning of each shift the operator will verify this. The operator will partially open the air supply at the blast station and hold a clean cloth or blotter against the airflow. If any oil or water is found, the system must be cleaned or dried prior to abrasive cleaning. Air pressure will be provided at 85 to 110 P.S.I. as measured at the blast plot.
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5.10 The abrasive materials used for cleaning will be coarse Flintabrasive, Garnet, or other abrasive material meeting the Contractor’s specifications. Prior to the start of the job, the Contractor shall present, blast material specifications and quality control procedures for abrasive materials, to BP for acceptance.
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5.11 Prior to abrasive blasting, the material shall have protector masks installed to protect threads, seal areas and shoulders from damage.
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5.12 After abrasive blasting, the material shall be thoroughly cleaned with dry, oil free compressed air to remove abrasive blasting material and other foreign material from the surface area.
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5.13 The Contractor will conduct tests on both ends of the first 10 blasted pieces to establish that the anchor profile depth and appearance are satisfactory. Thereafter, tests will be conducted on both ends of every twenty-fifth piece. The test must be conducted with Testex Coarse Press-O-Film or equivalent and measured with the appropriate gauge. These tests will be conducted after full length blasting but before end blasting. Acceptable anchor profile depth will be verified to the Contractor’s Specifications. At BP’s request the BP QA/QC Inspector shall witness these tests, maintain the test results and include them with the final job report.
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5.14 After the material is blasted and the anchor profile depth and appearance tests are completed, the material will be visually inspected to determine coat-ability. The material will be classified “not suitable for coating” (NSC), if, in the opinion of the Contractors representative or the BP QA/QC Inspector, the surface condition of the material would preclude application of coatings to the material in accordance with the Contractors Specifications. The Contractor must, however, make every reasonable effort to blast the surface of the material to a coat-able condition. The NSC material will be identified, marked and segregated from the coat-a
ble material and BP shall be notified. If it is determined by the Contractor or the BP QA/QC Inspector that a second blast attempt on the NSC joint would possibly result in a coat-able piece, a second blast attempt, of at least two (2) passes, will be made.
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6.0 Internal Plastic Coating Application.
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6.1 Application of the coating material, as designated by BP, will be performed so that the required film thickness and coating properties are attained.
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6.2 Coating, mixing, and thinning will be controlled in accordance with the Contractor’s Standard Operating Procedures. These procedures will specify the coating material handling requirements, mixing methods, and general equipment settings necessary for a quality application.
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6.3 Individual coats should produce a uniform continuous coverage of the internal surface. When additional coats are required to meet specifications, those additional processes will be the decision and responsibility of the Contractor.
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6.4 Prior to coating, the material shall be properly masked to protect the threads, seal areas and shoulders from coating overspray or damage.
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6.5 When required, a sample from each batch of liquid coating will be taken. This sample will be sealed with tape, properly labeled with the batch number, job number and well charges. At BP’s request the BP QA/QC Inspector shall witness this process and initial each sample. The sample will be retained by the Contractor for subsequent evaluation, as directed, by BP.
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6.6 Different coating batches will not be mixed on individual lengths of material.
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6.7 The coating batch number(s) applicable to each BP order must be documented by the Contractor and retained in a permanent job file. At BP’s request the BP QA/QC Inspector will verify the coating batch(s) utilized and include them in the final job report.
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6.8 The shelf life of the batch(s) utilized on the BP material will be verified and documented by the Contractor. If the age of the coating exceeds the manufacturer’s suggested shelf life, it will not be applied to the BP material. At BP’s request the BP QA/QC inspector will verify the shelf life of the batch(s) utilized and include them in the final job report.
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6.9 The first coat of coating shall be applied as soon as possible after blasting. In no case shall coating be delayed more than one (1) hour without reblasting. If the event a rust bloom or visual oxidation occurs before the application of the first coat, the material must be re-blasted.
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6.10 Coating thickness and number of coats shall be in accordance with the Contractor’s coating specifications and provide a dry film thickness (DFT) as specified by the Contractor.
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6.11 Coating intermediate and final bake temperatures and times shall be in accordance with the Contractor’s coating specifications. Intermediate baking will be performed at 250° – 350° F for periods of 45 minutes to 1-1/2 hours depending on coating, material size and weight. Final baking will be done at temperatures of 400° – 500° F for periods of 1-4 hours depending on coating, material size and weight. The staging of temperatures during final bake is permitted. In order to insure that proper oven temperatures are maintained the BP QA/QC Inspector will be given a copy of the heat charts. These heat charts will be incl
uded with the BP QA/QC Inspector’s final job report. Additionally, at BP’s request the Contractor shall satisfactorily demonstrate to the BP QA/QC Inspector that the surface temperature of the material meets but does not exceed the established temperature limitations for both the intermediate and final bakes regardless of the method by which the material is heated (i.e., conveyor system or batch ovens).
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6.12 Minor irregularities in individual coats may be repaired to meet specifications anytime prior to final bake at the option of the Contractor. Repairs of this nature are limited to the end area of material where thickness of repairs can be measured. Minor surface irregularities that are within the coating thickness specifications will be considered acceptable. Runs, sags, blobs, filled threads and/or blisters will be rejected.
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6.13 The Contractor will conduct a sufficient number of visual and film thickness checks on the material in order to assure conformity to final product specifications.
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7.0 Final Inspection.
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7.1 After the final bake, the BP QA/QC Inspector shall conduct, at random, a dry film thickness test and visual inspection of the coated material. In addition to obvious defects such as blobs, blisters, etc., the visual inspection will verify that the final coating color is within the Contractors specifications. The color of the coating should be uniform throughout the entire length of the material.
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7.2 The color of finished baked coatings is variable. The Contractor will maintain coating color standards at the coating facility. The coating color standards will be used to determine the acceptable finished color of all thermoset coatings. Lengths that contain coating color within the standard range of the coating color standards will be considered acceptable. After each final bake, the color will be verified with the proper comparator. The BP QA/QC Inspector shall witness the coating color inspection process.
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7.3 The material shall be visually inspected from each end with sufficient light to detect any coating anomalies. The material will be sufficiently rotated during the visual inspection to inspect the entire inside area of the material. The material must be in a single layer for the inspection. Material will not be stacked during the final inspection. The final product should be free of runs, sags, and blisters. Surface roughness or surface irregularities will not be considered cause for rejection provided that the coating thickness is within specification.
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7.4 The dry film thickness of the material will be measured on both ends of the material with a MIKROTEST DFG magnetic thickness gauge. The calibration of the thickness gauge will be conducted at the beginning of each shift or every eight hours, whichever comes first, and must be witnessed by the BP QA/QC Inspector. Material with coating thickness outside of the specified ranges (specified by the Contractor) will be rejected and reprocessed.
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7.5 Coatings on the face of the pipe ends are exempted from the standard minimum coating thickness requirements.
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8.0 Holiday Testing.
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8.1 Holiday testing will be performed per NACE Standard TM-03-84 on each length of pipe coated with thin film holiday free internal coating. The testing will be performed utilizing a “Tinker-Rasor” type M-1 holiday tester or equivalent, which is calibrated at the beginning of each shift or when requested by the BP QA/QC Inspector. All calibrations and testing must be witnessed by the BP QA/QC Inspector. The procedure for holiday testing of the material is as follows:
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· A 2” thick cellulose sponge probe head saturated with selected electrolyte and detergent will be employed.
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· The sponge will be large enough to insure a 360° contact throughout the length of the pipe. The sponge will be replaced when worn.
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· A constant potential of 67.5 volts DC will be maintained between the sponge probe and the body of the tube during testing. The negative lead shall be connected to the pipe and the positive lead shall have continuity to the sponge. The tester alarm shall be activated before the testing of each joint to insure that continuity exists between the tube body and the holiday tester.
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· The sponge probe will be moved through the pipe at a rate of 60 fpm +5%.
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· Each length of pipe will be holiday tested once at the Contractor’s facility. Thin film coatings will be defined as holiday free when the electrical resistance between the wet sponge and the tube body is at no point less than 80,000 ohms.
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· The holiday test will be performed in both directions while running the wet sponge in and out of the tube.
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· All thin film corrosion coatings for both new and used pipe will be holiday free and will be applied and tested in accordance with the methods outlined above.
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· The holiday free specifications will apply only while the material is at the Contractor’s coating facility.
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· All coated pipe that is rejected shall be reprocessed according to surface preparation, application, and inspection procedures as outlined in this specification. Those coated lengths not meeting holiday specifications after being coated a second time are to be classified as NSC. Any length that Contractor or BP determines to be unsuitable for coating (NSC) due to internal surface defects (e.g., slivers, pitting, etc.) will be set aside. This pipe will be reprocessed only upon instructions from BP.
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9.0 Full Length Drifting.
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9.1 After final inspection, each length will be full length drifted with a plastic or wooden drift mandrel meeting the applicable API specifications for coated material with the exception of drill pipe products, which do not require full length drifting.
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10.0 Visual Thread Inspection.
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10.1 After final inspection and full length drifting, is completed, the threads and sealing surfaces shall be visually inspected in accordance with the procedure BP-DEIP-P004. Thread compound, as specified by BP, will be applied to all threaded surfaces and the proper clean dry thread protectors installed.
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11.1 Marking and Stenciling.
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11.1 The Contractor will re-apply inspection bands and stencils as instructed by BP. Further, a clear mill varnish, acceptable to BP, will be applied to the outer surface of the material to prevent corrosion.
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12.1 Documentation, Records And Reporting.
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12.1 At the end of the job, the Contractor will provide BP the following documents:
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· Prebake Heat Charts.
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· Testex Coarse Press-O-Film test strips.
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· Coating Batch number(s).
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· Intermediate Bake Heat Charts.
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· Final Bake Heat Charts.
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· Final report, stating the piece quantity, Prime and rejects (including NSC), along with the footage’s. The reason for rejection must be reported.
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· Individual pipe tally sheets indicating “threads off’ footage.
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12.2 Documentation, records and reporting requirements as listed in BP-DEIP-P005 shall apply.
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13.0 Health, Safety And Environmental.
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13.1 Health, safety and environmental requirements as listed in BP-DEIP-P001 shall apply.
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14.0 Visual Inspection Of Used Internal Plastic Coatings.
|
HARDBANDING OF DRILL PIPE TOOLJOINTS,
|
Procedure: BP-DEIP-P002
|
Revision: 0
|
||
HEAVYWEIGHT DRILL PIPE AND DRILL COLLARS
|
Date: 7/2/902
|
Approved By:
|
Date:
|
|
1.0 Scope.
|
|
1.1 This procedure details the BP GoM requirements for the hardbanding of drill pipe tooljoints (loose or attached), heavyweight drill pipe and drill collars. It is applicable to new or used non-hardbanded material and material which requires re-hardbanding.
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1.2 The application of proud wear resistant alloy hardfacing bands onto tooljoints, heavyweight drill pipe and drill collars significantly reduces external wear and casing wear.
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2.0 Referenced Documents.
|
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2.1 The following documents were used as reference for establishing this procedure.
|
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2.1.1 Part 1 BP Drill-string Hardbanding Specification for General Release (4/6/2000).
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2.1.2 ISO 9002 Quality Systems – Model for quality assurance in production and installation.
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2.1.3 ISO 9003 Quality Systems – Model for quality assurance in final inspection and test.
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2.1.4 API Q1 – Specification for Quality Programs.
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2.1.5 ASME IX – ASME Boiler and Pressure Vessel Code. Welding and Brazing Qualifications.
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2.1.6 ASTM E 709 – Standard Guide for Magnetic Particle Examination.
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2.1.7 ASTM E 165 – Standard Test Method for Liquid Penetrant Examination.
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2.1.8 API Specification 7 - Rotary Drill Stem Elements.
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2.1.9 API Recommended Practice 7G - Drill Stem Design and Operating Limits.
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3.0 Quality Assurance.
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3.1 The Applicator shall operate a Quality Assurance organization responsible for formulating and implementing a Quality System, which insures that the requirements of this procedure are met.
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3.2 The Applicator’s Ouality System shall be based on ISO 9002 and ISO 9003 or API Q1. Particular attention is drawn to Section 4.8.2 in ISO 9002 and Section 3.12 in API Q1 concerning Special Processes. Hardbanding and the associated practices are considered to be Special Processes and shall be qualified strictly in accordance with the requirements of this procedure.
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3.3 The effectiveness of the Applicator’s Quality System will be subject to monitoring by BP and may be audited following and agreed period of notice.
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4.0 Hardbandinq Types.
|
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4.1 There are two basic types or categories of hardbanding for drill pipe tooljoints, heavyweight drill pipe and drill collars utilized in the Oil Industry today. These comprise weld overlays that consist of wear resistant alloys that do not contain tungsten carbide granules and weld overlays consisting of tungsten carbide granules within a metallic substrate (normally a low carbon steel). In this procedure these types will be referred to as “Wear Resistant Alloy Overlays” and “Tungsten Carbide Overlays”.
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4.2 Wear Resistant Alloy Overlays. These materials are hard alloys containing no solid particles. Therefore, unlike tungsten carbide overlays, there is no possibility of hard particles standing proud or becoming exposed from a softer matrix and producing severe abrasive wear of the casing. Wear resistant alloy overlays are required when applying hardfacing for BP GoM and are strongly recommended verses tungsten carbide overlays in all cases.
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4.3 Tungsten Carbide Overlays. These consist of granules of tungsten carbide in a steel matrix. The use of tungsten carbide overlays is not permitted when applying hardfacing for BP GoM on drill pipe tooljoints, heavyweight drill pipe or drill collars. The use of drill pipe with tungsten carbide overlays is not permitted without the express consent of the responsible BP Engineer. Since heavyweight drill pipe and drill collars are used in open-hole sections the majority of time while drilling, BP GoM may accept tungsten carbide overlays on these items. However,
if tungsten carbide overlays are used on heavyweight drill pipe or drill collars BP GoM reserves the right to examine the hardfacing for acceptance on a case, by case basis.
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5.0 Welding Issues.
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5.1 Welding Processes. Hardbanding shall be deposited by the use of a mechanized GMAW welding technique using a solid wire or cored wire consumable. Self shielded or open arc welding techniques may also be used. Other techniques for the deposition of hardbanding may be proposed for consideration by BP.
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5.2 Preheat And Interpass Temperature. A minimum preheat temperature of 400°F shall be achieved through the full thickness of the component prior to the start of hardbanding or application of mild steel (butter-pass) and this temperature shall be maintained as the minimum interpass temperature throughout the welding process. The maximum interpass temperature for the application of hardbanding or mild steel shall be 650°F.
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5.3 Post Weld Thermal Regime. Immediately on completion of welding, the component shall be subjected to one of the following alternative thermal regimes:
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5.3.1 The temperature of the internal and external surface of the component shall be measured and if necessary the component shall be heated such that a temperature of 650°F is attained through the full thickness. The component shall then be allowed to slow cool to ambient temperature while fully wrapped in an insulating blanket or specially constructed insulating can. The components shall be kept under cover and shall not be exposed to any wind, drafts or rain during the cooling period.
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5.3.2 The component shall be placed in an oven and maintained at a temperature of 400°F for a minimum period of two (2) hours prior to slow cooling under insulation, as detailed in section 5.3.1 above.
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5.4 Welding Parameters. The welding parameters employed for hardbanding should be based on those recommended by the consumable manufacturer. However, it should be noted that these parameter values are often provided for guidance only and Applicators should undertake sufficient welding procedure development work to insure that they have established a stable welding condition prior to welding procedure qualification.
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5.5 Welding Procedures (WPS). All welding procedures associated with the application of hardbanding or mild steel shall be qualified in accordance with ASME IX, QW 216, QW 453 and the requirements of this procedure. Production welding equipment shall be employed for the welding procedure qualification.
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· The application of flush and proud hardbanding. A separate WPS is required for each type of hard metal consumable.
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· The application of mild steel.
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· The application of mild steel (butter-pass), flush and proud hardbanding on re-hardbanded components. A separate WPS is required for each type of hard metal consumable.
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5.6 Welding Procedure Qualification (PQR). All welding procedure qualifications shall be performed on a 4145H tubular material, preferred size of 6 5/8” OD and 2 3/4” ID, representing a typical drill collar. The manufacturer’s certificate, including full details of heat treatment, mechanical testing results and chemical analysis, for this material and the welding consumable shall be included in the PQR documentation. All relevant welding p
arameters shall be monitored and recorded during the production of the test weld and reported in the PQR.
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5.7 Manufacturing Reference Standards. Subsequent to the testing detailed in Section 5.6 above the remainder of the welding procedure qualification test piece shall be retained by the Applicator to act as a reference standard during production.
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5.8 Welder/Machine Operators Performance Qualification. Working in accordance with a qualified WPS each hardbanding welder/machine operator shall manufacture a test piece as detailed in section 5.6 in order to demonstrate his ability. The test piece shall be subjected to the examination detailed in Note 3, QW 453 and meet the criteria outlined in section 10.0 of this procedure. Each welder/machine operator performing a successful welding procedure qualification test shall be deemed to have completed a satisfactory performance test.
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5.9 Production Welding. Production welding shall be undertaken strictly in accordance with the qualified welding procedures. All welder/machine operators shall be qualified in accordance with section 5.8. A copy of the basic elements of the WPS shall be available for reference at each hardbanding station.
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6.0 Hardbandinq Configurations.
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6.1 Definitions. When applying new hardbanding and for the purposes of this procedure the following definitions shall apply.
|
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· “Proud” hardbanding is an overlay that stands proud from the base material. Tolerances for proud hardbanding are + 3/32” to + 1/8” as measured from the base material surface.
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· “Flush” hardbanding is an overlay that is flush with the base material surface. Tolerances for flush hardbanding are + 1/64” and — 0 as measured from the base material surface.
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6.2 Drill Pipe Tooljoints. Hardbanding (Wear Resistant Alloy Overlay) shall be applied in the following locations:
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· A three (3”) inch wide band on the box tooljoint OD next to the taper. These bands shall be applied proud.
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|
|
|
· One 3/4” wide band on the box tooljoint 18° taper. This band shall be applied flush.
|
|
|
|
· Three 3/4” long fingers 120° apart projecting from the base of the hardbanding on the box tooljoint taper onto the box upset. Fingers shall be applied flush.
|
|
|
|
· A one and one half (1 1/2”) inch wide band on the pin tooljoint OD next to the taper. These bands shall be applied proud.
|
|
6.3 Heavy Weight Drill Pipe. Hardbanding (Wear Resistant Alloy Overlay) shall be applied in the following locations:
|
|
|
|
· One 4” inch wide band on the box and pin tooljoint OD next to the taper. These bands shall be applied proud.
|
|
|
|
· One 1” wide band on the tapered section of the box tooljoint. This band shall be applied flush.
|
|
|
|
· Two 3” wide bands on each end of the center wear pad. These bands shall be applied proud.
|
|
|
|
6.4 Drill Collars With Slip Recess Groove. Hardbanding (Wear Resistant Alloy Overlay) shall be applied in the following locations:
|
|
|
|
· One, 4” wide band on the box end OD located 1” away from the beginning of the slip recess groove. This band shall be applied proud.
|
|
|
|
· One, 10” wide band on the drill collar OD located 1” away from the end of the slip recess groove. This band shall be applied proud.
|
|
6.5 Drill Collars With Slip And Elevator Recess Grooves. Hardbanding (Wear Resistant Alloy Overlay) shall be applied in the following locations:
|
|
· One, 4” wide band on the box end OD located 1” away from the beginning of the slip recess groove. This band shall be applied proud.
|
|
|
|
· One, 1” wide band on the wear pad OD between the two recess grooves. This band shall be applied proud.
|
|
|
|
· One, 10” wide band on the drill collar OD located 1” away from the end of the slip recess groove. This band shall be applied proud.
|
|
|
|
7.0 Pre-Hardbandinq Considerations.
|
|
7.1 Mill Slots, Chip Slots and Identification Grooves. Inspect the tooljoints to determine if there are mill slots, chip slots, identification grooves or other machined areas on the tooljoints that will interfere with the application of hardbanding per section 6.2. If machined areas exist and will interfere with the hardbanding application process notify the Material Supplier prior to hardbanding the material and obtain permission to fill the machined areas in with mild steel. The application of mild steel shall meet the requirements outlined in section 5.0 and
9.0.
|
|
7.2 Internal Plastic Coating. Inspect the material to determine if it is internally plastic coated. If the material is internally plastic coated notify the Material Supplier prior to hardbanding the material and inform the Material Supplier that the material will require re-coating after the hardbanding process.
|
|
7.3 Pre-Existing Hardband. Inspect the material to determine it the material has been previously hardbanded. If the material has been previously hardbanded notify the Material Supplier prior to the hardbanding the material and inform the Material Supplier that the existing hardbanding will have to be removed in accordance with section 9.0 prior to applying the new hardbanding.
|
|
|
|
8.0 Hardbanding Procedure.
|
|
8.1 Machining. When applying proud hardbanding, a groove shall be machined into the surface of the material prior to the application of hardbanding. The groove depth shall be 1/32” (+/-.010”) as measured from the surface of the material. When applying flush hardbanding, a groove shall be machined into the surface of the material prior to the application of hardbanding. The groove depth shall be 3/32” (- 0 + 1/32”) as measured from the surface of the material. When applying flush hardbanded fingers, three, 3/4” long, 1/2” wide and 3/32” deep slots shall be ground into the drill pipe box end upset. All groove and slot widths shall equal the intended width of the hardbanding to be applied as defined in section 6.0.
|
|
|
|
|
|
8.2 Surface Preparation. Hardbanding shall be deposited onto a machined or ground white metal surface. This surface shall be free from dirt, drilling mud, cement, paint, rust, cutting fluid, grease etc. Additionally, a two (2) inch band on either side of the machined area shall be thoroughly cleaned and degreased.
|
|
|
|
8.3 Preheat. Preheat the area requiring hardbanding in accordance with the BP approved WPS (See section 5.0 for more details). The preheat temperature shall be verified on each area requiring hardbanding on each piece with a calibrated pyrometer or the properly rated temperature sticks. When temperature sticks are used the Applicator shall have at a minimum, temperature sticks rated to the preheat temperature and maximum interpass temperature.
|
|
|
|
8.4 Hardbanding Application. Apply hardbanding to the material in accordance with the BP approved WPS (See section 5.0 for more details).
|
|
|
|
8.5 Interpass Temperature. Monitor the interpass temperature throughout the hardband application process to insure the minimum and maximum interpass temperatures are maintained in accordance with the BP approved WPS (See section 5.0 for more details). The interpass temperature shall be measured with a calibrated pyrometer or the properly temperature sticks. When temperature sticks are used the Applicator shall have at a minimum, temperature sticks rated to the minimum interpass temperature and maximum interpass temperature.
|
|
|
|
8.6 Post Weld Thermal Regime / Slow Cooling. Immediately on completion of the hardband application, the material shall be subjected to a post weld thermal regime in accordance with the BP approved WPS (See section 5.0 for more details).
|
|
|
|
8.7 Surface Finish. After the material has slow cooled to ambient temperature, remove all weld spatter or protrusions by grinding, sanding or machining methods. Close control of the hardband welding parameters should result in a good surface finish, such that it is not usually necessary to grind, sand or machine the entire hardbanded surface.
|
|
|
|
|
|
8.8 Inspection. Perform a dimensional inspection on each hardbanded area to insure the requirements outlined in section 6.0 have been met.
|
|
8.8.1 Perform a visual inspection on each hardbanded area. Acceptance and rejection criteria shall be per section 10.0.
|
|
8.8.2 Clean all connections and perform a visual inspection on the threaded and sealing surfaces in accordance with procedure BP-DEIP-P004.
|
|
|
|
8.8.3 Perform a bi-directional wet magnetic particle inspection on the HAZ and at least two (2) inches of the surrounding parent metal around all hardbanded areas. The bi-directional WMPI shall be performed in accordance with procedure BP-DEIP-P002 (the transverse MPI method shall be per section 7.0 and the longitudinal MPI method shall be per section 8.0). Acceptance and rejection criteria shall be per section 10.0.
|
|
|
|
8.9 Finishing. Blow the material ID out with compressed air to remove any debris. Apply the appropriate thread compound to all connections as specified by the Material Supplier and install clean dry thread protectors wrench tight. Apply a thin coat of rust inhibitor to the freshly hardbanded, ground, sanded or machined areas.
|
|
9.0 Removal of Existing Hardbanding and Application of Mild Steel.
|
|
9.1 Removal of Existing Hardbanding. The removal of existing hardbanding shall be performed with pre-approved methods or techniques such as, plasma arc gouging, grinding or machining. When plasma arc gouging techniques are used care shall be taken to minimize the heat input.
|
|
9.1.1 After removal of the existing hardbanding with plasma arc gouging techniques, the excavated area shall be machined smooth to provide a suitable surface for WMPI.
|
|
|
|
9.2 Inspection. All areas where previous hardbanding has been removed shall be etched with a 5% Nital solution to verify that all of the hardband material has been removed. This process shall be repeated as many times as necessary to insure all previous hardband material has been completely removed.
|
|
9.2.1 Perform a bi-directional wet magnetic particle inspection on all areas where hardbanding has been removed and all areas that have been affected during the removal process. The bi-directional WMPI shall be performed in accordance with procedure BP-DEIP-P002 (the transverse MPI method shall be per section 7.0 and the longitudinal MPI method shall be per section 8.0). Acceptance and rejection criteria shall be per section 10.0.
|
|
9.3 Application of Mild Steel. Apply mild steel to the previously excavated areas and/or mill slots, chip slots or identification grooves if necessary in accordance with the BP approved WPS (See section 5.0 for more details).
|
|
9.4 Machining. Machine the areas where mild steel has been applied back to the original OD or taper of the area.
|
|
9.5 Inspection. Perform a bi-directional wet magnetic particle inspection on all areas where mild steel has been applied. The bi-directional WMPI shall be performed in accordance with procedure BP-DEIP-P002 (the transverse MPI method shall be per section 7.0 and the longitudinal MPI method shall be per section 8.0). Acceptance and rejection criteria shall be per section 10.0.
|
|
10.0 Acceptance Criteria.
|
|
10.1 Mild Steel And Parent Material. Relevant indications on the external or internal surface (including HAZ) of parts shall be removed by grinding or machining, provided that the part still conforms to BP’s, the Manufacturer’s or API acceptance criteria after the removal process.
|
|
10.2 Wear Resistant Alloy Overlays. These hard wear resistant deposits possess relatively low ductility. Therefore, weld metal cracking often occurs transverse to the weld bead under the influence of residual stresses. Typically, these cracks may run straight across the weld bead or at an angle between 30° and 45°. Occasionally the cracks will interconnect. This is acceptable as long as the cracks are less than 1/16” wide or have a minimum spacing of 1/2” apart when the cracks
run across the full width of the hardbanded region. If cracks fail to meet this criteria remove the deposit and re-hardband the material in accordance with sections 8.0 and 9.0.
|
|
11.0 Documentation, Records and Reporting.
|
|
11.1 The Applicator shall submit to BP an inspection record, which will clearly state that the hardbanding has been applied and inspected in accordance with this procedure. The scope and content of this record shall include:
|
|
· A reference list of the Applicator’s procedures used in the production of the hardbanding and a copy of the WPS(s) and PQR(s).
|
|
|
|
· A copy of all NDE reports.
|
|
11.2 Documentation, records and reporting requirements as listed in procedure BP-DEIP-P005 shall apply.
|
|
12.0 General Requirements.
|
|
12.1 General requirements as listed in procedure BP-DEIP-P001 shall apply.
|
|
13.0 Marking And Stenciling.
|
|
13.1 Marking and stenciling requirements as listed in procedure BP-DEIP-P001 shall apply.
|
|
14.0 Documentation, Records and Reporting.
|
|
14.1 Documentation, records and reporting requirements as listed in procedure BP-DEIP-P005 shall apply.
|
|
|
|
15.0 Health, Safety And Environmental.
|
|
15.1 Health, safety and environmental requirements as listed in BP-DEIP-P001 shall apply.
|
MAKE AND BREAK OF DRILL PIPE AND
|
Procedure: BP-DEIP-MB001
|
Revision: 0
|
||
WORKSTRING TOOLJOINTS
|
Date: 6/6/02
|
Approved By:
|
Date:
|
|
1.0 Scope.
|
|
1.1 This procedure describes the processes established to make and break new drill pipe and workstring tooljoints, both, affixed or loose.
|
|
1.2 Since newly machined connections are susceptible to galling the make and break process is utilized to break in new connections (tooljoints) by work hardening the connection surface.
|
|
2.0 Personnel Qualifications.
|
|
2.1 Personnel performing make and break operations must be trained and experienced in the operation of the make and break unit.
|
|
3.0 Required Materials & Equipment.
|
|
3.1 Hydraulic Make And Break Unit. The make and break unit shall be capable of making up and breaking out two joints of range III drill pipe together to the manufacturers recommended torque value.
|
|
3.1.1 The unit shall be equipped with load cells and gauges capable of indicating the torque values obtained in Ft./Lbs.
|
|
|
|
3.1.2 Calibration of the load cells and gauges on the make and break unit shall be performed a minimum of once every six (6) months. The calibration documentation shall be available for review at the job site.
|
|
|
|
3.1.3 The make and break unit shall be equipped with the properly sized power and backup tongs.
|
|
|
|
3.1.4 Power and backup tongs will utilize low stress, large contact surface area dies to reduce grip marks.
|
|
|
|
3.2 Additional Required Equipment. The following equipment shall be available on the job sight and in good working order: Depth (pit) gauge, files, 50’ metal tally tape, absorbent pad, catch pans, cleaning solvent, cleaning brushes, thread compound, dope brushes, assorted paints and metal markers.
|
|
4.0 Make And Break Procedures.
|
|
4.1 Remove the thread protectors and stack them off the ground to prevent contamination with dirt, grit, grass etc.
|
|
4.2 Visually inspect the condition of the thread compound to insure a thin uniform coat of make-up thread compound has been applied and is not contaminated with dirt, grit, rust, scale etc.
|
|
4.3 Verify the make and break unit has been set up properly prior to commencing the make and break operation. The unit must be level and both tongs must be perpendicular to the tooljoints. In addition, the tooljoints shall be centered in the tongs and tong dies shall contact the tooljoints in a uniform fashion to prevent excessive grip marks and slippage.
|
|
4.4 Recommended torque values shall be obtained from the drill pipe manufacturer or their published documents prior to the start up of the make and break operation.
|
|
4.5 The make and break process shall consist of and be performed in the order listed below.
|
|
|
|
1. Make up a box and pin connection to 100% of the specified optimum torque value. Break out the box and pin connections.
|
|
|
|
2. Clean both connections and perform visual inspection for damages or excessive grip marks. Repair any minor damages with a file or emery cloth and apply a thin coating of dry moly lubricant over the repaired connection.
|
|
|
|
|
|
3. Provided that the damages are minor or non-existent repeat the operations outlined in step one (1) above two (2) more times without cleaning the connections.
|
|
|
|
4. After the third make and break cycle clean both connections and perform visual inspection for damages. Repair any minor damages with a file or emery cloth and apply a thin coating of dry moly lubricant over the repaired connection.
|
|
|
|
5. Repeat the operations outlined in steps one (1), two (2), three (3) and four (4) on the next four (4) sets of boxes and pins.
|
|
|
|
6. Provided that the damages are minor or non-existent on the first five (5) sets connections the remaining connections in the order shall be made up to 100% of the specified optimum torque value and broken out three (3) consecutive times without cleaning the connections between make and break cycles.
|
|
|
|
7. Clean all connections after the final make and break cycle and perform a visual inspection for damages or excessive grip marks. Repair any minor damages with a file or emery cloth and apply a thin coating of dry moly lubricant over the repaired connection.
|
|
|
|
8. Allow the connections to dry or dry the connections with compressed air. Apply a thin, uniform film of the specified thread compound to all connections and install thread protectors wrench tight.
|
|
5.1 Visual and dimensional requirements as listed in procedure BP-DEIP-P004 shall apply.
|
|
6.1 General requirements as listed in procedure BP-DEIP-P001 shall apply.
|
|
7.1 Marking and stenciling requirements as listed in procedure BP-DEIP-P001 shall apply.
|
|
8.0 Documentation, Records and Reporting.
|
|
8.1 Documentation, records and reporting requirements as listed in procedure BP-DEIP-P005 shall apply.
|
|
9.1 Health, safety and environmental requirements as listed in BP-DEIP-P001 shall apply.
|
CHRISTOPHER S. YOUNG
SR. MARKETING REPRESENTATIVE
|
TRANSOCEAN HOLDINGS INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
|
|
|
Subject: Letter of Agreement for adding Offshore Safety Assistant
|
Title
|
On Board
|
Assigned
to Rig
|
Daily Rate per
Person w/ Burden
|
Hourly Overtime
Rate w/Burden
|
||||||
Offshore Safety Advisor
|
1
|
2
|
$
|
930.23
|
NA
|
|||||
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
|
On Behalf of Transocean Holdings Inc..
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL: cyoung@houston.deepwater.com
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
CHRISTOPHER S. YOUNG
SR. MARKETING REPRESENTATIVE
|
TRANSOCEAN HOLDINGS INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 (“Contract”) by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
|
Subject: Letter of Agreement for Recycling program — Deepwater Horizon
|
Sincerely,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
|
On Behalf of Transocean Holdings Inc..
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL: cyoung@houston.deepwater.com
|
|
1. Provide a recycling service to reduce and separate the waste on the Rig.
|
|
2. Furnish recycling and general waste compactor units to the Rig.
|
|
3. Supply storage bins at dock locations for collection of recycled materials.
|
|
4. Collect and transport compacted bags of recycled materials from the storage bins.
|
|
5. Track and provide totals of the volume of recycled material collected
|
|
6. Maintain and repair compactor units as needed.
|
|
7. Training of Rig personnel in operating, tagging and delivery of the recycled materials to the storage bins
|
|
|
|
|
Recycle the Gulf Bags — New
|
5.5 cuft Tri-2 Bags
|
$ 10.35/each
|
||
14 cuft 6 x 2 bags
|
$ 10.15/each
|
Model 4000 Trash Compactor Bags
|
$ 10.20/each
|
|||
Processing Fee (per bag of recycled material)
|
$ 1.85/bag
|
|
|
TRANSOCEAN OFFSHORE DEEPWATER DRILLING, INC.
|
|
4 GREENWAY PLAZA (77046)
|
|
POST OFFICE BOX 2765
|
|
Gregory L. Cauthen
Senior Vice President, Chief Financial Officer and Treasurer
|
HOUSTON, TEXAS 77252-2765
|
February 18, 2003
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizo
n)
|
Sincerely,
|
|
/s/ Gregory L. Cauthen
|
|
Gregory L. Cauthen
|
|
Senior Vice President, Chief
|
|
Financial Officer & Treasurer
|
|
cc: Craig Duncan
|
|
|
TRANSOCEAN HOLDINGS INC.
|
|
4 GREENWAY PLAZA
|
|
HOUSTON, TX 77046
|
|
CHRISTOPHER S. YOUNG
|
|
SR. MARKETING REPRESENTATIVE
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
Reference
|
2001 Baseline Costs
plus Previous
Agreements
|
Actual Baseline
Costs
@ Jan. 1, 2003
|
Increase/
(Decrease)
|
Dayrate
Increase/
(Decrease)
|
|||||||||
2.3.2a Base Labor Costs
|
$
|
36,008
|
$
|
36,139
|
$
|
131
|
*
|
||||||
2.3.2b Catering Costs
|
$
|
2,366
|
$
|
2,780
|
$
|
414
|
$
|
414
|
|||||
2.3.2c Maintenance Element
|
13,851
|
13,946
|
$
|
95
|
*
|
||||||||
2.3.2d Insurance
|
$
|
1,799
|
$
|
5,137
|
$
|
3,338
|
$
|
3,338
|
|||||
Total
|
$
|
54,024/day
|
$
|
58,002/day
|
$
|
3,752/day
|
|
2.3.2a Base Labor rates did not change but several of our “burdens” did change on January 1. FICA limits increased as well as pension accruals and some insurance related items. We reduced the utilization bonus. The net result was a slight increase but not the 5% required to trigger an increase. Please note that the total includes all personnel added by letter agreement.
|
|
2.3.2b Contractor’s cost of catering has increased from $27.20 per man per day to $31.95, an increase of 17.5%. Please note the catering cost shown on the accompanying schedule only reflects the crew complement in the contract (77 on board the rig) while we actually have 83.
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
|
2.3.2c The Maintenance Element of the Baseline Cost increased $95 per day based on the change on the relevant Producer Price Index. The Index number for December 2002 increased to 146.8 from 145.8 in August of 2001, an increase of .69 %. The Bureau of Labor Statistics Data for the Producer Price Index series ID: WPU119102 is attached. Since the change was less than 5% we did not include it in the rate adjustment.
|
|
|
|
2.3.2d The insurance element increased $3,338 per day for a 186% increase and accounts for the majority of the overall cost increase. The cost of the various coverages is broken out on the accompanying schedule. Insurance costs increased dramatically throughout the industry for reasons already discussed. Please note that we lowered the insured value of the rig from $350 million to $320 million and increased the deductible from $500,000 to $10 million to reduce the H&M premium. Without the increased deductible, the premiums would have been significantly higher. Basically, we are self-insured for the first $10 million of coverage. The Marine P&I insurance cost shown on the accompanying schedule reflects a $4,832 per assigned person per year accrual determined by our insurance c
ompany for the self-insured $10 million.
|
|
|
Sincerely,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
|
On Behalf of R & B Falcon Drilling Co.
|
SIGNED
|
/s/ J. W. Farnsworth
|
|
PRINTED
|
J. W. Farnsworth
|
|
TITLE
|
VP Exploration
|
2001 Baseline
Costs Plus
Agreements
|
2001 Baseline
Costs Plus
Subsequent
Agreements
|
January 2003
Actual Baseline
Costs
|
Actual
Variance
|
Dayrate
Increase
|
Adjusted
2003
Baseline Costs
|
|||||||||||||||
2.3.2a) Base Labor Cost:
|
||||||||||||||||||||
Labor & Burden (for original Contract Crew Complement)
|
$
|
25,476
|
$
|
25,476
|
$
|
25,598
|
$
|
122
|
$
|
25,476
|
||||||||||
Training & Transportation Costs (for original Contract Crew Complement)
|
$
|
2,820
|
$
|
2,820
|
$
|
2,820
|
$
|
0
|
$
|
2,820
|
||||||||||
**
|
Labor & Burden for 7 Addl Personnel included in 2001 Baseline Calc.
|
$
|
2,278
|
NA
|
NA
|
NA
|
NA
|
|||||||||||||
**
|
Training & Transportation Costs (7 Addl Personnel incl. In 2001)
|
$
|
335
|
NA
|
NA
|
NA
|
NA
|
|||||||||||||
***
|
Labor & Burden (18 Addl Pers. (incl. 7 added above) @ Jan 2003)
|
$
|
0
|
$
|
6,852
|
$
|
6,860
|
$
|
9
|
$
|
6,852
|
|||||||||
***
|
Training & Transportation Costs (18 Addl Personnel - Onboard)
|
$
|
0
|
$
|
860
|
$
|
860
|
$
|
0
|
$
|
860
|
|||||||||
Total Base Labor Cost
|
$
|
30,909
|
$
|
36,008
|
$
|
36,139
|
$
|
131
|
$
|
0
|
$
|
36,008
|
||||||||
Percentage Increase
|
036
|
%*
|
||||||||||||||||||
2.3.2b) Base Catering Cost:
|
||||||||||||||||||||
59 Contractor Personnel in Original Contract
|
$
|
1,605
|
$
|
1,605
|
$
|
1,885
|
$
|
280
|
$
|
1,885
|
||||||||||
**
|
7 Additional Personnel included in 2001 Baseline Cost Calculation
|
$
|
190
|
NA
|
NA
|
NA
|
NA
|
|||||||||||||
***
|
18 Additional Personnel (including the 7 Addtl. Included in 2001)
|
$
|
0
|
$
|
490
|
$
|
576
|
$
|
86
|
$
|
576
|
|||||||||
10 Company Personnel
|
$
|
272
|
$
|
272
|
$
|
320
|
$
|
48
|
$
|
320
|
||||||||||
Total Base Catering Costs
|
$
|
2,067
|
$
|
2,366
|
$
|
2,780
|
$
|
414
|
$
|
414
|
$
|
2,780
|
||||||||
Percentage Increase
|
17.5
|
%
|
||||||||||||||||||
2.3.2c) Base Maintenance Element:
|
$
|
13,851
|
$
|
13,851
|
$
|
13,946
|
$
|
95
|
$
|
0
|
$
|
13,851
|
||||||||
Percentage Increase
|
0.69
|
%*
|
||||||||||||||||||
2.3.2d) Base Insurance Cost:
|
||||||||||||||||||||
Hull & Machinery
|
$
|
1,289
|
$
|
1,289
|
$
|
2,422
|
$
|
1,133
|
$
|
2,422
|
||||||||||
Marine P&I
|
$
|
343
|
$
|
343
|
$
|
2,039
|
$
|
1,695
|
$
|
2,039
|
||||||||||
Excess Liability
|
$
|
72
|
$
|
72
|
$
|
520
|
$
|
448
|
$
|
520
|
||||||||||
Brokers Fee
|
$
|
94
|
$
|
94
|
$
|
110
|
$
|
15
|
$
|
110
|
||||||||||
Oil Pollution
|
$
|
0
|
$
|
0
|
$
|
46
|
$
|
46
|
$
|
46
|
||||||||||
Total Base Insurance Cost:
|
$
|
1,799
|
$
|
1,799
|
$
|
5,137
|
$
|
3,338
|
$
|
3,338
|
$
|
5,137
|
||||||||
Percentage Increase
|
185.6
|
%
|
||||||||||||||||||
Total
|
$
|
48,626
|
$
|
54,024
|
$
|
58,002
|
$
|
3,977
|
$
|
3,752
|
$
|
57,776
|
||||||||
Total Dayrate Increase =
|
$
|
3,752/day
|
A
|
B
|
C
|
D
|
|||||||||||
GOM Base Labor
|
GOM Overtime Rates
|
|||||||||||||
No. Of Personnel
|
Daily Rate per
|
Daily
|
||||||||||||
On
Board
|
Assigned
To Rig
|
JOB CLASSIFICATION
|
person (inc.
TT&C)
|
Total Daily on
Board Cost
|
Overtime
Rates
|
Hourly
Overtime Rates
|
||||||||
1
|
2
|
OIM
|
965.59
|
871.93
|
824.67
|
68.72
|
||||||||
1
|
2
|
OSA - Horizon
|
889.04
|
795.38
|
748.12
|
62.34
|
||||||||
3
|
6
|
Toolpusher
|
786.15
|
2,077.48
|
645.23
|
53.77
|
||||||||
2
|
4
|
Driller
|
662.47
|
1,137.62
|
621.66
|
51.81
|
||||||||
4
|
8
|
Assistant Driller
|
511.05
|
1,669.57
|
441.18
|
36.76
|
||||||||
2
|
4
|
Pumpman
|
430.72
|
674.11
|
345.42
|
28.79
|
||||||||
12
|
24
|
Floorman
|
386.35
|
3,901.75
|
342.26
|
28.52
|
||||||||
14
|
28
|
Roustabouts
|
346.81
|
3,998.53
|
295.13
|
24.59
|
||||||||
1
|
2
|
Welder
|
494.23
|
400.57
|
421.13
|
35.09
|
||||||||
4
|
8
|
Crane Operator
|
511.05
|
1,009.57
|
441.10
|
36.76
|
||||||||
2
|
4
|
Chief Mechanic
|
595.17
|
1,003.03
|
541.45
|
45.12
|
||||||||
1
|
2
|
Mechanic
|
490.02
|
396.36
|
416.11
|
34.68
|
||||||||
2
|
4
|
Motor Operator
|
386.77
|
651.13
|
342.76
|
28.56
|
||||||||
1
|
2
|
Electrical Supervisor
|
675.09
|
581.43
|
534.17
|
44.51
|
||||||||
2
|
4
|
Chief Electrician
|
595.17
|
1,003.03
|
541.45
|
45.12
|
||||||||
1
|
2
|
Electrician
|
490.02
|
396.36
|
416.11
|
34.68
|
||||||||
2
|
4
|
Chief Electronic Technician
|
603.59
|
1,019.85
|
551.47
|
45.96
|
||||||||
1
|
2
|
Senior Sub Sea Sup
|
777.26
|
683.60
|
636.35
|
53.03
|
||||||||
1
|
2
|
Assistant Subsea
|
561.53
|
467.87
|
501.34
|
41.78
|
||||||||
2
|
4
|
Material Co-Ordinator
|
456.37
|
725.43
|
376.00
|
31.33
|
||||||||
1
|
2
|
Master
|
863.11
|
769.45
|
722.19
|
60.18
|
||||||||
1
|
2
|
Chief Mate
|
687.71
|
594.05
|
651.74
|
54.31
|
||||||||
1
|
2
|
Chief Engineer
|
803.26
|
709.59
|
662.34
|
55.19
|
||||||||
1
|
2
|
1st Assistant Engineer
|
645.65
|
551.99
|
601.61
|
50.13
|
||||||||
2
|
4
|
2nd Assistant Engineer
|
612.00
|
1,036.68
|
561.50
|
46.79
|
||||||||
2
|
4
|
DP Operator
|
561.53
|
935.73
|
501.34
|
41.78
|
||||||||
2
|
4
|
Assistant Dp Operator
|
477.40
|
767.49
|
401.07
|
33.42
|
||||||||
2
|
4
|
Deck Pusher
|
497.81
|
873.21
|
475.11
|
39.59
|
||||||||
1
|
2
|
Bosun
|
477.40
|
383.74
|
401.07
|
33.42
|
||||||||
3
|
6
|
AB Seaman
|
403.59
|
1,027.17
|
362.81
|
30.23
|
||||||||
1
|
2
|
RSTT
|
485.82
|
392.16
|
411.10
|
34.26
|
||||||||
1
|
2
|
Medic
|
385.88
|
292.22
|
291.98
|
24.33
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
0
|
0
|
-
|
—
|
—
|
—
|
—
|
||||||||
77
|
154
|
Total Labor Costs =
|
$
|
32,458.08
|
||||||||||
TRANSOCEAN OFFSHORE DEEPWATER DRILLING INC.
|
|
BETSY KELLY
|
4 GREENWAY PLAZA
|
MANAGER-INSURANCE
|
HOUSTON, TX 77046
|
Coverage:
Insured Value:
Deductible:
NET ANNUAL PREMIUM:
|
All Risk Hull & Machinery
$ 320,000,000
$10,000,000
$ 883,943
|
|
Coverage:
Deductible:
NET ANNUAL COST:
|
Primary Marine Protection & Indemnity
$10,000,000 per occurrence
$ 744,235*
|
|
Coverage:
Insured Value:
Deductible:
NET ANNUAL PREMIUM:
|
Excess Liability
$452,000,000
XS of Primary Marine P & I
$ 189,799
|
|
Coverage:
NET ANNUAL PREMIUM:
|
Oil Pollution
$ 16,820
|
|
U.S. Broker:
Annual Fee:
|
McGriff, Seibels & Williams, Inc
$ 40,024
|
(713) 232-7766 FAX
|
(713) 232-7630 TEL
|
BKELLY@HOUSTON.DEEPWATER.COM
|
U. S. Department of Labor
Bureau of Labor Statistics
Bureau of Labor Statistics Data
|
|
www.bls.gov
|
Search | A-Z Index
|
Change
|
|
Output
|
From: 1992 To 2002 Go
|
Options:
|
include graphs NEW!
|
More Formatting Options
|
Year
|
Jan
|
Feb
|
Mar
|
Apr
|
May
|
Jun
|
Jul
|
Aug
|
Sep
|
Oct
|
Nov
|
Dec
|
Annual
|
||||||||||||||
1992
|
110.1
|
110.1
|
110.1
|
110.1
|
110.2
|
110.4
|
110.6
|
110.6
|
110.6
|
110.8
|
112.4
|
112.5
|
110.7
|
||||||||||||||
1993
|
112.8
|
112.9
|
113.3
|
112.1
|
112.0
|
112.2
|
112.3
|
112.3
|
113.4
|
113.4
|
113.4
|
114.6
|
112.9
|
||||||||||||||
1994
|
114.6
|
114.6
|
114.6
|
114.6
|
114.7
|
114.9
|
115.4
|
115.4
|
115.9
|
117.8
|
117.8
|
117.8
|
115.7
|
||||||||||||||
1995
|
118.3
|
118.6
|
119.2
|
119.2
|
119.3
|
119.6
|
120.4
|
120.4
|
120.4
|
122.0
|
122.2
|
122.2
|
120.1
|
||||||||||||||
1996
|
124.0
|
124.0
|
124.0
|
124.3
|
124.2
|
124.8
|
125.3
|
125.3
|
125.3
|
126.2
|
126.6
|
127.1
|
125.1
|
||||||||||||||
1997
|
127.7
|
127.9
|
128.6
|
129.1
|
129.2
|
129.3
|
129.3
|
129.5
|
129.7
|
130.3
|
131.4
|
132.0
|
129.5
|
||||||||||||||
1998
|
133.1
|
132.9
|
133.1
|
133.0
|
133.0
|
133.0
|
132.9
|
132.9
|
132.9
|
133.6
|
133.6
|
133.6
|
133.1
|
||||||||||||||
1999
|
133.8
|
133.7
|
133.7
|
133.9
|
133.9
|
134.0
|
134.0
|
133.7
|
133.7
|
133.7
|
134.4
|
134.6
|
133.9
|
||||||||||||||
2000
|
134.9
|
136.3
|
136.3
|
136.3
|
136.5
|
136.5
|
136.5
|
136.6
|
136.7
|
138.7
|
138.7
|
138.7
|
136.9
|
||||||||||||||
2001
|
143.5
|
143.9
|
144.0
|
144.0
|
144.0
|
145.5
|
145.6
|
145.8
|
145.7
|
146.1
|
146.1
|
146.1
|
145.0
|
||||||||||||||
2002
|
146.2
|
146.2
|
146.6
|
146.6
|
146.4
|
146.4
|
146.4
|
146.4
|
146.8
|
(P)
|
146.8
|
(P)
|
146.8
|
(P)
|
146.8
|
(P)
|
146.5
|
(P)
|
|
TRANSOCEAN OFFSHORE DEEPWATER DRILLING INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
Sincerely,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
|
TRANSOCEAN OFFSHORE DEEPWATER DRILLING INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
Sincerely,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
|
AGREED AND ACCEPTED THIS 14th DAY OF APRIL, 2003
|
|
BP AMERICA PRODUCTION COMPANY
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
|
TRANSOCEAN OFFSHORE DEEPWATER DRILLING INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 (“Contract”) by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings, Inc,(“Contractor or TODDI”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
|
1. TODDI shall purchase the following pipe and rent it to Company over the remaining term of the Contract referenced above. Specifications of the pipe are as follows:
|
Footage
|
18,000
|
Joints
|
439
|
Pipe OD
|
6 5/8”
|
Connection
|
6 5/8 FH
|
Weight
|
34.01
|
OD
|
8 1/4”
|
Grade
|
S-135
|
ID
|
4 1/4”
|
Upset
|
IEU
|
Pin Tong
|
10”
|
Range
|
3
|
Box Tong
|
13”
|
Internal Coating
|
TK34 XT*
|
Hardfacing Pin
|
None
|
Inspection
|
Truscope AS
|
Hardfacing Box
|
Armacor M
|
Delivery
|
16 weeks*
|
||
Make & Break & 95% wall included
|
|
2. Tooljoints (Pin & Box) shall be manufactured long enough to provide for a minimum of two full recuts and still have sufficient tong space excluding proud hardbanded area. Company’s coating, hardbanding and make & break specifications are attached and made a part of this Agreement.
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
|
3. The rental rate will be approximately $3,000/day assuming that 18 months will be remaining on the contract at time of pipe delivery and that the total cost of the pipe is approximately $1.29 million. The exact calculation will be made when the pipe is delivered and the total cost (based on good footage) and the remaining number of days in the term are known. The total rental amount to be recovered will be calculated at 1.27418155 times the total cost of the pipe. The total cost of the pipe will include inspection and transportation.
|
|
4. The rental rate shall begin upon delivery of the pipe to TODDI following acceptance in accordance with Company’s QA/QC specifications and inspection criteria. These specifications and criteria are made a part of this Agreement. The rental rate shall cease when the total rental paid equals 1.27418155 times the final cost of the pipe. The rental agreement will continue as long the Contract is in force however the rental rate will be zero after the total rental paid equals 1.27418155 times the final cost of the pipe.
|
|
|
|
5. Contractor shall furnish all handling equipment required for this pipe during the term of the rental at no cost to Company.
|
|
|
|
6. Initial inspection is included in the cost of the pipe. Company reserves the right to re-inspect the pipe at Company’s cost. Company will be responsible for all inspections during the term of the rental.
|
|
|
|
7. The pipe shall be treated as Contractor’s in-hole equipment per Article 22.3 of the Contract except for the cost of inspections.
|
|
|
|
8. During the term of the rental, Company will have the option of moving the pipe to another Transocean Rig at Company’s option and expense.
|
/s/ Christopher S. Young
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
|
TRANSOCEAN HOLDINGS INC.
1311 BROADFIELD, SUITE 400
HOUSTON, TX 77084
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
|
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
Sincerely,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
|
On Behalf of Transocean Holdings Inc.,
|
SIGNED
|
/s/ Jerry R Rhoads
|
|
PRINTED
|
Jerry R Rhoads
|
|
TITLE
|
Contracts Specialist
|
|
TRANSOCEAN HOLDINGS INC.
4 GREENWAY PLAZA
HOUSTON, TX 77046
|
|
Attn: Mr. Randy Rhoads
|
|
Re: Drilling Contract No. 980249 dated December 9, 1998 by and between R&B Falcon Drilling Company predecessor in interest to Transocean Holdings Inc. (“Contractor”) and Vastar Resources, Inc. predecessor in interest to BP America Production Company (“Company”), as amended for RBS-8D (now known as the Deepwater Horizon)
|
|
|
Reference
|
2003 Baseline
Costs plus Previous
Agreements
|
Actual Baseline
Costs
@ Jan. 1, 2003
|
Increase/
(Decrease)
|
Dayrate
Increase/
(Decrease)
|
|||||||||
2.3.2a Base Labor Costs
|
$
|
36,008
|
$
|
36,099
|
$
|
91
|
*
|
||||||
2.3.2b Catering Costs
|
$
|
2,780
|
$
|
2,650
|
$
|
(130
|
)
|
$
|
(130
|
)
|
|||
2.3.2c Maintenance Element
|
$
|
13,851
|
$
|
14,589
|
$
|
738
|
$
|
738
|
|||||
2.3.2d Insurance
|
$
|
5,137
|
$
|
5,137
|
0
|
||||||||
Total
|
$
|
57,776/day
|
$
|
58,475/day
|
$
|
608day
|
|
2.3.2a Base Labor rates changed by the adjustment of the utilization bonus and pension accruals. The net result was a slight increase but not the 5% required to trigger an increase.
|
|
2.3.2b We have changed catering companies on the Horizon which has provided a decrease from $31.95 per man per day to $30.45, a decrease of 6.3%. Please note the catering cost shown on the accompanying schedule only reflects the crew complement in the contract (77 on board the rig) while we actually have 83.
|
PHONE: (832) 587-8506
|
FAX: (832) 587-8754
|
EMAIL:cyoung@houston.deepwater.com
|
|
2.3.2c The Maintenance Element of the Baseline Cost increased $738 per day based on the change on the relevant Producer Price Index. The Index number for December 2003 increased to 153.8 from 145.8 in August of 2001, an increase of 5.33%. The Bureau of Labor Statistics Data for the Producer Price Index series ID: WPU119102 is attached.
|
|
|
|
2.3.2d Costs of insurance premiums have not changed due to the fact that our Risk Department negotiated a 14 month agreement for the previous increases. We will keep you advised of any increases regarding insurance.
|
|
|
Paragraph 2.3.2b
|
(130
|
)
|
||
Paragraph 2.3.2c
|
738
|
|||
Total Increase
|
$
|
608
|
net increase effective January 1, 2004
|
|
Sincerely,
|
|
/s/ Christopher S. Young
|
|
Christopher S. Young
|
|
Sr. Marketing Representative
|
|
On Behalf of R & B Falcon Drilling Co.
|
SIGNED
|
/s/ Scott Sigurdson
|
|
PRINTED
|
Scott Sigurdson
|
|
TITLE
|
Wells Manager
|
Clause No.:
|
January 2003
Actual Baseline
Costs
|
January 2004
Actual Baseline
Costs
|
Variance
|
Adjusted
2004
Baseline Costs
|
||||||||||
2.3.2a)
|
Base Labor Cost:
|
|||||||||||||
Labor & Burden (per schedule)
|
$
|
25,476
|
$
|
25,626
|
$
|
150
|
$
|
25,476
|
||||||
Training & Transportation Costs
|
$
|
2,820
|
$
|
3,024
|
$
|
204
|
$
|
2,820
|
||||||
**
|
Labor & Burden (18 Addl Personnel - Onboard)
|
$
|
6,852
|
$
|
6,792
|
$
|
-59
|
$
|
6,852
|
|||||
**
|
(Training & Transportation Costs (18 Addl Personnel - Onboard)
|
$
|
860
|
$
|
656
|
$
|
-204
|
$
|
860
|
|||||
Total Base Labor Cost
|
$
|
36,008
|
$
|
36,099
|
$
|
91
|
$
|
36,008
|
||||||
Percentage Increase
|
0.25
|
%*
|
||||||||||||
2.3.2b)
|
Base Catering Cost:
|
|||||||||||||
59 Contractor Personnel
|
$
|
1,885
|
$
|
1,797
|
$
|
-88
|
$
|
1,797
|
||||||
**
|
18 Additional Personnel
|
$
|
576
|
$
|
549
|
$
|
-27
|
$
|
549
|
|||||
10 Company Personnel
|
$
|
320
|
$
|
305
|
$
|
-15
|
$
|
305
|
||||||
Total Base Catering Costs
|
$
|
2,780
|
$
|
2,650
|
$
|
-130
|
$
|
2,650
|
||||||
Percentage Increase
|
-6.3
|
%
|
||||||||||||
2.3.2c)
|
Base Maintenance Element:
|
$
|
13,851
|
$
|
14,589
|
$
|
738
|
$
|
14,589
|
|||||
Percentage Increase
|
5.33
|
%
|
||||||||||||
2.3.2d)
|
Base Insurance Cost:
|
|||||||||||||
Hull & Machinery
|
$
|
2,422
|
$
|
2,422
|
$
|
0
|
$
|
2,422
|
||||||
Marine P&I
|
$
|
2,039
|
$
|
2,039
|
$
|
0
|
$
|
2,039
|
||||||
Excess Liability
|
$
|
520
|
$
|
520
|
$
|
0
|
$
|
521
|
||||||
Brokers Fee
|
$
|
110
|
$
|
110
|
$
|
0
|
$
|
110
|
||||||
Oil Pollution
|
$
|
46
|
$
|
46
|
$
|
0
|
$
|
46
|
||||||
Total Base Insurance Cost:
|
$
|
5,137
|
$
|
5,137
|
$
|
0
|
$
|
5,137
|
||||||
Percentage Increase
|
0.0
|
%
|
||||||||||||
Total Baseline Operating Costs
|
$
|
57,776
|
$
|
58,475
|
$
|
608
|
$
|
58,384
|
||||||
Total Dayrate Increase =
|
$
|
608/day
|
A
|
B
|
C
|
D
|
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
GOM Base Labor
|
GOM Overtime Rates
|
|||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
No. of Personnel
|
Daily Rate per
|
Daily
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
On
Board
|
Assigned To
Rig
|
JOB CLASSIFICATION
|
person (inc.
TT&C)
|
Total Daily on
Board Cost
|
Overtime
Rates
|
Hourly
Overtime Rates
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
OIM
|
958.32
|
866.16
|
818.90
|
68.24
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
OSA - Horizon
|
868.26
|
776.10
|
728.84
|
60.74
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
3
|
6
|
Toolpusher
|
793.31
|
2,103.44
|
653.89
|
54.49
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Driller
|
659.31
|
1,134.31
|
619.69
|
51.64
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
4
|
8
|
Assistant Driller
|
508.91
|
1,667.01
|
440.42
|
36.70
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Pumpman
|
427.86
|
671.40
|
343.80
|
28.65
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
12
|
24
|
Floorman
|
383.58
|
3,886.55
|
340.75
|
28.40
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
14
|
28
|
Roustabouts
|
342.07
|
3,953.17
|
291.27
|
24.27
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Welder
|
483.29
|
391.13
|
409.87
|
34.16
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
4
|
8
|
Crane Operator
|
499.66
|
1,630.00
|
429.39
|
35.78
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Chief Mechanic
|
591.28
|
998.23
|
538.59
|
44.88
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Mechanic
|
493.19
|
401.03
|
421.68
|
35.14
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Motor Operator
|
397.26
|
675.10
|
357.04
|
29.75
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Electrical Supervisor
|
659.31
|
567.15
|
519.90
|
43.32
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Chief Electrician
|
589.72
|
995.12
|
536.74
|
44.73
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Electrician
|
488.44
|
396.28
|
416.02
|
34.67
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Chief Electronic Technician
|
597.91
|
1,011.50
|
546.50
|
45.54
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Senior Sub Sea Sup
|
759.49
|
667.32
|
620.07
|
51.67
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Assistant Subsea
|
559.02
|
466.86
|
500.14
|
41.68
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Material Co-Ordinator
|
451.60
|
718.88
|
372.10
|
31.01
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Master
|
852.37
|
760.21
|
712.95
|
59.41
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Chief Mate
|
671.59
|
579.43
|
634.32
|
52.86
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
Chief Engineer
|
759.56
|
667.40
|
620.14
|
51.68
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
1
|
2
|
1st Assistant Engineer
|
658.33
|
566.17
|
618.52
|
51.54
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
2nd Assistant Engineer
|
653.50
|
1,122.68
|
612.76
|
51.06
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
DP Operator
|
561.07
|
937.81
|
502.58
|
41.88
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
2
|
4
|
Assistant Dp Operator
|
475.10
|
765.88
|
400.11
|
33.34
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Exhibit 31.1
CEO CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
I, Steven L. Newman, certify that:
1. I have reviewed this report on Form 10-Q of Transocean Ltd.;
Exhibit 31.2
CFO CERTIFICATION PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
I, Ricardo H. Rosa, certify that:
Exhibit 32.1
CERTIFICATION PURSUANT TO SECTION 906 OF
THE SARBANES-OXLEY ACT OF 2002 (SUBSECTIONS (a) AND (b)
OF SECTION 1350, CHAPTER 63 OF TITLE 18, UNITED STATES CODE)
Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), I, Steven L. Newman, Chief Executive Officer of Transocean Ltd., a Swiss corporation (the “Company”), hereby certify, to my knowledge, that:
The foregoing certification is being furnished solely pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and is not being filed as part of the Report or as a separate disclosure document.
A signed original of this written statement required by Section 906 has been provided to Transocean Ltd. and will be retained by Transocean Ltd. and furnished to the Securities and Exchange Commission or its staff upon request.
Exhibit 32.2
CERTIFICATION PURSUANT TO SECTION 906 OF
THE SARBANES-OXLEY ACT OF 2002 (SUBSECTIONS (a) AND (b)
OF SECTION 1350, CHAPTER 63 OF TITLE 18, UNITED STATES CODE)
Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), I, Ricardo H. Rosa, Senior Vice President and Chief Financial Officer of Transocean Ltd., a Swiss corporation (the “Company”), hereby certify, to my knowledge, that:
The foregoing certification is being furnished solely pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code) and is not being filed as part of the Report or as a separate disclosure document.
A signed original of this written statement required by Section 906 has been provided to Transocean Ltd. and will be retained by Transocean Ltd. and furnished to the Securities and Exchange Commission or its staff upon request.
|