UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
|
|
|
þ
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|
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
|
For the quarterly period ended September 26, 2008
or
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|
o
|
|
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
|
For the transition period from
to
Commission File Number 001-31305
FOSTER WHEELER LTD.
(Exact name of registrant as specified in its charter)
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Bermuda
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22-3802649
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(State or other jurisdiction of incorporation or organization)
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(I.R.S. Employer Identification No.)
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Perryville Corporate Park
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Clinton, New Jersey
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08809-4000
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(Address of principal executive offices)
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(Zip Code)
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(908) 730-4000
(Registrants telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed
by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or
for such shorter period that the Registrant was required to file such reports) and (2) has been
subject to such filing requirements for the past 90 days. Yes
þ
No
o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated
filer, a non-accelerated filer, or a smaller reporting company. See the definitions of large
accelerated filer, accelerated filer and smaller reporting company in Rule 12b-2 of the
Exchange Act. (Check one):
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Large accelerated filer
þ
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Accelerated filer
o
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Non-accelerated filer
o
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|
Smaller reporting company
o
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|
|
|
|
(Do not check if a smaller reporting company)
|
|
|
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of
the Exchange Act). Yes
o
No
þ
Indicate the number of shares outstanding of each of the issuers classes of common stock, as
of the latest practicable date: 133,753,790 common shares ($0.01 par value) were outstanding as of
October 24, 2008.
FOSTER WHEELER LTD.
INDEX
2
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS
(in thousands of dollars, except per share amounts)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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Fiscal Quarters Ended
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|
Fiscal Nine Months Ended
|
|
|
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September 26,
|
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|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Operating revenues
|
|
$
|
1,718,355
|
|
|
$
|
1,299,872
|
|
|
$
|
5,215,101
|
|
|
$
|
3,641,760
|
|
Cost of operating revenues
|
|
|
(1,489,095
|
)
|
|
|
(1,101,912
|
)
|
|
|
(4,522,654
|
)
|
|
|
(3,067,442
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract profit
|
|
|
229,260
|
|
|
|
197,960
|
|
|
|
692,447
|
|
|
|
574,318
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Selling, general and administrative expenses
|
|
|
(74,831
|
)
|
|
|
(62,686
|
)
|
|
|
(218,771
|
)
|
|
|
(180,079
|
)
|
Other income, net
|
|
|
(1,178
|
)
|
|
|
22,319
|
|
|
|
36,995
|
|
|
|
43,730
|
|
Other deductions, net
|
|
|
(8,986
|
)
|
|
|
(7,672
|
)
|
|
|
(27,080
|
)
|
|
|
(33,075
|
)
|
Interest income
|
|
|
12,457
|
|
|
|
12,467
|
|
|
|
35,155
|
|
|
|
24,263
|
|
Interest expense
|
|
|
(5,193
|
)
|
|
|
(4,716
|
)
|
|
|
(16,204
|
)
|
|
|
(14,652
|
)
|
Minority interest in income of consolidated affiliates
|
|
|
(834
|
)
|
|
|
(1,765
|
)
|
|
|
(1,859
|
)
|
|
|
(5,038
|
)
|
Net asbestos-related gain/(provision)
|
|
|
(1,725
|
)
|
|
|
8,633
|
|
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|
30,738
|
|
|
|
8,633
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
148,970
|
|
|
|
164,540
|
|
|
|
531,421
|
|
|
|
418,100
|
|
Provision for income taxes
|
|
|
(21,050
|
)
|
|
|
(35,439
|
)
|
|
|
(104,683
|
)
|
|
|
(102,324
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
127,920
|
|
|
$
|
129,101
|
|
|
$
|
426,738
|
|
|
$
|
315,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Earnings per common share (see Note 1):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
0.89
|
|
|
$
|
0.91
|
|
|
$
|
2.96
|
|
|
$
|
2.24
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
$
|
0.88
|
|
|
$
|
0.89
|
|
|
$
|
2.94
|
|
|
$
|
2.18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
3
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEET
(in thousands of dollars, except share data and per share amounts)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
|
December 28,
|
|
|
|
2008
|
|
|
2007
|
|
ASSETS
|
|
|
|
|
|
|
|
|
Current Assets:
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$
|
1,308,924
|
|
|
$
|
1,048,544
|
|
Accounts and notes receivable, net:
|
|
|
|
|
|
|
|
|
Trade
|
|
|
634,975
|
|
|
|
580,883
|
|
Other
|
|
|
121,518
|
|
|
|
98,708
|
|
Contracts in process
|
|
|
291,466
|
|
|
|
239,737
|
|
Prepaid, deferred and refundable income taxes
|
|
|
39,955
|
|
|
|
36,532
|
|
Other current assets
|
|
|
30,102
|
|
|
|
39,979
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
2,426,940
|
|
|
|
2,044,383
|
|
|
|
|
|
|
|
|
Land, buildings and equipment, net
|
|
|
364,377
|
|
|
|
337,485
|
|
Restricted cash
|
|
|
26,430
|
|
|
|
20,937
|
|
Notes and accounts receivable long-term
|
|
|
2,103
|
|
|
|
2,941
|
|
Investments in and advances to unconsolidated affiliates
|
|
|
210,168
|
|
|
|
198,346
|
|
Goodwill, net
|
|
|
65,060
|
|
|
|
53,345
|
|
Other intangible assets, net
|
|
|
61,705
|
|
|
|
61,190
|
|
Asbestos-related insurance recovery receivable
|
|
|
287,695
|
|
|
|
324,588
|
|
Other assets
|
|
|
90,934
|
|
|
|
93,737
|
|
Deferred income taxes
|
|
|
102,154
|
|
|
|
112,036
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$
|
3,637,566
|
|
|
$
|
3,248,988
|
|
|
|
|
|
|
|
|
LIABILITIES, TEMPORARY EQUITY AND SHAREHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
Current Liabilities:
|
|
|
|
|
|
|
|
|
Current installments on long-term debt
|
|
$
|
19,490
|
|
|
$
|
19,368
|
|
Accounts payable
|
|
|
360,675
|
|
|
|
372,531
|
|
Accrued expenses
|
|
|
319,329
|
|
|
|
331,814
|
|
Billings in excess of costs and estimated earnings on uncompleted contracts
|
|
|
835,236
|
|
|
|
744,236
|
|
Income taxes payable
|
|
|
69,919
|
|
|
|
55,824
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
1,604,649
|
|
|
|
1,523,773
|
|
|
|
|
|
|
|
|
Long-term debt
|
|
|
203,582
|
|
|
|
185,978
|
|
Deferred income taxes
|
|
|
81,139
|
|
|
|
81,008
|
|
Pension, postretirement and other employee benefits
|
|
|
254,308
|
|
|
|
290,741
|
|
Asbestos-related liability
|
|
|
334,142
|
|
|
|
376,803
|
|
Other long-term liabilities and minority interest
|
|
|
203,843
|
|
|
|
216,916
|
|
Commitments and contingencies
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES
|
|
|
2,681,663
|
|
|
|
2,675,219
|
|
|
|
|
|
|
|
|
Temporary Equity:
|
|
|
|
|
|
|
|
|
Non-vested restricted awards subject to redemption
|
|
|
4,892
|
|
|
|
2,728
|
|
|
|
|
|
|
|
|
TOTAL TEMPORARY EQUITY
|
|
|
4,892
|
|
|
|
2,728
|
|
|
|
|
|
|
|
|
Shareholders Equity:
|
|
|
|
|
|
|
|
|
Preferred shares:
|
|
|
|
|
|
|
|
|
$0.01 par value; authorized: September 26, 2008 - 901,150 shares and
December 28, 2007 - 901,943 shares; issued and
outstanding: September 26, 2008 - 1,094 shares and
December 28, 2007 - 1,887 shares
|
|
|
|
|
|
|
|
|
Common shares:
|
|
|
|
|
|
|
|
|
$0.01 par value; authorized: September 26, 2008 - 296,007,803 shares and
December 28, 2007 - 296,007,011 shares; issued and
outstanding: September 26, 2008 - 142,971,885
shares and December 28, 2007 - 143,877,804 shares
|
|
|
1,430
|
|
|
|
1,439
|
|
Paid-in capital
|
|
|
1,346,884
|
|
|
|
1,385,311
|
|
Accumulated deficit
|
|
|
(127,857
|
)
|
|
|
(554,595
|
)
|
Accumulated other comprehensive loss
|
|
|
(269,446
|
)
|
|
|
(261,114
|
)
|
|
|
|
|
|
|
|
TOTAL SHAREHOLDERS EQUITY
|
|
|
951,011
|
|
|
|
571,041
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES, TEMPORARY EQUITY AND SHAREHOLDERS EQUITY
|
|
$
|
3,637,566
|
|
|
$
|
3,248,988
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
4
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF
CHANGES IN SHAREHOLDERS EQUITY
(in thousands of dollars, except share data)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26, 2008
|
|
|
September 28, 2007
|
|
|
|
Shares
|
|
|
Amount
|
|
|
Shares
|
|
|
Amount
|
|
Preferred Shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of period
|
|
|
1,887
|
|
|
$
|
|
|
|
|
3,658
|
|
|
$
|
|
|
Preferred shares converted into common shares
|
|
|
(793
|
)
|
|
|
|
|
|
|
(290
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
1,094
|
|
|
$
|
|
|
|
|
3,368
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common Shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of period
|
|
|
143,877,804
|
|
|
$
|
1,439
|
|
|
|
138,182,948
|
|
|
$
|
1,382
|
|
Retirement of common shares purchased under common share
repurchase program
|
|
|
(1,285,548
|
)
|
|
|
(13
|
)
|
|
|
|
|
|
|
|
|
Issuance of common shares upon exercise of common share
purchase warrants
|
|
|
85,057
|
|
|
|
1
|
|
|
|
1,799,988
|
|
|
|
18
|
|
Issuance of common shares upon exercise of stock options
|
|
|
128,996
|
|
|
|
1
|
|
|
|
2,905,998
|
|
|
|
29
|
|
Issuance of common shares upon vesting of restricted awards
|
|
|
62,486
|
|
|
|
1
|
|
|
|
684,796
|
|
|
|
7
|
|
Issuance of common shares upon conversion of preferred shares
|
|
|
103,090
|
|
|
|
1
|
|
|
|
37,690
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
142,971,885
|
|
|
$
|
1,430
|
|
|
|
143,611,420
|
|
|
$
|
1,436
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Paid-in Capital:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of period
|
|
|
|
|
|
$
|
1,385,311
|
|
|
|
|
|
|
$
|
1,348,800
|
|
Retirement of common shares purchased under common share
repurchase program
|
|
|
|
|
|
|
(50,014
|
)
|
|
|
|
|
|
|
|
|
Issuance of common shares upon exercise of common share
purchase warrants
|
|
|
|
|
|
|
398
|
|
|
|
|
|
|
|
8,422
|
|
Issuance of common shares upon exercise of stock options
|
|
|
|
|
|
|
2,594
|
|
|
|
|
|
|
|
16,211
|
|
Share-based compensation expense-stock options and
restricted awards
|
|
|
|
|
|
|
8,436
|
|
|
|
|
|
|
|
4,356
|
|
Excess tax benefit related to equity-based incentive program
|
|
|
|
|
|
|
161
|
|
|
|
|
|
|
|
4,130
|
|
Issuance of common shares upon vesting of restricted awards
|
|
|
|
|
|
|
(1
|
)
|
|
|
|
|
|
|
(7
|
)
|
Issuance of common shares upon conversion of preferred shares
|
|
|
|
|
|
|
(1
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
1,346,884
|
|
|
|
|
|
|
$
|
1,381,912
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated Deficit:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of period
|
|
|
|
|
|
$
|
(554,595
|
)
|
|
|
|
|
|
$
|
(944,113
|
)
|
Cumulative effect of adoption of FIN 48
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,356
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of period, as adjusted
|
|
|
|
|
|
|
(554,595
|
)
|
|
|
|
|
|
|
(948,469
|
)
|
Net income for the period
|
|
|
|
|
|
|
426,738
|
|
|
|
|
|
|
|
315,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
(127,857
|
)
|
|
|
|
|
|
$
|
(632,693
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated Other Comprehensive Loss:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of period
|
|
|
|
|
|
$
|
(261,114
|
)
|
|
|
|
|
|
$
|
(343,342
|
)
|
Foreign currency translation adjustments
|
|
|
|
|
|
|
(19,490
|
)
|
|
|
|
|
|
|
19,495
|
|
Net gain/(loss) on derivative instruments designated
as cash flow hedges, net of tax
|
|
|
|
|
|
|
(6
|
)
|
|
|
|
|
|
|
1,279
|
|
Pension and other postretirement benefits, net of tax
|
|
|
|
|
|
|
11,164
|
|
|
|
|
|
|
|
11,882
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
(269,446
|
)
|
|
|
|
|
|
$
|
(310,686
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Shareholders Equity
|
|
|
|
|
|
$
|
951,011
|
|
|
|
|
|
|
$
|
439,969
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
5
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(in thousands of dollars)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Net income
|
|
$
|
127,920
|
|
|
$
|
129,101
|
|
|
$
|
426,738
|
|
|
$
|
315,776
|
|
Foreign currency translation adjustments
|
|
|
(39,749
|
)
|
|
|
10,113
|
|
|
|
(19,490
|
)
|
|
|
19,495
|
|
Net gain/(loss) on derivative instruments designated
as cash flow hedges, net of tax
|
|
|
(3,268
|
)
|
|
|
(587
|
)
|
|
|
(6
|
)
|
|
|
1,279
|
|
Pension and other postretirement benefits, net of tax
|
|
|
3,625
|
|
|
|
3,984
|
|
|
|
11,164
|
|
|
|
11,882
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
$
|
88,528
|
|
|
$
|
142,611
|
|
|
$
|
418,406
|
|
|
$
|
348,432
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
6
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
(in thousands of dollars)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
426,738
|
|
|
$
|
315,776
|
|
Adjustments to reconcile net income to cash flows
from operating activities:
|
|
|
|
|
|
|
|
|
Depreciation and amortization
|
|
|
33,366
|
|
|
|
27,120
|
|
Net asbestos-related provision/(gain)
|
|
|
5,175
|
|
|
|
(8,633
|
)
|
Share-based compensation expense-stock options and restricted awards
|
|
|
10,600
|
|
|
|
5,100
|
|
Excess tax benefit related to equity-based incentive program
|
|
|
(161
|
)
|
|
|
(3,888
|
)
|
Deferred tax
|
|
|
5,499
|
|
|
|
15,146
|
|
Loss/(gain) on sale of assets
|
|
|
831
|
|
|
|
(6,887
|
)
|
Equity in the net earnings of partially-owned affiliates, net of dividends
|
|
|
(4,985
|
)
|
|
|
(23,150
|
)
|
Other noncash items
|
|
|
1,875
|
|
|
|
8,152
|
|
Changes in assets and liabilities:
|
|
|
|
|
|
|
|
|
Increase in receivables
|
|
|
(96,337
|
)
|
|
|
(81,496
|
)
|
Net change in contracts in process and billings in excess
of costs and estimated earnings on uncompleted contracts
|
|
|
40,047
|
|
|
|
(27,663
|
)
|
(Decrease)/increase in accounts payable and accrued expenses
|
|
|
(10,556
|
)
|
|
|
79,347
|
|
Increase in income taxes payable
|
|
|
13,514
|
|
|
|
14,462
|
|
Net change in other assets and liabilities
|
|
|
(17,814
|
)
|
|
|
(71,735
|
)
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
407,792
|
|
|
|
241,651
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
Acquisition of businesses, net of cash acquired
|
|
|
(14,856
|
)
|
|
|
(6,319
|
)
|
Change in restricted cash
|
|
|
(6,143
|
)
|
|
|
(2,848
|
)
|
Capital expenditures
|
|
|
(62,415
|
)
|
|
|
(33,504
|
)
|
Proceeds from sale of assets
|
|
|
718
|
|
|
|
6,732
|
|
Investments in and advances to unconsolidated affiliates
|
|
|
(4,429
|
)
|
|
|
(1,242
|
)
|
Return of investment from unconsolidated affiliates
|
|
|
2,330
|
|
|
|
6,324
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(84,795
|
)
|
|
|
(30,857
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
Repurchase and retirement of common shares
|
|
|
(50,027
|
)
|
|
|
|
|
Distributions to minority third-party ownership interests
|
|
|
(9,625
|
)
|
|
|
(5,179
|
)
|
Proceeds from common share purchase warrant exercises
|
|
|
399
|
|
|
|
8,440
|
|
Proceeds from stock option exercises
|
|
|
2,595
|
|
|
|
16,240
|
|
Excess tax benefit related to equity-based incentive program
|
|
|
161
|
|
|
|
3,888
|
|
Proceeds from issuance of short-term debt
|
|
|
3,658
|
|
|
|
|
|
Proceeds from issuance of long-term debt
|
|
|
25,030
|
|
|
|
330
|
|
Repayment of long-term debt and capital lease obligations
|
|
|
(9,387
|
)
|
|
|
(6,225
|
)
|
|
|
|
|
|
|
|
Net cash (used in)/provided by financing activities
|
|
|
(37,196
|
)
|
|
|
17,494
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of exchange rate changes on cash and cash equivalents
|
|
|
(25,421
|
)
|
|
|
21,222
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Increase in cash and cash equivalents
|
|
|
260,380
|
|
|
|
249,510
|
|
Cash and cash equivalents at beginning of year
|
|
|
1,048,544
|
|
|
|
610,887
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$
|
1,308,924
|
|
|
$
|
860,397
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
7
FOSTER WHEELER LTD. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(amounts in thousands of dollars, except share data and per share amounts)
(unaudited)
1. Summary of Significant Accounting Policies
Basis of Presentation
The accompanying condensed consolidated financial statements are
unaudited. In the opinion of management, all adjustments necessary for a fair presentation of such
financial statements have been included. Such adjustments only consisted of normal recurring
items. Interim results are not necessarily indicative of results for a full year.
The financial statements and notes are presented in accordance with the requirements of Form
10-Q and do not contain certain information included in our annual report on Form 10-K for the
fiscal year ended December 28, 2007 (2007 Form 10-K), filed with the Securities and Exchange
Commission on February 26, 2008. The condensed consolidated balance sheet as of December 28, 2007
was derived from the audited financial statements included in our 2007 Form 10-K, but does not
include all the disclosures required by accounting principles generally accepted in the United
States of America for annual consolidated financial statements. A summary of our significant
accounting policies is presented below.
Principles of Consolidation
The condensed consolidated financial statements include the
accounts of Foster Wheeler Ltd. and all significant domestic and foreign subsidiaries as well as
certain entities in which we have a controlling interest. Intercompany transactions and balances
have been eliminated.
Our fiscal year is the 52- or 53-week annual accounting period ending the last Friday in
December for domestic operations and December 31 for foreign operations. There were 13 weeks in
the third quarter in both fiscal years 2008 and 2007.
Capital Alterations
On January 8, 2008, our shareholders approved an increase in our
authorized share capital at a special general meeting of common shareholders. The increase in
authorized share capital was necessary in order to effect a two-for-one stock split of our common
shares which was approved by our Board of Directors on November 6, 2007. The stock split was
effected on January 22, 2008 in the form of a stock dividend to common shareholders of record at
the close of business on January 8, 2008 in the ratio of one additional Foster Wheeler Ltd. common
share in respect of each common share outstanding. As a result, all references to share capital,
the number of shares, stock options, restricted awards, per share amounts, cash dividends, and any
other reference to shares in the condensed consolidated financial statements, unless otherwise
noted, have been adjusted to reflect the stock split on a retroactive basis.
Use of Estimates
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States of America requires management to make estimates
and assumptions that affect the reported amounts of assets and liabilities at the date of the
financial statements and revenues and expenses during the periods reported. Actual results could
differ from those estimates. Changes in estimates are reflected in the periods in which they
become known. Significant estimates are used when accounting for long-term contracts including
estimates of total costs and customer and vendor claims, employee benefit plan obligations,
share-based compensation plans, uncertain tax positions and deferred taxes, and asbestos
liabilities and expected recoveries, among others.
Revenue Recognition on Long-Term Contracts
Revenues and profits on long-term fixed-price
contracts are recorded under the percentage-of-completion method. Progress towards completion is
measured using physical completion of individual tasks for all contracts with a value of $5,000 or
greater. Progress toward completion of fixed-priced contracts with a value less than $5,000 is
measured using the cost-to-cost method.
Revenues and profits on cost-reimbursable contracts are recorded as the services are rendered
based on the estimated revenue per man-hour, including any incentives assessed as probable. We
include flow-through costs consisting of materials, equipment or subcontractor services as revenue
on cost-reimbursable contracts when we have overall responsibility as the contractor for the
engineering specifications and procurement or procurement services for such costs.
Contracts in process are stated at cost, increased for profits recorded on the completed
effort or decreased for estimated losses, less billings to the customer and progress payments on
uncompleted contracts.
8
We have numerous contracts that are in various stages of completion. Such contracts require
estimates to determine the extent of revenue and profit recognition. These estimates may be
revised from time to time as
additional information becomes available. In accordance with the accounting and disclosure
requirements of the American Institute of Certified Public Accountants Statement of Position
(SOP) 81-1, Accounting for Performance of Construction-Type and Certain Production-Type
Contracts and Statement of Financial Accounting Standards (SFAS) No. 154, Accounting Changes
and Error Correctionsa replacement of APB Opinion No. 20 and FASB Statement No. 3, we review all
of our material contracts monthly and revise our estimates as appropriate. These estimate
revisions, which include both increases and decreases in estimated profit, result from events such
as earning project incentive bonuses or the incurrence or forecasted incurrence of contractual
liquidated damages for performance or schedule issues, providing services and purchasing
third-party materials and equipment at costs differing from those previously estimated and testing
of completed facilities which, in turn, eliminates or confirms completion and warranty-related
costs. Project incentives are recognized when it is probable they will be earned. Project
incentives are frequently tied to cost, schedule and/or safety targets and, therefore, tend to be
earned late in a projects life cycle. There were 26 and 38 separate projects that had final
estimated contract profit revisions whose impact on contract profit exceeded $1,000 during the
first fiscal nine months of 2008 and 2007, respectively. The changes in final estimated contract
profits resulted in net increases to contract profit of $9,120 and $26,070 during the fiscal
quarter and nine months ended September 26, 2008, respectively. The changes in final estimated
contract profits resulted in a net increase to contract profit of $17,980 and $34,120 during the
fiscal quarter and nine months ended September 28, 2007, respectively. The impact on contract
profit is measured as of the beginning of the quarterly and year-to-date periods and represents the
incremental contract profit or loss that would have been recorded in prior periods had we been able
to recognize in those periods the impact of the current period changes in final estimated profits.
Please see Note 11 for further information related to changes in final estimated profits.
Claims are amounts in excess of the agreed contract price (or amounts not included in the
original contract price) that we seek to collect from customers or others for delays, errors in
specifications and designs, contract terminations, disputed or unapproved change orders as to both
scope and price or other causes of unanticipated additional costs. We record claims in accordance
with paragraph 65 of SOP 81-1, which states that recognition of amounts as additional contract
revenue related to claims is appropriate only if it is probable that the claims will result in
additional contract revenue and if the amount can be reliably estimated. Under SOP 81-1, those two
requirements are satisfied by the existence of all of the following conditions: the contract or
other evidence provides a legal basis for the claim; additional costs are caused by circumstances
that were unforeseen at the contract date and are not the result of deficiencies in our
performance; costs associated with the claim are identifiable or otherwise determinable and are
reasonable in view of the work performed; and the evidence supporting the claim is objective and
verifiable. If such requirements are met, revenue from a claim may be recorded only to the extent
that contract costs relating to the claim have been incurred. Costs attributable to claims are
treated as costs of contract performance as incurred and are recorded in contracts in process. As
of September 26, 2008, our condensed consolidated financial statements assumed recovery of
commercial claims of $27,400, of which $800 has yet to be expended. As of December 28, 2007, our
condensed consolidated financial statements assumed recovery of commercial claims of $22,200, of
which $3,700 was yet to be expended.
In certain circumstances, we may defer pre-contract costs when it is probable that these costs
will be recovered under a future contract. Such deferred costs would then be included in contract
costs upon execution of the anticipated contract. We had no material deferred pre-contract costs
as of September 26, 2008 or December 28, 2007.
Certain special-purpose subsidiaries in our global power business group are reimbursed by
customers for their costs, including amounts related to principal repayments of non-recourse
project debt, for building and operating certain facilities over the lives of the corresponding
service contracts.
Cash and Cash Equivalents
Cash and cash equivalents include highly liquid short-term
investments with original maturities of three months or less. Cash and cash equivalents of
$1,003,382 and $800,036 were maintained by our foreign subsidiaries as of September 26, 2008 and
December 28, 2007, respectively. These subsidiaries require a portion of these funds to support
their liquidity and working capital needs, as well as to comply with required minimum
capitalization and contractual restrictions. Accordingly, a portion of these funds may not be
readily available for repatriation to U.S. entities.
9
Trade Accounts Receivable
Trade accounts receivable represent amounts billed to customers.
In accordance with terms under our long-term contracts, our customers may withhold certain
percentages of such billings until completion and acceptance of the work performed. Final payments
of all such amounts withheld might not be received within a one-year period. In conformity with
industry practice, however, the full amount of accounts receivable, including such amounts
withheld, are included in current assets on the condensed consolidated balance sheet.
Trade accounts receivable are continually evaluated for collectibility. Provisions are
established on a project-specific basis when there is an issue associated with the clients ability
to make payments or there are circumstances where the client is not making payment due to
contractual issues.
Contracts in Process and Billings in Excess of Costs and Estimated Earnings on Uncompleted
Contracts
Under long-term contracts, amounts recorded in contracts in process and billings in
excess of costs and estimated earnings on uncompleted contracts may not be realized or paid,
respectively, within a one-year period. In conformity with industry practice, however, the full
amount of contracts in process and billings in excess of costs and estimated earnings on
uncompleted contracts is included in current assets and current liabilities on the condensed
consolidated balance sheet, respectively.
Land, Buildings and Equipment
Depreciation is computed on a straight-line basis using
estimated lives ranging from 10 to 50 years for buildings and from 3 to 35 years for equipment.
Expenditures for maintenance and repairs are charged to expense as incurred. Renewals and
betterments are capitalized. Upon retirement or other disposition of fixed assets, the cost and
related accumulated depreciation are removed from the accounts and the resulting gains or losses,
if any, are reflected in earnings.
Investments in and Advances to Unconsolidated Affiliates
We use the equity method of
accounting for affiliates in which our investment ownership ranges from 20% to 50% unless
significant economic or governance considerations indicate that we are unable to exert significant
influence in which case the cost method is used. The equity method is also used for affiliates in
which our investment ownership is greater than 50% but we do not have a controlling interest.
Currently, all of our investments in affiliates in which our investment ownership is 20% or greater
and that are not consolidated are recorded using the equity method. Affiliates in which our
investment ownership is less than 20% are carried at cost.
Intangible Assets
Intangible assets consist principally of goodwill, trademarks and patents.
Goodwill is allocated to our reporting units on a relative fair value basis at the time of the
original purchase price allocation. Patents and trademarks are amortized on a straight-line basis
over periods of 3 to 40 years. Customer relationships and backlog are amortized on a straight-line
basis over periods of 1 to 15 years.
We test goodwill for impairment at the reporting unit level as defined in SFAS No. 142,
Goodwill and Other Intangible Assets. This test is a two-step process. The first step of the
goodwill impairment test, used to identify potential impairment, compares the fair value of the
reporting unit with its carrying amount, including goodwill. If the fair value, which is estimated
based on discounted future cash flows, exceeds the carrying amount, goodwill is not considered
impaired. If the carrying amount exceeds the fair value, the second step must be performed to
measure the amount of the impairment loss, if any. The second step compares the implied fair value
of the reporting units goodwill with the carrying amount of that goodwill. In the fourth quarter
of each fiscal year, we evaluate goodwill at each reporting unit to assess recoverability, and
impairments, if any, are recognized in earnings. An impairment loss would be recognized in an
amount equal to the excess of the carrying amount of the goodwill over the implied fair value of
the goodwill. SFAS No. 142 also requires that intangible assets with determinable useful lives be
amortized over their respective estimated useful lives and reviewed for impairment in accordance
with SFAS No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets.
In July 2008, we acquired the majority of the assets and work force of an engineering design
company that has an engineering center in Kolkata, India. In conjunction with the acquisition, we
recorded $6,610 of goodwill and $330 of identifiable intangible assets. Please see Note 2 for
further information related to this acquisition.
In February 2008, we acquired a biopharmaceutical engineering company that is based in
Philadelphia, Pennsylvania. In conjunction with the acquisition, we recorded $5,523 of goodwill
and $3,600 of identifiable intangible assets. Please see Note 2 for further information related to
this acquisition.
10
We had total net goodwill of $65,060 and $53,345 as of September 26, 2008 and December 28,
2007, respectively. Of the $65,060 of goodwill as of September 26, 2008, $53,016 is related to our
global power business group and $12,044 is related to our global engineering and construction
group. In fiscal year 2007, the fair value of all reporting units exceeded the carrying amounts
except for a domestic reporting unit, where a goodwill impairment charge of $2,401 was recorded
related to winding down of certain operations.
We had total unamortized identifiable intangible assets of $61,705 and $61,190 as of September
26, 2008 and December 28, 2007, respectively. Of the $61,705 of identifiable intangible assets as
of September 26, 2008, $58,213 is related to our global power business group and $3,492 is related
to our global engineering and construction business group. The following table details amounts
relating to our identifiable intangible assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26, 2008
|
|
|
December 28, 2007
|
|
|
|
Gross
|
|
|
|
|
|
|
Net
|
|
|
Gross
|
|
|
|
|
|
|
Net
|
|
|
|
Carrying
|
|
|
Accumulated
|
|
|
Carrying
|
|
|
Carrying
|
|
|
Accumulated
|
|
|
Carrying
|
|
|
|
Amount
|
|
|
Amortization
|
|
|
Amount
|
|
|
Amount
|
|
|
Amortization
|
|
|
Amount
|
|
Patents
|
|
$
|
39,390
|
|
|
$
|
(22,538
|
)
|
|
$
|
16,852
|
|
|
$
|
39,375
|
|
|
$
|
(21,026
|
)
|
|
$
|
18,349
|
|
Trademarks
|
|
|
63,668
|
|
|
|
(22,065
|
)
|
|
|
41,603
|
|
|
|
63,344
|
|
|
|
(20,503
|
)
|
|
|
42,841
|
|
Customer relationships
and backlog
|
|
|
3,630
|
|
|
|
(380
|
)
|
|
|
3,250
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
106,688
|
|
|
$
|
(44,983
|
)
|
|
$
|
61,705
|
|
|
$
|
102,719
|
|
|
$
|
(41,529
|
)
|
|
$
|
61,190
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization expense related to identifiable intangible assets, which is recorded within cost
of operating revenues on the condensed consolidated statement of
operations, totaled $1,157 and
$3,454 for the fiscal quarter and nine months ended September 26, 2008, respectively. Amortization
expense totaled $912 and $2,720 for the fiscal quarter and nine months ended September 28, 2007,
respectively. Amortization expense is expected to approximate $4,600 each year in the next five
years.
Income Taxes
Deferred tax assets/liabilities are established for the difference between the
financial reporting and income tax basis of assets and liabilities, as well as for operating loss
and tax credit carryforwards. Deferred tax assets are reduced by a valuation allowance when it is
more likely than not that some portion or all of the deferred tax assets will not be realized.
Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates
on the date of enactment.
We do not make a provision for U.S. federal income taxes on foreign subsidiary earnings if we
expect such earnings to be permanently reinvested outside the United States.
We recognize interest accrued on the unrecognized tax benefits in interest expense and
penalties on the unrecognized tax benefits in other deductions, net on our consolidated statement of
operations.
Foreign Currency
The functional currency of our foreign operations is the local currency of
their country of domicile. Assets and liabilities of our foreign subsidiaries are translated into
U.S. dollars at period-end exchange rates with the resulting translation adjustment recorded as a
separate component within accumulated other comprehensive loss. Income and expense accounts and
cash flows are translated at weighted-average exchange rates for the period. Transaction gains and
losses that arise from exchange rate fluctuations on transactions denominated in a currency other
than the functional currency are included in other income, net and other deductions, net, based on
the net transaction gain or loss during each of the fiscal nine months ended September 26, 2008 and
September 28, 2007.
We maintain a foreign currency risk-management strategy that uses foreign currency forward
contracts to protect us from unanticipated fluctuations in cash flows that may arise from
volatility in currency exchange rates between the functional currencies of our subsidiaries and the
foreign currencies in which some of our operating purchases and sales are denominated. We utilize
these contracts solely to hedge specific foreign currency exposures, whether or not they qualify
for hedge accounting under SFAS No. 133, Accounting for Derivative Instruments and Hedging
Activities. During the fiscal quarters and nine months ended September 26, 2008 and September 28,
2007, none of the contracts met the requirements for hedge accounting under SFAS No. 133.
Accordingly, we recorded pretax foreign exchange losses of $(2,313) and $(1,326) for the fiscal
quarter and nine months ended September 26, 2008, respectively. Similarly, we recorded a pretax
foreign exchange gain/(loss) of $(90) and $576 for the fiscal quarter and nine months ended
September 28, 2007, respectively. These amounts were recorded in the following line items on the
condensed consolidated statement of operations for the periods indicated:
11
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Cost of operating revenues
|
|
$
|
(2,550
|
)
|
|
$
|
(54
|
)
|
|
$
|
(1,239
|
)
|
|
$
|
674
|
|
Other income/(deductions)
|
|
|
237
|
|
|
|
(36
|
)
|
|
|
(87
|
)
|
|
|
(98
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pretax gain/(loss)
|
|
$
|
(2,313
|
)
|
|
$
|
(90
|
)
|
|
$
|
(1,326
|
)
|
|
$
|
576
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The mark-to-market adjustments on foreign exchange contracts for these unrealized gains or
losses are recorded in either contracts in process or billings in excess of costs and estimated
earnings on uncompleted contracts on the condensed consolidated balance sheet.
During the fiscal nine months ended September 26, 2008 and September 28, 2007, we included net
cash inflows on the settlement of derivatives of $6,353 and $4,280, respectively, within the net
change in contracts in process and billings in excess of costs and estimated earnings on
uncompleted contracts, a component of cash flows from operating activities in the condensed
consolidated statement of cash flows.
Interest Rate Risk
We use interest rate swap contracts to manage interest rate risk
associated with some of our variable rate special-purpose limited recourse project debt. Certain
of our affiliates in which we have an equity interest also use interest rate swap contracts to
manage interest rate risk associated with their limited recourse project debt. Upon entering into
the swap contracts, we designate the interest rate swaps as cash flow hedges in accordance with
SFAS No. 133. We assess at inception, and on an ongoing basis, whether the interest rate swaps are
highly effective in offsetting changes in the cash flows of the project debt. Consequently, we
record the fair value of our interest rate swap contracts in our condensed consolidated balance
sheet at each balance sheet date. Changes in the fair value of the interest rate swap contracts
are recorded as a component of comprehensive income on our condensed consolidated statement of
comprehensive income. As of September 26, 2008 and December 28, 2007, we had net gains on the swap
contracts of $1,667 and $1,673, respectively, which were recorded net of tax provisions of $632 and
$635, respectively, and were included in accumulated other comprehensive loss on the condensed
consolidated balance sheet.
Retirement of Common Shares under Common Share Repurchase Program
On September 12, 2008, we
announced a share repurchase program pursuant to which our Board of Directors authorized the
repurchase of up to $750,000 of our outstanding common shares. Any repurchases will be made at our
discretion in the open market or in privately negotiated transactions in compliance with applicable
securities laws and other legal requirements and will depend on a variety of factors, including
market conditions, share price and other factors. The program does not obligate us to acquire any
particular number of common shares. The program has no expiration date and may be suspended or
discontinued at any time. Any repurchases made pursuant to the share repurchase program will be
funded using our cash on hand.
All common shares acquired under our common share repurchase program are immediately retired
upon purchase. The common share value, on the condensed consolidated balance sheet, is reduced for
the par value of the retired common shares. Paid-in capital, on the condensed consolidated
balance sheet, is reduced for the excess of fair value and related fees paid above par value for
the common shares acquired.
Common shares retired under the common share repurchase program reduce the weighted-average
number of common shares outstanding during the reporting period when calculating earnings per
common share, as described below.
Earnings per Common Share
Basic earnings per common share is computed by dividing net income
by the weighted-average number of common shares outstanding during the reporting period, excluding
non-vested restricted shares of 82,980 and 165,960 as of September 26, 2008 and September 28, 2007,
respectively. Restricted shares and restricted share units (collectively, restricted awards) are
included in the weighted-average number of common shares outstanding when such restricted awards
vest.
Diluted earnings per common share is computed by dividing net income by the combination of the
weighted-average number of common shares outstanding during the reporting period and the impact of
dilutive securities, if any, such as outstanding stock options, warrants to purchase common shares
and the non-vested portion of restricted awards to the extent such securities are dilutive.
12
In profitable periods, outstanding stock options and warrants have a dilutive effect under the
treasury stock method when the average common share price for the period exceeds the assumed
proceeds from the exercise of the warrant or option. The assumed proceeds include the exercise
price, compensation cost, if any, for future service that has not yet been recognized in the
condensed consolidated statement of operations, and any tax benefits that would be recorded in
paid-in capital when the option or warrant is exercised. Under the treasury stock method, the
assumed proceeds are assumed to be used to repurchase common shares in the current period. The
dilutive impact of the non-vested portion of restricted awards is determined using the treasury
stock method, but the proceeds include only the unrecognized compensation cost and tax benefits as
assumed proceeds.
The computations of basic and diluted earnings per common share were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Basic earnings per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
127,920
|
|
|
$
|
129,101
|
|
|
$
|
426,738
|
|
|
$
|
315,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average number of common shares outstanding
for basic earnings per common share
|
|
|
144,030,570
|
|
|
|
142,517,528
|
|
|
|
143,980,815
|
|
|
|
141,034,618
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic earnings per common share
|
|
$
|
0.89
|
|
|
$
|
0.91
|
|
|
$
|
2.96
|
|
|
$
|
2.24
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted earnings per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
127,920
|
|
|
$
|
129,101
|
|
|
$
|
426,738
|
|
|
$
|
315,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average number of common shares outstanding
for basic earnings per common share
|
|
|
144,030,570
|
|
|
|
142,517,528
|
|
|
|
143,980,815
|
|
|
|
141,034,618
|
|
Effect of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Options to purchase common shares
|
|
|
451,516
|
|
|
|
672,578
|
|
|
|
560,480
|
|
|
|
1,153,288
|
|
Warrants to purchase common shares
|
|
|
558,564
|
|
|
|
1,640,534
|
|
|
|
589,065
|
|
|
|
2,134,916
|
|
Non-vested portion of restricted awards
|
|
|
158,946
|
|
|
|
261,824
|
|
|
|
219,571
|
|
|
|
243,272
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted-average number of common shares outstanding
for diluted earnings per common share
|
|
|
145,199,596
|
|
|
|
145,092,464
|
|
|
|
145,349,931
|
|
|
|
144,566,094
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted earnings per common share
|
|
$
|
0.88
|
|
|
$
|
0.89
|
|
|
$
|
2.94
|
|
|
$
|
2.18
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The following table summarizes the common share equivalent of potentially dilutive securities
that have been excluded from the denominator used in the calculation of diluted earnings per common
share due to their antidilutive effect:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Common shares issuable under outstanding options not included
in the computation of diluted earnings per common share
because the assumed proceeds were greater than the average
common share price for the period
|
|
|
526,600
|
|
|
|
165,736
|
|
|
|
478,221
|
|
|
|
357,756
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13
Share-Based Compensation Plans
Our share-based compensation plans are accounted for in
accordance with the provisions of SFAS No. 123R, Share-Based Payment. We estimate the fair value
of each option award on the date of grant using the Black-Scholes option valuation model. We then
recognize the grant date fair value of each option as compensation expense ratably using the
straight-line attribution method over the service period (generally the vesting period). The
Black-Scholes model incorporates the following assumptions:
|
|
|
Expected volatility we estimate the volatility of our common share price at the
date of grant using historical volatility adjusted for periods of unusual stock price
activity.
|
|
|
|
|
Expected term we estimate the expected term of options granted to our chief
executive officer based on a combination of vesting schedules, contractual life of the
option, past history and estimates of future exercise behavior patterns as outlined in
SFAS No. 123R. For grants to other employees and the remaining directors, we estimate
the expected term using the simplified method, as outlined in Staff Accounting
Bulletin No. 107, Share-Based Payment.
|
|
|
|
|
Risk-free interest rate we estimate the risk-free interest rate using the U.S.
Treasury yield curve for periods equal to the expected term of the options in effect at
the time of grant.
|
|
|
|
|
Dividends we use an expected dividend yield of zero because we have not declared
or paid a cash dividend since July 2001 and we do not have any plans to declare or pay
any cash dividends.
|
We used the following weighted-average assumptions to estimate the fair value of the options
granted for the periods indicated:
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
September 26,
|
|
September 28,
|
|
|
2008
|
|
2007
|
Expected volatility
|
|
45.99%
|
|
42.59%
|
Expected term
|
|
3.6 years
|
|
3.2 years
|
Risk-free interest rate
|
|
2.16%
|
|
4.47%
|
Expected dividend yield
|
|
0%
|
|
0%
|
We estimate the fair value of restricted awards using the market price of our common shares on
the date of grant. We then recognize the fair value of each restricted award as compensation cost
ratably using the straight-line attribution method over the service period (generally the vesting
period).
We estimate pre-vesting forfeitures at the time of grant using a combination of historical
data and demographic characteristics, and we revise those estimates in subsequent periods if actual
forfeitures differ from those estimates. We record share-based compensation expense only for those
awards that are expected to vest.
Recent Accounting Developments
In September 2006, the Financial Accounting Standards Board
(FASB) issued SFAS No. 157, Fair Value Measurements. SFAS No. 157 defines fair value,
establishes a framework for measuring fair value in generally accepted accounting principles, and
expands disclosures about fair value measurements. The standard is effective for financial assets
and liabilities, as well as for any other assets and liabilities that are required to be measured
at fair value on a recurring basis, in financial statements for fiscal years beginning after
November 15, 2007. In February 2008, the FASB issued a partial one-year deferral of SFAS No. 157
for nonfinancial assets and liabilities that are only subject to fair value measurement on a
nonrecurring basis. We have elected to defer the application of SFAS No. 157 for our nonfinancial
assets and liabilities measured at fair value on a nonrecurring basis until the fiscal year
beginning December 27, 2008, and are in the process of assessing its impact on our financial
position and results of operations related to such assets and liabilities. Our financial assets
and liabilities that are recorded at fair value consist primarily of the assets or liabilities
arising from derivative financial instruments. The adoption of SFAS No. 157 did not have a
material effect on our financial position or results of operations.
SFAS No. 157 defines fair value as the price that would be received to sell an asset or paid
to transfer a liability in an orderly transaction between market participants at the measurement
date. We utilize market data or assumptions that we believe market participants would use in
pricing the asset or liability, including assumptions about risk and the risks inherent in the
inputs to the valuation technique. These inputs can be readily observable, market corroborated or
generally unobservable.
14
SFAS No. 157 establishes a fair value hierarchy that prioritizes the inputs used to measure
fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets
for identical assets or liabilities and
the lowest priority to unobservable inputs. The three levels of the fair value hierarchy
defined by SFAS No. 157 are as follows:
|
|
|
Level 1: Quoted prices are available in active markets for identical assets or
liabilities as of the reporting date.
|
|
|
|
Level 2: Pricing inputs are other than quoted prices in active markets included in
Level 1, which may include quoted prices for similar instruments in active markets,
quoted prices for identical or similar instruments in markets that are not active or
model-derived valuations whose inputs are observable or whose significant value drivers
are observable, either directly or indirectly through market corroboration, for
substantially the full term of the financial instrument. Level 2 instruments are
valued based on pricing inputs as of the reporting date.
|
|
|
|
|
Level 3: Pricing inputs include significant inputs that are generally less
observable from objective sources. These inputs may be used with internally developed
methodologies that result in managements best estimate of fair value from the
perspective of a market participant.
|
We utilize foreign currency forward contracts to protect us from unanticipated fluctuations in
cash flows that may arise from volatility in currency exchange rates. We also use interest rate
swap contracts to manage interest rate risk associated with some of our variable rate debt. The
foreign currency forward contracts and interest rate swap contracts are valued using broker
quotations, or market transactions in either the listed or over-the-counter markets. As such,
these derivative instruments are classified within level 2.
The following table sets forth our financial assets and liabilities that were accounted for at
fair value on a recurring basis as of September 26, 2008:
|
|
|
|
|
|
|
September 26,
|
|
|
2008
|
Assets:
|
|
|
|
|
Foreign currency forward contracts
|
|
$
|
10,784
|
|
Interest rate swap contracts
|
|
|
2,744
|
|
|
|
|
|
|
Liabilities:
|
|
|
|
|
Foreign currency forward contracts
|
|
|
8,033
|
|
Interest rate swap contracts
|
|
|
445
|
|
In December 2007, the FASB issued SFAS No. 141 (revised 2007), Business Combinations. SFAS
No. 141R replaces SFAS No. 141, Business Combinations and changes the accounting treatment for
business acquisitions. SFAS No. 141R requires the acquiring entity in a business combination to
recognize all (and only) the assets acquired and liabilities assumed in the transaction and
establishes the acquisition-date fair value as the measurement objective for all assets acquired
and liabilities assumed in a business combination. Certain provisions of this standard will, among
other things, impact the determination of acquisition-date fair value of consideration paid in a
business combination (including contingent consideration); exclude transaction costs from
acquisition accounting; and change accounting practices for acquired contingencies,
acquisition-related restructuring costs, in-process research and development, indemnification
assets, and tax benefits. Most of the provisions of SFAS No. 141R apply prospectively to business
combinations for which the acquisition date is on or after the beginning of the first annual
reporting period beginning on or after December 15, 2008. Early adoption is not permitted. We are
currently assessing the impact that SFAS No. 141R may have on our financial position, results of
operations and cash flows.
15
In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated
Financial Statements an amendment of ARB No. 51. SFAS No. 160 amends the accounting and
reporting standards for the noncontrolling interest in a subsidiary (often referred to as minority
interest) and for the deconsolidation of a subsidiary. Under SFAS No. 160, the noncontrolling
interest in a subsidiary is reported as equity in the parent companys consolidated financial
statements. SFAS No. 160 also requires that the parent companys consolidated statement of
operations include both the parent and noncontrolling interest share of the subsidiarys statement
of operations. Formerly, the noncontrolling interest share was shown as a reduction of income on
the parents consolidated statement of operations. SFAS No. 160 is effective for fiscal years, and
interim periods within those fiscal years, beginning on or after December 15, 2008. SFAS No. 160 is
to be applied prospectively as of the beginning of the fiscal year in which this statement is
initially applied; however, presentation and disclosure requirements shall be applied
retrospectively for all periods presented. We do not believe that SFAS No. 160 will have a
significant impact on our financial position, results of operations and cash flows.
In March 2008, the FASB issued SFAS No. 161, Disclosures about Derivative Instruments and
Hedging Activities. SFAS No. 161 requires enhanced disclosures to enable investors to better
understand the effects of derivative instruments and hedging activities on an entitys financial
position, financial performance and cash flows. SFAS No. 161 changes the disclosure requirements
about the location and amounts of derivative instruments in an entitys financial statements, how
derivative instruments and related hedged items are accounted for under SFAS No. 133, and how
derivative instruments and related hedged items affect the companys financial position, financial
performance and cash flows. Additionally, SFAS No. 161 requires disclosure of the fair values of
derivative instruments and their gains and losses in a tabular format. SFAS No. 161 also requires
more information about an entitys liquidity by requiring disclosure of derivative features that
are credit risk-related. Finally, SFAS No. 161 requires cross-referencing within the footnotes to
enable financial statement users to locate important information about derivative instruments. SFAS
No. 161 is effective for financial statements issued for fiscal years and interim periods beginning
after November 15, 2008, with early application encouraged. We are currently assessing the impact
that SFAS No. 161 may have on our financial statement disclosures.
2. Business Combinations
In July 2008, we acquired the majority of the assets and work force of an engineering design
company for $6,500, plus up to $1,500 to be paid if certain performance milestones are met over the
following two years. This company, which has an engineering center in Kolkata, India, provides
engineering services to the petrochemical, refining, upstream oil and gas, and power industries.
The purchase price allocation and pro forma information for this acquisition were not material to
our condensed consolidated financial statements. This companys financial results are included
within our global engineering and construction business segment.
In February 2008, we acquired all of the outstanding capital stock of a biopharmaceutical
engineering company, based in Philadelphia, Pennsylvania, for $8,545 plus up to $3,638 to be paid
over the following three years if certain conditions are met, plus up to an additional $8,700 to be
paid if certain performance milestones are met over the following three years. This company
provides design, engineering, manufacture, installation, validation and startup/commissioning
services to the life sciences industry. The purchase price allocation and pro forma information
for this acquisition were not material to our condensed consolidated financial statements. This
companys financial results are included within our global engineering and construction business
segment.
In February 2007, we purchased the stock of a Finnish company that owns patented coal flow
measuring technology. The purchase price, net of cash acquired was
1,112 (approximately $1,473 at
the exchange rate in effect at the time of the acquisition). The purchase price allocation and pro
forma financial information for this acquisition were not material to our condensed consolidated
financial statements. This companys financial results are included within our global power
business segment.
16
We own a noncontrolling equity interest in two electric power generation projects, one
waste-to-energy project and one wind farm project in Italy and in a refinery/electric power
generation project in Chile. We also own a 50% noncontrolling equity interest in an Italian
project which generates earnings from royalty payments linked to the price of natural gas. The two
electric power generation projects in Italy are each 42% owned by us, the waste-to-energy project
is 39% owned by us and the wind farm project is 50% owned by us. The project in Chile is 85% owned
by us; however, we do not have a controlling interest in the Chilean project as a result of
participating rights held by the minority shareholder. We account for these investments in Italy
and Chile under the equity method. The following is summarized financial information for these
entities (each as a whole) in which we have an equity interest:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26, 2008
|
|
December 28, 2007
|
|
|
Italian
|
|
Chilean
|
|
Italian
|
|
Chilean
|
|
|
Projects
|
|
Project
|
|
Projects
|
|
Project
|
Balance Sheet Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current assets
|
|
$
|
281,616
|
|
|
$
|
49,207
|
|
|
$
|
294,482
|
|
|
$
|
49,353
|
|
Other assets (primarily buildings and equipment)
|
|
|
657,868
|
|
|
|
139,411
|
|
|
|
656,796
|
|
|
|
146,665
|
|
Current liabilities
|
|
|
32,304
|
|
|
|
21,140
|
|
|
|
72,009
|
|
|
|
21,044
|
|
Other liabilities (primarily long-term debt)
|
|
|
586,506
|
|
|
|
70,950
|
|
|
|
576,545
|
|
|
|
81,696
|
|
Net assets
|
|
|
320,674
|
|
|
|
96,528
|
|
|
|
302,724
|
|
|
|
93,278
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
September 26, 2008
|
|
September 28, 2007
|
|
|
Italian
|
|
Chilean
|
|
Italian
|
|
Chilean
|
|
|
Projects
|
|
Project
|
|
Projects
|
|
Project
|
Income Statement Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$
|
126,499
|
|
|
$
|
16,385
|
|
|
$
|
102,776
|
|
|
$
|
27,881
|
|
Gross earnings
|
|
|
29,373
|
|
|
|
10,590
|
|
|
|
40,982
|
|
|
|
19,774
|
|
Income before income taxes
|
|
|
15,287
|
|
|
|
9,017
|
|
|
|
37,880
|
|
|
|
18,193
|
|
Net earnings/(loss)
|
|
|
(5,570
|
)
|
|
|
7,485
|
|
|
|
23,362
|
|
|
|
18,193
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
September 26, 2008
|
|
September 28, 2007
|
|
|
Italian
|
|
Chilean
|
|
Italian
|
|
Chilean
|
|
|
Projects
|
|
Project
|
|
Projects
|
|
Project
|
Income Statement Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$
|
357,244
|
|
|
$
|
68,459
|
|
|
$
|
247,517
|
|
|
$
|
51,528
|
|
Gross earnings
|
|
|
100,725
|
|
|
|
40,967
|
|
|
|
70,513
|
|
|
|
30,420
|
|
Income before income taxes
|
|
|
61,759
|
|
|
|
37,244
|
|
|
|
61,947
|
|
|
|
25,242
|
|
Net earnings
|
|
|
24,225
|
|
|
|
30,913
|
|
|
|
37,973
|
|
|
|
25,242
|
|
Our share of equity in the net earnings of these partially-owned affiliates, which is recorded
within other income, net on the condensed consolidated statement of operations, totaled $2,202 and
$27,082 for the fiscal quarter and nine months ended September 26, 2008, respectively. Similarly,
our share of equity in the net earnings of these partially-owned affiliates totaled $18,935 and
$29,503 for the fiscal quarter and nine months ended September 28, 2007, respectively.
Our investment in these equity affiliates, which is recorded within investments in and
advances to unconsolidated affiliates on the condensed consolidated balance sheet, totaled $200,726
and $190,887 as of
September 26, 2008 and December 28, 2007, respectively. Distributions of $24,452 and $10,946
were received during the fiscal nine months ended September 26, 2008 and September 28, 2007,
respectively.
17
We have guaranteed certain performance obligations of the Chilean project. We have a
contingent obligation, which is measured annually based on the operating results of the Chilean
project for the preceding year. We did not have a current payment obligation under this guarantee
as of December 28, 2007.
We also have guaranteed the obligations of our subsidiary under the Chilean projects
operations and maintenance agreement. The guarantee is limited to $20,000 over the life of the
operations and maintenance agreement, which extends through 2016. No amounts have ever been paid
under the guarantee.
In addition, we have provided a $10,000 debt service reserve letter of credit to cover debt
service payments in the event that the Chilean project does not generate sufficient cash flow to
make such payments. We are required to maintain the debt service reserve letter of credit during
the term of the Chilean projects debt, which matures in 2014. As of September 26, 2008, no
amounts have been drawn under this letter of credit.
Under the Chilean projects operations and maintenance agreement, our subsidiary provides
services for the management, operation and maintenance of the refinery/electric power generation
facility. Our fees for these services were $2,328 and $6,984 for the fiscal quarter and nine
months ended September 26, 2008, respectively, and were $2,077 and $6,231 for the fiscal quarter
and nine months ended September 28, 2007, respectively. Our fees for these services were recorded
in operating revenues on our condensed consolidated statement of operations. We had a receivable
from our partially-owned affiliate in Chile of $9,300 and $6,168 recorded in trade accounts and
notes receivable on our condensed consolidated balance sheet as of September 26, 2008 and December
28, 2007, respectively.
18
4. Long-term Debt
The following table shows the components of our long-term debt:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26, 2008
|
|
|
December 28, 2007
|
|
|
|
Current
|
|
|
Long-term
|
|
|
Total
|
|
|
Current
|
|
|
Long-term
|
|
|
Total
|
|
Capital Lease Obligations
|
|
$
|
1,376
|
|
|
$
|
65,940
|
|
|
$
|
67,316
|
|
|
$
|
1,318
|
|
|
$
|
67,095
|
|
|
$
|
68,413
|
|
Special-Purpose Limited Recourse Project Debt:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Camden County Energy Recovery Associates
|
|
|
9,648
|
|
|
|
31,779
|
|
|
|
41,427
|
|
|
|
9,648
|
|
|
|
31,779
|
|
|
|
41,427
|
|
FW Power S.r.L.
|
|
|
|
|
|
|
68,565
|
|
|
|
68,565
|
|
|
|
|
|
|
|
45,041
|
|
|
|
45,041
|
|
Energia Holdings, LLC
|
|
|
4,675
|
|
|
|
16,426
|
|
|
|
21,101
|
|
|
|
4,144
|
|
|
|
21,101
|
|
|
|
25,245
|
|
Subordinated Robbins Facility Exit Funding Obligations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1999C Bonds at 7.25% interest, due October 15, 2009
|
|
|
18
|
|
|
|
19
|
|
|
|
37
|
|
|
|
18
|
|
|
|
19
|
|
|
|
37
|
|
1999C Bonds at 7.25% interest, due October 15, 2024
|
|
|
|
|
|
|
20,491
|
|
|
|
20,491
|
|
|
|
|
|
|
|
20,491
|
|
|
|
20,491
|
|
1999D Accretion Bonds at 7% interest, due October 15, 2009
|
|
|
|
|
|
|
301
|
|
|
|
301
|
|
|
|
|
|
|
|
286
|
|
|
|
286
|
|
Intermediate Term Loans in China at 7.02% interest
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,107
|
|
|
|
|
|
|
|
4,107
|
|
Term Loan in China at 6.57% interest, due December 28, 2008
|
|
|
3,650
|
|
|
|
|
|
|
|
3,650
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other
|
|
|
123
|
|
|
|
61
|
|
|
|
184
|
|
|
|
133
|
|
|
|
166
|
|
|
|
299
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
19,490
|
|
|
$
|
203,582
|
|
|
$
|
223,072
|
|
|
$
|
19,368
|
|
|
$
|
185,978
|
|
|
$
|
205,346
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Domestic Senior Credit Agreement
In October 2006, we executed a five-year domestic senior
credit agreement to be used for our domestic and foreign operations. The senior credit agreement,
as amended in May 2007, provides for a facility of $450,000, and includes a provision which permits
future incremental increases of up to $100,000 in total availability under the facility. We can
issue up to $450,000 under the letter of credit facility. A portion of the letters of credit
issued under the domestic senior credit agreement have performance pricing that is decreased (or
increased) as a result of improvements (or reductions) in the credit rating of the domestic senior
credit agreement as reported by Moodys Investors Service and/or Standard & Poors (S&P). We
also have the option to use up to $100,000 of the $450,000 for revolving borrowings at a rate equal
to adjusted LIBOR plus 1.50%, subject also to the performance pricing noted above. As a result of
the improvement in our S&P credit rating in March 2007, we have achieved the lowest possible
pricing under the performance pricing provisions of our domestic senior credit agreement.
We had $291,775 and $245,765 of letters of credit outstanding under this agreement as of
September 26, 2008 and December 28, 2007, respectively. The letter of credit fees ranged from
1.50% to 1.60% of the outstanding
amount, excluding a fronting fee of 0.125% per annum. There were no funded borrowings under
this agreement as of September 26, 2008 or December 28, 2007.
Subsequent to the fiscal quarter and nine months ended September 26, 2008, we and the
requisite lenders under our domestic senior credit agreement amended the domestic senior credit
agreement, effective September 29, 2008 to allow us to use cash up to $750,000 to repurchase our
outstanding common shares and increase the limit of permissible capital expenditures. Please see
Note 13 for further information related to the amended domestic senior credit agreement.
Subsequent to the fiscal quarter and nine months ended September 26, 2008, we acquired $19,208
of our Subordinated Robbins Facility Exit Funding Obligations, 1999C Bonds due October 15, 2024
(1999C Robbins Bonds) on October 3, 2008 for $19,016 of cash, plus accrued and unpaid interest to
date. Please see Note 13 for further information related to the acquisition of the 1999C Robbins
Bonds.
19
5. Pensions and Other Postretirement Benefits
We have defined benefit pension plans in the United States, the United Kingdom, France, Canada
and Finland, and we have other postretirement benefit plans for health care and life insurance
benefits in the United States and Canada.
Pension Benefits
Our defined benefit pension plans cover certain full-time employees. Under
the plans, retirement benefits are primarily a function of both years of service and level of
compensation. The components of benefit cost/(income) for our pension plans are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarter Ended September 26, 2008
|
|
|
Fiscal Quarter Ended September 28, 2007
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
Net periodic benefit cost/(income):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
|
|
|
$
|
2,614
|
|
|
$
|
177
|
|
|
$
|
2,791
|
|
|
$
|
|
|
|
$
|
3,541
|
|
|
$
|
156
|
|
|
$
|
3,697
|
|
Interest cost
|
|
|
4,991
|
|
|
|
12,197
|
|
|
|
475
|
|
|
|
17,663
|
|
|
|
4,758
|
|
|
|
11,441
|
|
|
|
427
|
|
|
|
16,626
|
|
Expected return on plan assets
|
|
|
(6,035
|
)
|
|
|
(11,976
|
)
|
|
|
(388
|
)
|
|
|
(18,399
|
)
|
|
|
(5,517
|
)
|
|
|
(12,156
|
)
|
|
|
(451
|
)
|
|
|
(18,124
|
)
|
Amortization of transition
(asset)/obligation
|
|
|
|
|
|
|
(14
|
)
|
|
|
25
|
|
|
|
11
|
|
|
|
|
|
|
|
(15
|
)
|
|
|
24
|
|
|
|
9
|
|
Amortization of prior service cost
|
|
|
|
|
|
|
1,233
|
|
|
|
5
|
|
|
|
1,238
|
|
|
|
|
|
|
|
1,312
|
|
|
|
5
|
|
|
|
1,317
|
|
Amortization of net actuarial loss
|
|
|
696
|
|
|
|
4,105
|
|
|
|
116
|
|
|
|
4,917
|
|
|
|
821
|
|
|
|
4,337
|
|
|
|
168
|
|
|
|
5,326
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net periodic benefit cost/(income)
|
|
$
|
(348
|
)
|
|
$
|
8,159
|
|
|
$
|
410
|
|
|
$
|
8,221
|
|
|
$
|
62
|
|
|
$
|
8,460
|
|
|
$
|
329
|
|
|
$
|
8,851
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes recognized in other
comprehensive income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of transition
asset/(obligation)
|
|
$
|
|
|
|
$
|
14
|
|
|
$
|
(25
|
)
|
|
$
|
(11
|
)
|
|
$
|
|
|
|
$
|
15
|
|
|
$
|
(24
|
)
|
|
$
|
(9
|
)
|
Amortization of prior service cost
|
|
|
|
|
|
|
(1,233
|
)
|
|
|
(5
|
)
|
|
|
(1,238
|
)
|
|
|
|
|
|
|
(1,312
|
)
|
|
|
(5
|
)
|
|
|
(1,317
|
)
|
Amortization of net actuarial loss
|
|
|
(696
|
)
|
|
|
(4,105
|
)
|
|
|
(116
|
)
|
|
|
(4,917
|
)
|
|
|
(821
|
)
|
|
|
(4,337
|
)
|
|
|
(168
|
)
|
|
|
(5,326
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income recognized in other
comprehensive income
|
|
$
|
(696
|
)
|
|
$
|
(5,324
|
)
|
|
$
|
(146
|
)
|
|
$
|
(6,166
|
)
|
|
$
|
(821
|
)
|
|
$
|
(5,634
|
)
|
|
$
|
(197
|
)
|
|
$
|
(6,652
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended September 26, 2008
|
|
|
Fiscal Nine Months Ended September 28, 2007
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
Net periodic benefit cost/(income):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
|
|
|
$
|
8,031
|
|
|
$
|
536
|
|
|
$
|
8,567
|
|
|
$
|
|
|
|
$
|
10,449
|
|
|
$
|
455
|
|
|
$
|
10,904
|
|
Interest cost
|
|
|
14,971
|
|
|
|
37,500
|
|
|
|
1,468
|
|
|
|
53,939
|
|
|
|
14,274
|
|
|
|
33,742
|
|
|
|
1,218
|
|
|
|
49,234
|
|
Expected return on plan assets
|
|
|
(18,106
|
)
|
|
|
(36,815
|
)
|
|
|
(1,252
|
)
|
|
|
(56,173
|
)
|
|
|
(16,549
|
)
|
|
|
(35,852
|
)
|
|
|
(1,281
|
)
|
|
|
(53,682
|
)
|
Amortization of transition
(asset)/obligation
|
|
|
|
|
|
|
(43
|
)
|
|
|
74
|
|
|
|
31
|
|
|
|
|
|
|
|
(46
|
)
|
|
|
67
|
|
|
|
21
|
|
Amortization of prior service cost
|
|
|
|
|
|
|
3,792
|
|
|
|
15
|
|
|
|
3,807
|
|
|
|
|
|
|
|
3,869
|
|
|
|
14
|
|
|
|
3,883
|
|
Amortization of net actuarial loss
|
|
|
2,090
|
|
|
|
12,623
|
|
|
|
345
|
|
|
|
15,058
|
|
|
|
2,464
|
|
|
|
12,965
|
|
|
|
475
|
|
|
|
15,904
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
SFAS No. 87 net
periodic benefit cost/(income)
|
|
|
(1,045
|
)
|
|
|
25,088
|
|
|
|
1,186
|
|
|
|
25,229
|
|
|
|
189
|
|
|
|
25,127
|
|
|
|
948
|
|
|
|
26,264
|
|
SFAS No. 88 cost*
|
|
|
|
|
|
|
|
|
|
|
644
|
|
|
|
644
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net periodic benefit cost/(income)
|
|
$
|
(1,045
|
)
|
|
$
|
25,088
|
|
|
$
|
1,830
|
|
|
$
|
25,873
|
|
|
$
|
189
|
|
|
$
|
25,127
|
|
|
$
|
948
|
|
|
$
|
26,264
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes recognized in other
comprehensive income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of transition
asset/(obligation)
|
|
$
|
|
|
|
$
|
43
|
|
|
$
|
(74
|
)
|
|
$
|
(31
|
)
|
|
$
|
|
|
|
$
|
46
|
|
|
$
|
(67
|
)
|
|
$
|
(21
|
)
|
Amortization of prior service cost
|
|
|
|
|
|
|
(3,792
|
)
|
|
|
(15
|
)
|
|
|
(3,807
|
)
|
|
|
|
|
|
|
(3,869
|
)
|
|
|
(14
|
)
|
|
|
(3,883
|
)
|
Amortization of net actuarial loss
|
|
|
(2,090
|
)
|
|
|
(12,623
|
)
|
|
|
(345
|
)
|
|
|
(15,058
|
)
|
|
|
(2,464
|
)
|
|
|
(12,965
|
)
|
|
|
(475
|
)
|
|
|
(15,904
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income recognized in other
comprehensive income
|
|
$
|
(2,090
|
)
|
|
$
|
(16,372
|
)
|
|
$
|
(434
|
)
|
|
$
|
(18,896
|
)
|
|
$
|
(2,464
|
)
|
|
$
|
(16,788
|
)
|
|
$
|
(556
|
)
|
|
$
|
(19,808
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
*
|
|
Charges were recorded in accordance with the provisions of SFAS No. 88, Accounting for
Settlements and Curtailments of Defined Benefit Pension Plans and for Termination Benefits,
related to the settlement of obligations to former employees in Canada of $644 in the fiscal nine
months ended September 26, 2008.
|
The U.S. pension plans, which are frozen to new entrants and additional benefit accruals, and
the Canadian, Finnish and French plans are non-contributory. The U.K. plan, which is closed to new
entrants, is contributory.
20
Based on the funded status at fiscal year-end 2007 and upon our most recent annual valuation
report, we do not expect to be required to make any mandatory contributions to our U.S. pension
plans in fiscal year 2008. We made mandatory contributions of approximately $24,700 to our foreign
pension plans during the fiscal nine months ended September 26, 2008. We expect to make total
mandatory contributions of approximately $32,700 to our foreign plans in fiscal year 2008. We may
elect to make discretionary contributions to our U.S. and U.K. pension plans during the fiscal
fourth quarter of 2008.
Other Postretirement Benefits
Certain employees in the United States and Canada may become
eligible for health care and life insurance benefits (other postretirement benefits) if they
qualify for and commence normal or early retirement pension benefits as defined in the U.S. and
Canadian pension plans while working for us. Additionally, one of our subsidiaries in the United
States also has a benefit plan, referred to as the Survivor Income Plan (SIP), which provides
coverage for an employees beneficiary upon the death of the employee. This plan has been closed
to new entrants since 1988.
The components of benefit cost for our other postretirement plans, including the SIP, are as
follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Net periodic postretirement benefit cost:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
35
|
|
|
$
|
36
|
|
|
$
|
106
|
|
|
$
|
105
|
|
Interest cost
|
|
|
1,156
|
|
|
|
1,191
|
|
|
|
3,470
|
|
|
|
3,572
|
|
Amortization of prior service credit
|
|
|
(1,165
|
)
|
|
|
(1,191
|
)
|
|
|
(3,496
|
)
|
|
|
(3,571
|
)
|
Amortization of net actuarial loss
|
|
|
117
|
|
|
|
238
|
|
|
|
350
|
|
|
|
714
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic postretirement benefit cost
|
|
$
|
143
|
|
|
$
|
274
|
|
|
$
|
430
|
|
|
$
|
820
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes recognized in other
comprehensive income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of prior service credit
|
|
$
|
1,165
|
|
|
$
|
1,191
|
|
|
$
|
3,496
|
|
|
$
|
3,571
|
|
Amortization of net actuarial loss
|
|
|
(117
|
)
|
|
|
(238
|
)
|
|
|
(350
|
)
|
|
|
(714
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total loss recognized in other
comprehensive income
|
|
$
|
1,048
|
|
|
$
|
953
|
|
|
$
|
3,146
|
|
|
$
|
2,857
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6. Guarantees and Warranties
We have agreed to indemnify certain third parties relating to businesses and/or assets that we
previously owned and sold to such third parties. Such indemnifications relate primarily to
potential environmental and tax exposures for activities conducted by us prior to the sale of such
businesses and/or assets. It is not possible to predict the maximum potential amount of future
payments under these or similar indemnifications due to the conditional nature of the obligations
and the unique facts and circumstances involved in each particular indemnification.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Maximum
|
|
Carrying Amount of Liability
|
|
|
Potential
|
|
September 26,
|
|
December 28,
|
|
|
Payment
|
|
2008
|
|
2007
|
Environmental indemnifications
|
|
No limit
|
|
$
|
8,200
|
|
|
$
|
6,900
|
|
Tax indemnifications
|
|
No limit
|
|
$
|
|
|
|
$
|
|
|
We also maintain contingencies for warranty expenses on certain of our long-term contracts.
Generally, warranty contingencies are accrued over the life of the contract so that a sufficient
balance is maintained to cover our aggregate exposure at the conclusion of the project.
21
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
Warranty
Liability
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
$
|
87,800
|
|
|
$
|
69,900
|
|
Accruals
|
|
|
34,900
|
|
|
|
25,100
|
|
Settlements
|
|
|
(5,000
|
)
|
|
|
(10,800
|
)
|
Adjustments to provisions
|
|
|
(15,200
|
)
|
|
|
(6,600
|
)
|
|
|
|
|
|
|
|
Balance at end of period
|
|
$
|
102,500
|
|
|
$
|
77,600
|
|
|
|
|
|
|
|
|
We are contingently liable for performance under standby letters of credit, bank guarantees
and surety bonds totaling $953,300 and $818,600 as of September 26, 2008 and December 28, 2007,
respectively. These balances include the standby letters of credit issued under the domestic
senior credit agreement discussed in Note 4 and from other facilities worldwide. No material
claims have been made against these guarantees.
We have also guaranteed certain performance obligations in a Chilean refinery/electric power
generation project in which we hold a noncontrolling equity interest. See Note 3 for further
information.
7. Preferred Shares
We issued 599,944 preferred shares in connection with our 2004 equity-for-debt exchange.
There were approximately 1,094 preferred shares outstanding as of September 26, 2008. Each
preferred share is convertible at the holders option into 130 common shares, or up to
approximately 142,273 additional common shares if all outstanding preferred shares as of September
26, 2008 are converted.
The preferred shareholders have no voting rights except in certain limited circumstances. The
preferred shares have the right to receive dividends and other distributions, including liquidating
distributions, on an as-if-converted basis when and if declared and paid on the common shares. The
preferred shares have a $0.01 liquidation preference per share.
8. Share-Based Compensation Plans
Our share-based compensation plans include both restricted awards and stock option awards.
Compensation cost for our share-based plans of $3,956 and $10,600 was charged against income for
the fiscal quarter and nine months ended September 26, 2008, respectively. The related income tax
benefit recognized in the condensed consolidated statements of operations and comprehensive income
was $82 and $240 for the fiscal quarter and nine months ended September 26, 2008, respectively.
Compensation cost for our share-based plans of $1,732 and $5,100 was charged against income for the
fiscal quarter and nine months ended September 28, 2007, respectively. The related income tax
benefit recognized in the condensed consolidated statements of operations and comprehensive income
was $22 and $65 for the fiscal quarter and nine months ended September 28, 2007, respectively. We
received $2,595 and $16,240 in cash from option exercises under our share-based compensation plans
for the fiscal nine months ended September 26, 2008 and September 28, 2007, respectively.
As of September 26, 2008, we had $8,885 and $10,038 of total unrecognized compensation cost
related to stock options and restricted awards, respectively. Those costs are expected to be
recognized as expense over a weighted-average period of approximately 21 months.
9. Common Share Purchase Warrants
In connection with the equity-for-debt exchange consummated in 2004, we issued 4,152,914 Class
A common share purchase warrants and 40,771,560 Class B common share purchase warrants. Each Class
A warrant entitles its owner to purchase 3.3682 common shares at an exercise price of $4.689 per
common share thereunder, subject to the terms of the warrant agreement between the warrant agent
and us. The Class A warrants are exercisable on or before September 24, 2009. Each Class B
warrant entitled its owner to purchase 0.1446 common shares at an exercise price of $4.689 per
common share thereunder, subject to the terms and conditions of the warrant agreement between the
warrant agent and us. The Class B warrants were exercisable on or before September 24, 2007.
22
In January 2006, we completed transactions that increased the number of common shares to be
delivered upon the exercise of our Class A and Class B common share purchase warrants during the
offer period and raised $75,336 in net proceeds. The exercise price per warrant was not increased
in the offers. Holders of approximately 95% of the Class A warrants and 57% of the Class B
warrants participated in the offers resulting in the aggregate issuance of approximately 16,807,000
common shares.
Cumulatively through September 26, 2008, 3,970,840 Class A warrants and 38,730,407 Class B
warrants have been exercised for 19,724,589 common shares. The number of common shares issuable
upon the exercise of the remaining outstanding Class A warrants is approximately 613,262 as of
September 26, 2008. The remaining outstanding Class B warrants expired on September 24, 2007.
The holders of the Class A warrants are not entitled to vote, to receive dividends or to
exercise any of the rights of common shareholders for any purpose until such warrants have been
duly exercised. We currently maintain and intend to continue to maintain at all times during which
the warrants are exercisable, a shelf registration statement relating to the issuance of common
shares underlying the warrants for the benefit of the warrant holders, subject to the terms of the
registration rights agreement. The registration statement became effective on December 28, 2005
and will be updated by December 28, 2008.
Also in connection with the equity-for-debt exchange consummated in 2004, we entered into a
registration rights agreement with certain selling security holders in which we agreed to file a
registration statement to cover resales of our securities held by them immediately following the
exchange offer. We filed a registration statement in accordance with this agreement on October 29,
2004. The registration statement, which became effective on December 23, 2004 and updated on March
22, 2006, must remain in effect until December 23, 2009 unless certain events occur to terminate
our obligations under the registration rights agreement prior to that date. We plan to update the
registration statement by March 22, 2009. If we fail to maintain the registration statement as
required or it becomes unavailable for more than two 45-day periods in any consecutive 12-month
period, we are required to pay damages at a rate of $13.7 per day for each day that the
registration statement is not effective. As of September 26, 2008, the maximum exposure under this
provision was approximately $5,000. We have not incurred, and do not expect to incur, any damages
under the registration rights agreement.
10. Income Taxes
Our effective tax rate is dependent on the location and amount of our taxable earnings and the
effects of changes in valuation allowances. Our effective tax rates for the fiscal quarters and
nine months ended September 26, 2008 and September 28, 2007 were lower than the U.S. statutory rate
of 35% due principally to:
|
|
|
Income earned in tax jurisdictions with tax rates lower than the U.S. statutory
rate, which is expected to contribute to an approximate twelve-percentage point
reduction in the effective tax rate for the full year 2008; and
|
|
|
|
|
A valuation allowance decrease which is expected to contribute to an approximate
six-percentage point reduction in the effective tax rate for the full year 2008. A
decrease in our valuation allowance occurred in the fiscal quarter and nine months
ended September 26, 2008 because we recognized earnings in jurisdictions where we
continue to maintain a full valuation allowance (primarily the United States and
Finland).
|
These factors which reduce the effective tax rate were partially offset by our inability to
recognize a tax benefit for losses subject to valuation allowance in certain other jurisdictions
and other permanent differences.
As we currently have positive earnings in most jurisdictions, we evaluate, on a quarterly
basis, the need for the valuation allowances against deferred tax assets in those jurisdictions in
which we currently maintain a valuation allowance. Such evaluation includes a review of all
available evidence, both positive and negative, in determining whether a valuation allowance is
necessary. If the trend for positive earnings continues in those jurisdictions where we have
recorded a valuation allowance (primarily the United States and Finland), we may conclude that a
valuation allowance is no longer needed in either or both jurisdictions.
23
Our subsidiaries file income tax returns in numerous tax jurisdictions, including the United
States, several U.S. states and numerous non-U.S. jurisdictions around the world. Tax returns are
also filed in jurisdictions where our subsidiaries execute project-related work. The statute of
limitations varies by the various jurisdictions in which we operate. Because of the number of
jurisdictions in which we file tax returns, in any given year the statute of limitations in certain
jurisdictions may expire without examination within the 12-month period from the balance sheet
date. As a result, we expect recurring changes in unrecognized tax benefits due to the expiration
of the statute of limitations, none of which are expected to be individually significant. With few
exceptions, we are no longer subject to U.S. (including federal, state and local) or non-U.S.
income tax examinations by tax authorities for years before fiscal year 2002.
During the fiscal quarter ended June 27, 2008, we settled a tax audit in the Asia Pacific
region which resulted in a $3,200 reduction of unrecognized tax benefits and a corresponding
reduction in the provision for income taxes. A number of tax years are also under audit by the
relevant state and foreign tax authorities. We anticipate that several of these audits may be
concluded in the foreseeable future, including in fiscal year 2008. Based on the status of these
audits, it is reasonably possible that the conclusion of the audits may result in a reduction of
unrecognized tax benefits. However, it is not possible to estimate the impact of this change at
this time.
We recognize interest accrued on the unrecognized tax benefits in interest expense and
penalties on the unrecognized tax benefits in other deductions, net on our condensed consolidated
statement of operations. During the fiscal quarter and nine months ended September 26, 2008, we
recorded net interest expense and net penalties of $330 and $853, respectively, of which the amount
for the fiscal nine months ended September 26, 2008 is net of $3,518 of previously accrued tax
penalties which were ultimately not assessed. During the fiscal quarter and nine months ended
September 28, 2007, we recorded $1,074 and $1,874 in interest expense and penalties, respectively.
11. Business Segments
We operate through two business groups: our
Global Engineering and Construction Group
(Global
E&C Group) and our
Global Power Group
.
Global Engineering and Construction Group
Our Global E&C Group, which operates worldwide, designs, engineers and constructs onshore and
offshore upstream oil and gas processing facilities, natural gas liquefaction facilities and
receiving terminals, gas-to-liquids facilities, oil refining, chemical and petrochemical,
pharmaceutical and biotechnology facilities and related infrastructure, including power generation
and distribution facilities, and gasification facilities. Our Global E&C Group is also involved in
the design of facilities in new or developing market sectors, including carbon capture and storage,
solid fuel-fired integrated gasification combined-cycle power plants, coal-to-liquids,
coal-to-chemicals and biofuels. Our Global E&C Group generates revenues from engineering,
procurement and construction activities pursuant to contracts spanning up to approximately four
years in duration and from returns on its equity investments in various power production
facilities.
Our Global E&C Group provides the following services:
|
|
|
Design, engineering, project management, construction and construction management
services, including the procurement of equipment, materials and services from third-party
suppliers and contractors.
|
|
|
|
|
Environmental remediation services, together with related technical, engineering, design
and regulatory services.
|
|
|
|
|
Development, engineering, procurement, construction, ownership and operation of power
generation facilities, from conventional and renewable sources, and waste-to-energy
facilities in Europe.
|
24
Global Power Group
Our Global Power Group designs, manufactures and erects steam generating and auxiliary
equipment for electric power generating stations and industrial facilities worldwide and owns
and/or operates several cogeneration, independent power production and waste-to-energy facilities,
as well as power generation facilities for the process and petrochemical industries. Our Global
Power Group generates revenues from engineering activities, equipment supply, construction
contracts, operating and maintenance agreements, royalties from licensing its technology, and from
returns on its investments in various power production facilities.
Our Global Power Groups steam generating equipment includes a full range of technologies,
offering independent power producers, utilities and industrial clients high-value technology
solutions for converting a wide range of fuels, such as coal, petroleum coke, oil, gas, biomass and
municipal solid waste, into steam, which can be used for power generation, district heating and in
industrial processes.
Our Global Power Group offers several other products and services related to steam generators:
|
|
|
Design, manufacture and installation of auxiliary equipment, which includes feedwater
heaters, steam condensers and heat-recovery equipment.
|
|
|
|
|
A full line of new and retrofit nitrogen-oxide (NO
x
) reduction systems such
as selective non-catalytic and catalytic NO
x
reduction systems as well as
complete low NO
x
combustion systems.
|
|
|
|
|
A broad range of steam generator site services, including construction and erection
services, engineering, plant upgrading and life extensions.
|
|
|
|
|
Research, analysis and experimental work in fluid dynamics, heat transfer, combustion,
fuel technology, materials engineering and solid mechanics.
|
Corporate and Finance Group
In addition to these two business groups, which also represent operating segments for
financial reporting purposes, we report corporate center expenses and expenses related to certain
legacy liabilities, such as asbestos, in the Corporate and Finance Group (C&F Group), which we
also treat as an operating segment for financial reporting purposes.
EBITDA is the primary measure of operating performance used by our chief operating decision
maker.
25
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
C&F
|
|
|
|
Total
|
|
|
E&C Group
|
|
|
Power Group
|
|
|
Group
(1)
|
|
Fiscal quarter ended September 26, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
1,718,355
|
|
|
$
|
1,287,405
|
|
|
$
|
430,950
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(2)
|
|
$
|
165,243
|
|
|
$
|
122,828
|
|
|
$
|
64,753
|
|
|
$
|
(22,338
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(5,193
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(11,080
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
148,970
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(21,050
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
127,920
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal quarter ended September 28, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
1,299,872
|
|
|
$
|
951,402
|
|
|
$
|
348,470
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(3)
|
|
$
|
178,977
|
|
|
$
|
129,232
|
|
|
$
|
58,390
|
|
|
$
|
(8,645
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(4,716
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(9,721
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
164,540
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(35,439
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
129,101
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal nine months ended September 26, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
5,215,101
|
|
|
$
|
3,928,136
|
|
|
$
|
1,286,965
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(4)
|
|
$
|
580,991
|
|
|
$
|
412,976
|
|
|
$
|
197,547
|
|
|
$
|
(29,532
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(16,204
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(33,366
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
531,421
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(104,683
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
426,738
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal nine months ended September 28, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
3,641,760
|
|
|
$
|
2,626,816
|
|
|
$
|
1,014,944
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(5)
|
|
$
|
459,872
|
|
|
$
|
395,364
|
|
|
$
|
99,780
|
|
|
$
|
(35,272
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(14,652
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(27,120
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
418,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(102,324
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
315,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Includes general corporate income and expense, our captive insurance operation and the
elimination of transactions and balances related to intercompany interest.
|
|
(2)
|
|
Includes in the fiscal quarter ended September 26, 2008: increased/(decreased) contract
profit of $9,120 from the regular re-evaluation of final estimated contract profits*: $12,750
in our Global E&C Group and $(3,630) in our Global Power Group; and a charge of $1,725 in our
C&F Group on the revaluation of our asbestos liability and related asset resulting from our
rolling 15-year asbestos liability estimate.
|
|
(3)
|
|
Includes in the fiscal quarter ended September 28, 2007: increased contract profit of $17,980
from the regular re-evaluation of final estimated contract profits*: $10,810 in our Global E&C
Group and $7,170 in our Global
Power Group; and a gain of $8,633 in our C&F Group on the settlement of coverage litigation with
two asbestos insurance carriers.
|
|
(4)
|
|
Includes in the fiscal nine months ended September 26, 2008: increased/(decreased) contract
profit of $26,070 from the regular re-evaluation of final estimated contract profits*: $35,770
in our Global E&C Group and $(9,700) in our Global Power Group; a gain of $35,913 in our C&F
Group on the settlement of coverage litigation with two asbestos insurance carriers; and a
charge of $5,175 in our C&F Group on the revaluation of our asbestos liability and related
asset resulting from our rolling 15-year asbestos liability estimate.
|
26
|
|
|
(5)
|
|
Includes in the fiscal nine months ended September 28, 2007: increased/(decreased) contract
profit of $34,120 from the regular re-evaluation of final estimated contract profits*: $50,550
in our Global E&C Group and $(16,430) in our Global Power Group; and a gain of $8,633 in our
C&F Group on the settlement of coverage litigation with two asbestos insurance carriers.
|
|
*
|
|
Please refer to Revenue Recognition on Long-Term Contracts in Note 1 regarding changes in
our final estimated contract profits.
|
The accounting policies of our business segments are the same as those described in our
summary of significant accounting policies. The only significant intersegment transactions relate
to interest on intercompany balances. We account for interest on those arrangements as if they
were third party transactionsi.e. at current market rates, and we include the elimination of that
activity in the results of the C&F Group.
Operating revenues by industry were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
2008
|
|
|
2007
|
|
|
2008
|
|
|
2007
|
|
Power generation
|
|
$
|
412,228
|
|
|
$
|
353,098
|
|
|
$
|
1,229,081
|
|
|
$
|
999,347
|
|
Oil refining
|
|
|
438,843
|
|
|
|
370,048
|
|
|
|
1,198,499
|
|
|
|
975,531
|
|
Pharmaceutical
|
|
|
21,267
|
|
|
|
40,571
|
|
|
|
55,376
|
|
|
|
133,267
|
|
Oil and gas
|
|
|
431,059
|
|
|
|
213,567
|
|
|
|
1,392,904
|
|
|
|
669,259
|
|
Chemical/petrochemical
|
|
|
365,460
|
|
|
|
272,568
|
|
|
|
1,196,405
|
|
|
|
718,328
|
|
Power plant operation and maintenance
|
|
|
32,128
|
|
|
|
31,153
|
|
|
|
98,034
|
|
|
|
90,678
|
|
Environmental
|
|
|
8,089
|
|
|
|
16,126
|
|
|
|
23,753
|
|
|
|
40,305
|
|
Other, net of eliminations
|
|
|
9,281
|
|
|
|
2,741
|
|
|
|
21,049
|
|
|
|
15,045
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total third-party revenues
|
|
$
|
1,718,355
|
|
|
$
|
1,299,872
|
|
|
$
|
5,215,101
|
|
|
$
|
3,641,760
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12. Litigation and Uncertainties
Asbestos
Some of our U.S. and U.K. subsidiaries are defendants in numerous asbestos-related lawsuits
and out-of-court informal claims pending in the United States and United Kingdom. Plaintiffs claim
damages for personal injury alleged to have arisen from exposure to or use of asbestos in
connection with work allegedly performed by our subsidiaries during the 1970s and earlier.
United States
A summary of U.S. claim activity is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Number of Claims
|
|
|
Fiscal Quarters Ended
|
|
Fiscal Nine Months Ended
|
|
|
September 26,
|
|
September 28,
|
|
September 26,
|
|
September 28,
|
|
|
2008
|
|
2007
|
|
2008
|
|
2007
|
Open claims at beginning of period
|
|
|
130,740
|
|
|
|
133,580
|
|
|
|
131,340
|
|
|
|
135,890
|
|
New claims
|
|
|
860
|
|
|
|
1,080
|
|
|
|
3,710
|
|
|
|
4,160
|
|
Claims resolved
|
|
|
(1,230
|
)
|
|
|
(1,850
|
)
|
|
|
(4,680
|
)
|
|
|
(7,240
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Open claims at end of period
|
|
|
130,370
|
|
|
|
132,810
|
|
|
|
130,370
|
|
|
|
132,810
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
We had the following U.S. asbestos-related assets and liabilities recorded on our condensed
consolidated balance sheet as of the dates set forth below. Total U.S. asbestos-related
liabilities are estimated through the fiscal third quarter of 2023. Although it is likely that
claims will continue to be filed after that date, the uncertainties inherent in any long-term
forecast prevent us from making reliable estimates of the indemnity and defense costs that might be
incurred after that date.
27
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
|
December 28,
|
|
|
|
2008
|
|
|
2007
|
|
Asbestos-related assets recorded within:
|
|
|
|
|
|
|
|
|
Accounts and notes receivable-other
|
|
$
|
41,200
|
|
|
$
|
47,100
|
|
Asbestos-related insurance recovery receivable
|
|
|
244,500
|
|
|
|
279,100
|
|
|
|
|
|
|
|
|
Total asbestos-related assets
|
|
$
|
285,700
|
|
|
$
|
326,200
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asbestos-related liabilities recorded within:
|
|
|
|
|
|
|
|
|
Accrued expenses
|
|
$
|
63,000
|
|
|
$
|
72,000
|
|
Asbestos-related liability
|
|
|
290,900
|
|
|
|
331,300
|
|
|
|
|
|
|
|
|
Total asbestos-related liabilities
|
|
$
|
353,900
|
|
|
$
|
403,300
|
|
|
|
|
|
|
|
|
Since fiscal year-end 2004, we have worked with Analysis, Research & Planning Corporation
(ARPC), nationally recognized consultants in projecting asbestos liabilities, to estimate the
amount of asbestos-related indemnity and defense costs at year-end for the next 15 years. Based on
its review of fiscal year 2007 activity, ARPC recommended that the assumptions used to estimate our
future asbestos liability be updated as of fiscal year-end 2007. Accordingly, we developed a
revised estimate of our indemnity and defense costs through fiscal year-end 2022 considering the
advice of ARPC. In the fiscal fourth quarter of 2007, we increased our liability for asbestos
indemnity and defense costs through fiscal year-end 2022 to $403,300, which brought our liability
to a level consistent with ARPCs reasonable best estimate. In connection with updating our
estimated asbestos liability and related asset, we recorded a charge of $7,400 in the fiscal fourth
quarter of 2007. Our estimated asbestos liability increased during the fiscal nine months ended
September 26, 2008 by $6,400, which represents the rolling 15-year asbestos-related liability
estimate, and was reduced by payments amounting to approximately $55,800.
The amount paid for asbestos litigation, defense and case resolution was $18,600 and $55,800
for the fiscal quarter and nine months ended September 26, 2008, respectively, and $21,800 and
$66,700 for the fiscal quarter and nine months ended September 28, 2007, respectively. In fiscal
year 2008, proceeds from settlements with our insurers exceeded payments made by $10,600 and
$21,800 in the fiscal quarter and nine months ended September 26, 2008, respectively. We funded
$1,500 and $30,500 of the payments made during the fiscal quarter and nine months ended September
28, 2007, respectively, while all remaining amounts were paid from insurance proceeds. Through
September 26, 2008, total cumulative indemnity costs paid were approximately $652,200 and total
cumulative defense costs paid were approximately $277,300.
As of September 26, 2008, total asbestos-related liabilities were comprised of an estimated
liability of $130,000 relating to open (outstanding) claims being valued and an estimated liability
of $223,900 relating to future unasserted claims through the fiscal third quarter of 2023.
Our liability estimate is based upon the following information and/or assumptions: number of
open claims, forecasted number of future claims, estimated average cost per claim by disease type -
mesothelioma, lung cancer and non-malignancies and the breakdown of known and future claims into
disease type mesothelioma, lung cancer or non-malignancies. The total estimated liability, which
has not been discounted for the time value of money, includes both the estimate of forecasted
indemnity amounts and forecasted defense costs. Total defense costs and indemnity liability
payments are estimated to be incurred through the fiscal third quarter of 2023, during which period
the incidence of new claims is forecasted to decrease each year. We believe that it is likely that
there will be new claims filed after the fiscal third quarter of 2023, but in light of
uncertainties inherent in long-term forecasts, we do not believe that we can reasonably estimate
the indemnity and defense costs that might be incurred after the fiscal third quarter of 2023.
Historically, defense costs have represented approximately 29.8% of total defense and indemnity
costs.
The overall historic average combined indemnity and defense cost per resolved claim through
September 26, 2008 has been approximately $2.7. The average cost per resolved claim is increasing
and we believe will continue to increase in the future.
28
The asbestos-related asset recorded within accounts and notes receivable-other as of September
26, 2008 reflects amounts due in the next 12 months under executed settlement agreements with
insurers and does not include any estimate for future settlements. The recorded asbestos-related
insurance recovery receivable includes an estimate of recoveries from insurers in the unsettled
insurance coverage litigation referred to below based upon the application of New Jersey law to
certain insurance coverage issues and assumptions relating to cost allocation and other factors as
well as an estimate of the amount of recoveries under existing settlements with other insurers.
Such amounts have not been discounted for the time value of money.
Since fiscal year-end 2005, we have worked with Peterson Risk Consulting, nationally
recognized experts in the estimation of insurance recoveries, to review our estimate of the value
of the settled insurance asset and assist in the estimation of our unsettled asbestos insurance
asset. Based on insurance policy data, historical claim data, future liability estimates including
the expected timing of payments and allocation methodology assumptions we provided them, Peterson
Risk Consulting provided an analysis of the unsettled insurance asset as of September 26, 2008. We
utilized that analysis to determine our estimate of the value of the unsettled insurance asset as
of September 26, 2008.
As of September 26, 2008, we estimated the value of our unsettled asbestos insurance asset
related to ongoing litigation in New York state court with our subsidiaries insurers at $23,300.
The litigation relates to the amounts of insurance coverage available for asbestos-related claims
and the proper allocation of the coverage among our subsidiaries various insurers and our
subsidiaries as self-insurers. We believe that any amounts that our subsidiaries might be
allocated as self-insurer would be immaterial.
An adverse outcome in the pending insurance litigation described above could limit our
remaining insurance recoveries and result in a reduction in our insurance asset. However, a
favorable outcome in all or part of the litigation could increase remaining insurance recoveries
above our current estimate. If we prevail in whole or in part in the litigation, we will re-value
our asset relating to remaining available insurance recoveries based on the asbestos liability
estimated at that time.
Over the last several years, certain of our subsidiaries have entered into settlement
agreements calling for insurers to make lump-sum payments, as well as payments over time, for use
by our subsidiaries to fund asbestos-related indemnity and defense costs and, in certain cases, for
reimbursement for portions of out-of-pocket costs previously incurred.
In the fiscal nine months ended September 28, 2007, our subsidiaries reached agreements to
settle their disputed asbestos-related insurance coverage with two additional insurers. We
recorded a gain of $8,600 for these settlements in the fiscal nine months ended September 28, 2007,
of which both settlements occurred in the third fiscal quarter.
In the fiscal nine months ended September 26, 2008, our subsidiaries reached agreements to
settle their disputed asbestos-related insurance coverage with two additional insurers. We
recorded a gain of $35,900 for these settlements in the fiscal nine months ended September 26,
2008, of which both settlements occurred prior to the third fiscal quarter. We received cash of
$40,500 from these 2008 settlements during the fiscal nine months ended September 26, 2008.
We intend to continue to attempt to negotiate additional settlements where achievable on a
reasonable basis in order to minimize the amount of future costs that we would be required to fund
out of the cash flow generated from our operations. Unless we settle with the remaining insurers
at recovery amounts significantly in excess of our current estimate, it is likely that the amount
of our insurance settlements will not cover all future asbestos-related costs and we will be
required to fund a portion of such future costs, which will reduce our cash flows and working
capital.
In fiscal year 2006, we were successful in our appeal of a New York state trial court decision
that previously had held that New York, rather than New Jersey, law applies in the above coverage
litigation with our subsidiaries insurers, and as a result, we increased our insurance asset and
recorded a gain of $19,500. On February 13, 2007, our subsidiaries insurers were granted
permission by the appellate court to appeal the decision to the New York Court of Appeals, the
states highest court. On October 11, 2007, the New York Court of Appeals upheld the appellate
court decision in our favor.
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Even if the coverage litigation is resolved in a manner favorable to us, our insurance
recoveries (both from the litigation and from settlements) may be limited by insolvencies among our
insurers. We have not assumed recovery in the estimate of our asbestos insurance asset from any of
our currently insolvent insurers. Other insurers may become insolvent in the future and our
insurers may fail to reimburse amounts owed to us on a timely basis. Failure to realize the
expected insurance recoveries, or delays in receiving material amounts from our insurers, could
have a material adverse effect on our financial condition and our cash flows.
Based on the fiscal year-end 2007 liability estimate, an increase of 25% in the average per
claim indemnity settlement amount would increase the liability by $70,400 and the impact on expense
would be dependent upon available insurance recoveries. Assuming no change to the assumptions
currently used to estimate our insurance asset, this increase would result in a charge in the
statement of operations in the range of approximately 70% to 80% of the increase in the liability.
Long-term cash flows would ultimately change by the same amount. Should there be an increase in
the estimated liability in excess of this 25%, the percentage of that increase that would be
expected to be funded by additional insurance recoveries will decline.
We had net cash inflows of $21,800 as a result of insurance settlement proceeds in excess of
the asbestos liability indemnity payments and defense costs during the fiscal nine months ended
September 26, 2008. We expect to have net cash inflows of $17,400 as a result of insurance
settlement proceeds in excess of the asbestos liability indemnity and defense costs for the full
twelve months of fiscal year 2008. This estimate assumes no additional settlements with insurance
companies or elections by us to fund additional payments. As we continue to collect cash from
insurance settlements and assuming no increase in our asbestos-related insurance liability or any
future insurance settlements, the asbestos-related insurance receivable recorded on our condensed
consolidated balance sheet will continue to decrease.
The estimate of the liabilities and assets related to asbestos claims and recoveries is
subject to a number of uncertainties that may result in significant changes in the current
estimates. Among these are uncertainties as to the ultimate number and type of claims filed, the
amounts of claim costs, the impact of bankruptcies of other companies with asbestos claims,
uncertainties surrounding the litigation process from jurisdiction to jurisdiction and from case to
case, as well as potential legislative changes. Increases in the number of claims filed or costs
to resolve those claims could cause us to increase further the estimates of the costs associated
with asbestos claims and could have a material adverse effect on our financial condition, results
of operations and cash flows.
United Kingdom
Some of our subsidiaries in the United Kingdom have also received claims alleging personal
injury arising from exposure to asbestos. To date, 889 claims have been brought against our U.K.
subsidiaries of which 347 remained open as of September 26, 2008. None of the settled claims has
resulted in material costs to us.
As of September 26, 2008, we had recorded total liabilities of $46,000 comprised of an
estimated liability relating to open (outstanding) claims of $7,600 and an estimated liability
relating to future unasserted claims through the fiscal third quarter of 2023 of $38,400. Of the
total, $2,800 was recorded in accrued expenses and $43,200 was recorded in asbestos-related
liability on the condensed consolidated balance sheet. An asset in an equal amount was recorded
for the expected U.K. asbestos-related insurance recoveries, of which $2,800 was recorded in
accounts and notes receivable-other and $43,200 was recorded as asbestos-related insurance recovery
receivable on the condensed consolidated balance sheet. The liability estimates are based on a
U.K. House of Lords judgment that pleural plaque claims do not amount to a compensable injury and
accordingly, we have reduced our liability assessment. If this ruling is reversed by legislation,
the total asbestos liability and related asset recorded in the U.K. would be approximately $62,200.
Project Claims
In the ordinary course of business, we are parties to litigation involving clients and
subcontractors arising out of project contracts. Such litigation includes claims and counterclaims
by and against us for canceled contracts, for additional costs incurred in excess of current
contract provisions, as well as for back charges for alleged breaches of warranty and other
contract commitments. If we were found to be liable for any of the claims/counterclaims against
us, we would incur a charge against earnings to the extent a reserve had not been established for
the matter in our accounts or if the liability exceeds established reserves.
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Power Plant Arbitration Eastern Europe
In June 2006, we commenced arbitration against a client seeking final payment for our services
in connection with two power plants that we designed and built in Eastern Europe. The dispute
primarily concerns whether we are liable to the client for liquidated damages (LDs) under the
contract for delayed completion of the projects. The client contends that it is owed LDs, limited
under the contract at approximately
37,600 (approximately $54,900 at the exchange rate in
effect as of September 26, 2008), and is retaining as security for these LDs approximately
22,000 (approximately $32,200 at the exchange rate in effect as of September 26, 2008) in
contract payments otherwise due to us for work performed. The client contends that it is owed an
additional
6,900 (approximately $10,100 at the exchange rate in effect as of September 26,
2008) for the cost of consumable materials it had to incur due to the extended commissioning period
on both projects, the cost to relocate a piece of equipment on one of the projects and the cost of
various warranty repairs and punch list work. We are seeking payment of the
22,000
(approximately $32,200 at the exchange rate in effect as of September 26, 2008 and which is
recorded within contracts in process on the condensed consolidated balance sheet) in retention that
is being held by the client for LDs, plus approximately
4,900 (approximately $7,200 at the
exchange rate in effect as of September 26, 2008) in interest on the retained funds, as well as
approximately
9,100 (approximately $13,300 at the exchange rate in effect as of September 26,
2008) in additional compensation for extra work performed beyond the original scope of the
contracts and the clients failure to procure the required property insurance for the project,
which should have provided coverage for some of the damages we incurred on the project related to
turbine repairs. In October 2008, a liability award by the arbitration panel in our favor was
received. The award includes amounts that are fixed and amounts that require substantiation at a
hearing on damages, which has not yet been scheduled by the panel. With estimated interest
to be awarded at the damages hearing, we believe the fixed amount awarded will be in line with our
previously estimated recovery.
Power Plant Dispute Ireland
In 2006, a dispute arose with a client because of material corrosion that is occurring at two
power plants we designed and built in Ireland, which began operation in December 2005 and June
2006. The boilers at both plants are designed to burn milled peat as the primary fuel, supplied
from different local sources. The peat being supplied is out of the range specified by our
contract and, while the matter is still under investigation, we believe this variation from the
agreed specifications is the cause of alkali halides corrosion that is affecting the boiler tubes.
We have identified a technical solution to ameliorate the boiler tube corrosion, and we and the
client are in the process of evaluating the proposed solution for the boiler tube corrosion in
light of continued investigation and data collection and analysis. Disavowing responsibility for
the fuel specification, the client has refused to pay for the cost of the corrective work and has
reserved its rights against us under the contract, which could include repairing or rejecting the
plants and recovering consequential damages in the event we are determined to be grossly negligent.
We have advised the client that we are not responsible for the cost of corrective work to address
corrosion resulting from out-of-specification fuel and we have been engaging in discussions with
the client regarding our respective claims.
There is also corrosion occurring to subcontractor-provided emissions control equipment and
induction fans at the back-end of the power plants. The cause of this back-end corrosion, which we
discovered during the fiscal second quarter of 2007 to be more extensive than previously assessed,
is under investigation. Based upon the information gathered to date, we believe the corrosion is
due principally to the low set point temperature design of the emissions control equipment that was
set by our subcontractor. If this proves to be the case, we believe the subcontractor would be
responsible for the cost to remedy this problem under our agreement with them, although we may have
direct responsibility for this cost to the client under our agreement with them. To date, the
subcontractor has denied responsibility for the corrosion, contending it is the result of
out-of-specification fuel supplied by the client. We have reserved our rights against the client
if this proves to be the case. To the extent that we incur costs for correcting this problem, we
intend to pursue claims against our subcontractor and/or our client, depending upon the cause of
the corrosion. Due to the potential magnitude of the amounts involved, there can be no assurance
that we will collect amounts for which our subcontractor may be determined to be liable. From a
plant rejection standpoint, we do not believe that the back-end corrective work will materially
impact our availability guaranty to the client described below.
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The contract for these plants contains an availability guaranty requiring the plants to meet
specified energy generation levels over a three year period. The availability guaranty is
expressly conditioned upon the use of the contract-specified fuel. The availability guaranty
provides for liquidated damages which could reach the contract cap for liquidated damages of
17,500 (approximately $25,600 at the exchange rate in effect as of September 26, 2008). In
addition to liquidated damages, in the event that availability of either of the plants as an
average of the best two out of the first three years of operation is 80% or below, the client may
be entitled to certain remedies, the most significant of which would be the right to reject both
plants and seek reimbursement of the
351,000 contract price paid for the plants (approximately
$513,000 at the exchange rate in effect as of September 26, 2008) plus restoration costs at the
sites. The client has alleged that at least one of the plants has failed to meet the availability
guaranty which we have disputed. We have advised the client that we do not believe we are
responsible under our availability guaranty (which is expressly subject to the clients provision
of specified fuel).
Under the contract, disputes are to be arbitrated under The Institution of Engineers of
Ireland Arbitration Procedure. On May 13, 2008, the client served a notice, referring the parties
dispute to arbitration. An arbitration panel has not been appointed and we continue to engage in
discussions with the client at its request to resolve this dispute as referenced above. Although
no pleading has been filed by the client in the proceeding, damages that the client may seek could
include, but may not be limited to, the cost to correct the corrosion in the boiler tubes and
emissions control equipment, liquidated damages under the availability guaranty, consequential
damages, including but not limited to lost profits, in the event gross negligence is proven and, in
the event of rejection, the total amount paid in respect of the plants, under the contract or
otherwise, plus the cost to dismantle the plants. As such, the costs claimed could exceed the
above-stated contract price paid for the plants and liquidated damages. We intend to vigorously
oppose such claims if asserted in the arbitration.
We have completed the necessary corrective actions for certain defects in the conveyor
equipment at the plants. While we believe that the subcontractor that provided the equipment is
responsible for the defects, our investigation is continuing.
During the fiscal fourth quarter of 2006, we established a contingency of $25,000 in relation
to this project. Primarily as a result of the fiscal second quarter of 2007 discovery of the more
extensive back-end corrosion, the contingency was increased by $30,000 during the fiscal second
quarter of 2007.
The performance of our subsidiary executing the foregoing contract in Ireland is guaranteed by
Foster Wheeler Ltd. In addition, there are
16,700 (approximately $24,400 at the exchange rate
in effect as of September 26, 2008) of outstanding retention bonds that have been issued in favor
of the client.
Due to the inherent commercial, legal and technical uncertainties underlying the estimation of
all of the project claims described above, the amounts ultimately realized or paid by us could
differ materially from the balances, if any, included in our financial statements, which could
result in additional material charges against earnings, and which could also materially adversely
impact our financial condition and cash flows.
Camden County Waste-to-Energy Project
One of our project subsidiaries, Camden County Energy Recovery Associates, LP (CCERA) owns
and operates a waste-to-energy facility in Camden County, New Jersey (the Project). The
Pollution Control Finance Authority of Camden County (PCFA) issued bonds to finance the
construction of the Project and to acquire a landfill for Camden Countys use. Pursuant to a loan
agreement between the PCFA and CCERA, proceeds from the bonds were loaned by the PCFA to CCERA and
used by CCERA to finance the construction of the facility. Accordingly, the proceeds of this loan
were recorded as debt on CCERAs balance sheet and, therefore, are included in our condensed
consolidated balance sheet. CCERAs obligation to service the debt incurred pursuant to the loan
agreement is limited to depositing all tipping fees and electric revenues received with the trustee
of the PCFA bonds. The trustee is required to pay CCERA its service fees prior to servicing the
PCFA bonds. CCERA has no other debt repayment obligations under the loan agreement with the PCFA.
In 1997, the United States Supreme Court effectively invalidated New Jerseys long-standing
municipal solid waste flow rules and regulations, eliminating the guaranteed supply of municipal
solid waste to the Project with its corresponding tipping fee revenue. As a result, tipping fees
have been reduced to market rate in order to provide a steady supply of fuel to the Project. Since
the ruling, those market-based revenues have not been, and are not expected to be, sufficient to
service the debt on outstanding bonds issued by the PCFA to finance the construction of the
Project.
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In 1998, CCERA filed suit against the PCFA and other parties seeking, among other things, to
void the applicable contracts and agreements governing the Project (Camden County Energy Recovery
Assoc. v. N.J. Department of Environmental Protection, et al., Superior Court of New Jersey, Mercer
County, L-268-98). Since 1999, the State of New Jersey has provided subsidies sufficient to ensure
the payment of each of the PCFAs debt service payments as they became due. The bonds outstanding
in connection with the Project were issued by the PCFA, not by us or CCERA, and the bonds are not
guaranteed by either us or CCERA. In the litigation, the defendants have asserted, among other
things, that an equitable portion of the outstanding debt on the Project should be allocated to
CCERA even though CCERA did not guarantee the bonds.
At this time, we cannot determine the ultimate outcome of the foregoing and the potential
effects on CCERA and the Project. If the State of New Jersey were to fail to subsidize the debt
service, and there were to be a default on a debt service payment, the bondholders might proceed to
attempt to exercise their remedies, by among other things, seizing the collateral securing the
bonds. We do not believe this collateral includes CCERAs plant.
Environmental Matters
CERCLA and Other Remedial Matters
Under U.S. federal statutes, such as the Resource Conservation and Recovery Act, Comprehensive
Environmental Response, Compensation, and Liability Act of 1980 (CERCLA), the Clean Water Act and
the Clean Air Act, and similar state laws, the current owner or operator of real property and the
past owners or operators of real property (if disposal of toxic or hazardous substances took place
during such past ownership or operation) may be jointly and severally liable for the costs of
removal or remediation of toxic or hazardous substances on or under their property, regardless of
whether such materials were released in violation of law or whether the owner or operator knew of,
or was responsible for, the presence of such substances. Moreover, under CERCLA and similar state
laws, persons who arrange for the disposal or treatment of hazardous or toxic substances may also
be jointly and severally liable for the costs of the removal or remediation of such substances at a
disposal or treatment site, whether or not such site was owned or operated by such person, which we
refer to as an off-site facility. Liability at such off-site facilities is typically allocated
among all of the financially viable responsible parties based on such factors as the relative
amount of waste contributed to a site, toxicity of such waste, relationship of the waste
contributed by a party to the remedy chosen for the site and other factors.
We currently own and operate industrial facilities and we have also transferred our interests
in industrial facilities that we formerly owned or operated. It is likely that as a result of our
current or former operations, hazardous substances have affected the facilities or the real
property on which they are or were situated. We also have received and may continue to receive
claims pursuant to indemnity obligations from the present owners of facilities we have transferred,
which claims may require us to incur costs for investigation and/or remediation.
We are currently engaged in the investigation and/or remediation under the supervision of the
applicable regulatory authorities at four of our or our subsidiaries former facilities. In
addition, we sometimes engage in investigation and/or remediation without the supervision of a
regulatory authority. Although we do not expect the environmental conditions at our present or
former facilities to cause us to incur material costs in excess of those for which reserves have
been established, it is possible that various events could cause us to incur costs materially in
excess of our present reserves in order to fully resolve any issues surrounding those conditions.
Further, no assurance can be provided that we will not discover additional environmental conditions
at our currently or formerly owned or operated properties, or that additional claims will not be
made with respect to formerly owned properties, requiring us to incur material expenditures to
investigate and/or remediate such conditions.
We have been notified that we are a potentially responsible party (PRP) under CERCLA or
similar state laws at three off-site facilities. At each of these sites, our liability should be
substantially less than the total site remediation costs because the percentage of waste
attributable to us compared to that attributable to all other PRPs is low. We do not believe that
our share of cleanup obligations at any of the off-site facilities as to which we have received a
notice of potential liability will exceed $500 in the aggregate. We have also received and
responded to a request for information from the United States Environmental Protection Agency
(USEPA) regarding a fourth off-site facility. We do not know what, if any, further actions USEPA
may take regarding this fourth off-site facility.
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Mountain Top
In February 1988, one of our subsidiaries, Foster Wheeler Energy Corporation (FWEC), entered
into a Consent Agreement and Order with the USEPA and the Pennsylvania Department of Environmental
Protection (PADEP) regarding its former manufacturing facility in Mountain Top, Pennsylvania.
The order essentially required FWEC to investigate and remediate as necessary contaminants,
including trichloroethylene (TCE), in the soil and groundwater at the facility. Pursuant to the
order, in 1993 FWEC installed a pump and treat system to remove TCE from the groundwater. It is
not possible at the present time to predict how long FWEC will be required to operate and maintain
this system.
In the fall of 2004, FWEC sampled the private domestic water supply wells of certain
residences in Mountain Top and identified approximately 30 residences whose water supply contained
TCE at levels in excess of Safe Drinking Water Act standards. The subject residences are located
approximately one mile to the southwest of where the TCE previously was discovered in the soils at
the former FWEC facility.
Since that time, FWEC, USEPA, and PADEP have cooperated in an investigation to, among other
things, attempt to identify the source(s) of the TCE in the residential wells. Although FWEC
believed the evidence available was not sufficient to support a determination that FWEC was
responsible for the TCE in the residential wells, FWEC in October 2004 began providing the
potentially affected residences with bottled water. It thereafter arranged for the installation,
maintenance, and testing of filters to remove the TCE from the water being drawn from the wells.
In August 2005, FWEC entered into a settlement agreement with USEPA whereby FWEC agreed to arrange
and pay for the hookup of public water to the affected residences, which involved the extension of
a water main and the installation of laterals from the main to the affected residences. The
foregoing hookups have been completed, but there may be a limited number of additional hookups in
the future. As residences were hooked up, FWEC ceased providing bottled water and filters to them.
FWEC is incurring costs related to public outreach and communications in the affected area. FWEC
may be required to pay the agencies costs in overseeing and responding to the situation. FWEC is
likely to incur further costs in connection with a Remedial Investigation / Feasibility Study, as
well as costs for continuing to monitor the groundwater in the area of the affected residences.
FWEC has accrued its best estimate of the cost of the foregoing and it reviews this estimate on a
quarterly basis.
Other costs to which FWEC could be exposed could include, among other things, FWECs counsel
and consulting fees, further agency oversight and/or response costs, costs and/or exposure related
to potential litigation, and other costs related to possible further investigation and/or
remediation. At present, it is not possible to determine whether FWEC will be determined to be
liable for some or all of the items described in this paragraph, nor is it possible to reliably
estimate the potential liability associated with the items.
If one or more third-parties are determined to be a source of the TCE, FWEC will evaluate its
options regarding the potential recovery of the costs FWEC has incurred, which options could
include seeking to recover those costs from those determined to be a source.
Between March 2006 and May 2006, complaints against FWEC were filed in three separate actions:
Sarah Martin et al. v. Foster Wheeler Energy Corporation
, Case No. 3376-06, Court of Common Pleas,
Luzerne County, Pennsylvania (subsequently removed to the United States District Court, Middle
District of Pennsylvania),
Donna Rose Cunningham et al. v. Foster Wheeler Energy Corporation
, Case
No. 3:CV-06-0805, United States District Court, Middle District of Pennsylvania, and
Gary Prezkop,
Personal Representative of the Estate of Mary Prezkop, Deceased, and in his own right, v. Foster
Wheeler Energy Corporation et al.,
Case No. 000545
,
Court of Common Pleas, Philadelphia County,
Pennsylvania. The complaints claimed to be on behalf of those owning or residing on property
impacted or threatened with impacts of the TCE released from the former FWEC facility. The
complaints sought to recover costs of environmental remediation and continued environmental
monitoring of plaintiffs property, diminution in property value, costs associated with obtaining
healthy water, the establishment of medical monitoring trust funds, and damages for emotional
distress. One complaint was on behalf of a class, and one included claims for wrongful death.
FWEC has since resolved all of the above litigation for amounts that, individually and in the
aggregate, did not have a material impact on our financial position, results of operations or cash
flows. Additionally, in September 2008, FWEC was notified by claimants counsel of a potential new
claim for personal injuries allegedly related to exposure to TCE in the affected area. FWEC is in
the process of investigating the potential claim, and it is premature to predict its possible
outcome.
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Other Environmental Matters
Our operations, especially our manufacturing and power plants, are subject to comprehensive
laws adopted for the protection of the environment and to regulate land use. The laws of primary
relevance to our operations regulate the discharge of emissions into the water and air, but can
also include hazardous materials handling and disposal, waste disposal and other types of
environmental regulation. These laws and regulations in many cases require a lengthy and complex
process of obtaining licenses, permits and approvals from the applicable regulatory agencies.
Noncompliance with these laws can result in the imposition of material civil or criminal fines or
penalties. We believe that we are in substantial compliance with existing environmental laws.
However, no assurance can be provided that we will not become the subject of enforcement
proceedings that could cause us to incur material expenditures. Further, no assurance can be
provided that we will not need to incur material expenditures beyond our existing reserves to make
capital improvements or operational changes necessary to allow us to comply with future
environmental laws.
With regard to the foregoing, the waste-to-energy facility operated by our CCERA project
subsidiary is subject to certain revisions to New Jerseys mercury air emission regulations. The
revisions make CCERAs mercury control requirements more stringent, especially when the last phase
of the revisions becomes effective in 2012. CCERAs management believes that the data generated
during recent stack testing tends to indicate that the facility will be able to comply with even
the most stringent of the regulatory revisions without installing additional control equipment.
Even if the equipment had to be installed, CCERA believes that the projects sponsor would be
responsible to pay for the equipment. However, the sponsor may not have sufficient funds to do so
or may assert that it is not so responsible. Estimates of the cost of installing the additional
control equipment are approximately $30,000 based on our last assessment.
13. Subsequent Events
Effective September 29, 2008, we and the requisite lenders under our domestic senior
credit agreement amended the domestic senior credit agreement to (1) allow us to use cash of up to
$750,000 to repurchase our outstanding common shares under our common share repurchase program,
subject to certain conditions, and (2) increase the aggregate amount of permissible capital
expenditures from $40,000 to $80,000 for fiscal year 2008 and $70,000 for fiscal years thereafter,
subject to certain adjustments that have been reflected in the domestic senior credit agreement
since its original execution in September 2006, including, among other items, an exclusion related
to capital expenditures that are financed by special-purpose project debt. Please see Note 4 for a
detailed listing of special-purpose project debt.
On October 3, 2008, we acquired $19,208 of our 1999C Robbins Bonds (as defined in Note 4) for
$19,016 of cash, plus accrued and unpaid interest to date. We will record a gain on the
acquisition of $192 in the fiscal fourth quarter of 2008. After the acquisition, we have $1,283 of
1999C Robbins Bonds outstanding.
Subsequent to the quarter ended September 26, 2008, pursuant to our common share repurchase
program, we repurchased an aggregate of 9,233,394 common shares that settled prior to November 5,
2008 for an aggregate cost of $288,147. Cumulatively through November 5, 2008, we have repurchased
10,518,942 common shares for an aggregate cost of $338,173. We have executed the repurchases in
accordance with a 10b5-1 repurchase plan as well as other open market purchases. The 10b5-1
repurchase plan allows us to purchase common shares at times when we may not otherwise do so due to
regulatory or internal restrictions. Purchases under the 10b5-1 repurchase plan are based on
parameters set forth in the plan.
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ITEM 2. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(amounts in thousands of dollars, except share data and per share amounts)
The following is managements discussion and analysis of certain significant factors that have
affected our financial condition and results of operations for the periods indicated below. This
discussion and analysis should be read in conjunction with our consolidated financial statements
and notes thereto included in this quarterly report on Form 10-Q and our annual report on Form 10-K
for the fiscal year ended December 28, 2007, which we refer to as our 2007 Form 10-K.
Safe Harbor Statement
This managements discussion and analysis of financial condition and results of operations,
other sections of this quarterly report on Form 10-Q and other reports and oral statements made by
our representatives from time to time may contain forward-looking statements that are based on our
assumptions, expectations and projections about Foster Wheeler Ltd. and the various industries
within which we operate. These include statements regarding our expectations about revenues
(including as expressed by our backlog), our liquidity, the outcome of litigation and legal
proceedings and recoveries from customers for claims and the costs of current and future asbestos
claims and the amount and timing of related insurance recoveries. Such forward-looking statements
by their nature involve a degree of risk and uncertainty. We caution that a variety of factors,
including but not limited to the factors described in Part I, Item 1A, Risk Factors, in our 2007
Form 10-K, which we filed with the SEC on February 26, 2008 and the following, could cause business
conditions and our results to differ materially from what is contained in forward-looking
statements:
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changes in the rate of economic growth in the United States and other major
international economies;
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changes in investment by the oil and gas, oil refining, chemical/petrochemical and power
industries;
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changes in the financial condition of our customers;
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changes in regulatory environments;
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changes in project design or schedules;
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contract cancellations;
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changes in our estimates of costs to complete projects;
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changes in trade, monetary and fiscal policies worldwide;
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compliance with laws and regulations relating to our global operations;
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currency fluctuations;
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war and/or terrorist attacks on facilities either owned by us or where equipment or
services are or may be provided by us;
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interruptions to shipping lanes or other methods of transit;
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outcomes of pending and future litigation, including litigation regarding our liability
for damages and insurance coverage for asbestos exposure;
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protection and validity of our patents and other intellectual property rights;
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increasing competition by foreign and domestic companies;
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compliance with our debt covenants;
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recoverability of claims against our customers and others by us and claims by third
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A change in tax laws, treaties or regulations, or their interpretation, of any country in
which we operate could result in a higher tax rate on our earnings, which could result in a
significant negative impact on our earnings and cash flows from operations. We continue to assess
the impact of various U.S. federal and state legislative proposals, and modifications to existing
tax treaties between the United States and foreign countries, that could result in a material
increase in our U.S. federal and state taxes. The U.S. Congress has in the past considered and may
in the future consider legislation affecting the tax treatment of U.S. companies that have
undertaken certain types of expatriation transactions or companies use of or relocation to
offshore jurisdictions, including Bermuda. We cannot predict whether any specific legislation will
be enacted or the terms of any such legislation.
Other factors and assumptions not identified above were also involved in the formation of
these forward-looking statements and the failure of such other assumptions to be realized, as well
as other factors, may also cause actual results to differ materially from those projected. Most of
these factors are difficult to predict accurately and are generally beyond our control. You should
consider the areas of risk described above in connection with any forward-looking statements that
may be made by us.
In addition, this managements discussion and analysis of financial condition and results of
operations contains several statements regarding current and future general global economic
conditions. These statements are based on our compilation of economic data and analyses from a
variety of external sources. While we believe these statements to be reasonably accurate, global
economic conditions are difficult to analyze and predict and are subject to significant uncertainty
and as a result, these statements may prove to be wrong.
We undertake no obligation to publicly update any forward-looking statements, whether as a
result of new information, future events or otherwise. You are advised, however, to consult any
additional disclosures we make in proxy statements, quarterly reports on Form 10-Q, annual reports
on Form 10-K and current reports on Form 8-K filed with the Securities and Exchange Commission.
Overview
We operate through two business groups the Global Engineering & Construction Group, which we
refer to as our Global E&C Group, and our Global Power Group. In addition to these two business
groups, we also report corporate center expenses and expenses related to certain legacy
liabilities, such as asbestos, in the Corporate and Finance Group, which we refer to as the C&F
Group.
Since fiscal year 2007, we have been exploring strategic acquisitions within the engineering
and construction industry to complement or expand on our technical capabilities or access to new
market segments. During the first fiscal nine months of 2008, we acquired a U.S.-based
biopharmaceutical engineering company as part of our strategy to enhance our positioning in the
pharmaceutical marketplace, especially in the U.S., and acquired the majority of the assets and
work force of an engineering design company, with an engineering center in Kolkata, India, which
provides engineering services to the petrochemical, refining, upstream oil and gas, and power
industries. We are also exploring acquisitions within the power industry to complement our product
offering. However, there is no assurance that we will consummate acquisitions in the future.
Results for the Fiscal Third Quarter and First Nine Months of 2008
We had net income of $127,900 in the fiscal third quarter of 2008, compared to net income of
$129,100 in the comparable period in fiscal year 2007. Net income for the fiscal third quarter of
2008, compared to the corresponding period of 2007, was favorably impacted by the following:
|
|
|
An increase to contract profit of $31,300 in the fiscal third quarter of 2008,
resulting from the continued strong performance of our Global E&C Group and
improved performance of our Global Power Group.
|
|
|
|
|
A reduction in our effective tax rate during the fiscal third quarter of 2008,
compared to the corresponding period in 2007.
|
These increases were offset by the following:
|
|
|
A net reduction to net income of $10,400 attributable to a net asbestos-related
provision of $1,800 in the fiscal third quarter of 2008, as compared to a net
asbestos-related gain of $8,600 in the fiscal third quarter of 2007.
|
37
|
|
|
A decrease in our share of equity earnings in certain of our equity interest
projects of $17,800 for the fiscal third quarter of 2008, compared to the
corresponding period of 2007.
|
|
|
|
|
An increase in selling, general and administrative expenses of $12,100 during
the fiscal third quarter of 2008, compared to the corresponding period in 2007.
|
|
|
|
|
A $14,400 gain related to favorable resolution of project claims in the fiscal
third quarter of 2007. The $14,400 gain increased contract profit by $9,600 and
interest income by $4,000 and reduced other deductions, net by $800.
|
For the first fiscal nine months of 2008, we had net income of $426,700 compared to net income
of $315,800 in the comparable period in fiscal year 2007. The increase in net income for the
fiscal nine months ended September 26, 2008, compared to the corresponding period of 2007, resulted
primarily from the following:
|
|
|
Increased contract profit of $118,100 resulting from the sharply improved
performance by our Global Power Group and continued strong operating performance by
our Global E&C Group. This contract profit increase included a
$7,500 commitment fee received in the fiscal nine months ended
September 26, 2008 for a contract that our Global Power Group
was not awarded. Additionally, the contract profit increase includes
the impact to contract profit in the fiscal nine months ended
September 28, 2007 for a charge of $30,000 on a legacy project
in our Global Power Group. Please refer to Note 12 to the
condensed consolidated financial statements in this quarterly report
on Form 10-Q for further information.
|
|
|
|
|
A net increase to net income of $22,100 attributable to a net asbestos-related
gain of $30,700 in the fiscal nine months ended September 26, 2008, as compared to
a net asbestos-related gain of $8,600 in the fiscal nine months ended September 28,
2007.
|
|
|
|
|
A reduction in our effective tax rate during the first fiscal nine months of
2008, compared to the corresponding period in 2007.
|
These increases were offset in part by the following:
|
|
|
An increase in selling, general and administrative expenses of $38,700 during
the first fiscal nine months of 2008, compared to the corresponding period in 2007.
|
|
|
|
|
A $14,400 gain in our Global Power Group related to favorable resolution of
project claims in the fiscal nine months ended September 28, 2007. The $14,400
gain increased contract profit by $9,600 and interest income by $4,000 and reduced
other deductions, net by $800.
|
Additional highlights included the following:
|
|
|
Our consolidated operating revenues increased 32% to $1,718,400 in the fiscal third
quarter of 2008, as compared to $1,299,900 in the fiscal third quarter of 2007, and
increased 43% to $5,215,100 in the fiscal nine months ended September 26, 2008, as compared
to $3,641,800 in the fiscal nine months ended September 28, 2007. These increases in
operating revenues in both the fiscal quarter and nine months ended September 26, 2008
reflect increased flow-through revenues and greater business activity in both our Global
E&C Group and our Global Power Group.
|
|
|
|
|
Our consolidated new orders, measured in terms of future revenues, were $1,390,300 in
the fiscal third quarter of 2008, as compared to $840,500 in the fiscal second quarter of
2008 and $1,878,500 in the fiscal third quarter of 2007.
|
|
|
|
|
Our consolidated backlog of unfilled orders, measured in future revenues, as of
September 26, 2008 was $7,262,200, as compared to $8,172,800 as of June 27, 2008 and
$6,273,100 as of September 28, 2007.
|
|
|
|
|
Our consolidated backlog, measured in terms of Foster Wheeler scope (as defined in the
section entitled Backlog and New Orders within this Item 2), as of September 26, 2008,
was $3,193,400, as compared to $3,323,300 as of June 27, 2008 and $3,011,600 as of
September 28, 2007.
|
38
|
|
|
E&C man-hours in backlog (in thousands) as of September 26, 2008 were 14,400, as
compared to 13,500 as of June 27, 2008 and 13,300 as of September 28, 2007.
|
Challenges and Drivers
Our primary operating focus continues to be booking quality new business and executing our
contracts well. The global markets in which we operate are largely dependent on overall economic
growth and the resultant demand for oil and gas, electric power, petrochemicals and refined
products.
In our Global E&C business, long-term demand is forecasted to be strong for the end products
produced by our clients, and is expected to continue to stimulate investment by our clients in new
and expanded plants. Therefore, attracting and retaining qualified technical personnel to execute
the existing backlog of unfilled orders and future bookings will continue to be a management
priority. Equally important is ensuring that we maintain an appropriate management infrastructure
to integrate and manage the technical personnel. We believe the primary drivers and constraints in
our Global E&C market are: global economic growth, our clients long-term view of oil and natural
gas prices and end product demand, and scope and timing of client investments. See Results of
Operations-Business Segments-Global E&C Group-Overview of Segment below for a more detailed
discussion of the challenges and drivers that impact our Global E&C Group, including our view of
the current global economic outlook.
In our Global Power Group business, we believe the primary drivers and constraints in the
global steam generator market are: economic growth, power plant price inflation, concern related to
greenhouse gas emissions, entry into new geographic markets, impact of environmental regulation,
and capacity constraints of electricity markets. These drivers differ across world regions,
countries and provinces. See Results of Operations-Business Segments-Global Power Group-Overview
of Segment below for a more detailed discussion of the challenges and drivers that impact our
Global Power Group, including our view of current global economic outlook.
New Orders
The Global E&C Groups new orders, measured in future revenues, increased to $955,200 in the
fiscal third quarter of 2008 as compared to $646,300 in the fiscal second quarter of 2008 and
decreased as compared to $1,572,000 in the fiscal third quarter of 2007. These new orders are
inclusive of estimated flow-through revenues, as defined below, of $290,900, $108,300 and $874,200
for the fiscal third quarter of 2008, fiscal second quarter of 2008 and fiscal third quarter of
2007, respectively. We expect capital investments and therefore the demand for our services and
equipment in the markets served by our Global E&C Group, including the chemical, petrochemical, oil
refining, liquefied natural gas, which we refer to as LNG, and upstream oil and gas industries, to
be strong in the longer term but there is uncertainty in the market outlook in the near to medium
term regarding the timing of new projects.
The Global Power Groups new orders increased to $435,100 in the fiscal third quarter of 2008,
as compared to $194,200 in the fiscal second quarter of 2008 and $306,500 in the fiscal third
quarter of 2007. Although new orders increased as compared to the fiscal second quarter of 2008,
our new orders in fiscal year 2008 are impacted by the delays we have seen in the North American
power markets that we serve, as well as, instances of schedule slippage in some of the European
power markets that we serve.
Results of Operations:
Operating Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
1,718,355
|
|
|
$
|
1,299,872
|
|
|
$
|
418,483
|
|
|
|
32.2
|
%
|
Fiscal nine months ended
|
|
$
|
5,215,101
|
|
|
$
|
3,641,760
|
|
|
$
|
1,573,341
|
|
|
|
43.2
|
%
|
The composition of our operating revenues varies from period to period based on the portfolio
of contracts in execution during any given period. Our operating revenues are therefore dependent
on our portfolio of contracts, the strength of the various geographic markets and industries we
serve and our ability to address those markets and industries.
39
The increases in operating revenues in the fiscal third quarter and nine months ended
September 26, 2008, compared to the corresponding periods of fiscal year 2007, were driven by our
Global E&C Group, which experienced increases in operating revenues of $336,000 and $1,301,300,
respectively, representing 80% and 83%, respectively, of the increases in consolidated operating
revenues for each period. The increases in operating revenues are the result of our Global E&C
Groups success in meeting the strong market demand in the oil and gas, petrochemical and refining
industries that stimulated investment by our customers. In the fiscal third quarter and nine
months ended September 26, 2008, our Global E&C Group operating revenues from these three
industries increased by $379,200 and $1,424,700, respectively, while operating revenues from the
other industries we serve declined by $43,200 and $123,400, respectively. Please refer to the
section entitled, Business Segments within this Item 2 for a discussion of our view of the
outlook for the oil and gas, petrochemical and refining industries.
The increases in our Global E&C Groups operating revenues during the fiscal third quarter and
nine months ended September 26, 2008, were driven by the execution of projects located in Asia
(increases of $171,700, or 90%, and $491,600, or 96%, respectively), Australia, New Zealand and the
Pacific islands, which we refer to as Australasia (increases of $233,900, or 145%, and $726,700, or
134%, respectively) and Europe (increases of $45,700, or 25%, and $123,200, or 23%, respectively).
Our Global E&C Groups operating revenues in the fiscal third quarter and nine months ended
September 26, 2008, included $650,000 and $2,228,700, respectively, of flow-through revenues.
Flow-through revenues increased by $220,100 and $1,136,500, respectively from fiscal year 2007,
representing 66% and 87%, respectively, of the increase in our Global E&C Groups operating
revenues and 53% and 72%, respectively, of the increase in consolidated operating revenues.
Flow-through revenues and costs result when we purchase materials, equipment or subcontractor
services on behalf of our customer on a reimbursable basis with no profit on the materials,
equipment or subcontractor services and which we have the overall responsibility as the contractor
for the engineering specifications and procurement or procurement services for the materials,
equipment or subcontractor services included in flow-through costs. Although flow-through revenues
and costs do not impact contract profit or net earnings, increased amounts of flow-through revenues
have the effect of reducing our reported contract profit margins as a percent of operating
revenues.
Our Global Power Group, which predominantly serves the power generation industry, contributed
$82,500, or 20%, and $272,000, or 17%, to the increase in consolidated operating revenues in the
fiscal third quarter and nine months ended September 26, 2008, respectively. The increase in
operating revenues in our Global Power Group is primarily attributable to the execution of projects
located in Europe, North America and South America.
Please refer to the section entitled Business Segments within this Item 2 for further
information.
Contract Profit:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
229,260
|
|
|
$
|
197,960
|
|
|
$
|
31,300
|
|
|
|
15.8
|
%
|
Fiscal nine months ended
|
|
$
|
692,447
|
|
|
$
|
574,318
|
|
|
$
|
118,129
|
|
|
|
20.6
|
%
|
Contract profit is computed as operating revenues less cost of operating revenues.
The increase in contract profit for the fiscal third quarter of 2008, as compared to the
corresponding period of fiscal year 2007, was driven primarily by increased volumes of business in
our Global E&C Group. Our Global E&C Group experienced sustained contract profit margins,
excluding the impact on contract profit margins of flow-through revenues, in the fiscal third
quarter of 2008, as compared to the corresponding period of fiscal year 2007, which had minimal
impact on the increase in contract profit generated by the increased volumes of business in our
Global E&C Group. Our Global Power Group experienced increased volumes of business executed at
improved contract profit margins in the fiscal third quarter of 2008, as compared to the
corresponding period of fiscal year 2007, excluding a $9,600 gain related to the favorable
resolution of project claims in the fiscal third quarter of 2007. Please refer to the section
entitled Business Segments within this Item 2 for further information.
40
The increase in contract profit for the fiscal nine months ended September 26, 2008, as
compared to the corresponding period of fiscal year 2007, was driven primarily by increased volumes
of business in our Global E&C Group. Our Global E&C Group experienced decreased contract profit
margins, excluding the impact on contract profit margins of flow-through revenues, in the nine
months ended September 26, 2008, as compared to the corresponding period of fiscal year 2007, which
partially offset the increase in contract profit generated by the increased volumes of business in
our Global E&C Group. Our Global Power Group experienced increased volumes of business in the
fiscal nine months ended September 26, 2008, as compared to the corresponding period of fiscal year
2007. The contract profit in our Global Power Group in the fiscal nine months ended September 26,
2008 was positively impacted in the nine months ended September 26, 2008 by a $7,500 commitment fee
that our Global Power Group received on a contract that we were not awarded. The contract profit
in our Global Power Group in the fiscal nine months ended September 28, 2007 was negatively
impacted by a $30,000 charge on a legacy project as described in Note 12 to the condensed
consolidated financial statements in this quarterly report on Form 10-Q and was positively impacted
by $9,600 resulting from the favorable resolution of project claims. Our Global Power Group
experienced increased contract profit margins in the fiscal nine months ended September 26, 2008,
as compared to the corresponding period of fiscal year 2007, excluding the above noted items.
Please refer to the section entitled Business Segments within this Item 2 for further
information.
41
Selling, General and Administrative (SG&A) Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
74,831
|
|
|
$
|
62,686
|
|
|
$
|
12,145
|
|
|
|
19.4
|
%
|
Fiscal nine months ended
|
|
$
|
218,771
|
|
|
$
|
180,079
|
|
|
$
|
38,692
|
|
|
|
21.5
|
%
|
SG&A expenses include the costs associated with general management, sales pursuit, including
proposal expenses, and research and development costs.
The increase in SG&A expenses in the fiscal third quarter of 2008, compared to the
corresponding period in fiscal year 2007, results from increases in general overhead costs of
$7,100, sales pursuit costs of $4,800 and research and development costs of $300.
The increase in SG&A expenses in the first fiscal nine months of 2008, compared to the
corresponding period in fiscal year 2007, results from increases in general overhead costs of
$22,900, sales pursuit costs of $15,000 and research and development costs of $800. The general
overhead costs increase includes $600 in our Global Power Group related to the settlement of
pension obligations for certain former employees in Canada. Please refer to Note 5 to the
condensed consolidated financial statements in this quarterly report on Form 10-Q for further
information.
The increases in general overhead and sales pursuit costs in the fiscal third quarter and nine
months ended September 26, 2008, result primarily from the increased volume of business in the
first fiscal nine months of 2008, which drove an increase in the number of non-technical support
staff and related costs in the fiscal year 2008 periods compared to the corresponding periods in
fiscal year 2007.
Other Income, net:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
(1,178
|
)
|
|
$
|
22,319
|
|
|
$
|
(23,497
|
)
|
|
|
(105.3
|
)%
|
Fiscal nine months ended
|
|
$
|
36,995
|
|
|
$
|
43,730
|
|
|
$
|
(6,735
|
)
|
|
|
(15.4
|
)%
|
Other income, net in the fiscal third quarter of 2008 consisted primarily of $2,700 in equity
earnings generated from our ownership interests, in build, own and operate projects in Italy and
Chile, and $(4,500) of foreign exchange losses. Our share of equity earnings in certain of our
projects in Italy were unfavorably impacted by $5,800, of which $5,500 related to periods prior to
the fiscal third quarter of 2008, as a result of a change in tax rates as it relates to those
projects.
Other income, net in the fiscal third quarter of 2007 consisted primarily of $20,500 in
equity earnings generated from our investments, primarily from our ownership interests, in build,
own and operate projects in Italy and Chile.
Other income, net in the first fiscal nine months of 2008 consisted primarily of $28,000 in
equity earnings generated from our ownership interests, in build, own and operate projects in Italy
and Chile, $2,000 of foreign exchange gains and a $1,600 gain from an insurance settlement. Our
share of equity earnings in certain of our projects in Italy were favorably impacted by $8,200, of
which $3,400 related to reporting periods prior to the first fiscal nine months of 2008, as a
result of a recently enacted regulatory ruling that provides for reimbursement of costs associated
with emission rights. Our share of equity earnings in certain of our projects in Italy were
unfavorably impacted by $5,800, as a result of a change in tax rates as it relates to those projects.
In addition, our share of equity earnings in our project in Chile increased by $2,200 due in large
part to an increase in electric tariff rates when compared to the fiscal year 2007 average electric
tariff rates.
Other income, net in the first fiscal nine months of 2007 consisted primarily of $31,600 in
equity earnings generated from our ownership interests, in build, own and operate projects in Italy
and Chile and a $6,600 gain on a real estate investment.
42
Other Deductions, net:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
8,986
|
|
|
$
|
7,672
|
|
|
$
|
1,314
|
|
|
|
17.1
|
%
|
Fiscal nine months ended
|
|
$
|
27,080
|
|
|
$
|
33,075
|
|
|
$
|
(5,995
|
)
|
|
|
(18.1
|
)%
|
Other
deductions, net in the fiscal third quarter of 2008 consisted primarily of $4,300 of
legal fees, $1,200 of bank fees, a $2,200 impairment charge related
to a 15% owned investment in a power project development in Italy carried at cost and a $800 loss on the sale of fixed assets, partially offset
by a net $(200) reduction in tax penalties, which reflects the reversal of $(500) of previously
accrued tax penalties which were ultimately not assessed.
Other deductions, net in the fiscal third quarter of 2007 consisted primarily of $800 of bank
fees, $3,800 of legal fees, which includes $(800) of reimbursed fees related to the favorable
resolution of project claims, $200 of consulting fees, $1,200 of tax penalties and a $500 provision
for dispute resolution and environmental remediation costs.
Other
deductions, net in the first fiscal nine months of 2008 consisted
primarily of $16,900
of legal fees, $3,400 of bank fees, a $1,800 provision for dispute resolution and environmental
remediation costs, $1,100 of consulting fees, a $2,200 impairment charge related to a 15% owned
investment in a power project development in Italy carried at cost and a $800 loss on the sale of fixed assets,
partially offset by a net reduction in tax penalties of $(1,900), which includes the reversal of
$(3,500) of previously accrued tax penalties which were ultimately not assessed.
Other deductions, net in the first fiscal nine months of 2007 consisted primarily of $2,500 of
bank fees, $13,300 of legal fees, which includes $(800) of reimbursed fees related to the favorable
resolution of project claims, $400 of consulting fees, $1,700 of tax penalties and a $9,700
provision for dispute resolution and environmental remediation costs.
Interest Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
12,457
|
|
|
$
|
12,467
|
|
|
$
|
(10
|
)
|
|
|
(0.1
|
)%
|
Fiscal nine months ended
|
|
$
|
35,155
|
|
|
$
|
24,263
|
|
|
$
|
10,892
|
|
|
|
44.9
|
%
|
The decrease in interest income in the fiscal third quarter of 2008, as compared to the
corresponding period of fiscal year 2007, was driven primarily by $4,000 in interest income
recognized in the fiscal third quarter of 2007 related to the favorable resolution of project
claims, partially offset by increased interest income in the fiscal third quarter of 2008 which was
primarily driven by higher average cash and cash equivalents balances.
The increase in interest income in the fiscal nine months ended September 26, 2008, as
compared to the corresponding period of fiscal year 2007, was driven primarily by higher average
cash and cash equivalents balances, partially offset by $4,000 in interest income recognized in the
fiscal nine months ended September 28, 2007 related to the favorable resolution of project claims.
Interest Expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
5,193
|
|
|
$
|
4,716
|
|
|
$
|
477
|
|
|
|
10.1
|
%
|
Fiscal nine months ended
|
|
$
|
16,204
|
|
|
$
|
14,652
|
|
|
$
|
1,552
|
|
|
|
10.6
|
%
|
The increase in interest expense in the fiscal third quarter and first fiscal nine months of
2008, compared to the corresponding periods of fiscal year 2007, resulted from the increased
borrowings under our FW Power S.r.L. special-purpose limited recourse project debt as we continue
construction of the electric power generating wind farm projects in Italy.
43
Minority Interest in Income of Consolidated Affiliates:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
834
|
|
|
$
|
1,765
|
|
|
$
|
(931
|
)
|
|
|
(52.7
|
)%
|
Fiscal nine months ended
|
|
$
|
1,859
|
|
|
$
|
5,038
|
|
|
$
|
(3,179
|
)
|
|
|
(63.1
|
)%
|
Minority interest in income of consolidated affiliates represents third-party ownership
interests in the results of our Global Power Groups Martinez, California gas-fired cogeneration
facility and our manufacturing facilities in Poland and the Peoples Republic of China. The change
in minority interest in income of consolidated affiliates is based upon changes in the underlying
earnings of the subsidiaries. The decrease in minority interest in income of consolidated
affiliates in the fiscal third quarter and first nine months of 2008, compared to the corresponding
periods in fiscal year 2007, primarily resulted from decreased earnings from the Martinez,
California facility mainly driven by higher natural gas pricing, which was partially offset by
increased electricity sales and plant optimization in off-peak hours.
Net Asbestos-Related Gain/(Provision):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
(1,725
|
)
|
|
$
|
8,633
|
|
|
$
|
(10,358
|
)
|
|
|
(120.0
|
)%
|
Fiscal nine months ended
|
|
$
|
30,738
|
|
|
$
|
8,633
|
|
|
$
|
22,105
|
|
|
|
256.1
|
%
|
Net asbestos-related expense in the fiscal third quarter of 2008 resulted from an expense of
$1,800 on the revaluation of our asbestos liability and related asset resulting from our rolling
15-year asbestos liability estimate.
Net asbestos-related gain in the fiscal nine months ended September 26, 2008 resulted from a
gain of $35,900 associated with settlement agreements that our subsidiaries reached with two
additional insurers, partially offset by an expense of $5,200 on the revaluation of our asbestos
liability and related asset resulting from our rolling 15-year asbestos liability estimate.
Net asbestos-related gain in the fiscal third quarter and fiscal nine months ended September
28, 2007, resulted from a gain of $8,600 associated with settlement agreements that our
subsidiaries reached with two insurers.
Please refer to Note 12 to the condensed consolidated financial statements in this quarterly
report on Form 10-Q for further information.
44
Provision for Income Taxes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
21,050
|
|
|
$
|
35,439
|
|
|
$
|
(14,389
|
)
|
|
|
(40.6
|
)%
|
Fiscal nine months ended
|
|
$
|
104,683
|
|
|
$
|
102,324
|
|
|
$
|
2,359
|
|
|
|
2.3
|
%
|
The tax provision for each year-to-date period is calculated by multiplying pre-tax income by
the estimated annual effective tax rate for such period. Our effective tax rate can fluctuate
significantly from period to period and may differ significantly from the U.S. federal statutory
rate as a result of income taxed in various foreign jurisdictions with rates different from the
U.S. statutory rate and also as a result of our inability to recognize a tax benefit for losses
generated by certain unprofitable operations. In addition, Statement of Financial Accounting
Standards No. 109, Accounting for Income Taxes, requires us to reduce our deferred tax benefits
by a valuation allowance when, based upon available evidence, it is more likely than not that the
tax benefit of losses (or other deferred tax assets) will not be realized in the future. In
periods when operating units subject to a valuation allowance generate pretax earnings, the
corresponding reduction in the valuation allowance favorably impacts our effective tax rate.
Our effective tax rate is, therefore, dependent on the location and amount of our taxable
earnings and the effects of changes in valuation allowances. Our effective tax rates for the
fiscal quarter and nine months ended September 26, 2008 and September 28, 2007 were lower than the
U.S. statutory rate of 35% due principally to:
|
|
|
Income earned in tax jurisdictions with tax rates lower than the U.S. statutory
rate, which is expected to contribute to an approximate twelve-percentage point
reduction in the effective tax rate for the full year 2008; and
|
|
|
|
|
A valuation allowance decrease which is expected to contribute to an approximate
six-percentage point reduction in the effective tax rate for the full year 2008. A
decrease in our valuation allowance occurred in the fiscal quarter and nine months
ended September 26, 2008 because we recognized earnings in jurisdictions where we
continue to maintain a full valuation allowance (primarily the United States and
Finland).
|
These factors which reduce the effective tax rate were partially offset by our inability to
recognize a tax benefit for losses subject to valuation allowance in certain other jurisdictions
and other permanent differences.
We monitor the jurisdictions for which valuation allowances against deferred tax assets were
established in previous years. As we currently have positive earnings in most jurisdictions, we
evaluate, on a quarterly basis, the need for the valuation allowances against deferred tax assets
in those jurisdictions. Such evaluation includes a review of all available evidence, both positive
and negative, in determining whether a valuation allowance is necessary. If the trend for positive
earnings continues in those jurisdictions where we have recorded a valuation allowance (primarily
the United States and Finland), we may conclude that a valuation allowance is no longer needed in
either or both jurisdictions.
For statutory purposes, the majority of the U.S. federal tax benefits, against which valuation
allowances have been established, do not expire until 2024 and beyond, based on current tax laws.
EBITDA:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
September 28,
|
|
|
|
|
|
|
2008
|
|
2007
|
|
$ Change
|
|
% Change
|
Fiscal quarter ended
|
|
$
|
165,243
|
|
|
$
|
178,977
|
|
|
$
|
(13,734
|
)
|
|
|
(7.7
|
)%
|
Fiscal nine months ended
|
|
$
|
580,991
|
|
|
$
|
459,872
|
|
|
$
|
121,119
|
|
|
|
26.3
|
%
|
The decline in EBITDA for the fiscal third quarter of 2008, compared to the corresponding
period of 2007, resulted primarily from the following:
|
|
|
A net asbestos-related provision of $1,800 in our C&F Group in the fiscal third
quarter of 2008, as compared to a net asbestos-related gain of $8,600 in our C&F
Group in the fiscal third quarter of 2007.
|
45
|
|
|
A decrease in our share of equity earnings in certain of our Global E&C Groups
projects in Italy of $5,800, of which $5,500 related to periods prior to the fiscal
third quarter of 2008, as a result of a change in tax rates as it relates to those
projects.
|
|
|
|
|
A $2,200 impairment charge in our Global E&C Group in the fiscal third quarter
of 2008 related to a 15% owned investment in a power project
development in Italy carried at cost.
|
|
|
|
|
A $14,400 gain in our Global Power Group related to favorable resolution of
project claims in the fiscal third quarter of 2007. The $14,400 gain increased
contract profit by $9,600 and interest income by $4,000 and reduced other
deductions, net by $800.
|
These declines were offset in part by increased volumes of business, strong operating
performance and increased contract profit margins in our Global Power Group and sustained contract
profit margins in our Global E&C Group in the fiscal third quarter of 2008, as compared to the
corresponding period of 2007. Please refer to the section entitled Contract Profit above for
further discussion of contract profit margins.
The increase in EBITDA for the fiscal nine months ended September 26, 2008, compared to the
corresponding period of 2007, resulted primarily from the following:
|
|
|
Increased volumes of business, strong operating performance and increased
contract profit margins in our Global Power Group in the fiscal nine months ended
September 26, 2008, as compared to the corresponding period of 2007. Please refer
to the section entitled Contract Profit above for further discussion on contract
profit margins.
|
|
|
|
|
A net asbestos-related gain of $30,700 in our C&F Group in the fiscal nine
months ended September 26, 2008, as compared to a net asbestos-related gain of
$8,600 in our C&F Group in the fiscal nine months ended September 28, 2007.
|
|
|
|
|
An increase in our share of equity earnings in certain of our Global E&C Groups
projects in Italy of $8,200 in the fiscal nine months ended September 26, 2008, of
which $3,400 related to reporting periods prior to the fiscal nine months ended
September 26, 2008, as a result of a recently enacted regulatory ruling that
provides for reimbursement of costs associated with emission rights.
|
|
|
|
|
A $7,500 commitment fee received in the fiscal nine months ended September 26,
2008 for a contract that our Global Power Group was not awarded.
|
|
|
|
|
An increase of $2,200 in our share of equity earnings from one of our Global
Power Groups equity interest investments during the fiscal nine months ended
September 26, 2008, due primarily to an increase in electric tariff rates in Chile
when compared to the fiscal year 2007 average electric tariff rates.
|
|
|
|
|
A charge of $30,000 on a legacy project in our Global Power Group incurred
during the fiscal nine months ended September 28, 2007. Please refer to Note 12 to
the condensed consolidated financial statements in this quarterly report on Form
10-Q for further information.
|
These increases were offset in part by the following:
|
|
|
A decrease in our share of equity earnings in certain of our Global E&C Groups
projects in Italy of $5,800 during the fiscal nine months ended September 26, 2008,
as a result of a change in tax rates as it relates to those projects.
|
|
|
|
|
A $2,200 impairment charge in our Global E&C Group in the fiscal nine months
ended September 26, 2008 related to a 15% owned investment in a power project
development in Italy
carried at cost.
|
|
|
|
|
A $14,400 gain in our Global Power Group related to favorable resolution of
project claims in the fiscal nine months ended September 28, 2007. The $14,400
gain increased contract profit by $9,600 and interest income by $4,000 and reduced
other deductions, net by $800.
|
See the individual segment explanations below for additional details.
46
EBITDA is a supplemental financial measure not defined in generally accepted accounting
principles, or GAAP. We define EBITDA as income before interest expense, income taxes,
depreciation and amortization. We have presented EBITDA because we believe it is an important
supplemental measure of operating performance. EBITDA, after adjustment for certain unusual and
infrequent items specifically excluded in the terms of our current and prior senior credit
agreements, is used for certain covenants under our current and prior senior credit agreements. We
believe that the line item on the condensed consolidated statements of operations and comprehensive
income entitled net income is the most directly comparable GAAP financial measure to EBITDA.
Since EBITDA is not a measure of performance calculated in accordance with GAAP, it should not be
considered in isolation of, or as a substitute for, net income as an indicator of operating
performance or any other GAAP financial measure. EBITDA, as calculated by us, may not be
comparable to similarly titled measures employed by other companies. In addition, this measure
does not necessarily represent funds available for discretionary use and is not necessarily a
measure of our ability to fund our cash needs. As EBITDA excludes certain financial information
that is included in net income, users of this financial information should consider the type of
events and transactions that are excluded. Our non-GAAP performance measure, EBITDA, has certain
material limitations as follows:
|
|
|
It does not include interest expense. Because we have borrowed money to finance
some of our operations, interest is a necessary and ongoing part of our costs and
has assisted us in generating revenue. Therefore, any measure that excludes
interest expense has material limitations;
|
|
|
|
|
It does not include taxes. Because the payment of taxes is a necessary and
ongoing part of our operations, any measure that excludes taxes has material
limitations; and
|
|
|
|
|
It does not include depreciation and amortization. Because we must utilize
property, plant and equipment and intangible assets in order to generate revenues
in our operations, depreciation and amortization are necessary and ongoing costs of
our operations. Therefore, any measure that excludes depreciation and amortization
has material limitations.
|
A reconciliation of EBITDA to net income is shown below.
47
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
C&F
|
|
|
|
Total
|
|
|
E&C Group
|
|
|
Power Group
|
|
|
Group
(1)
|
|
Fiscal quarter ended September 26, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(2)
|
|
$
|
165,243
|
|
|
$
|
122,828
|
|
|
$
|
64,753
|
|
|
$
|
(22,338
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(5,193
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(11,080
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
148,970
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(21,050
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
127,920
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal quarter ended September 28, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(3)
|
|
$
|
178,977
|
|
|
$
|
129,232
|
|
|
$
|
58,390
|
|
|
$
|
(8,645
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(4,716
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(9,721
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
164,540
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(35,439
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
129,101
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal nine months ended September 26, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(4)
|
|
$
|
580,991
|
|
|
$
|
412,976
|
|
|
$
|
197,547
|
|
|
$
|
(29,532
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(16,204
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(33,366
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
531,421
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(104,683
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
426,738
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal nine months ended September 28, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(5)
|
|
$
|
459,872
|
|
|
$
|
395,364
|
|
|
$
|
99,780
|
|
|
$
|
(35,272
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(14,652
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(27,120
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
418,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(102,324
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
315,776
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Includes general corporate income and expense, our captive insurance operation and the
elimination of transactions and balances related to intercompany interest.
|
|
(2)
|
|
Includes in the fiscal quarter ended September 26, 2008: increased/(decreased) contract
profit of $9,100 from the regular re-evaluation of final estimated contract profits*: $12,700
in our Global E&C Group and $(3,600) in our Global Power Group; and a charge of $1,800 in our
C&F Group on the revaluation of our asbestos liability and related asset resulting from our
rolling 15-year asbestos liability estimate.
|
|
(3)
|
|
Includes in the fiscal quarter ended September 28, 2007: increased contract profit of
$18,000 from the regular re-evaluation of final estimated contract profits*: $10,800 in our
Global E&C Group and $7,200 in our Global Power Group; and a gain of $8,600 in our C&F Group
on the settlement of coverage litigation with two asbestos insurance carriers.
|
|
(4)
|
|
Includes in the fiscal nine months ended September 26, 2008: increased/(decreased) contract
profit of $26,100 from the regular re-evaluation of final estimated contract profits*:
$35,800 in our Global E&C Group and $(9,700) in our Global Power Group; a gain of $35,900 in
our C&F Group on the settlement of coverage litigation with two asbestos insurance carriers;
and a charge of $5,200 in our C&F Group on the revaluation of our asbestos liability and
related asset resulting from our rolling 15-year asbestos liability estimate.
|
|
(5)
|
|
Includes in the fiscal nine months ended September 28, 2007: increased/(decreased) contract
profit of $34,100 from the regular re-evaluation of final estimated contract profits*:
$50,500 in our Global E&C Group and $(16,400) in our Global Power Group; and a gain of $8,600
in our C&F Group on the settlement of coverage litigation with two asbestos insurance
carriers.
|
48
|
|
|
*
|
|
Please refer to Revenue Recognition on Long-Term Contracts in Note 1 to the condensed
consolidated financial statements in this quarterly report on Form 10-Q for further
information regarding changes in our final estimated contract profits.
|
The accounting policies of our business segments are the same as those described in our
summary of significant accounting policies. The only significant intersegment transactions relate
to interest on intercompany balances. We account for interest on those arrangements as if they
were third party transactionsi.e. at current market rates, and we include the elimination of that
activity in the results of the C&F Group.
Business Segments
EBITDA, as discussed and defined above, is the primary measure of operating performance used
by our chief operating decision maker.
Global E&C Group
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
Fiscal Nine Months Ended
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
|
|
|
|
|
|
|
September 26,
|
|
|
September 28,
|
|
|
|
|
|
|
|
|
|
2008
|
|
|
2007
|
|
|
$ Change
|
|
|
% Change
|
|
|
2008
|
|
|
2007
|
|
|
$ Change
|
|
|
% Change
|
|
Operating revenues
|
|
$
|
1,287,405
|
|
|
$
|
951,402
|
|
|
$
|
336,003
|
|
|
|
35.3
|
%
|
|
$
|
3,928,136
|
|
|
$
|
2,626,816
|
|
|
$
|
1,301,320
|
|
|
|
49.5
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$
|
122,828
|
|
|
$
|
129,232
|
|
|
$
|
(6,404
|
)
|
|
|
(5.0
|
)%
|
|
$
|
412,976
|
|
|
$
|
395,364
|
|
|
$
|
17,612
|
|
|
|
4.5
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Results
The increases in operating revenues in the fiscal third quarter and nine months ended
September 26, 2008, as compared to the corresponding periods of fiscal year 2007, reflect increased
volumes of work and flow-through revenues as a result of our Global E&C Groups success in meeting
the strong market demand in the oil and gas, petrochemical and refining industries that stimulated
investment by our customers. In the fiscal third quarter and
nine months ended September 26, 2008, our Global E&C Groups operating revenues from these
three industries increased by $379,200 and $1,424,700, respectively, while operating revenues from
the other industries we serve declined by $43,200 and $123,400, respectively.
The increases in our Global E&C Groups operating revenues during the fiscal third quarter and
nine months ended September 26, 2008, were driven by the execution of projects located in Asia
(increases of $171,700, or 90%, and $491,600, or 96%, respectively), Australasia (increases of
$233,900, or 145%, and $726,700, or 134%, respectively), and Europe (increases of $45,700, or 25%,
and $123,200, or 23%, respectively). Please refer to the section entitled Overview of Segment
below for our view of the outlook for the oil and gas, petrochemical and refining industries.
Our Global E&C Groups operating revenues in the fiscal third quarter and nine months ended
September 26, 2008 included $650,000 and $2,228,700, respectively, of flow-through revenues.
Flow-through revenues in the fiscal third quarter and nine months ended September 26, 2008
increased by $220,100 and $1,136,500, respectively, from the corresponding periods of fiscal year
2007, representing 66% and 87%, respectively, of the increase in our Global E&C Groups operating
revenues. As discussed above, although flow-through revenues and costs do not impact contract
profit or net earnings, increased amounts of flow-through revenues have the effect of reducing our
reported contract profit margins as a percent of operating revenues.
The decrease in our Global E&C Groups EBITDA in the fiscal third quarter of 2008, as compared
to the corresponding period of fiscal year 2007, resulted primarily from the following:
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A decrease in our share of equity earnings in certain of our Global E&C Groups
projects in Italy of $5,800, of which $5,500 related to periods prior to the
fiscal third quarter of 2008, as a result of a change in tax rates as it relates to
those projects.
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A $2,200 impairment charge in our Global E&C Group in the fiscal third quarter
of 2008 related to a 15% owned investment in a power project
development in Italy carried at cost.
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Foreign exchange losses of $6,100 in the fiscal third quarter of 2008, compared to foreign exchange gains of $6,000 recognized
in prior quarters of 2008 and compared to foreign exchange losses of $600 recognized in the fiscal third quarter of 2007.
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49
These decreases were offset in part by increased volumes of business, strong operating
performance and sustained contract profit margins in our Global E&C Group in the fiscal third
quarter of 2008, as compared to the corresponding period of 2007.
The increase in our Global E&C Groups EBITDA in the fiscal nine months ended September 26,
2008, as compared to the corresponding period of fiscal year 2007, resulted primarily from the
following:
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Increased volumes of business due to the strength of the industries served and
sustained demand for our products and services in the geographic markets served.
This demand is discussed further in the section Overview of Segment below.
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An increase in our share of equity earnings in certain of our Global E&C
Groups projects in Italy of $8,200 during the fiscal nine months ended September
26, 2008, of which $3,400 related to reporting periods prior to the fiscal nine
months ended September 26, 2008, as a result of a recently enacted regulatory
ruling that provides for reimbursement of costs associated with emission rights.
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These increases were offset in part by the following:
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Decreased contract profit margins, excluding the impact on contract profit
margins of flow-through revenues, in the fiscal nine months ended September 26,
2008, as compared to the corresponding period of fiscal year 2007.
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A decrease in our share of equity earnings in certain of our Global E&C Groups
projects in Italy of $5,800 during the fiscal nine months ended September 26, 2008,
as a result of a change in tax rates as it relates to those projects.
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A $2,200 impairment charge in our Global E&C Group in the fiscal nine months
ended September 26, 2008 related to a 15% owned investment in a
power project development in Italy
carried at cost.
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Overview of Segment
Our Global E&C Group, which operates worldwide, designs, engineers and constructs onshore and
offshore upstream oil and gas processing facilities, natural gas liquefaction facilities and
receiving terminals, gas-to-liquids facilities, oil refining, chemical and petrochemical,
pharmaceutical and biotechnology facilities and related infrastructure, including power generation
and distribution facilities, and gasification facilities. Our Global E&C Group is also involved in
the design of facilities in new or developing market sectors, including carbon capture and storage,
solid fuel-fired integrated gasification combined-cycle power plants, coal-to-liquids,
coal-to-chemicals and biofuels. Our Global E&C Group generates revenues from engineering and
construction activities pursuant to contracts spanning up to approximately four years in duration
and from returns on its equity investments in various power production facilities.
Our Global E&C Group owns one of the leading technologies used in refinery residue upgrading
and a hydrogen production process used in oil refineries and petrochemical plants. Additionally,
our Global E&C Group has experience with, and is able to work with, a wide range of processes owned
by others.
Below is an overview of the primary drivers and constraints applicable to our Global E&C
Group.
Demand for Oil and Gas, Petrochemicals and Refined Products and Global Economic
Outlook
We expect investment in new oil and gas, refining and petrochemicals/chemicals facilities, and
modernization, expansion and upgrading of existing facilities in these sectors, to continue to be
robust in the longer term although there is uncertainty in the near
to medium term regarding the timing of new projects.
Our business has not been significantly impacted to date by the global credit market crisis,
however, the possibility exists that credit conditions, as well as the slowdown in global economic
growth, could materially adversely affect the industries in which our clients operate and as a
result, our Global E&C Groups business.
50
We believe that the overall global refining system is still running at high utilization rates
and that global demand for many refined products, particularly middle distillates (diesel, jet
fuel, and heating oil), will continue to grow. We believe that refining capacity will therefore
continue to be added through the development of grassroots refineries, notably in the Middle East
and Asia. Significant upgrades and expansions also continue to be planned or are underway at
existing refineries in many regions. Clean fuel programs are also being implemented to meet
tighter fuel specifications in refiners domestic and/or export markets. We are currently working
on refinery projects in the Americas, Europe, Asia and the Middle East.
Some refiners are also investing in refinery/petrochemical integration. We believe that the
drivers for this investment include: adding value to their refinery streams, diversification of
their production, and margin enhancement. We are working on a number of integrated
refinery/petrochemical projects in Asia and the Middle East.
The price differentials between heavier, higher-sulfur crude oil and lighter, sweeter crudes
remain at a sufficient level to continue to stimulate refinery investment in facilities which
enable refiners to process the cheaper, higher-sulfur crudes instead of the lighter, more expensive
crudes, or to upgrade their lower-value refinery residues to higher-value transportation fuels, for
which demand continues to grow. We expect to see continued investment in these projects.
We have considerable experience and expertise in this area, including our proprietary delayed
coking technology, which enables refineries to upgrade lower quality crude oil or refinery residue
to high value refined products such as transportation fuels. We are currently executing a
significant number of delayed coking projects, including:
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Feasibility studies;
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Delayed coking technology license agreements and process design packages;
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Front-end engineering and design, or FEED, contracts;
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Engineering, procurement and construction supervision contracts; and
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Full engineering, procurement and construction contracts.
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These projects are located in Asia, Europe, the Middle East, North America, and South America.
The subsequent phases of some of these projects for which we are working on the early phases,
offer us further opportunities. We believe further coking opportunities exist in regions such as
the Americas, where coking is a well-established residue upgrading route, and in regions such as
Asia which are now looking at residue upgrading as an option, but where investment in residue
upgrading has not previously been a prime focus for refiners.
51
Investment in Petrochemical Plants
Investment in petrochemical plants began to rise sharply in 2004 in response to strong growth
in demand for petrochemicals. The majority of this investment has been centered in Asia and the
Middle East. We are seeing:
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Further new planned investment in Asia and the Middle East;
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Investment in specialty chemicals, particularly in the Middle East, stimulated
by governmental desire to further diversify their economies to lessen their
dependence on crude oil exports and to provide sustained employment for their
growing young populations; and
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Increasing interest in developing new chemical facilities and expanding existing
plants in other locations including North Africa, the Commonwealth of Independent
States and South America.
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Client Expectation for Oil and Natural Gas Prices
We believe that our clients long-term expectation for sustained oil prices, together with
longer-term projections for robust growth in global oil and gas demand, provide a strong stimulus
to clients to invest in upstream oil and gas facilities, including LNG production, in Africa, the
Americas, Asia, Australasia, the Commonwealth of Independent States and Caspian region and the
Middle East.
We believe that rising demand for natural gas in Europe, Asia and the United States, combined
with a shortfall in indigenous production, and a desire for flexibility and/or security of gas
supply, will continue to act as a stimulant to the LNG business. Although LNG demand continues to
grow strongly, the pace at which new liquefaction train construction projects have received
approval to proceed has slowed over the last two or three years. We believe this indicates that
significant additional liquefaction capacity over and above the approved projects will need to be
developed.
Scope and Timing of Investments in Engineering and Construction Services, Equipment and
Materials
While the longer term outlook for client investment in the oil and gas, refining and
petrochemicals industries remains positive, some companies are electing to commit to only partial
or staged investments, to reduce the scope of their investments, to postpone or cancel contemplated
investments or to involve additional partners in their investments. As we work with our clients in
the early study and front-end design phases of their projects, we are helping some of them develop
a revised project that meets their investment parameters, develop a staged investment plan, or
revise the scope of or configuration of their original project so that they are able to obtain
approval to proceed with their investment. In addition, as discussed above, although the credit
market crisis has not directly impacted our business as yet, we believe that its impact on general
economic conditions appears to be deepening and becoming more widespread and the full impact has
yet to be realized.
Pharmaceutical Facility Investment
Client investment in new pharmaceutical production facilities has slowed since 2003. We
believe this is attributable to a range of factors including industry cost pressure. Investment
has focused on plant rationalization, upgrading and improvement projects rather than on major new
greenfield production facilities and on biotechnology facilities. In February 2008, we acquired a
U.S.-based biopharmaceutical engineering company as part of our strategy to enhance our positioning
in the pharmaceutical marketplace, especially in the U.S.
52
Global Power Group
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Fiscal Quarters Ended
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Fiscal Nine Months Ended
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September 26,
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September 28,
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September 26,
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September 28,
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2008
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2007
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$ Change
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% Change
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2008
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2007
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$ Change
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% Change
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Operating revenues
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$
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430,950
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$
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348,470
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$
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82,480
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23.7
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%
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$
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1,286,965
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$
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1,014,944
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$
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272,021
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26.8
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%
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EBITDA
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$
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64,753
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$
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58,390
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$
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6,363
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10.9
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%
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$
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197,547
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$
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99,780
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$
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97,767
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98.0
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%
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Results
The increases in operating revenues in the fiscal third quarter and nine months ended
September 26, 2008, as compared to the corresponding periods of fiscal year 2007, result from the
increased volume of business in our operations in Asia, Europe, North America and South America,
primarily through the execution of projects located in Asia (increases of $14,200, or 34%, and
$13,500, or 10%, respectively), Europe (increases of $34,200, or 31%, and $129,000, or 43%,
respectively), North America (increases of $26,500, or 15%, and $84,300, or 16%, respectively) and
South America (increases of $3,000, or 15%, and $42,800, or 89%, respectively).
The increase in our Global Power Groups EBITDA in the fiscal third quarter of 2008, as
compared to the corresponding period of fiscal year 2007, resulted primarily from the following:
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Increased volumes of business executed during the period. Refer to the section
Overview of Segment below for a discussion of the strength of the industries
served and demand for our products and services.
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Increased contract profit margins experienced on our contracts executed,
excluding the $9,600 gain noted below related to the favorable resolution of
project claims in the fiscal third quarter of 2007.
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These increases were offset in part by a $14,400 gain in our Global Power Group related to
favorable resolution of project claims in the fiscal third quarter of 2007. The $14,400 gain
increased contract profit by $9,600 and interest income by $4,000 and reduced other deductions, net
by $800.
The increase in our Global Power Groups EBITDA in the fiscal nine months ended September 26,
2008, as compared to the corresponding period of fiscal year 2007, resulted primarily from the
following:
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Increased volumes executed during the period. Refer to the section Overview
of Segment below for a discussion of the strength of the industries served and
demand for our products and services.
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Increased contract profit margins experienced on our contracts executed,
excluding the $9,600 gain noted below related to favorable resolution of project
claims in the fiscal nine months ended September 28, 2007.
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A $7,500 commitment fee received in the fiscal nine months ended September 26,
2008 for a contract that our Global Power Group was not awarded.
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An increase of $2,200 in our share of equity earnings from one of our Global
Power Groups equity interest investments during the fiscal nine months ended
September 26, 2008, due primarily to an increase in electric tariff rates in Chile
when compared to the fiscal year 2007 average electric tariff rates.
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A charge of $30,000 on a legacy project in our Global Power Group incurred
during the fiscal nine months ended September 28, 2007. Please refer to Note 12 to
the condensed consolidated financial statements in this quarterly report on Form
10-Q for further information.
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These increases were offset in part by a $14,400 gain in our Global Power Group related to
favorable resolution of project claims in the fiscal nine months ended September 28, 2007. The
$14,400 gain increased contract profit by $9,600 and interest income by $4,000 and reduced other
deductions, net by $800.
53
Overview of Segment
Our Global Power Group designs, manufactures and erects steam generators for electric power
generating stations, district heating plants and industrial facilities worldwide. The vast
majority of the global steam generator market utilizes coal as the primary fuel for the steam
generator. Therefore, the market drivers and constraints associated with coal use strongly affect
the steam generator market and our Global Power Groups business. Additionally, our Global Power
Group designs, manufactures and erects auxiliary equipment for electric power generating stations
and industrial facilities worldwide and owns and/or operates several cogeneration, independent
power production and waste-to-energy facilities, as well as power generation facilities for the
process and petrochemical industries.
Below is an overview of the primary drivers and constraints applicable to the business areas
within our Global Power Group.
Economic Growth
Historically, demand for our steam generators and auxiliary equipment has been significantly
affected by electricity demand and industrial output, which in turn has been significantly affected
by economic growth. A further slowdown or recession in economic growth, in connection with the
credit market crisis discussed above in the section entitled, Results of Operations-Business
Segments-Global E&C Group-Overview of Segment, could materially adversely affect the industries in
which our clients operate and as a result, our Global Power Groups business. In particular, we
believe that both the U.S. and segments in Europe are experiencing a slowdown in economic growth
that could cause a softening in demand for steam generators and, as a result, could adversely
affect our Global Power Groups business in these regions. However, we believe that economic
growth in developing countries, such as China, India, Indonesia, Korea, South Africa, Turkey,
Vietnam, and parts of South America and the Middle East will continue to drive strong demand for
steam generators for electric power generating stations, district heating plants and industrial
facilities in these countries. We also believe demand for steam generators fired or co-fired by
low carbon and carbon neutral fuels will increase, as further described below.
Power Plant Price Inflation
Although we are starting to see some softening in commodities prices during the fiscal third
quarter of 2008, we believe that the substantial price inflation experienced previously through
fiscal year 2008 related to commodities and labor services for new power plants, retro-fit and
related services will continue to suppress future demand for steam generators, which in turn could
adversely affect our Global Power Groups business opportunities.
Concern Related to Greenhouse Gases
Concern for emissions related to greenhouse gases, such as carbon dioxide, or CO
2,
from fossil fuel power plants, could suppress future demand for utility steam generators and in
turn adversely affect our Global Power Groups business opportunities. We believe that this concern
is currently strongest in the U.S. and Europe and could adversely affect our Global Power Groups
business opportunities in these regions. We have recently experienced delays in certain North
American projects we view as prospects and we believe this is a result of a combination of these
market restraining factors (environmental pressure, high fossil fuel prices, high power plant
prices and softening economic growth), as discussed above. We believe that concern related to
greenhouse gases is not currently as strong in Africa, Asia, Latin America, Eastern Europe or the
Middle East, and is not significantly suppressing the demand for utility coal-fired steam
generators in these regions and that these regions continue to offer business opportunities to our
Global Power Group.
We believe our Global Power Group is well positioned to serve the global utility steam
generator market with its circulating-fluidized bed, which we refer to as CFB, steam generator
technology, even with continued concern related to greenhouse gases. In addition to cleanly burning
a wide spectrum of coal types, CFBs can also burn biomass and recycled fuels (such as tires,
demolition wood, plastics, waste paper, waste and waste coal). These fuels, in many regions, are
considered to be carbon neutral or low carbon fuels, allowing owners of CFB power plants to achieve
substantially lower carbon emission as compared to conventional pulverized coal, which we refer to
as PC, steam generator technology. We believe power markets around the world, especially in the
U.S. and in Western Europe, are valuing low carbon and carbon neutral fuels even more, driven by
increased regulatory uncertainty around greenhouse gas regulation and that our CFB technology is
well-positioned for this market opportunity. This is evidenced by an increase in recent awards for
CFBs which either co-fire or fully fire low carbon and carbon neutral fuels, such as biomass and
waste fuels.
54
We believe that concern related to greenhouse gases is driving a strong preference for
supercritical once-through-units, which we refer to as OTU, steam generator technology, in nearly
all world regions within the utility steam generator market. OTU steam generator technology offers
higher efficiency and hence reduced CO
2
emissions since the steam is produced at
supercritical conditions.
We believe our Global Power Group is well positioned to serve the supercritical OTU market as
evidenced by our Global Power Groups success in securing three projects based on supercritical OTU
technology: (1) a project, awarded in fiscal year 2005 and planned to be commercially operational
by fiscal year 2009, in Poland where we will be supplying the worlds first supercritical OTU CFB
steam generator which will utilize advanced BENSON vertical tube technology; (2) a project, awarded
in fiscal year 2007 and planned to be commercially operational by fiscal year 2011, for the design
and supply, or D&S, of a supercritical OTU PC steam generator for a coal-fired generating facility
located in West Virginia; and (3) a D&S project, awarded in 2008, for our second supercritical OTU
CFB project which will be located in Russia and is the first CFB in that country. A key component
of our strategy is to leverage these key wins to further grow our position in the supercritical
utility steam generator market for both PC and CFB steam generators.
We believe that supercritical CFB steam generator technology has the potential to further
penetrate the supercritical utility steam generator market, especially for non-premium solid fuels
such as biomass, lignite, brown coals and waste coals. Since we expect to be the first steam
generator supplier with an operational supercritical CFB reference plant (which is expected to be
commissioned in Poland in fiscal year 2009), and have recently been awarded a contract in Russia
for the second supercritical CFB ordered in the world, we believe we are well positioned to pursue
this market opportunity.
Entry into New Geographic Markets
We believe that the worlds largest utility steam generator markets will continue to be in
Asia, such as China and India, offering both opportunity and challenges to our Global Power Groups
business. Historically, we believe it has been difficult for foreign companies to significantly
penetrate these markets due to entrenched low-cost domestic steam generator suppliers, government
controlled and owned steam generator companies, and national trade policies favoring domestic
suppliers. Our Global Power Group is participating in these markets on a limited basis while
growing its manufacturing and engineering operations in China to provide high quality products
competitive in these regions as well as the rest of the world.
To maximize business opportunities in these regions, our Global Power Group is augmenting our
direct sales and supply chain capacity into these markets by licensing our technology to select
boiler suppliers in these regions, which is increasing our market penetration through licensees.
Impact of Environmental Regulations
We believe that environmental regulations will continue to become more restrictive globally
and that this will drive continued global demand for our Global Power Groups environmental
products and services, such as selective non-catalytic and catalytic NOx reduction systems, low NOx
burners, over-fire air systems, coal/air balancing systems and coal mill upgrade equipment.
Capacity Constraints in Electricity Markets
We believe that the amount of unused available electric generating capacity as a percentage of
total electric capacity will remain tight globally and that coal fired steam generator power plant
owners and operators will continue to run these plants at historically high utilization rates. The
high utilization rates are expected to increase the need for maintenance, which we believe will
continue to spur overhaul and additional maintenance investment by owners and operators of these
plants, especially in the U.S. and Europe, which have sizable older steam generator power plant
fleets. We believe these factors are contributing to a strong demand for our Global Power Groups
steam generator aftermarket products and services.
55
Liquidity and Capital Resources
Fiscal Year-to-Date 2008 Activities
As of September 26, 2008, we had cash and cash equivalents and restricted cash totaling
$1,335,300, compared to $1,069,500 as of December 28, 2007. The increase was primarily driven by
an increase in cash and cash equivalents of $260,400 which results primarily from net cash provided
by operations of $407,800, partially offset by net cash used in investing activities of $84,800,
net cash used in financing activities of $37,200 and unfavorable exchange rate changes on cash and
cash equivalents of $25,400. Restricted cash was $26,400 and $20,900 as of September 26, 2008 and
December 28, 2007, respectively. Of the $1,335,300 total of cash and cash equivalents and
restricted cash as of September 26, 2008, $1,028,200 was held by our foreign subsidiaries. Please
refer to Note 1 to the condensed consolidated financial statements in this quarterly report on Form
10-Q for additional details on cash balances.
Net cash provided by operations in the first fiscal nine months of 2008 was $407,800, compared
to net cash provided by operations of $241,700 in the comparable period of fiscal year 2007. Net
cash provided by operations in the first fiscal nine months of 2008 was positively impacted by our
strong operating performance and net proceeds from settlements with asbestos insurers in excess of
liability indemnity payments and defense costs of $21,800, partially offset by cash used for
working capital activities of $53,300. The increase in cash provided by operations of $166,100 in
the first fiscal nine months of 2008, compared to the corresponding period of fiscal year 2007,
results primarily from an increase in net income of $111,000, a net increase in cash flows of
$52,300 from asbestos settlements in excess of liability indemnity payments and defense costs (net
proceeds of $21,800 in the first fiscal nine months of 2008 versus funding of $30,500 in the first
fiscal nine months of 2007), partially offset by a net reduction in cash flows of $38,000 for a net
increase in working capital (net decrease of $53,300 versus $15,400 in the first fiscal nine months
of 2008 and 2007, respectively).
Net cash provided by operations in the first fiscal nine months of 2007 was also positively
impacted by our strong operating performance, partially offset by making $35,000 of mandatory and
discretionary contributions to our domestic pension plan, funding $30,500 of asbestos liability
indemnity payments and defense costs and cash used for working capital activities of $15,400.
Our working capital varies from period to period depending on the mix, stage of completion and
commercial terms and conditions of our contracts. Working capital in our Global E&C Group tends to
rise as the workload of reimbursable contracts increases since services are rendered prior to
billing clients while working capital tends to decrease in our Global Power Group when the workload
increases as cash tends to be received prior to ordering materials and equipment. The change in
working capital in the first fiscal nine months of 2008, compared to the corresponding period of
fiscal year 2007, reflects an increase in working capital generated by the increase in workload
experienced by our Global E&C Group, partially offset by a decrease in working capital generated by
the increase in workload experienced by our Global Power Group. As more fully described below in
-Outlook, we believe our existing cash balances and forecasted net cash provided from operating
activities will be sufficient to fund our operations throughout the next 12 months. Our ability to
further increase our cash flows from operating activities in future periods will depend in large
part on the demand for our products and services and our operating performance in the future.
Please refer to the sections entitled -Global E&C Group-Overview of Segment and -Global Power
Group-Overview of Segment above for our view of the outlook for each of our business segments.
56
Net cash used in investing activities in the first fiscal nine months of 2008 was $84,800,
compared to net cash used in investing activities of $30,900 in the comparable period in fiscal
year 2007. The net cash used in investing activities in the first fiscal nine months of 2008 is
attributable primarily to capital expenditures of $62,400 which included $19,000 of expenditures in
FW Power S.r.L. as we continue construction of the electric power generating wind farm projects in
Italy, an increase in restricted cash of $6,100 primarily driven by an increase in debt service
funds for FW Power S.r.L. and $14,900 of net cash used for the purchase price of acquisitions, net
of cash acquired. The cash used in
investing activities in the first fiscal nine months of 2007 is attributable primarily to capital
expenditures of $33,500 (which included $10,600 of expenditures in FW Power S.r.L., related to the
construction of the electric power generating wind farm projects in Italy), an increase in
restricted cash of $2,800 primarily driven by an increase in client escrow funds and an increase in
debt service funds for FW Power S.r.L., a $1,500 payment to purchase a Finnish company that owns
patented coal flow measuring technology and a $4,800 payment made in September 2007 related to the
FW Power acquisition in fiscal year 2006, partially offset by a $6,300 return of investment from
our unconsolidated affiliates and proceeds from the sale of assets of $6,700. The capital
expenditures in both fiscal years related primarily to project construction (including the FW Power
S.r.L. electric power generating wind farm projects in Italy noted above), leasehold improvements,
information technology equipment and office equipment. The increase in capital expenditures has
been driven primarily by our Global E&C Group, with particular increases driven by operations in
Asia, Italy and the U.S. Our Global Power Group capital expenditure increase was driven by our
European operations.
Net cash used in financing activities in the first fiscal nine months of 2008 was $37,200
compared to $17,500 of net cash provided by financing activities in the comparable period in fiscal
year 2007. The net cash used in financing activities in the first fiscal nine months of 2008 is
attributable primarily to $50,000 used to repurchase and retire our common shares associated with
the share repurchase program we announced on September 12, 2008,
distributions to minority third-party ownership interests of $9,600 and repayment of long-term debt and capital lease obligations of
$9,400, partially offset by proceeds from the issuance of long-term project debt of $28,700 and
cash provided from exercises of stock options of $2,600. The net cash provided by financing
activities in the first fiscal nine months of 2007 primarily reflects cash provided from exercises
of stock options and warrants, partially offset by the repayment of our convertible notes, which
matured in June 2007, and a scheduled payment on our limited-recourse project debt.
57
Outlook
Our liquidity forecasts cover, among other analyses, existing cash balances, cash flows from
operations, cash repatriations from non-U.S. subsidiaries, working capital needs, unused credit
line availability and claim recoveries and proceeds from asset sales, if any. These forecasts
extend over a rolling 12-month period. Based on these forecasts, we believe our existing cash
balances and forecasted net cash provided by operating activities will be sufficient to fund our
operations throughout the next 12 months. Based on these forecasts, our primary cash needs will be
to fund working capital, capital expenditures, asbestos liability indemnity and defense costs,
acquisitions and up to $750,000 for our common share repurchase program that we announced on
September 12, 2008. The majority of our cash balances are invested in short-term interest bearing
accounts with maturities of less than three months. We continue to consider investing some of our
cash in longer-term investment opportunities, including the acquisition of other entities or
operations in the engineering and construction industry or power industry and/or the reduction of
certain liabilities such as unfunded pension liabilities. We may elect to make discretionary
contributions to our U.S. and U.K. pension plans during the fiscal
fourth quarter of 2008.
We have performed an evaluation of our credit exposure in response to the current global
credit market crisis. The evaluation included analysis of counterparty credit exposure, in
general, and specifically related to cash and cash equivalents, bonding and bank guarantees,
forward currency contracts, pension assets, insurance assets and clients. We believe that we are
well diversified and third-party credit exposure should not expose us to material downside risks.
However, the crisis continues to develop at a rapid pace. We will continue to closely monitor the
global liquidity and credit market crisis and continue to take appropriate actions, as necessary,
to limit our exposure.
It is customary in the industries in which we operate to provide standby letters of credit,
bank guarantees or performance bonds in favor of clients to secure obligations under contracts. We
believe that we will have sufficient letter of credit capacity from existing facilities throughout
the next 12 months.
Our domestic operating entities do not generate sufficient cash flows to fund our obligations
related to corporate overhead expenses and asbestos-related liabilities. Consequently, we require
cash repatriations from our non-U.S. subsidiaries in the normal course of our operations to meet
our domestic cash needs and have successfully repatriated cash for many years. We believe that we
can repatriate the required amount of cash from our foreign subsidiaries and we continue to have
access to the revolving credit portion of our domestic senior credit facility, if needed.
Beginning in the fourth fiscal quarter of 2008, we have begun to repatriate cash from our
non-U.S. subsidiaries to partially fund our common share repurchase program, which is described
below. As of October 24, 2008, we have repatriated cash totaling approximately $125,400 to fund
our common share repurchase program.
We had net cash inflows of $21,800 as a result of insurance settlement proceeds in excess of
the asbestos liability indemnity payments and defense costs during the fiscal nine months ended
September 26, 2008. We expect to have net cash inflows of $17,400 as a result of insurance
settlement proceeds in excess of the asbestos liability indemnity and defense costs for the full
twelve months of fiscal year 2008. This estimate assumes no additional settlements with insurance
companies or elections by us to fund additional payments. As we continue to collect cash from
insurance settlements and assuming no increase in our asbestos-related insurance liability or any
future insurance settlements, the asbestos-related insurance receivable recorded on our balance
sheet will continue to decrease.
We anticipate spending
30,000 (approximately $43,800 at the exchange rate as of September
26, 2008) in FW Power S.r.L. in fiscal year 2008 as we continue construction of the electric power
generating wind farm projects in Italy, of which
12,500 (approximately $19,000 at the exchange
rate as of September 26, 2008) was spent as of September 26, 2008. We have secured total borrowing
capacity under the FW Power S.r.L. credit facilities of
75,400 (approximately $110,100 at the
exchange rate as of September 26, 2008).
We had $291,800 and $245,800 of letters of credit outstanding under our domestic senior credit
agreement as of September 26, 2008 and December 28, 2007, respectively. The letter of credit fees
now range from 1.50% to 1.60%, excluding a fronting fee of 0.125% per annum. We do not intend to
borrow under our domestic senior revolving credit facility during fiscal year 2008. A portion of
the letters of credit issued under the domestic senior credit agreement have performance pricing
that is decreased (or increased) as a result of improvements (or reductions) in the credit rating
assigned to the domestic senior credit agreement by Moodys Investors Service and/or Standard &
Poors. However, this performance pricing is not expected to materially impact our liquidity or
capital resources in fiscal year 2008.
58
We do not expect to be required to make any mandatory contributions to our U.S. pension plans
in fiscal year 2008. We expect to contribute a total of approximately $32,700 to our foreign
pension plans in fiscal year 2008, of which $24,700 has been contributed in the fiscal nine months
ended September 26, 2008.
Please refer to Note 4 to the condensed consolidated financial statements in this quarterly
report on Form 10-Q for further information regarding our debt obligations.
On September 12, 2008, we announced a share repurchase program pursuant to which we are
authorized to repurchase up to $750,000 of our outstanding common shares. Any repurchases will be
made at our discretion in the open market or in privately negotiated transactions in compliance
with applicable securities laws and other legal requirements and will depend on a variety of
factors, including market conditions, share price and other factors. The program does not
obligate us to acquire any particular number of common shares. The program has no expiration date
and may be suspended or discontinued at any time. Any repurchases made pursuant to the share
repurchase program will be funded using our cash on hand. Please refer to Part II, Item 2, for a
description of the common shares purchased pursuant to this program in the fiscal quarter ended
September 26, 2008. Subsequent to the quarter ended September 26, 2008, we repurchased an
aggregate of 9,233,394 common shares that settled prior to November 5, 2008 pursuant to our common
share repurchase program for an aggregate cost of $288,100. Cumulatively through November 5, 2008,
we have repurchased 10,518,942 common shares for an aggregate cost of $338,173. We have executed
the repurchases in accordance with a 10b5-1 repurchase plan as well as other open market purchases.
The 10b5-1 repurchase plan allows us to purchase common shares at times when we may not otherwise
do so due to regulatory or internal restrictions. Purchases under the 10b5-1 repurchase plan are
based on parameters set forth in the plan.
Effective September 29, 2008, we and the requisite lenders under our domestic senior
credit agreement amended the domestic senior credit agreement to (1) allow us to use cash of up to
$750,000 to repurchase our outstanding common shares under our common share repurchase program,
subject to certain conditions, and (2) increase the aggregate amount of permissible capital
expenditures from $40,000 to $80,000 for fiscal year 2008 and $70,000 for fiscal years thereafter,
subject to certain adjustments that have been reflected in the domestic senior credit agreement
since its original execution in September 2006, including, among other items, an exclusion related
to capital expenditures that are financed by special-purpose project debt. Please refer to Note 4
to the condensed consolidated financial statements in this quarterly report on Form 10-Q for a
detailed listing of our special-purpose project debt.
On October 3, 2008, we acquired $19,200 of our 1999C Robbins Bonds (as defined in Note 4 to
the condensed consolidated financial statements in this quarterly report on Form 10-Q) for $19,000
of cash, plus accrued and unpaid interest to date. After the acquisition, we have $1,300 of 1999C
Robbins Bonds outstanding.
We have not declared or paid a cash dividend since July 2001 and we do not have any plans to
declare or pay any cash dividends. Our current credit agreement contains limitations on cash
dividend payments as well as other restricted payments.
Off-Balance Sheet Arrangements
We own several noncontrolling equity interests in power projects in Chile and Italy. Certain
of the projects have third-party debt that is not consolidated in our balance sheet. We have also
issued certain guarantees for the Chilean project. Please refer to Note 3 to the condensed
consolidated financial statements in this quarterly report on Form 10-Q for further information
related to these projects.
59
Backlog and New Orders
The backlog of unfilled orders includes amounts based on signed contracts as well as agreed
letters of intent, which we have determined are legally binding and likely to proceed. Although
backlog represents only business that is considered likely to be performed, cancellations or scope
adjustments may and do occur. The elapsed time from the award of a contract to completion of
performance may be up to approximately four years. The dollar amount of backlog is not necessarily
indicative of our future earnings related to the performance of such work due to factors outside
our control, such as changes in project schedules, scope adjustments or project cancellations. We
cannot predict with certainty the portion of backlog to be performed in a given year. Backlog is
adjusted quarterly to reflect project cancellations, deferrals, revised project scope and cost, and
sales of subsidiaries, if any.
Backlog measured in Foster Wheeler scope reflects the dollar value of backlog excluding
third-party costs incurred by us on a reimbursable basis as agent or principal, which we refer to
as flow-through costs. Foster Wheeler scope measures the component of backlog with profit
potential and corresponds to our services plus fees for reimbursable contracts and total selling
price for fixed-price or lump-sum contracts.
60
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26, 2008
|
|
|
September 28, 2007
|
|
|
|
Global
|
|
|
Global
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
|
|
|
|
E&C
|
|
|
Power
|
|
|
|
|
|
|
E&C
|
|
|
Power
|
|
|
|
|
|
|
Group
|
|
|
Group
|
|
|
Total
|
|
|
Group
|
|
|
Group
|
|
|
Total
|
|
NEW ORDERS (FUTURE REVENUES)
BY PROJECT LOCATION :
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America
|
|
$
|
74,600
|
|
|
$
|
106,600
|
|
|
$
|
181,200
|
|
|
$
|
131,000
|
|
|
$
|
73,100
|
|
|
$
|
204,100
|
|
South America
|
|
|
29,600
|
|
|
|
95,300
|
|
|
|
124,900
|
|
|
|
7,400
|
|
|
|
10,800
|
|
|
|
18,200
|
|
Europe
|
|
|
381,600
|
|
|
|
132,300
|
|
|
|
513,900
|
|
|
|
163,800
|
|
|
|
196,300
|
|
|
|
360,100
|
|
Asia
|
|
|
343,500
|
|
|
|
88,000
|
|
|
|
431,500
|
|
|
|
1,022,100
|
|
|
|
20,000
|
|
|
|
1,042,100
|
|
Middle East
|
|
|
62,400
|
|
|
|
100
|
|
|
|
62,500
|
|
|
|
104,200
|
|
|
|
400
|
|
|
|
104,600
|
|
Australasia and other
|
|
|
63,500
|
|
|
|
12,800
|
|
|
|
76,300
|
|
|
|
143,500
|
|
|
|
5,900
|
|
|
|
149,400
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
955,200
|
|
|
$
|
435,100
|
|
|
$
|
1,390,300
|
|
|
$
|
1,572,000
|
|
|
$
|
306,500
|
|
|
$
|
1,878,500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America
|
|
$
|
364,100
|
|
|
$
|
492,600
|
|
|
$
|
856,700
|
|
|
$
|
214,700
|
|
|
$
|
639,900
|
|
|
$
|
854,600
|
|
South America
|
|
|
44,900
|
|
|
|
126,000
|
|
|
|
170,900
|
|
|
|
13,600
|
|
|
|
79,400
|
|
|
|
93,000
|
|
Europe
|
|
|
939,400
|
|
|
|
417,100
|
|
|
|
1,356,500
|
|
|
|
567,800
|
|
|
|
531,200
|
|
|
|
1,099,000
|
|
Asia
|
|
|
651,100
|
|
|
|
116,800
|
|
|
|
767,900
|
|
|
|
1,455,300
|
|
|
|
140,200
|
|
|
|
1,595,500
|
|
Middle East
|
|
|
194,400
|
|
|
|
100
|
|
|
|
194,500
|
|
|
|
355,700
|
|
|
|
5,200
|
|
|
|
360,900
|
|
Australasia and other
|
|
|
114,900
|
|
|
|
13,100
|
|
|
|
128,000
|
|
|
|
268,100
|
|
|
|
7,200
|
|
|
|
275,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
2,308,800
|
|
|
$
|
1,165,700
|
|
|
$
|
3,474,500
|
|
|
$
|
2,875,200
|
|
|
$
|
1,403,100
|
|
|
$
|
4,278,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NEW ORDERS (FUTURE REVENUES)
BY INDUSTRY:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Quarters Ended
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Power generation
|
|
$
|
5,300
|
|
|
$
|
403,000
|
|
|
$
|
408,300
|
|
|
$
|
12,700
|
|
|
$
|
275,300
|
|
|
$
|
288,000
|
|
Oil refining
|
|
|
561,400
|
|
|
|
|
|
|
|
561,400
|
|
|
|
274,000
|
|
|
|
|
|
|
|
274,000
|
|
Pharmaceutical
|
|
|
44,500
|
|
|
|
|
|
|
|
44,500
|
|
|
|
21,800
|
|
|
|
|
|
|
|
21,800
|
|
Oil and gas
|
|
|
116,200
|
|
|
|
|
|
|
|
116,200
|
|
|
|
176,700
|
|
|
|
|
|
|
|
176,700
|
|
Chemical/petrochemical
|
|
|
230,000
|
|
|
|
|
|
|
|
230,000
|
|
|
|
1,073,200
|
|
|
|
|
|
|
|
1,073,200
|
|
Power plant operation and
maintenance
|
|
|
|
|
|
|
32,100
|
|
|
|
32,100
|
|
|
|
|
|
|
|
31,200
|
|
|
|
31,200
|
|
Environmental
|
|
|
8,200
|
|
|
|
|
|
|
|
8,200
|
|
|
|
7,300
|
|
|
|
|
|
|
|
7,300
|
|
Other, net of eliminations
|
|
|
(10,400
|
)
|
|
|
|
|
|
|
(10,400
|
)
|
|
|
6,300
|
|
|
|
|
|
|
|
6,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
955,200
|
|
|
$
|
435,100
|
|
|
$
|
1,390,300
|
|
|
$
|
1,572,000
|
|
|
$
|
306,500
|
|
|
$
|
1,878,500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fiscal Nine Months Ended
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Power generation
|
|
$
|
43,800
|
|
|
$
|
1,067,700
|
|
|
$
|
1,111,500
|
|
|
$
|
20,400
|
|
|
$
|
1,313,600
|
|
|
$
|
1,334,000
|
|
Oil refining
|
|
|
1,429,200
|
|
|
|
|
|
|
|
1,429,200
|
|
|
|
978,000
|
|
|
|
|
|
|
|
978,000
|
|
Pharmaceutical
|
|
|
84,500
|
|
|
|
|
|
|
|
84,500
|
|
|
|
80,500
|
|
|
|
|
|
|
|
80,500
|
|
Oil and gas
|
|
|
240,400
|
|
|
|
|
|
|
|
240,400
|
|
|
|
462,500
|
|
|
|
|
|
|
|
462,500
|
|
Chemical/petrochemical
|
|
|
483,000
|
|
|
|
|
|
|
|
483,000
|
|
|
|
1,266,900
|
|
|
|
|
|
|
|
1,266,900
|
|
Power plant operation and
maintenance
|
|
|
|
|
|
|
98,000
|
|
|
|
98,000
|
|
|
|
|
|
|
|
89,500
|
|
|
|
89,500
|
|
Environmental
|
|
|
23,300
|
|
|
|
|
|
|
|
23,300
|
|
|
|
25,400
|
|
|
|
|
|
|
|
25,400
|
|
Other, net of eliminations
|
|
|
4,600
|
|
|
|
|
|
|
|
4,600
|
|
|
|
41,500
|
|
|
|
|
|
|
|
41,500
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
2,308,800
|
|
|
$
|
1,165,700
|
|
|
$
|
3,474,500
|
|
|
$
|
2,875,200
|
|
|
$
|
1,403,100
|
|
|
$
|
4,278,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
61
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 26, 2008
|
|
|
September 28, 2007
|
|
|
|
Global
|
|
|
Global
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
|
|
|
|
E&C
|
|
|
Power
|
|
|
|
|
|
|
E&C
|
|
|
Power
|
|
|
|
|
|
|
Group
|
|
|
Group
|
|
|
Total
|
|
|
Group
|
|
|
Group
|
|
|
Total
|
|
BACKLOG (FUTURE REVENUES)
BY CONTRACT TYPE:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lump-sum turnkey
|
|
$
|
17,900
|
|
|
$
|
345,100
|
|
|
$
|
363,000
|
|
|
$
|
116,300
|
|
|
$
|
525,000
|
|
|
$
|
641,300
|
|
Other fixed-price
|
|
|
441,600
|
|
|
|
946,600
|
|
|
|
1,388,200
|
|
|
|
401,900
|
|
|
|
655,900
|
|
|
|
1,057,800
|
|
Reimbursable
|
|
|
5,351,800
|
|
|
|
172,100
|
|
|
|
5,523,900
|
|
|
|
4,385,800
|
|
|
|
199,700
|
|
|
|
4,585,500
|
|
Eliminations
|
|
|
(700
|
)
|
|
|
(12,200
|
)
|
|
|
(12,900
|
)
|
|
|
(10,500
|
)
|
|
|
(1,000
|
)
|
|
|
(11,500
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
5,810,600
|
|
|
$
|
1,451,600
|
|
|
$
|
7,262,200
|
|
|
$
|
4,893,500
|
|
|
$
|
1,379,600
|
|
|
$
|
6,273,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BACKLOG (FUTURE REVENUES)
BY PROJECT LOCATION:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America
|
|
$
|
302,900
|
|
|
$
|
612,400
|
|
|
$
|
915,300
|
|
|
$
|
218,900
|
|
|
$
|
542,200
|
|
|
$
|
761,100
|
|
South America
|
|
|
44,500
|
|
|
|
168,200
|
|
|
|
212,700
|
|
|
|
12,200
|
|
|
|
86,900
|
|
|
|
99,100
|
|
Europe
|
|
|
877,800
|
|
|
|
544,300
|
|
|
|
1,422,100
|
|
|
|
642,500
|
|
|
|
616,200
|
|
|
|
1,258,700
|
|
Asia
|
|
|
1,598,800
|
|
|
|
119,000
|
|
|
|
1,717,800
|
|
|
|
2,265,400
|
|
|
|
127,700
|
|
|
|
2,393,100
|
|
Middle East
|
|
|
443,300
|
|
|
|
100
|
|
|
|
443,400
|
|
|
|
1,205,900
|
|
|
|
600
|
|
|
|
1,206,500
|
|
Australasia and other
|
|
|
2,543,300
|
|
|
|
7,600
|
|
|
|
2,550,900
|
|
|
|
548,600
|
|
|
|
6,000
|
|
|
|
554,600
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
5,810,600
|
|
|
$
|
1,451,600
|
|
|
$
|
7,262,200
|
|
|
$
|
4,893,500
|
|
|
$
|
1,379,600
|
|
|
$
|
6,273,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BACKLOG (FUTURE REVENUES)
BY INDUSTRY:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Power generation
|
|
$
|
51,800
|
|
|
$
|
1,329,700
|
|
|
$
|
1,381,500
|
|
|
$
|
101,000
|
|
|
$
|
1,263,100
|
|
|
$
|
1,364,100
|
|
Oil refining
|
|
|
1,778,500
|
|
|
|
|
|
|
|
1,778,500
|
|
|
|
1,761,200
|
|
|
|
|
|
|
|
1,761,200
|
|
Pharmaceutical
|
|
|
66,600
|
|
|
|
|
|
|
|
66,600
|
|
|
|
58,000
|
|
|
|
|
|
|
|
58,000
|
|
Oil and gas
|
|
|
2,638,400
|
|
|
|
|
|
|
|
2,638,400
|
|
|
|
718,700
|
|
|
|
|
|
|
|
718,700
|
|
Chemical/petrochemical
|
|
|
1,243,400
|
|
|
|
|
|
|
|
1,243,400
|
|
|
|
2,186,100
|
|
|
|
|
|
|
|
2,186,100
|
|
Power plant operation and maintenance
|
|
|
|
|
|
|
121,900
|
|
|
|
121,900
|
|
|
|
|
|
|
|
116,500
|
|
|
|
116,500
|
|
Environmental
|
|
|
13,400
|
|
|
|
|
|
|
|
13,400
|
|
|
|
42,200
|
|
|
|
|
|
|
|
42,200
|
|
Other, net of eliminations
|
|
|
18,500
|
|
|
|
|
|
|
|
18,500
|
|
|
|
26,300
|
|
|
|
|
|
|
|
26,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
5,810,600
|
|
|
$
|
1,451,600
|
|
|
$
|
7,262,200
|
|
|
$
|
4,893,500
|
|
|
$
|
1,379,600
|
|
|
$
|
6,273,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
FOSTER WHEELER SCOPE
IN BACKLOG
|
|
$
|
1,754,700
|
|
|
$
|
1,438,700
|
|
|
$
|
3,193,400
|
|
|
$
|
1,645,100
|
|
|
$
|
1,366,500
|
|
|
$
|
3,011,600
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
E&C MAN-HOURS
IN BACKLOG (in thousands)
|
|
|
14,400
|
|
|
|
|
|
|
|
14,400
|
|
|
|
13,300
|
|
|
|
|
|
|
|
13,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Inflation
The effect of inflation on our financial results is minimal. Although a majority of our
revenues are realized under long-term contracts, the selling prices of such contracts, established
for deliveries in the future, generally reflect estimated costs to complete the projects in these
future periods. In addition, many of our projects are reimbursable at actual cost plus a fee,
while some of the fixed-price contracts provide for price adjustments through escalation clauses.
Application of Critical Accounting Estimates
Our condensed consolidated financial statements are presented in accordance with accounting
principles generally accepted in the United States of America. Management and the Audit Committee
of our Board of Directors approve the critical accounting policies.
A full discussion of our critical accounting policies and estimates is included in our 2007
Form 10-K. We did not have a significant change to the application of our critical accounting
policies and estimates during the first fiscal nine months of 2008.
62
Accounting Developments
In September 2006, the Financial Accounting Standards Board, or FASB, issued SFAS No. 157,
Fair Value Measurements. SFAS No. 157 defines fair value, establishes a framework for measuring
fair value in generally accepted accounting principles, and expands disclosures about fair value
measurements. The standard is effective for financial assets and liabilities, as well as for any
other assets and liabilities that are required to be measured at fair value on a recurring basis,
in financial statements for fiscal years beginning after November 15, 2007. In February 2008, the
FASB issued a partial one-year deferral of SFAS No. 157 for nonfinancial assets and liabilities
that are only subject to fair value measurement on a nonrecurring basis. We have elected to defer
the application of SFAS No. 157 for our nonfinancial assets and liabilities measured at fair value
on a nonrecurring basis until the fiscal year beginning December 27, 2008, and are in the process
of assessing its impact on our financial position and results of operations related to such assets
and liabilities. Our financial assets and liabilities that are recorded at fair value consist
primarily of the assets or liabilities arising from derivative financial instruments. The adoption
of SFAS No. 157 did not have a material effect on our financial position or results of operations.
In December 2007, the FASB issued SFAS No. 141 (revised 2007), Business Combinations. SFAS
No. 141R replaces SFAS No. 141, Business Combinations and changes the accounting treatment for
business acquisitions. SFAS No. 141R requires the acquiring entity in a business combination to
recognize all (and only) the assets acquired and liabilities assumed in the transaction and
establishes the acquisition-date fair value as the measurement objective for all assets acquired
and liabilities assumed in a business combination. Certain provisions of this standard will, among
other things, impact the determination of acquisition-date fair value of consideration paid in a
business combination (including contingent consideration); exclude transaction costs from
acquisition accounting; and change accounting practices for acquired contingencies,
acquisition-related restructuring costs, in-process research and development, indemnification
assets, and tax benefits. Most of the provisions of SFAS No. 141R apply prospectively to business
combinations for which the acquisition date is on or after the beginning of the first annual
reporting period beginning on or after December 15, 2008. Early adoption is not permitted. We are
currently assessing the impact that SFAS No. 141R may have on our financial position, results of
operations and cash flows.
In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated
Financial Statements an amendment of ARB No. 51. SFAS No. 160 amends the accounting and
reporting standards for the noncontrolling interest in a subsidiary (often referred to as minority
interest) and for the deconsolidation of a subsidiary. Under SFAS No. 160, the noncontrolling
interest in a subsidiary is reported as equity in the parent companys consolidated financial
statements. SFAS No. 160 also requires that the parent companys consolidated statement of
operations include both the parent and noncontrolling interest share of the subsidiarys statement
of operations. Formerly, the noncontrolling interest share was shown as a reduction of income on
the parents consolidated statement of operations. SFAS No. 160 is effective for fiscal years, and
interim periods within those fiscal years, beginning on or after December 15, 2008. SFAS No. 160 is
to be applied prospectively as of the beginning of the fiscal year in which this statement is
initially applied; however, presentation and disclosure requirements shall be applied
retrospectively for all periods presented. We do not believe that SFAS No. 160 will have a
significant impact on our financial position, results of operations and cash flows.
In March 2008, the FASB issued SFAS No. 161, Disclosures about Derivative Instruments and
Hedging Activities. SFAS No. 161 requires enhanced disclosures to enable investors to better
understand the effects of derivative instruments and hedging activities on an entitys financial
position, financial performance and cash flows. SFAS No. 161 changes the disclosure requirements
about the location and amounts of derivative instruments in an entitys financial statements, how
derivative instruments and related hedged items are accounted for under SFAS No. 133, and how
derivative instruments and related hedged items affect the companys financial position, financial
performance and cash flows. Additionally, SFAS No. 161 requires disclosure of the fair values of
derivative instruments and their gains and losses in a tabular format. SFAS No. 161 also requires
more information about an entitys liquidity by requiring disclosure of derivative features that
are credit risk-related. Finally, SFAS No. 161 requires cross-referencing within footnotes to
enable financial statement users to locate important information about derivative instruments. SFAS
No. 161 is effective for financial statements issued for fiscal years and interim periods beginning
after November 15, 2008, with early application encouraged. We are currently assessing the impact
that SFAS No. 161 may have on our financial statement disclosures.
63
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
During the fiscal quarter and nine months ended September 26, 2008, there were no material
changes in the market risks as described in our annual report on Form 10-K for the fiscal year
ended December 28, 2007.
ITEM 4. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
We maintain disclosure controls and procedures designed to ensure that information required to
be disclosed by us in the reports that we file or submit under the Securities Exchange Act of 1934,
as amended (the Exchange Act), is recorded, processed, summarized and reported, within the time
periods specified in the SECs rules and forms. Disclosure controls and procedures include,
without limitation, controls and procedures designed to ensure that the information required to be
disclosed by us in the reports that we file or submit under the Exchange Act is accumulated and
communicated to our management, including our principal executive and principal financial officers,
or persons performing similar functions, as appropriate, to allow timely decisions regarding
required disclosure. In designing and evaluating the disclosure controls and procedures, we
recognize that any controls and procedures, no matter how well designed and operated, can provide
only reasonable assurance of achieving the desired control objectives and we necessarily are
required to apply our judgment in evaluating the cost-benefit relationship of possible controls and
procedures.
As of the end of the period covered by this report, our chief executive officer and our chief
financial officer carried out an evaluation, with the participation of our Disclosure Committee and
management, of the effectiveness of the design and operation of our disclosure controls and
procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) pursuant to
Exchange Act Rule 13a-15. Based on this evaluation, our chief executive officer and our chief
financial officer concluded, at the reasonable assurance level, that our disclosure controls and
procedures were effective as of the end of the period covered by this report.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting in the fiscal quarter
ended September 26, 2008 that have materially affected, or are reasonably likely to materially
affect, our internal control over financial reporting.
64
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
Please refer to Note 12 to the condensed consolidated financial statements in this quarterly
report on Form 10-Q for a discussion of legal proceedings, which is incorporated by reference in
this Part II.
ITEM 1A. RISK FACTORS
Information regarding our risk factors appears in Part I, Item 1A, Risk Factors, in our
annual report on Form 10-K for the fiscal year ended December 28, 2007, which we filed with the SEC
on February 26, 2008. There have been no material changes in those risk factors.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS (amounts in thousands of
dollars, except share data and per share amounts)
(c) Purchases of Equity Securities by the Issuer and Affiliated Purchasers.
On September 12, 2008, we announced a share repurchase program pursuant to which we are
authorized to repurchase up to $750,000 of our outstanding common shares. The following table
provides information with respect to common share purchases during the fiscal third quarter of
2008.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Number of
|
|
|
Approximate
|
|
|
|
|
|
|
|
|
|
|
|
Shares Purchased
|
|
|
Dollar Value of
|
|
|
|
|
|
|
|
|
|
|
|
as Part of
|
|
|
Shares that May
|
|
|
|
|
|
|
|
Average
|
|
|
Publicly
|
|
|
Yet Be Purchased
|
|
|
|
Total Number of
|
|
|
Price Paid
|
|
|
Announced Plans
|
|
|
Under the Plans
|
|
Fiscal Month
|
|
Shares Purchased (1)
|
|
|
per Share
|
|
|
or Programs
|
|
|
or Programs
|
|
June 28, 2008 through July 25, 2008
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
July 26, 2008 through August 22, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
August 23, 2008 through September 26, 2008
|
|
|
1,285,548
|
|
|
|
38.89
|
|
|
|
1,285,548
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
1,285,548
|
|
|
$
|
38.89
|
|
|
|
1,285,548
|
(2)
|
|
$
|
699,999
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
During the fiscal third quarter of 2008, we repurchased an aggregate of 1,285,548 shares
of Foster Wheeler Ltd. common shares in open market transactions pursuant to the repurchase program
that was publicly announced on September 12, 2008 and which authorizes us to repurchase up to
$750,000 of our outstanding common shares. The repurchase program has no expiration date and may
be suspended for periods or discontinued at any time. We did not repurchase any of our common
shares other than through our publicly announced repurchase program.
|
|
(2)
|
|
As of September 26, 2008, an aggregate of 1,285,548 shares were purchased for a total of
$50,001 since the inception of the repurchase program announced on September 12, 2008.
|
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
None.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.
ITEM 5. OTHER INFORMATION
None.
65
|
|
|
Exhibit No.
|
|
Exhibits
|
|
|
|
3.1
|
|
Memorandum of Association of Foster Wheeler Ltd. (Filed as Annex II to Foster Wheeler
Ltd.s Form S-4/A (File No. 333-52468) filed on March 9, 2001, and incorporated herein by
reference.)
|
|
|
|
3.2
|
|
Memoranda of Reduction of Share Capital and Memorandum of Increase in Share Capital each
dated December 1, 2004. (Filed as Exhibit 99.2 to Foster Wheeler Ltd.s Form 8-K, dated
November 29, 2004 and filed on December 2, 2004, and incorporated herein by reference.)
|
|
|
|
3.3
|
|
Certificate of Designation relating to Foster Wheeler Ltd.s Series B Convertible
Preferred Shares, adopted on September 24, 2004. (Filed as Exhibit 3.1 to Foster Wheeler
Ltd.s Form 10-Q for the quarter ended September 24, 2004, and incorporated herein by
reference.)
|
|
|
|
3.4
|
|
Bye-Laws of Foster Wheeler Ltd., amended May 9, 2006. (Filed as Exhibit 3.2 to Foster
Wheeler Ltd.s Form 8-K, dated May 9, 2006 and filed on May 12, 2006, and incorporated
herein by reference.)
|
|
|
|
3.5
|
|
Memorandum of Increase of Share Capital dated February 7, 2008. (Filed as Exhibit 3.5 to
Foster Wheeler Ltd.s Form 10-K for the fiscal year ended December 28, 2007, and
incorporated herein by reference.)
|
|
|
|
10.1
|
|
Amendment No. 2, dated September 29, 2008, to the Credit Agreement, dated September 13,
2006, between Foster Wheeler LLC, Foster Wheeler Inc., Foster Wheeler USA Corporation,
Foster Wheeler North America Corp., Foster Wheeler Energy Corporation and Foster Wheeler
International Corporation, as borrowers, Foster Wheeler Ltd., Foster Wheeler Holdings
Ltd., the subsidiary guarantors party thereto, the lenders party thereto, and BNP Paribas.
(Filed as Exhibit 10.1 to Foster Wheeler Ltd.s Form 8-K, dated September 29, 2008 and
filed on October 14, 2008, and incorporated herein by reference.)
|
|
|
|
10.2
|
|
Employment Agreement, dated as of August 20, 2008, between Foster Wheeler Ltd. and Peter
D. Rose.
|
|
|
|
10.3
|
|
Agreement for the Termination of Fixed Term Employment Contract, dated as of September 30,
2008, between Foster Wheeler Continental Europe S.r.L. and Umberto della Sala.
|
|
|
|
10.4
|
|
Fixed Term Employment Agreement, dated as of October 1, 2008, between Foster Wheeler
Global E&C S.r.L. and Umberto della Sala.
|
|
|
|
10.5
|
|
First Amendment to the Employment Agreement, dated as of October 1, 2008, between Foster
Wheeler Ltd. and Umberto della Sala.
|
|
|
|
10.6
|
|
Deed of Variation, dated as of October 8, 2008, between Foster Wheeler Energy Limited and
David Wardlaw. (Filed as Exhibit 10.1 to Foster Wheeler Ltd.s Form 8-K, dated October 8,
2008 and filed on October 14, 2008, and incorporated herein by reference.)
|
|
|
|
23.1
|
|
Consent of Analysis, Research & Planning Corporation.
|
|
|
|
23.2
|
|
Consent of Peterson Risk Consulting.
|
|
|
|
31.1
|
|
Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 of Raymond J.
Milchovich.
|
|
|
|
31.2
|
|
Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 of Franco Baseotto.
|
|
|
|
32.1
|
|
Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002 of Raymond J. Milchovich.
|
|
|
|
32.2
|
|
Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002 of Franco Baseotto.
|
66
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly
caused this Report to be signed on its behalf by the undersigned, thereunto duly authorized.
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FOSTER WHEELER LTD.
(Registrant)
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Date: November 5, 2008
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/s/
Raymond J. Milchovich
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Raymond J. Milchovich
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Chairman and Chief Executive Officer
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Date: November 5, 2008
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/s/
Franco Baseotto
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Franco Baseotto
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Executive Vice President, Chief Financial
Officer and Treasurer
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67
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