UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
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þ
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
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For the quarterly period ended September 28, 2007
or
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o
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
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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 or a non-accelerated filer. See the definition of accelerated filer and large accelerated
filer in Rule 12b-2 of the Exchange Act.
Large accelerated filer
þ
Accelerated filer
o
Non-accelerated filer
o
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: 71,835,337 common shares ($0.01 par value) were outstanding as of
October 31, 2007.
FOSTER WHEELER LTD.
INDEX
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Part I FINANCIAL INFORMATION
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Financial Statements (Unaudited):
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Condensed Consolidated Statement of Operations for the Three and Nine Months Ended September 28, 2007 and September 29, 2006
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Condensed Consolidated Balance Sheet as of September 28, 2007 and December 29, 2006
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Condensed Consolidated Statement of Changes in Shareholders Equity for the Nine Months Ended September 28, 2007 and September 29, 2006
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Condensed Consolidated Statement of Comprehensive Income for the Three and Nine Months Ended September 28, 2007 and September 29, 2006
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Condensed Consolidated Statement of Cash Flows for the Nine Months Ended September 28, 2007 and September 29, 2006
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Notes to Condensed Consolidated Financial Statements
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Management's Discussion and Analysis of Financial Condition and Results of Operations
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Quantitative and Qualitative Disclosures about Market Risk
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Controls and Procedures
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Part II OTHER INFORMATION
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Legal Proceedings
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Risk Factors
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Exhibits
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EX-10.1: CONSULTING AGREEMENT
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EX-31.1: CERTIFICATION
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EX-31.2: CERTIFICATION
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EX-32.1: CERTIFICATION
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EX-32.2: CERTIFICATION
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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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Three Months Ended
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Nine Months Ended
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September 28,
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September 29,
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September 28,
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September 29,
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2007
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2006
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2007
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2006
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Operating revenues
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$
|
1,299,872
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$
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910,580
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$
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3,641,760
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$
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2,301,729
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Cost of operating revenues
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(1,101,912
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)
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(781,391
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)
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(3,067,442
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)
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(1,964,280
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)
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Contract profit
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197,960
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129,189
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574,318
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337,449
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Selling, general and administrative expenses
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(62,686
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)
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(51,543
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)
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(180,079
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)
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(159,570
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)
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Other income
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34,786
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5,382
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67,993
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41,250
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Other deductions
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(7,672
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)
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(14,983
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)
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(33,075
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)
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(33,070
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)
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Interest expense
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(4,716
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)
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(5,068
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)
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(14,652
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)
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(19,803
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)
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Minority interest in income of consolidated affiliates
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(1,765
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)
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(2,255
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)
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(5,038
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)
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(3,251
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)
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Net asbestos-related gains
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8,633
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|
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36,074
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8,633
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115,664
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Prior domestic senior credit agreement fees and expenses
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(14,823
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)
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(14,823
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)
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Loss on debt reduction initiatives
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(12,483
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)
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Income before income taxes
|
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|
164,540
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|
81,973
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|
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|
418,100
|
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251,363
|
|
Provision for income taxes
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(35,439
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)
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(6,146
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)
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(102,324
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)
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(52,487
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)
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|
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Net income
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$
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129,101
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$
|
75,827
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$
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315,776
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$
|
198,876
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Earnings per common share (see Note 1):
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Basic
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$
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1.81
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|
|
$
|
1.12
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|
|
$
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4.48
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$
|
2.72
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|
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|
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Diluted
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$
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1.78
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$
|
1.07
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$
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4.37
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$
|
2.55
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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)
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|
|
|
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September 28,
|
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December 29,
|
|
|
|
2007
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|
2006
|
|
ASSETS
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Current Assets:
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Cash and cash equivalents
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$
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860,397
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|
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$
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610,887
|
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Accounts and notes receivable, net:
|
|
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Trade
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|
563,854
|
|
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|
483,819
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Other
|
|
|
123,623
|
|
|
|
83,497
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Contracts in process
|
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|
239,697
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|
|
159,121
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Prepaid, deferred and refundable income taxes
|
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|
27,401
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20,708
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Other current assets
|
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|
36,299
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31,288
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|
|
|
|
|
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Total current assets
|
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|
1,851,271
|
|
|
|
1,389,320
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Land, buildings and equipment, net
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326,886
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|
|
|
302,488
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Restricted cash
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|
22,684
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|
19,080
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Notes and accounts receivable long-term
|
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|
2,980
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|
|
5,395
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|
Investments in and advances to unconsolidated affiliates
|
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191,406
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|
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167,186
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Goodwill, net
|
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|
52,052
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|
|
|
51,573
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Other intangible assets, net
|
|
|
61,953
|
|
|
|
62,004
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|
Asbestos-related insurance recovery receivable
|
|
|
311,279
|
|
|
|
350,322
|
|
Other assets
|
|
|
95,116
|
|
|
|
91,081
|
|
Deferred income taxes
|
|
|
119,882
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|
|
|
127,574
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|
|
|
|
|
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TOTAL ASSETS
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|
$
|
3,035,509
|
|
|
$
|
2,566,023
|
|
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|
|
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LIABILITIES, TEMPORARY EQUITY AND SHAREHOLDERS EQUITY
|
|
|
|
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Current Liabilities:
|
|
|
|
|
|
|
|
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Current installments on long-term debt
|
|
$
|
24,567
|
|
|
$
|
21,477
|
|
Accounts payable
|
|
|
323,391
|
|
|
|
263,715
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|
Accrued expenses
|
|
|
328,608
|
|
|
|
288,658
|
|
Billings in excess of costs and estimated earnings on uncompleted contracts
|
|
|
686,805
|
|
|
|
622,422
|
|
Income taxes payable
|
|
|
69,871
|
|
|
|
51,331
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
1,433,242
|
|
|
|
1,247,603
|
|
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|
|
|
|
|
|
Long-term debt
|
|
|
175,201
|
|
|
|
181,492
|
|
Deferred income taxes
|
|
|
70,395
|
|
|
|
66,522
|
|
Pension, postretirement and other employee benefits
|
|
|
344,615
|
|
|
|
385,976
|
|
Asbestos-related liability
|
|
|
363,478
|
|
|
|
424,628
|
|
Other long-term liabilities and minority interest
|
|
|
206,882
|
|
|
|
196,092
|
|
Commitments and contingencies
|
|
|
|
|
|
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|
|
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|
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|
|
TOTAL LIABILITIES
|
|
|
2,593,813
|
|
|
|
2,502,313
|
|
|
|
|
|
|
|
|
Temporary Equity:
|
|
|
|
|
|
|
|
|
Non-vested restricted awards subject to redemption
|
|
|
1,727
|
|
|
|
983
|
|
|
|
|
|
|
|
|
TOTAL TEMPORARY EQUITY
|
|
|
1,727
|
|
|
|
983
|
|
|
|
|
|
|
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|
Shareholders Equity:
|
|
|
|
|
|
|
|
|
Preferred shares:
|
|
|
|
|
|
|
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$0.01 par value; authorized: September 28, 2007 - 903,424 shares and
December 29, 2006 - 903,714 shares; issued and outstanding:
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|
|
|
|
|
|
|
September 28, 2007 - 3,368 shares and December 29, 2006 - 3,658 shares
|
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|
|
|
|
|
|
Common shares:
|
|
|
|
|
|
|
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$0.01 par value; authorized: September 28, 2007 - 148,002,024 shares and
December 29, 2006 - 148,001,734 shares; issued and outstanding:
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|
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|
|
|
|
|
|
September 28, 2007 - 71,805,710 shares and December 29, 2006 - 69,091,474 shares
|
|
|
717
|
|
|
|
690
|
|
Paid-in capital
|
|
|
1,382,631
|
|
|
|
1,349,492
|
|
Accumulated deficit
|
|
|
(632,693
|
)
|
|
|
(944,113
|
)
|
Accumulated other comprehensive loss
|
|
|
(310,686
|
)
|
|
|
(343,342
|
)
|
|
|
|
|
|
|
|
TOTAL SHAREHOLDERS EQUITY
|
|
|
439,969
|
|
|
|
62,727
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES, TEMPORARY EQUITY AND SHAREHOLDERS EQUITY
|
|
$
|
3,035,509
|
|
|
$
|
2,566,023
|
|
|
|
|
|
|
|
|
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)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 28, 2007
|
|
|
September 29, 2006
|
|
|
|
Shares
|
|
|
Amount
|
|
|
Shares
|
|
|
Amount
|
|
Preferred Shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
|
3,658
|
|
|
$
|
|
|
|
|
4,195
|
|
|
$
|
|
|
Preferred shares converted into common shares
|
|
|
(290
|
)
|
|
|
|
|
|
|
(522
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
3,368
|
|
|
$
|
|
|
|
|
3,673
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common Shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
|
69,091,474
|
|
|
$
|
690
|
|
|
|
57,462,262
|
|
|
$
|
575
|
|
Issuance of common shares upon exercise of common share
purchase warrants
|
|
|
899,994
|
|
|
|
9
|
|
|
|
8,416,333
|
|
|
|
85
|
|
Issuance of common shares upon equity-for-debt exchange
|
|
|
|
|
|
|
|
|
|
|
1,277,900
|
|
|
|
13
|
|
Issuance of common shares upon exercise of stock options
|
|
|
1,452,999
|
|
|
|
15
|
|
|
|
1,139,325
|
|
|
|
11
|
|
Issuance of common shares related to restricted awards
|
|
|
342,398
|
|
|
|
3
|
|
|
|
343,126
|
|
|
|
3
|
|
Issuance of common shares upon conversion of preferred shares
|
|
|
18,845
|
|
|
|
|
|
|
|
34,545
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
71,805,710
|
|
|
$
|
717
|
|
|
|
68,673,491
|
|
|
$
|
687
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Paid-in Capital:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
|
|
|
|
$
|
1,349,492
|
|
|
|
|
|
|
$
|
1,187,518
|
|
Issuance of common shares upon exercise of common share
purchase warrants
|
|
|
|
|
|
|
8,431
|
|
|
|
|
|
|
|
75,330
|
|
Issuance of common shares upon equity-for-debt exchange
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
58,750
|
|
Issuance of common shares upon exercise of stock options
|
|
|
|
|
|
|
16,225
|
|
|
|
|
|
|
|
12,301
|
|
Share-based compensation expense-stock options and
restricted awards
|
|
|
|
|
|
|
4,356
|
|
|
|
|
|
|
|
12,531
|
|
Excess tax benefit related to share-based compensation
|
|
|
|
|
|
|
4,130
|
|
|
|
|
|
|
|
1,115
|
|
Reclassification of unearned compensation balance upon
adoption of SFAS No. 123R
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(8,358
|
)
|
Issuance of common shares related to restricted awards
|
|
|
|
|
|
|
(3
|
)
|
|
|
|
|
|
|
(3
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
1,382,631
|
|
|
|
|
|
|
$
|
1,339,184
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated Deficit:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
|
|
|
|
$
|
(944,113
|
)
|
|
|
|
|
|
$
|
(1,206,097
|
)
|
Cumulative effect of adoption of FIN 48
|
|
|
|
|
|
|
(4,356
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year, as adjusted
|
|
|
|
|
|
|
(948,469
|
)
|
|
|
|
|
|
|
(1,206,097
|
)
|
Net income for the period
|
|
|
|
|
|
|
315,776
|
|
|
|
|
|
|
|
198,876
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
(632,693
|
)
|
|
|
|
|
|
$
|
(1,007,221
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated Other Comprehensive Loss:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
|
|
|
|
$
|
(343,342
|
)
|
|
|
|
|
|
$
|
(314,796
|
)
|
Foreign currency translation adjustments
|
|
|
|
|
|
|
19,495
|
|
|
|
|
|
|
|
(2,763
|
)
|
Net gain/(loss) on derivative instruments designated
as cash flow hedges, net of tax
|
|
|
|
|
|
|
1,279
|
|
|
|
|
|
|
|
(696
|
)
|
Defined benefit pension and other postretirement plans:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Minimum pension liability adjustment, net of tax
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(538
|
)
|
Reclassification adjustment for amortization of prior service
cost/(credit), net loss/(gain) and transition obligation/
(asset) included in net periodic benefit expense, net of tax
|
|
|
|
|
|
|
11,882
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
(310,686
|
)
|
|
|
|
|
|
$
|
(318,793
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unearned Compensation:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at beginning of year
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
$
|
(8,358
|
)
|
Reclassification of unearned compensation balance upon
adoption of SFAS No. 123R
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8,358
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance at end of period
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Shareholders Equity
|
|
|
|
|
|
$
|
439,969
|
|
|
|
|
|
|
$
|
13,857
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
5
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(in thousands of dollars)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Net income
|
|
$
|
129,101
|
|
|
$
|
75,827
|
|
|
$
|
315,776
|
|
|
$
|
198,876
|
|
Foreign currency translation adjustments
|
|
|
10,113
|
|
|
|
(1,951
|
)
|
|
|
19,495
|
|
|
|
(2,763
|
)
|
Net (loss)/gain on derivative instruments designated
as cash flow hedges, net of tax
|
|
|
(587
|
)
|
|
|
(964
|
)
|
|
|
1,279
|
|
|
|
(696
|
)
|
Defined benefit pension and other postretirement plans:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Minimum pension liability adjustment, net of tax
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(538
|
)
|
Reclassification adjustment for amortization of prior
service cost/(credit), net loss/(gain) and transition
obligation/(asset) included in net periodic benefit
expense, net of tax
|
|
|
3,984
|
|
|
|
|
|
|
|
11,882
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income
|
|
$
|
142,611
|
|
|
$
|
72,912
|
|
|
$
|
348,432
|
|
|
$
|
194,879
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See notes to condensed consolidated financial statements.
6
FOSTER WHEELER LTD. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS
(in thousands of dollars, except share data)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
315,776
|
|
|
$
|
198,876
|
|
Adjustments to reconcile net income to cash flows
from operating activities:
|
|
|
|
|
|
|
|
|
Depreciation and amortization
|
|
|
27,120
|
|
|
|
22,284
|
|
Net asbestos-related gains
|
|
|
(8,633
|
)
|
|
|
(94,144
|
)
|
Loss on debt reduction initiatives
|
|
|
|
|
|
|
5,206
|
|
Prior domestic senior credit agreement fees and expenses
|
|
|
|
|
|
|
14,823
|
|
Share-based compensation expense-stock options and restricted awards
|
|
|
5,100
|
|
|
|
12,828
|
|
Excess tax benefit related to share-based compensation
|
|
|
(3,888
|
)
|
|
|
(984
|
)
|
Deferred tax
|
|
|
15,146
|
|
|
|
8,954
|
|
Gain on sale of assets
|
|
|
(6,887
|
)
|
|
|
(1,167
|
)
|
Equity in the net earnings of partially-owned affiliates, net of dividends
|
|
|
(23,150
|
)
|
|
|
(3,952
|
)
|
Other noncash items
|
|
|
5,036
|
|
|
|
3,115
|
|
Changes in assets and liabilities:
|
|
|
|
|
|
|
|
|
Increase in receivables
|
|
|
(81,496
|
)
|
|
|
(119,861
|
)
|
Net change in contracts in process and billings in excess
of costs and estimated earnings on uncompleted contracts
|
|
|
(27,663
|
)
|
|
|
140,590
|
|
Increase/(decrease) in accounts payable and accrued expenses
|
|
|
79,347
|
|
|
|
(5,719
|
)
|
Increase in income taxes payable
|
|
|
14,462
|
|
|
|
22,986
|
|
Net change in other assets and liabilities
|
|
|
(71,735
|
)
|
|
|
(70,214
|
)
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
238,535
|
|
|
|
133,621
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
Acquisition of businesses, net of cash acquired
|
|
|
(6,319
|
)
|
|
|
457
|
|
Change in restricted cash
|
|
|
(2,848
|
)
|
|
|
4,801
|
|
Capital expenditures
|
|
|
(33,504
|
)
|
|
|
(19,381
|
)
|
Proceeds from sale of assets
|
|
|
6,732
|
|
|
|
1,503
|
|
Investments in and advances to unconsolidated affiliates
|
|
|
(1,242
|
)
|
|
|
(3,362
|
)
|
Return of investment from unconsolidated affiliates
|
|
|
6,324
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(30,857
|
)
|
|
|
(15,982
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
Partnership distributions to minority partners
|
|
|
(2,063
|
)
|
|
|
(1,941
|
)
|
Proceeds from common share purchase warrant exercises
|
|
|
8,440
|
|
|
|
75,415
|
|
Proceeds from stock option exercises
|
|
|
16,240
|
|
|
|
12,312
|
|
Excess tax benefit related to share-based compensation
|
|
|
3,888
|
|
|
|
984
|
|
Proceeds from issuance of long-term debt
|
|
|
330
|
|
|
|
2,126
|
|
Repayment of long-term debt and capital lease obligations
|
|
|
(6,225
|
)
|
|
|
(81,876
|
)
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
20,610
|
|
|
|
7,020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of exchange rate changes on cash and cash equivalents
|
|
|
21,222
|
|
|
|
11,584
|
|
|
|
|
|
|
|
|
|
Increase in cash and cash equivalents
|
|
|
249,510
|
|
|
|
136,243
|
|
Cash and cash equivalents at beginning of year
|
|
|
610,887
|
|
|
|
350,669
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$
|
860,397
|
|
|
$
|
486,912
|
|
|
|
|
|
|
|
|
NON-CASH FINANCING ACTIVITIES
In April 2006, 1,277,900 common shares were exchanged for $50,000 of aggregate principal amount of 2011 senior notes.
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 29, 2006 (2006 Form 10-K), filed with the Securities and Exchange
Commission on February 27, 2007. The condensed consolidated balance sheet as of December 29, 2006
was derived from the audited financial statements included in our 2006 Form 10-K, but does not
include all the disclosures required by accounting principles generally accepted in the United
States of America. A summary of our significant accounting policies is presented below.
As described further in Note 10, we adopted the provisions of Financial Accounting Standards
Board (FASB) Interpretation No. 48 (FIN 48), Accounting for Uncertainty in Income Taxesan
interpretation of FASB Statement No. 109, Accounting for Income Taxes, on December 30, 2006, the
first day of fiscal year 2007.
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.
Revisions
Our prior period condensed consolidated statement of operations has been revised
to classify incentive bonus expense consistent with the classification of the underlying employees
salary expense. This revision had no impact on net income as previously reported in our condensed
consolidated statement of operations, or on our condensed consolidated balance sheet, our condensed
consolidated statement of changes in shareholders equity, our condensed consolidated statement of
comprehensive income or our condensed consolidated statement of cash flows. A summary of the
financial statement line items affected by the revision is presented below.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Nine Months Ended
|
|
|
September 29, 2006
|
|
September 29, 2006
|
|
|
As Previously
|
|
As
|
|
As Previously
|
|
As
|
|
|
Reported
|
|
Revised
|
|
Reported
|
|
Revised
|
Cost of operating revenues
|
|
$
|
(775,268
|
)
|
|
$
|
(781,391
|
)
|
|
$
|
(1,952,937
|
)
|
|
$
|
(1,964,280
|
)
|
Contract profit
|
|
|
135,312
|
|
|
|
129,189
|
|
|
|
348,792
|
|
|
|
337,449
|
|
Selling, general and administrative expenses
|
|
|
(57,666
|
)
|
|
|
(51,543
|
)
|
|
|
(170,913
|
)
|
|
|
(159,570
|
)
|
Net income
|
|
|
75,827
|
|
|
|
75,827
|
|
|
|
198,876
|
|
|
|
198,876
|
|
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.
8
Revenues and profits on cost-reimbursable contracts are recorded as the services are rendered.
We include flow-through costs consisting of materials, equipment and subcontractor costs as
revenue on cost-reimbursable contracts when we are responsible 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.
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, executing 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 38 and 19 separate projects that had
final estimated profit revisions exceeding $1,000 during the first nine months of 2007 and 2006,
respectively. The changes in final estimated profits resulted in a net increase to contract profit
of $17,980 and $34,120 during the three and nine months ended September 28, 2007, respectively.
Similarly, the changes in final estimated profits resulted in a net increase/(decrease) to contract
profit of $(10,270) and $1,020 during the three and nine months ended September 29, 2006,
respectively. 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. 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 28,
2007, our condensed consolidated financial statements assumed recovery of commercial claims from
customers of $16,900, of which $2,400 was yet to be expended. As of December 29, 2006, our
condensed consolidated financial statements assumed recovery of commercial claims from customers of
$3,900, all of which was recorded on our condensed consolidated balance sheet.
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 on receipt of the anticipated contract. We had no deferred pre-contract costs as of
September 28, 2007 or December 29, 2006.
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 included
$671,038 and $490,934 maintained by our foreign subsidiaries as of September 28, 2007 and December
29, 2006, 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 of 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, 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 operations 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 significant investments in affiliates 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 11 to 40 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 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.
As of September 28, 2007 and December 29, 2006, we had goodwill of $52,052 and $51,573,
respectively. The increase of $479 in goodwill resulted from changes in foreign currency exchange
rates. All of the goodwill is related to our global power business group. In 2006, the fair value
of the reporting units exceeded the carrying amounts.
10
As described further in Note 2, in February 2007, we acquired a Finnish company that owns
patented coal flow measuring technology. In conjunction with the acquisition, we recorded $1,463
of identifiable intangible assets. We had total unamortized identifiable intangible assets of
$61,953 and $62,004 as of September 28, 2007 and December 29, 2006, respectively. The following
table details amounts relating to those assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28, 2007
|
|
|
December 29, 2006
|
|
|
|
Gross
|
|
|
|
|
|
|
Net
|
|
|
Gross
|
|
|
|
|
|
|
Net
|
|
|
|
Carrying
|
|
|
Accumulated
|
|
|
Carrying
|
|
|
Carrying
|
|
|
Accumulated
|
|
|
Carrying
|
|
|
|
Amount
|
|
|
Amortization
|
|
|
Amount
|
|
|
Amount
|
|
|
Amortization
|
|
|
Amount
|
|
Patents
|
|
$
|
39,101
|
|
|
$
|
(20,564
|
)
|
|
$
|
18,537
|
|
|
$
|
37,185
|
|
|
$
|
(19,206
|
)
|
|
$
|
17,979
|
|
Trademarks
|
|
|
63,452
|
|
|
|
(20,036
|
)
|
|
|
43,416
|
|
|
|
62,699
|
|
|
|
(18,674
|
)
|
|
|
44,025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
102,553
|
|
|
$
|
(40,600
|
)
|
|
$
|
61,953
|
|
|
$
|
99,884
|
|
|
$
|
(37,880
|
)
|
|
$
|
62,004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization expense related to patents and trademarks, which is recorded within cost of
operating revenues on the condensed consolidated statement of operations, totaled $912 and $2,720
for the three and nine months ended September 28, 2007, respectively. Similarly, amortization
expense totaled $898 and $2,676 for the three and nine months ended September 29, 2006,
respectively. Amortization expense is expected to approximate $3,600 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 bases 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.
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 and income and expenses and cash flows are translated at
weighted-average exchange rates for the period.
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 three and nine months ended September 28, 2007 and September 29, 2006,
none of the contracts met the requirements for hedge accounting under SFAS No. 133. Accordingly,
we recorded a pretax foreign exchange gain/(loss) of $(90) and $576 for the three and nine months
ended September 28, 2007, respectively. Similarly, we recorded pretax foreign exchange gains of
$487 and $2,857 for the three and nine months ended September 29, 2006, respectively. These
amounts were recorded in the following line items on our condensed consolidated statement of
operations for the periods indicated:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Cost of operating revenues
|
|
$
|
(54
|
)
|
|
$
|
589
|
|
|
$
|
674
|
|
|
$
|
2,996
|
|
Other deductions
|
|
|
(36
|
)
|
|
|
(102
|
)
|
|
|
(98
|
)
|
|
|
(139
|
)
|
Pretax (loss)/gain
|
|
$
|
(90
|
)
|
|
$
|
487
|
|
|
$
|
576
|
|
|
$
|
2,857
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 our condensed consolidated balance sheet.
During the nine months ended September 28, 2007 and September 29, 2006, we included cash
inflows/(outflows) on the settlement of derivatives of $4,280 and $990, respectively, within the
net change in
11
contracts in process and billings in excess of costs and estimated earnings on
uncompleted contracts in the operating activities section of our 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 on 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 28, 2007 and December 29, 2006, we had net gains on the swap
contracts of $1,621 and $342, respectively, which were recorded net of tax of $798 and $203,
respectively, and were included in accumulated other comprehensive loss on our condensed
consolidated balance sheet.
Restrictions on Shareholders Dividends
We have not declared or paid a common share dividend
since July 2001 and we do not have any plans to declare or pay any common share dividends. Our
current credit agreement contains limitations on dividend payments.
Earnings per Common Share
Basic and diluted earnings per common share are computed using net
income attributable to common shareholders rather than total net income. As described further in
Note 9, we completed two common share purchase warrant offer transactions in January 2006, which
increased the number of common shares delivered upon the exercise of our Class A and Class B
warrants during the offer period. We issued 373,948 additional common shares as a result of the
warrant offers. Since the warrant holders were not necessarily common shareholders prior to the
warrant offers, the issuance of the additional shares was not considered a pro rata common share
dividend to common shareholders. Rather, the fair value of the additional shares was treated as a
preferential distribution to a sub-set of common shareholders. Accordingly, we were required to
reduce net income attributable to the common shareholders by the fair value of the additional
common shares when calculating earnings per common share for the nine months ended September 29,
2006. The fair value of the additional shares issued was $19,445, which was determined using the
common share price at the time of issuance of the shares.
Basic earnings per common share is computed by dividing net income attributable to common
shareholders by the weighted-average number of common shares outstanding during the reporting
period, excluding non-vested restricted shares of 82,980 and 875,028 as of September 28, 2007 and
September 29, 2006, respectively. Restricted shares and restricted share units (collectively,
restricted awards) are included in the weighted-average number of common shares outstanding when
such shares vest.
Diluted earnings per common share is computed by dividing net income attributable to common
shareholders 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.
In profitable periods, outstanding stock options and warrants have a dilutive effect under the
treasury stock method when our average common share market 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.
12
The computations of basic and diluted earnings per common share were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Net income
|
|
$
|
129,101
|
|
|
$
|
75,827
|
|
|
$
|
315,776
|
|
|
$
|
198,876
|
|
Fair value of additional shares issued as part of
warrant offers
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(19,445
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to common shareholders
|
|
$
|
129,101
|
|
|
$
|
75,827
|
|
|
$
|
315,776
|
|
|
$
|
179,431
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic earnings per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to common shareholders
|
|
$
|
129,101
|
|
|
$
|
75,827
|
|
|
$
|
315,776
|
|
|
$
|
179,431
|
|
Weighted-average number of common shares outstanding
for basic earnings per common share
|
|
|
71,258,764
|
|
|
|
67,710,728
|
|
|
|
70,517,309
|
|
|
|
65,871,698
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic earnings per common share
|
|
$
|
1.81
|
|
|
$
|
1.12
|
|
|
$
|
4.48
|
|
|
$
|
2.72
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted earnings per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to common shareholders
|
|
$
|
129,101
|
|
|
$
|
75,827
|
|
|
$
|
315,776
|
|
|
$
|
179,431
|
|
Weighted-average number of common shares outstanding
for basic earnings per common share
|
|
|
71,258,764
|
|
|
|
67,710,728
|
|
|
|
70,517,309
|
|
|
|
65,871,698
|
|
Effect of dilutive securities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Options to purchase common shares
|
|
|
336,289
|
|
|
|
1,306,035
|
|
|
|
576,644
|
|
|
|
1,571,787
|
|
Warrants to purchase common shares
|
|
|
820,267
|
|
|
|
1,092,055
|
|
|
|
1,067,458
|
|
|
|
1,906,512
|
|
Non-vested portion of restricted awards
|
|
|
130,912
|
|
|
|
1,012,770
|
|
|
|
121,636
|
|
|
|
1,024,313
|
|
Weighted-average number of common shares outstanding
for diluted earnings per common share
|
|
|
72,546,232
|
|
|
|
71,121,588
|
|
|
|
72,283,047
|
|
|
|
70,374,310
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted earnings per common share
|
|
$
|
1.78
|
|
|
$
|
1.07
|
|
|
$
|
4.37
|
|
|
$
|
2.55
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Common shares issuable under outstanding options not included
in the computation of diluted earnings per common share
because the assumed proceeds were greater than our average
common share price for the period
|
|
|
82,868
|
|
|
|
474,482
|
|
|
|
178,878
|
|
|
|
472,089
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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. For other
employees and the non-employee directors, we estimate the expected term using the
simplified method, as outlined in Staff Accounting Bulletin No. 107, Topic 14:
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 life 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 common share dividend since July 2001 and we do not have any plans to declare
or pay any common share dividends.
|
We used the following weighted-average assumptions to estimate the fair value of the options
granted for the periods indicated:
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
September 28,
|
|
September 29,
|
|
|
2007
|
|
2006
|
Expected volatility
|
|
|
42.59
|
%
|
|
|
44.22
|
%
|
Expected term
|
|
3.2 years
|
|
|
4.5 years
|
|
Risk-free interest rate
|
|
|
4.47
|
%
|
|
|
4.91
|
%
|
Expected dividend yield
|
|
|
0.00
|
%
|
|
|
0.00
|
%
|
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 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.
SFAS No. 157 is effective for all financial statements issued for fiscal years beginning after
November 15, 2007. We do not expect our adoption of this new standard to have a material impact on
our financial position, results of operations or cash flows.
In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets
and Financial Liabilities, including an amendment of FASB Statement No. 115. SFAS No. 159 permits
entities to choose to measure many financial instruments and certain other items at fair value that
are not currently required to be measured at fair value. Unrealized gains and losses on items for
which the fair value option has been elected are reported in earnings. SFAS No. 159 does not
affect any existing accounting literature that requires certain assets and liabilities to be
carried at fair value. SFAS No. 159 is effective for fiscal years beginning after November 15,
2007. We are still evaluating whether we want to adopt this new optional standard.
14
2. Business Combinations
On April 7, 2006, we completed the purchase of the remaining 51% interest in MF Power, a
company that was 49% owned by us prior to the acquisition. Subsequent to the acquisition, we own
100% of the equity interests of MF Power, which was renamed FW Power S.r.L. (FW Power). FW Power
is dedicated to the development, construction and operation of electric power generating wind farm
projects in Italy. In accordance with the terms of the purchase agreement, we were required to pay
a purchase price of up to 16,393, of which 12,580 (approximately $15,200 at the exchange
rate in effect at the time of payment) was paid at closing and the
final payment of 3,440
(approximately $4,800 at the exchange rate in effect at the time of payment) was paid in September
2007 upon start of construction of a third wind farm being developed by FW Power as part of the
purchase contract with the seller.
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 for this acquisition was not material.
3. Equity Interests
We own non-controlling equity interests 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. The two electric power generation projects 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. The following is
summarized financial information for the entities (each as a whole) in which we have an equity
interest:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28, 2007
|
|
December 29, 2006
|
|
|
Italian
|
|
Chilean
|
|
Italian
|
|
Chilean
|
|
|
Projects
|
|
Project
|
|
Projects
|
|
Project
|
Balance Sheet Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current assets
|
|
$
|
241,979
|
|
|
$
|
29,125
|
|
|
$
|
199,606
|
|
|
$
|
27,013
|
|
Other assets (primarily buildings and equipment)
|
|
|
621,509
|
|
|
|
149,025
|
|
|
|
536,543
|
|
|
|
156,236
|
|
Current liabilities
|
|
|
77,252
|
|
|
|
13,325
|
|
|
|
42,134
|
|
|
|
18,226
|
|
Other liabilities (primarily long-term debt)
|
|
|
494,326
|
|
|
|
76,563
|
|
|
|
470,618
|
|
|
|
88,836
|
|
Net assets
|
|
|
291,910
|
|
|
|
88,262
|
|
|
|
223,397
|
|
|
|
76,187
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
September 28, 2007
|
|
September 29, 2006
|
|
|
Italian
|
|
Chilean
|
|
Italian
|
|
Chilean
|
|
|
Projects
|
|
Project
|
|
Projects
|
|
Project
|
Income Statement Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$
|
102,776
|
|
|
$
|
27,881
|
|
|
$
|
58,839
|
|
|
$
|
10,922
|
|
Gross profit
|
|
|
40,982
|
|
|
|
19,774
|
|
|
|
14,539
|
|
|
|
5,125
|
|
Income before income taxes
|
|
|
37,880
|
|
|
|
18,193
|
|
|
|
11,831
|
|
|
|
5,615
|
|
Net earnings
|
|
|
23,362
|
|
|
|
18,193
|
|
|
|
(7,864
|
)
|
|
|
5,615
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
September 28, 2007
|
|
September 29, 2006
|
|
|
Italian
|
|
Chilean
|
|
Italian
|
|
Chilean
|
|
|
Projects
|
|
Project
|
|
Projects
|
|
Project
|
Income Statement Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$
|
247,517
|
|
|
$
|
51,528
|
|
|
$
|
230,495
|
|
|
$
|
32,888
|
|
Gross profit
|
|
|
70,513
|
|
|
|
30,420
|
|
|
|
61,462
|
|
|
|
16,050
|
|
Income before income taxes
|
|
|
61,947
|
|
|
|
25,242
|
|
|
|
60,610
|
|
|
|
12,314
|
|
Net earnings
|
|
|
37,973
|
|
|
|
25,242
|
|
|
|
37,331
|
|
|
|
12,314
|
|
15
Our share of equity in the net earnings of these partially-owned affiliates, which are
recorded within other income on the condensed consolidated statement of operations, totaled $18,935
and $29,503 for the three and nine months ended September 28, 2007, respectively. For the three
and nine months ended September 29, 2006, our share of equity in the net earnings of these
partially-owned affiliates totaled $562 and $23,227, respectively. Our share of the equity earnings on certain
of the Italian projects were
favorably impacted by $6,283 during the third quarter of 2007, of which $4,398 related to the first
and second quarters of 2007, due to a tariff rate increase occurring in the quarter as a result of the
favorable outcome of a rate appeal. In the third quarter of 2006,
the majority owners of certain of the Italian projects sold their interests to another third party.
Prior to this sale, our share of equity in the net earnings of these projects was reported on a
pretax basis in other income and the associated taxes were reported in the provision for income
taxes because we and the other partners elected pass-through taxation treatment under local law.
As a direct result of the ownership change arising from the sale, the subject entities are now
precluded from electing pass-through taxation treatment. As a result, commencing in the third
quarter of 2006, we began reporting our share of the related after-tax earnings in other income.
Our share of equity in the net earnings of these projects is reported in other income, net of a
$4,300 and $7,400 tax provision for the three 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 $182,338
and $150,752 as of September 28, 2007 and December 29, 2006, respectively. Distributions of
$10,946 and $17,688 were received from these equity affiliates during the nine months ended
September 28, 2007 and September 29, 2006, respectively.
Since the third quarter of 2006, we have evaluated our investment in the wind farm project in
Italy under FASB Interpretation No. 46R (FIN 46R), Consolidation of Variable Interest Entities,
and have concluded that while the entity is a variable interest entity, we were not the primary
beneficiary. In July 2007, the wind farm project secured project financing. As a result, in the
third quarter of 2007, we re-evaluated our previous conclusion and reconfirmed our conclusion that
we are not the primary beneficiary. As such, we have included our share of the net earnings of the
wind farm project in our condensed consolidated financial statements using the equity method.
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 29, 2006.
We also have a guarantee that supports 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 28, 2007, no
amounts have ever been drawn under this letter of credit.
16
4.
Long-term Debt
The following table shows the components of our long-term debt:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28, 2007
|
|
|
December 29, 2006
|
|
|
|
Current
|
|
|
Long-term
|
|
|
Total
|
|
|
Current
|
|
|
Long-term
|
|
|
Total
|
|
Capital Lease Obligations
|
|
$
|
1,229
|
|
|
$
|
66,852
|
|
|
$
|
68,081
|
|
|
$
|
1,537
|
|
|
$
|
65,319
|
|
|
$
|
66,856
|
|
Special-Purpose Limited Recourse Project Debt:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Camden County Energy Recovery Associates
|
|
|
9,360
|
|
|
|
41,427
|
|
|
|
50,787
|
|
|
|
9,360
|
|
|
|
41,427
|
|
|
|
50,787
|
|
FW Power
|
|
|
5,685
|
|
|
|
24,807
|
|
|
|
30,492
|
|
|
|
4,881
|
|
|
|
24,862
|
|
|
|
29,743
|
|
Foster Wheeler Coque Verde, L.P.
|
|
|
4,144
|
|
|
|
21,101
|
|
|
|
25,245
|
|
|
|
3,613
|
|
|
|
25,245
|
|
|
|
28,858
|
|
Subordinated Robbins Facility Exit Funding Obligations:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1999C Bonds at 7.25% interest, due October 15, 2009
|
|
|
16
|
|
|
|
|
|
|
|
16
|
|
|
|
16
|
|
|
|
37
|
|
|
|
53
|
|
1999C Bonds at 7.25% interest, due October 15, 2024
|
|
|
|
|
|
|
20,528
|
|
|
|
20,528
|
|
|
|
|
|
|
|
20,491
|
|
|
|
20,491
|
|
1999D Bonds at 7% interest, due October 15, 2009
|
|
|
|
|
|
|
281
|
|
|
|
281
|
|
|
|
|
|
|
|
267
|
|
|
|
267
|
|
Intermediate Term Loans in China at 6.03% interest
|
|
|
3,997
|
|
|
|
|
|
|
|
3,997
|
|
|
|
|
|
|
|
3,844
|
|
|
|
3,844
|
|
Convertible Subordinated Notes at 6.50% interest,
due June 1, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,070
|
|
|
|
|
|
|
|
2,070
|
|
Other
|
|
|
136
|
|
|
|
205
|
|
|
|
341
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
24,567
|
|
|
$
|
175,201
|
|
|
$
|
199,768
|
|
|
$
|
21,477
|
|
|
$
|
181,492
|
|
|
$
|
202,969
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Domestic Senior Credit Agreement
In October 2006, we executed a five-year domestic senior
credit agreement. In May 2007, we executed an amendment to the domestic senior credit agreement to
increase the facility by $100,000 to $450,000, to reduce the pricing on a portion of the letters of
credit issued under the facility and to restore 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 $312,435 and $189,036 of letters of credit outstanding under our domestic senior credit
agreement as of September 28, 2007 and December 29, 2006, respectively. The letter of credit fees
currently range from 1.50% to 1.60% of the outstanding amount. There were no funded borrowings
under this agreement as of September 28, 2007 or December 29, 2006.
17
5. Pensions and Other Postretirement Benefits
We have defined benefit pension plans in the United States, the United Kingdom, South Africa,
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. The
components of benefit cost for our pension plans are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 28, 2007
|
|
|
Three Months Ended September 29, 2006
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
Net Periodic Benefit Cost:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
|
|
|
$
|
3,541
|
|
|
$
|
156
|
|
|
$
|
3,697
|
|
|
$
|
|
|
|
$
|
3,953
|
|
|
$
|
241
|
|
|
$
|
4,194
|
|
Interest cost
|
|
|
4,758
|
|
|
|
11,441
|
|
|
|
427
|
|
|
|
16,626
|
|
|
|
4,644
|
|
|
|
9,168
|
|
|
|
427
|
|
|
|
14,239
|
|
Expected return on plan assets
|
|
|
(5,991
|
)
|
|
|
(12,156
|
)
|
|
|
(451
|
)
|
|
|
(18,598
|
)
|
|
|
(4,957
|
)
|
|
|
(10,188
|
)
|
|
|
(395
|
)
|
|
|
(15,540
|
)
|
Amortization of transition
(asset)/obligation
|
|
|
|
|
|
|
(15
|
)
|
|
|
24
|
|
|
|
9
|
|
|
|
|
|
|
|
(17
|
)
|
|
|
22
|
|
|
|
5
|
|
Amortization of prior service cost
|
|
|
|
|
|
|
1,312
|
|
|
|
5
|
|
|
|
1,317
|
|
|
|
|
|
|
|
1,253
|
|
|
|
4
|
|
|
|
1,257
|
|
Amortization of net loss
|
|
|
821
|
|
|
|
4,337
|
|
|
|
168
|
|
|
|
5,326
|
|
|
|
1,065
|
|
|
|
4,387
|
|
|
|
230
|
|
|
|
5,682
|
|
Other
|
|
|
474
|
|
|
|
|
|
|
|
|
|
|
|
474
|
|
|
|
426
|
|
|
|
|
|
|
|
|
|
|
|
426
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net periodic benefit cost
|
|
$
|
62
|
|
|
$
|
8,460
|
|
|
$
|
329
|
|
|
$
|
8,851
|
|
|
$
|
1,178
|
|
|
$
|
8,556
|
|
|
$
|
529
|
|
|
$
|
10,263
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes Recognized in Other
Comprehensive Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of transition
asset/(obligation)
|
|
$
|
|
|
|
$
|
15
|
|
|
$
|
(24
|
)
|
|
$
|
(9
|
)
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
Amortization of prior service cost
|
|
|
|
|
|
|
(1,312
|
)
|
|
|
(5
|
)
|
|
|
(1,317
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of net loss
|
|
|
(821
|
)
|
|
|
(4,337
|
)
|
|
|
(168
|
)
|
|
|
(5,326
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income recognized in other
comprehensive income
|
|
$
|
(821
|
)
|
|
$
|
(5,634
|
)
|
|
$
|
(197
|
)
|
|
$
|
(6,652
|
)
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 28, 2007
|
|
|
Nine Months Ended September 29, 2006
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
|
United
|
|
|
United
|
|
|
|
|
|
|
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
|
States
|
|
|
Kingdom
|
|
|
Other
|
|
|
Total
|
|
Net Periodic Benefit Cost:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
|
|
|
$
|
10,449
|
|
|
$
|
455
|
|
|
$
|
10,904
|
|
|
$
|
|
|
|
$
|
11,564
|
|
|
$
|
709
|
|
|
$
|
12,273
|
|
Interest cost
|
|
|
14,274
|
|
|
|
33,742
|
|
|
|
1,218
|
|
|
|
49,234
|
|
|
|
13,933
|
|
|
|
26,728
|
|
|
|
1,262
|
|
|
|
41,923
|
|
Expected return on plan assets
|
|
|
(17,972
|
)
|
|
|
(35,852
|
)
|
|
|
(1,281
|
)
|
|
|
(55,105
|
)
|
|
|
(14,871
|
)
|
|
|
(29,710
|
)
|
|
|
(1,174
|
)
|
|
|
(45,755
|
)
|
Amortization of transition
(asset)/obligation
|
|
|
|
|
|
|
(46
|
)
|
|
|
67
|
|
|
|
21
|
|
|
|
|
|
|
|
(51
|
)
|
|
|
65
|
|
|
|
14
|
|
Amortization of prior service cost
|
|
|
|
|
|
|
3,869
|
|
|
|
14
|
|
|
|
3,883
|
|
|
|
|
|
|
|
3,664
|
|
|
|
13
|
|
|
|
3,677
|
|
Amortization of net loss
|
|
|
2,464
|
|
|
|
12,965
|
|
|
|
475
|
|
|
|
15,904
|
|
|
|
3,196
|
|
|
|
12,763
|
|
|
|
685
|
|
|
|
16,644
|
|
Other
|
|
|
1,423
|
|
|
|
|
|
|
|
|
|
|
|
1,423
|
|
|
|
1,278
|
|
|
|
|
|
|
|
|
|
|
|
1,278
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net periodic benefit cost
|
|
$
|
189
|
|
|
$
|
25,127
|
|
|
$
|
948
|
|
|
$
|
26,264
|
|
|
$
|
3,536
|
|
|
$
|
24,958
|
|
|
$
|
1,560
|
|
|
$
|
30,054
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes Recognized in Other
Comprehensive Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of transition
asset/(obligation)
|
|
$
|
|
|
|
$
|
46
|
|
|
$
|
(67
|
)
|
|
$
|
(21
|
)
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
Amortization of prior service cost
|
|
|
|
|
|
|
(3,869
|
)
|
|
|
(14
|
)
|
|
|
(3,883
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of net loss
|
|
|
(2,464
|
)
|
|
|
(12,965
|
)
|
|
|
(475
|
)
|
|
|
(15,904
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total income recognized in other
comprehensive income
|
|
$
|
(2,464
|
)
|
|
$
|
(16,788
|
)
|
|
$
|
(556
|
)
|
|
$
|
(19,808
|
)
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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, and the South African plan are contributory.
18
At year-end 2006, we expected to make mandatory contributions of $20,400 to our U.S. pension
plans in 2007. In March 2007, we made the full year 2007 mandatory contribution of $20,400 to our
U.S. pension plans plus an additional discretionary contribution of $14,600. We do not expect to
be required to make any further mandatory contributions to the U.S. pension plans until 2013 or
later given our current actuarial assumptions. We also made a mandatory contribution of $26,400 to
our foreign pension plans during the nine months ended September 28, 2007. We expect to make total
mandatory contributions approximating $35,100 to our foreign plans in 2007.
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 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:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Net Periodic Postretirement Benefit Cost:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service cost
|
|
$
|
36
|
|
|
$
|
38
|
|
|
$
|
105
|
|
|
$
|
118
|
|
Interest cost
|
|
|
1,191
|
|
|
|
1,334
|
|
|
|
3,572
|
|
|
|
4,001
|
|
Amortization of prior service credit
|
|
|
(1,191
|
)
|
|
|
(1,190
|
)
|
|
|
(3,571
|
)
|
|
|
(3,571
|
)
|
Amortization of net loss
|
|
|
238
|
|
|
|
512
|
|
|
|
714
|
|
|
|
1,536
|
|
Other
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net periodic postretirement benefit cost
|
|
$
|
274
|
|
|
$
|
694
|
|
|
$
|
820
|
|
|
$
|
2,084
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Changes Recognized in Other
Comprehensive Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization of prior service credit
|
|
$
|
1,191
|
|
|
$
|
|
|
|
$
|
3,571
|
|
|
$
|
|
|
Amortization of net loss
|
|
|
(238
|
)
|
|
|
|
|
|
|
(714
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total loss recognized in other
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
comprehensive income
|
|
$
|
953
|
|
|
$
|
|
|
|
$
|
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 28,
|
|
December 29,
|
|
|
Payment
|
|
2007
|
|
2006
|
Environmental indemnifications
|
|
No limit
|
|
$
|
7,100
|
|
|
$
|
7,300
|
|
Tax indemnifications
|
|
No limit
|
|
$
|
|
|
|
$
|
|
|
19
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.
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
Balance at beginning of year
|
|
$
|
69,900
|
|
|
$
|
63,200
|
|
Accruals
|
|
|
25,100
|
|
|
|
16,200
|
|
Settlements
|
|
|
(10,800
|
)
|
|
|
(9,900
|
)
|
Adjustments to provisions
|
|
|
(6,600
|
)
|
|
|
(7,800
|
)
|
|
|
|
|
|
|
|
Balance at end of period
|
|
$
|
77,600
|
|
|
$
|
61,700
|
|
|
|
|
|
|
|
|
7. Preferred Shares
We issued 599,944 preferred shares in connection with our 2004 equity-for-debt exchange.
There were 3,368 preferred shares outstanding as of September 28, 2007. Each preferred share is
convertible at the holders option into 65 common shares, or up to approximately 219,420 additional
common shares if all outstanding preferred shares were 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-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 $1,732 and $5,100 was charged against income for the
three and nine months ended September 28, 2007, respectively. The related income tax benefit
recognized in the condensed consolidated statement of operations was $22 and $65 for the three and
nine months ended September 28, 2007, respectively. The compensation cost charged against income
for the three and nine months ended September 29, 2006 totaled $4,112 and $12,828, respectively.
The related income tax benefit recognized in the condensed consolidated statement of operations was
$67 and $236 for the three and nine months ended September 29, 2006, respectively. We received
$16,240 and $12,312 in cash from option exercises under our share-based compensation plans for the
nine months ended September 28, 2007 and September 29, 2006, respectively.
As of September 28, 2007, we had $5,838 and $6,401 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 24 months.
20
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 1.6841 common shares at an exercise price of $9.378 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 0.0723 common shares at an exercise price of $9.378 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.
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 8,403,500 common shares.
Cumulatively through September 28, 2007, 3,945,306 Class A warrants and 38,724,675 Class B
warrants have been exercised for 9,818,879 common shares. The number of common shares issuable
upon the exercise of the remaining outstanding Class A warrants is 349,633 as of September 28,
2007. 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.
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, 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. 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 28, 2007, the maximum exposure under this
provision is approximately $10,000. We have not, and do not, expect to incur any damages under the
related registration rights agreement.
21
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. Compared to the U.S. statutory rate of 35%, our
effective tax rate for the three and nine months ended September 28, 2007 and for the three and
nine months ended September 29, 2006 were lower because of non-U.S. earnings being taxed at rates
lower than the U.S. statutory rate and because of earnings in jurisdictions where we have
previously recorded a full valuation allowance (primarily the United States). These variances were
partially offset by losses subject to valuation allowance in certain other non-U.S. 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. Such evaluation includes a
review of all available evidence, both positive and negative, in determining whether a valuation
allowance is necessary.
In June 2006, the FASB issued FIN 48, which addresses the determination of whether tax
benefits claimed or expected to be claimed on a tax return should be recorded in the financial
statements. Under FIN 48, we recognize the tax benefit from an uncertain tax position only if it
is more likely than not that the tax position will be sustained on examination by the taxing
authorities, based on the technical merits of the position. The tax benefits recognized in the
financial statements from such a position are based on the largest benefit that has a greater than
fifty percent likelihood of being realized upon ultimate settlement. FIN 48 also provides guidance
on the derecognition of the benefit of an uncertain tax position, classification of the
unrecognized tax benefits in the balance sheet, accounting for and classification of interest and
penalties on income tax uncertainties, accounting in interim periods and disclosures.
Our subsidiaries file income tax returns in numerous tax jurisdictions, including the United
States, several U.S. states and several non-U.S. jurisdictions, primarily in Europe and Asia. 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 2002.
A number of tax years are under audit by the relevant federal, state, and foreign tax
authorities. We anticipate that several of these audits may be concluded in the foreseeable
future, including in 2007. 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 adopted the provisions of FIN 48 on December 30, 2006, the first day of fiscal year 2007.
As a result of the adoption of FIN 48, we recognized a $4,356 reduction in the opening balance of
our shareholders equity. This resulted from changes in the amount of tax benefits recognized
related to uncertain tax positions and the accrual of interest and penalties.
As of the adoption date, we had $44,786 of unrecognized tax benefits, of which $44,323 would,
if recognized, affect our effective tax rate. There were no material changes in this amount during
the nine months ended September 28, 2007.
In our condensed consolidated statement of operations, we recognize interest accrued on the
unrecognized tax benefits in interest expense and penalties on the unrecognized tax benefits in
other deductions. We recorded $1,074 and $1,874 in interest expense and penalties for the three
and nine months ended September 28, 2007, respectively. We had $24,206 accrued for the payment of
interest and penalties as of September 28, 2007.
22
11. Business Segments
We operate through two business groups: our
Global Engineering and Construction Group
, which
we refer to as our Global E&C Group, and our
Global Power 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 provides
engineering, project management and construction management services, and purchases equipment,
materials and services from third-party suppliers and contractors. 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
and biofuels. Our Global E&C Group owns one of the leading refinery residue upgrading technologies
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. Our Global E&C Group performs environmental remediation services, together with related
technical, engineering, design and regulatory services. Our Global E&C Group is also involved in
the development, engineering, construction and ownership of power generation and waste-to-energy
facilities in Europe. Our Global E&C Group generates revenues from engineering and construction
activities pursuant to contracts spanning up to four years in duration, from operating activities
pursuant to the long-term sale of project outputs, such as electricity, and from returns on its
equity investments in various production facilities.
Our Global Power Group designs and manufactures steam generating and auxiliary equipment for
electric power generating stations and industrial facilities worldwide. Our steam generating
equipment includes a full range of technologies, offering both utility and industrial clients
high-value technology solutions for economically converting a wide range of fuels, including coal,
petroleum coke, oil, gas, biomass and municipal solid waste, into steam and power. Our circulating
fluidized-bed boiler technology (CFB) is ideally suited to burning a very wide range of fuels,
including low-quality fuels, fuels with high moisture content and waste-type fuels, and is
recognized as one of the cleanest solid-fuel steam generating technologies available in the world
today. For both our utility CFB and pulverized coal (PC) boilers, we offer supercritical
once-through-unit designs to further improve the environmental performance of these units.
Once-through supercritical boilers operate at higher steam pressures than traditional plants, which
results in higher efficiencies and lower emissions, including carbon
dioxide
(CO
2
), which is
considered a greenhouse gas. Further, for the longer term, we are actively developing
oxy-combustion technology for both our CFB and PC utility boilers. We believe that oxy-combustion
is one part of a practical solution for capturing and storing nearly all the CO
2
from coal power
plants. This novel technology produces a concentrated stream of CO
2
as part of the boiler
combustion process avoiding the need for large and expensive back-end CO
2
separation equipment.
Auxiliary equipment includes feedwater heaters, steam condensers and heat-recovery equipment. Our
Global Power Group also offers a full line of new and retrofit nitrogen-oxide (NOx) reduction
systems such as selective non-catalytic and catalytic NOx reduction systems as well as complete
low-NOx combustion systems. We provide a broad range of site services relating to these products,
including construction and erection services, maintenance engineering, plant upgrading and life
extensions. Our Global Power Group also provides research analysis and experimental work in fluid
dynamics, heat transfer, combustion and fuel technology, materials engineering and solid mechanics.
In addition, our Global Power Group owns and operates 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 and construction contracts, royalties from licensing our technology and from
operating activities pursuant to the long-term sale of project outputs, such as electricity and
steam, operating and maintenance agreements, and from returns on its equity investments in various
production facilities.
In addition to these two business groups, which also represent operating segments, we report
corporate center expenses and expenses related to certain legacy liabilities, such as asbestos, in
the Corporate and Finance Group, which is also an operating segment and which we refer to as the
C&F Group.
23
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
C&F
|
|
|
|
Total
|
|
|
E&C Group
|
|
|
Power Group
|
|
|
Group
(1)
|
|
Three Months Ended September 28,
2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
1,299,872
|
|
|
$
|
951,402
|
|
|
$
|
348,470
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(2)
|
|
$
|
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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 29,
2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
910,580
|
|
|
$
|
619,659
|
|
|
$
|
290,979
|
|
|
$
|
(58
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(3)
|
|
$
|
95,059
|
|
|
$
|
78,668
|
|
|
$
|
20,371
|
|
|
$
|
(3,980
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(5,068
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(8,018
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
81,973
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(6,146
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
75,827
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 28,
2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
3,641,760
|
|
|
$
|
2,626,816
|
|
|
$
|
1,014,944
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(4)
|
|
$
|
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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 29,
2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Third-party revenues
|
|
$
|
2,301,729
|
|
|
$
|
1,515,382
|
|
|
$
|
786,347
|
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(5)
|
|
$
|
293,450
|
|
|
$
|
221,027
|
|
|
$
|
56,342
|
|
|
$
|
16,081
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(19,803
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(22,284
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
251,363
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(52,487
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
198,876
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Includes general corporate income and expense, our captive insurance operation and
eliminations.
|
|
(2)
|
|
Includes in the three months ended September 28, 2007: increased contract profit of
$17,980 from the regular re-evaluation of contract profit estimates: $10,810 in our Global
E&C Group and $7,170 in our Global Power Group; and a net gain of $8,633 recorded in our
C&F Group on asbestos-related insurance settlements.
|
|
(3)
|
|
Includes in the three months ended September 29, 2006: increased/(decreased) contract
profit of $(10,270) from the regular re-evaluation of contract profit estimates: $2,900 in
our Global E&C Group and $(13,170) in our Global Power Group; a net gain of $36,074
recorded in our C&F Group on an asbestos-related insurance settlement; and an aggregate
charge of $(14,823) recorded in our C&F Group in conjunction with the termination of our
prior senior credit agreement.
|
|
(4)
|
|
Includes in the nine months ended September 28, 2007: increased/(decreased) contract
profit of $34,120 from the regular re-evaluation of contract profit estimates: $50,550 in
our Global E&C Group and $(16,430) in our Global Power Group; and a net gain of $8,633
recorded in our C&F Group on asbestos-related insurance settlements.
|
24
|
|
|
(5)
|
|
Includes in the nine months ended September 29, 2006: increased/(decreased) contract
profit of $1,020 from the regular re-evaluation of contract profit estimates: $13,780 in
our Global E&C Group and $(12,760) in our Global Power Group; a net gain of $115,664
recorded in our C&F Group on an asbestos-related insurance settlement; an aggregate charge
of $(14,823) recorded in our C&F Group in conjunction with the termination of our prior
senior credit agreement; and a net charge of $(12,483) recorded in our C&F Group in
conjunction with certain debt reduction initiatives.
|
|
|
Third-party revenues by industry were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Power generation
|
|
$
|
353,098
|
|
|
$
|
306,438
|
|
|
$
|
999,347
|
|
|
$
|
821,053
|
|
Oil refining
|
|
|
370,048
|
|
|
|
176,681
|
|
|
|
975,531
|
|
|
|
437,315
|
|
Pharmaceutical
|
|
|
40,571
|
|
|
|
29,476
|
|
|
|
133,267
|
|
|
|
75,541
|
|
Oil and gas
|
|
|
213,567
|
|
|
|
202,897
|
|
|
|
669,259
|
|
|
|
491,573
|
|
Chemical/petrochemical
|
|
|
272,568
|
|
|
|
102,709
|
|
|
|
718,328
|
|
|
|
274,429
|
|
Power plant operation and
maintenance
|
|
|
31,153
|
|
|
|
29,708
|
|
|
|
90,678
|
|
|
|
81,524
|
|
Environmental
|
|
|
16,126
|
|
|
|
37,173
|
|
|
|
40,305
|
|
|
|
65,079
|
|
Other, net of eliminations
|
|
|
2,741
|
|
|
|
25,498
|
|
|
|
15,045
|
|
|
|
55,215
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total third-party revenues
|
|
$
|
1,299,872
|
|
|
$
|
910,580
|
|
|
$
|
3,641,760
|
|
|
$
|
2,301,729
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 our U.S. claim activity is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Number of Claims
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
2007
|
|
|
2006
|
|
|
2007
|
|
|
2006
|
|
Open claims at beginning of period
|
|
|
133,580
|
|
|
|
161,440
|
|
|
|
135,890
|
|
|
|
164,820
|
|
New claims
|
|
|
1,080
|
|
|
|
2,030
|
|
|
|
4,160
|
|
|
|
7,360
|
|
Claims resolved
|
|
|
(1,850
|
)
|
|
|
(12,670
|
)
|
|
|
(7,240
|
)
|
|
|
(21,380
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Open claims at end of period
|
|
|
132,810
|
|
|
|
150,800
|
|
|
|
132,810
|
|
|
|
150,800
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 year-end 2021. 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.
25
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
|
December 29,
|
|
|
|
2007
|
|
|
2006
|
|
Asbestos-related assets recorded within:
|
|
|
|
|
|
|
|
|
Accounts and notes receivable-other
|
|
$
|
59,000
|
|
|
$
|
47,000
|
|
Asbestos-related insurance recovery receivable
|
|
|
277,100
|
|
|
|
316,700
|
|
|
|
|
|
|
|
|
Total asbestos-related assets
|
|
$
|
336,100
|
|
|
$
|
363,700
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asbestos-related liabilities recorded within:
|
|
|
|
|
|
|
|
|
Accrued expenses
|
|
$
|
70,000
|
|
|
$
|
75,000
|
|
Asbestos-related liability
|
|
|
329,300
|
|
|
|
391,000
|
|
|
|
|
|
|
|
|
Total asbestos-related liabilities
|
|
$
|
399,300
|
|
|
$
|
466,000
|
|
|
|
|
|
|
|
|
Since 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 2006 activity, ARPC recommended that the assumptions used to estimate our
future asbestos liability be updated as of year-end 2006. Accordingly, we developed a revised
estimate of our indemnity and defense costs through year-end 2021 considering the advice of ARPC.
In the fourth quarter of 2006, we increased our liability for asbestos indemnity and defense costs
through year-end 2021 to $466,000, 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 $15,600 in the fourth quarter of 2006. Payments made during the
nine months ended September 28, 2007 reduced our estimated year-end 2006 liability by $66,700.
The amount spent on asbestos litigation, defense and case resolution was $21,800 and $66,700
for the three and nine months ended September 28, 2007, respectively, and $23,300 and $60,900 for
the three and nine months ended September 29, 2006, respectively. We funded $1,500 and $30,500 of
the payments made during the three and nine months ended September 28, 2007, respectively, while
all remaining amounts were paid from insurance proceeds. We funded $30,200 of the payments made
during the nine months ended September 29, 2006, while all remaining amounts were paid from
insurance proceeds. Through September 28, 2007, total cumulative indemnity costs paid were
$614,000 and total cumulative defense costs paid were $239,700.
As of September 28, 2007, total asbestos-related liabilities were comprised of an estimated
liability of $136,800 relating to open (outstanding) claims being valued and an estimated liability
of $262,500 relating to future unasserted claims through year-end 2021.
In the first nine months of 2007, the average per claim indemnity amounts we paid for claims
were higher than forecast but were partially offset by higher than forecasted rates of dismissals
of claims with zero indemnity payments. These factors tend to increase our indemnity costs.
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,
such as mesothelioma, lung cancer or non-malignancies, and the breakdown of known and future claims
into disease type, such as 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 year-end 2021, during which period new
claims are forecasted to decline from year to year. We believe that it is likely that there will
be new claims filed after 2021, 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 2021. Historically, defense costs have represented approximately 28% of total
defense and indemnity costs.
The overall historic average combined indemnity and defense cost per resolved claim through
September 28, 2007 has been approximately $2.5. The average cost per resolved claim is increasing
and we believe will continue to increase in the future.
26
The asbestos-related asset recorded within accounts and notes receivable-other as of September
28, 2007 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 unsettled insurers in the
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 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 year-end 2006. We utilized
that analysis to determine our estimate of the value of the unsettled insurance asset as of
year-end 2006.
As of September 28, 2007, we estimated the value of our asbestos insurance asset contested by
our subsidiaries insurers in ongoing litigation in New York state court at $26,500. 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 2006, our subsidiaries
reached agreements to settle their disputed asbestos-related insurance coverage with four of their
insurers. Primarily as a result of these insurance settlements, we increased our asbestos-related
insurance asset and recorded a gain of $96,200 in 2006.
In the third quarter of 2007, our subsidiaries reached agreements to settle their disputed
asbestos-related insurance coverage with two additional insurers. As a result of these
settlements, we increased our asbestos-related insurance asset and recorded a gain of $8,600 in the
third quarter of 2007.
We intend to continue to attempt to negotiate additional settlements with insurers 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 unsettled insurers available 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 flow and our working capital.
Also in 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.
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 also 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 flow.
27
At the year-end 2006 liability estimate, an increase of 25% in the average per claim indemnity
settlement amount would increase the liability by $81,200 and the impact on expense would be
dependent upon available additional 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 60% to 70% of the increase in the liability.
Long-term cash flow 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 have funded $30,500 of the asbestos liability indemnity payments and defense costs from our
cash flow in the first nine months of 2007, net of the cash received from insurance settlements.
We expect net positive cash inflows of $1,500 in the fourth quarter of 2007 from our asbestos
management program. The estimated positive fourth quarter of 2007 net cash inflow represents the
excess of our estimated cash receipts from existing insurance settlements over our estimated
indemnity payments and defense costs. For all of 2007, we are estimating a net cash outflow of
$29,000 from our asbestos management program. 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 insurance liability or any
future insurance settlements, the asbestos insurance receivable recorded on our 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, 855 claims have been brought against our U.K.
subsidiaries of which 343 remained open as of September 28, 2007. None of the settled claims has
resulted in material costs to us.
As of September 28, 2007, we had recorded total liabilities of $36,500 comprised of an
estimated liability relating to open (outstanding) claims of $6,000 and an estimated liability
relating to future unasserted claims through year-end 2021 of $30,500. Of the total, $2,300 was
recorded in accrued expenses and $34,200 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 $2,300 was recorded in accounts and notes
receivable-other and $34,200 was recorded as asbestos-related insurance recovery receivable on the
condensed consolidated balance sheet. The liability estimates are based on an October 17, 2007
final ruling from the U.K. House of Lords upholding a court decision that pleural plaque claims do
not amount to a compensable injury.
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.
28
Arbitration was commenced against us in March 2004 arising out of a compact CFB boiler that we
engineered, supplied and erected for a client in Asia. In addition to claims for damages for
breach of contract, the client was seeking to rescind the contract based upon alleged material
misrepresentations by us. If such relief had been granted, we could have been compelled to
reimburse the client for the purchase price paid ($25,700), in addition to other unquantified
damages. We vigorously defended the case and counterclaimed for unpaid receivables ($5,200), plus
interest, for various breaches and non-performance by the client. Due to its age and the ongoing
dispute, a reserve for the full amount of the receivable had previously been taken. Procedurally,
the liability and damages portions of the case were separated. The hearing on the liability
portion concluded in June 2006 and a decision on the liability portion was rendered in May 2007.
The clients claim for rescission was denied and we were awarded our unpaid receivable, plus
interest. We were also awarded delay damages, arbitration costs and counsel fees, subject to proof
of the amounts during the damages phase of the arbitration. Discussions with the client ensued
following the award and as a result of an agreement reached in September 2007, we re-established
the receivable and recognized the award for delay damages, arbitration costs and counsel fees in
our third quarter 2007 results. All amounts due under the agreement were collected in October
2007.
Arbitration was also commenced against us in July 2005 with respect to a thermal electric
power plant in South America that we designed, supplied and erected as a member of a consortium
with other parties. The plants concrete foundations experienced cracking, allegedly due to
out-of-specification materials used in the concrete poured by the consortiums subcontractor. The
client adopted an extensive plan to repair the foundations and is seeking reimbursement of its
repair costs ($9,500). Alleging that this extensive repair effort was in the nature of emergency
mitigation only, the client also claimed its estimated cost to totally demolish and reconstruct the
foundations at some point in the future ($14,300) plus lost profits during this demolition and
reconstruction period ($9,400). The arbitration hearing has concluded and the arbitrator has
dismissed the clients claims against us. Although the client has contested the decision in a
civil court proceeding, we believe there are no valid grounds to overturn the decision.
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 $53,600 at the exchange rate in
effect as of September 28, 2007), and is retaining as security for these LDs approximately
22,000 (approximately $31,400 at the exchange rate in effect as of September 28, 2007) in
contract payments otherwise due to us for work performed. The client contends that it is owed an
additional 6,900 (approximately $9,800 at the exchange rate in effect as of September 28, 2007)
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 $31,400 at the exchange rate in effect as of September 28, 2007 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 $7,000 at the
exchange rate in effect as of September 28, 2007) in interest on the retained funds, as well as
approximately 9,100 (approximately $13,000 at the exchange rate in effect as of September 28,
2007) 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. The matter is in its early stages. Accordingly, it is premature to predict the
outcome of this matter.
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 we believe this variation from the agreed specifications is the cause of the corrosion
to the boiler tubes. Working with the client, we have identified potential technical solutions to
ameliorate the corrosive effects of the out-of-specification fuel, and together with the client we
are in the process of evaluating those alternative solutions for the front-end corrosion. We have
advised the client that we intend to submit a claim for the cost of corrective work to address
corrosion resulting from out-of-specification fuel and we anticipate having discussions with the
client in the near future regarding our claim.
29
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 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 these costs under our agreement with them, although we may have direct
responsibility for these costs to the client under our EPC contract. 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 these issues, 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. We do not believe that the back end
corrective work will materially impact our availability guaranty to the client described below.
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 $25,000 at the exchange rate in effect as of September 28, 2007). 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
$500,800 at the exchange rate in effect as of September 28, 2007) plus restoration costs at the
sites. The client has alleged that at least one of the plants has failed to meet the availability
guaranty during its first year of operation, but we have disputed this allegation. 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).
All corrective work at the plants is being conducted under a mutual reservation of rights
agreement with the client. The parties have deferred their discussion of the commercial issues
while they focus on the potential technical solutions and their related implementation. In the
event that the parties are not able to resolve the dispute, the contract provides for arbitration
conducted under The Institution of Engineers of Ireland Arbitration Procedure.
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 fourth quarter of 2006, we established a contingency of $25,000 in relation to this
project. Primarily as a result of the second quarter of 2007 discovery of the more extensive back
end corrosion, the contingency was increased by $30,000 to $55,000 during the 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 $23,800 at the exchange rate
in effect as of September 28, 2007) 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 charges against earnings, and which could also materially adversely impact our
financial condition and cash flows.
30
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.
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.
31
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.
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 at that time was not sufficient to support a determination by a
governmental entity that FWEC was a PRP as to 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. 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. There is also a possibility that FWEC would incur
further costs if it were to conduct further investigation regarding the TCE. We have accrued our
best estimate of the cost related to the foregoing and review 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 the unsettled litigation described below beyond those for which accruals have been made 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 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 recovery of the costs FWEC has incurred, which options could include seeking
to recover those costs from those determined to be a source.
32
In March 2006, a complaint was filed in an action entitled
Sarah Martin and Jeffrey Martin 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). The complaint alleges that it is filed on behalf of the Martins and more than 25
others similarly situated whose wells were contaminated with a hazardous substance, TCE, that was
released at FWECs site. The complaint seeks to recover costs of environmental remediation and
continued environmental monitoring of alleged class members property, diminution in property
value, costs associated with obtaining healthy water, the establishment of a medical monitoring
trust fund, statutory, treble and punitive damages and interest and the costs of the suit.
In April 2007, the court in the
Martin
case preliminarily approved a class action settlement
that had been jointly filed by the plaintiffs and FWEC. The preliminary settlement can be
finalized only after a number of events have occurred, including, among other things, the
conclusion of the class members opt-in/opt-out process and the holding of a fairness hearing
before the court. A number of the class members have opted-out of the preliminary settlement, and
a number of them have objected that the preliminary settlement is not fair. The court has not yet
ruled on the fairness of the preliminary settlement.
Under the terms of the preliminary settlement, FWEC would pay the class and its counsel a
total of approximately $1,600 in exchange for a release by class members of all claims with respect
to the matters that are the subject of the litigation. The release would not extend to the claims
of those who opt-out of the settlement. The class, which is agreed upon only for the purposes of
the settlement, consists of three categories of persons who own or live on property in, or within
approximately 150 feet of, the area in which TCE is inferred to exist in the groundwater. One of
the three categories of the class would include those persons who live in residences at which TCE
was detected in private wells in 2004. We have accrued a provision sufficient to cover the class
action settlement.
In April 2006, a complaint was filed in an action entitled
Donna Rose Cunningham and Michael
A. Cunningham v. Foster Wheeler Energy Corporation
, United States District Court, Middle District
of Pennsylvania. The complaints allegations are generally similar to those in the
Martin
case,
except that the complaint is on behalf of the Cunninghams only, not an alleged class, and except
that the Cunninghams have included a claim for embarrassment, humiliation and emotional distress.
We have accrued a provision that we believe is appropriate for this matter.
In May 2006, a complaint was filed in an action entitled
Gary Prezkop, Personal Representative
of the Estate of Mary Prezkop, Deceased, and Gary Prezkop, in his own right, v. Foster Wheeler
Energy Corporation and Leonard M. Lulis.
Case No. 000545
,
Court of Common Pleas, Philadelphia
County, Pennsylvania. The complaints allegations are generally similar to those in the
Martin
and
Cunningham
cases, but they also include claims for Mary Prezkops alleged wrongful death. During
the third quarter of 2007, the matter was settled for an amount that will not have a material
impact on us; the settlement of certain claims on behalf of the Prezkop minors is subject to court
approval.
Based upon its investigation and the proceedings to date, FWEC will vigorously defend itself
against the remaining unsettled claims brought against it in the above proceedings. However, it is
premature to predict the ultimate outcome of these proceedings.
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.
33
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. Preliminary budgetary estimates of the cost of
installing the additional control equipment are approximately $24,000 based upon 2006 pricing.
13. Subsequent
Event
On November 6, 2007 our Board of Directors approved a two-for-one stock split of our common shares, subject to shareholder approval of an increase in the number of our authorized common shares. The increase in the number of authorized common shares is to be voted upon at a special general meeting of shareholders tentatively scheduled for January 8, 2008. The stock split will be effected in the form of a stock dividend in the ratio of one additional Foster Wheeler common share in respect of each common share outstanding on the record date for the stock dividend, which will be the same date as the special general meeting of shareholders.
34
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
managements discussion and analysis and other sections of this quarterly report on Form 10-Q
contain forward-looking statements that are based on our assumptions, expectations and projections
about the various industries within which we operate. Such forward-looking statements by their
nature involve a degree of risk and uncertainty. We caution that a variety of factors could cause
business conditions and results to differ materially from what is contained in our forward-looking
statements. For additional risk information, see Part II, Item 1A, Risk Factors.
This discussion and analysis should be read in conjunction with our financial statements and
notes thereto included in this quarterly report on Form 10-Q and our annual report on Form 10-K for
the year ended December 29, 2006, which we refer to as our 2006 Form 10-K.
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.
During the first quarter of 2007, we began exploring strategic acquisitions within the
engineering and construction industry to complement or expand on our technical capabilities.
However, there is no assurance that we will consummate any acquisitions.
Results
We reported record consolidated net income of $129,100 on consolidated operating revenues of
$1,299,900 in the third quarter of 2007, compared to consolidated net income of $75,800 on
consolidated operating revenues of $910,600 in the third quarter of 2006. Our results for the
third quarter of 2007 included the following pre-tax and
after-tax amounts: income of $14,400 related to the favorable resolution of project
claims and net asbestos-related gains of $8,600. Our results for the third quarter of 2006
included the following pre-tax and after-tax amounts: a net asbestos-related gain of $36,100 and fees and expenses related to the replacement of
our senior credit agreement of $14,800.
For the first nine months of 2007, we reported consolidated net income of $315,800 on
consolidated operating revenues of $3,641,800, compared to consolidated net income of $198,900 on
consolidated operating revenues of $2,301,700 for the comparable period of 2006. Our results for
the first nine months of 2007 included the following pre-tax and
after-tax amounts: income of $14,400 related to the favorable resolution of
project claims and net asbestos-related gains of $8,600. Our results for the first nine months of
2006 included the following pre-tax and
after-tax amounts: a net asbestos-related gain of $115,700, fees and expenses related to the replacement
of our senior credit agreement of $14,800 and a loss on debt reduction initiatives of $12,500.
Our third quarter and year-to-date 2007 results reflect the strong operating performance of
both our Global E&C Group and our Global Power Group.
Additional highlights included the following:
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Consolidated new orders were $1,878,500 in the third quarter of 2007, as compared to
$983,300 in the second quarter of 2007 and $1,996,100 in the third quarter of 2006.
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Consolidated backlog of unfilled orders, measured in terms of Foster Wheeler scope (as
defined below under Backlog and New Orders), as of September 28, 2007, was $3,038,600,
as compared to $2,804,300 as of June 29, 2007 and $2,997,200 as of September 29, 2006.
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Consolidated backlog of unfilled orders, measured in future revenues, as of September
28, 2007, was $6,273,100, as compared to $5,543,800 as of June 29, 2007 and $6,069,400 as
of September 29, 2006.
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E&C man-hours in backlog (in thousands) as of September 28, 2007, were 13,300, as
compared to 11,000 as of June 29, 2007 and 13,300 as of September 29, 2006.
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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. These markets continued to be strong in the first nine months of 2007, which in turn
continued to stimulate investment in new and expanded plants by our clients. We expect this strong
market demand to continue throughout the remainder of 2007 and into 2008. 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.
The Global E&C Groups new orders were $1,572,000 in the third quarter of 2007, as compared to
$430,500 in the second quarter of 2007 and $1,748,100 in the third quarter of 2006. We expect that
capital investments 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, will remain strong throughout the remainder of 2007 and into 2008. As a result, we
also expect the demand for the services and equipment supplied by engineering and construction
contractors such as us to remain strong throughout the remainder of 2007 and into 2008. We have
also seen a growing client preference to award reimbursable, rather than lump-sum turnkey,
contracts in the industries served by our Global E&C Group.
The Global Power Groups new orders were $306,500 in the third quarter of 2007, as compared to
$552,800 in the second quarter of 2007 and $248,000 in the third quarter of 2006. We believe that
the global power markets have strengthened and that there are significant growth opportunities
during the remainder of 2007 and into 2008 in the power markets we serve, such as solid fuel-fired
boilers, boiler services, boiler environmental products and boiler-related construction services.
We believe that we are well positioned to compete in both our Global E&C Group and Global
Power Group markets during the remainder of 2007 and into 2008. The challenges and drivers for
each of our Global E&C Group and our Global Power Group are discussed in more detail in the section
entitled Business Segments within this Item 2.
Results of Operations:
Consolidated Operating Revenues:
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|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
1,299,872
|
|
|
$
|
910,580
|
|
|
$
|
389,292
|
|
|
|
42.8
|
%
|
Nine months ended
|
|
$
|
3,641,760
|
|
|
$
|
2,301,729
|
|
|
$
|
1,340,031
|
|
|
|
58.2
|
%
|
The increases in consolidated operating revenues in the three and nine months ended September
28, 2007, compared to the corresponding periods of 2006, reflect our success in meeting the strong
market demand in both our Global E&C Group and our Global Power Group (please refer to the section
entitled Business Segments within this Item 2 and in Note 11 to the condensed consolidated
financial statements in this quarterly report on Form 10-Q for further information). The revenue
increases were due primarily to the significant increase in bookings that occurred in fiscal year
2006 in both our Global E&C Group and our Global Power Group as well as an increase in operational
capacity in our Global E&C Group. However, $250,400 and $669,300 of the third quarter and
year-to-date 2007 increases, respectively, result primarily from increases versus the corresponding
periods of 2006 in flow-through revenues and costs in our Global E&C Group on projects executed by
our United Kingdom, Continental Europe and Asia-Pacific operations. Flow-through revenues and
costs relate to projects where we purchase and install equipment on behalf of our customers on a
reimbursable basis with no mark-up. Flow-through revenues and costs do not impact contract profit
or net earnings, but increased amounts of flow-through revenues and costs have the effect of
reducing our reported profit margins as a percent of operating revenues. We continue to expect
flow-through revenues and costs in 2007 to be greater than in 2006.
36
Consolidated Contract Profit:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
197,960
|
|
|
$
|
129,189
|
|
|
$
|
68,771
|
|
|
|
53.2
|
%
|
Nine months ended
|
|
$
|
574,318
|
|
|
$
|
337,449
|
|
|
$
|
236,869
|
|
|
|
70.2
|
%
|
Consolidated contract profit is computed as consolidated operating revenues less consolidated
cost of operating revenues. The increases in contract profit for the three and nine months ended
September 28, 2007, compared to the corresponding periods of 2006, primarily reflect significant
increases in volume of revenues, excluding the flow-through costs described above, and increased
margins earned in both our Global E&C Group and our Global Power Group. The increase in contract
profit for the nine months ended September 28, 2007 was partially offset by a $30,000 charge
recorded in the second quarter of 2007 on a Global Power Group legacy project. Please refer to the
section entitled Business Segments within this Item 2 for further information.
Consolidated Selling, General and Administrative (SG&A) Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
62,686
|
|
|
$
|
51,543
|
|
|
$
|
11,143
|
|
|
|
21.6
|
%
|
Nine months ended
|
|
$
|
180,079
|
|
|
$
|
159,570
|
|
|
$
|
20,509
|
|
|
|
12.9
|
%
|
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 third
quarter of 2007, compared to the third quarter of 2006, results primarily from increases in sales
pursuit cost of $4,200, general overhead cost of $6,300 and research and development costs of $600.
The increase in SG&A expenses in the first nine months of 2007, compared to the corresponding
period of 2006, results from increases in sales pursuit costs of $10,400, general overhead costs of
$8,100 and research and development costs of $2,000. The increases result primarily from the
increased volume of business in the third quarter and the first nine months of 2007, which, in
addition to increasing the number of technical personnel, also increases our support staff and
related costs.
Consolidated Other Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
34,786
|
|
|
$
|
5,382
|
|
|
$
|
29,404
|
|
|
|
546.3
|
%
|
Nine months ended
|
|
$
|
67,993
|
|
|
$
|
41,250
|
|
|
$
|
26,743
|
|
|
|
64.8
|
%
|
Other income in the third quarter of 2007 consists primarily of $12,500 of interest income,
$20,500 in equity earnings generated from our investments, primarily from our minority ownership
interests, in build, own and operate projects in Italy and Chile and $200 of investment income.
Other income in the third quarter of 2006 consists primarily of $3,700 of interest income,
$900 in equity earnings generated from our investments, primarily from our minority ownership
interests, in build, own and operate projects in Italy and Chile.
Other income in the first nine months of 2007 consists primarily of $24,300 of interest
income, $31,600 in equity earnings generated from our investments, primarily from our minority
ownership interests, in build, own and operate projects in Italy and Chile, a $6,600 gain on a
real estate investment and $1,200 of investment income.
Other income in the first nine months of 2006 consists primarily of $10,200 of interest
income, $24,800 in equity earnings generated from our investments, primarily from our minority
ownership interests, in build, own and operate projects in Italy and Chile, a $1,000 gain on the
sale of a previously closed manufacturing facility in Dansville, New York and $800 of investment
income.
37
Consolidated Other Deductions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
7,672
|
|
|
$
|
14,983
|
|
|
$
|
(7,311
|
)
|
|
|
(48.8
|
)%
|
Nine months ended
|
|
$
|
33,075
|
|
|
$
|
33,070
|
|
|
$
|
5
|
|
|
|
0.0
|
%
|
Other deductions in the third quarter of 2007 consists primarily of $800 of bank fees, $3,800
of legal fees, $200 of consulting fees, $1,200 of tax penalties and penalties on unrecognized tax
benefits and a $500 provision for dispute resolution and environmental remediation costs.
Other deductions in the third quarter of 2006 consists primarily of $2,000 of bank fees,
$5,600 of legal fees, $700 of consulting fees, $1,500 of foreign exchange losses and a $4,200
provision for dispute resolution and environmental remediation costs, partially offset by $(200) of
bad debt recovery.
Other deductions in the first nine months of 2007 consists primarily of $2,500 of bank fees,
$13,300 of legal fees, $400 of consulting fees, $1,700 of tax penalties and penalties on
unrecognized tax benefits and a $9,700 provision for dispute resolution and environmental
remediation costs.
Other deductions in the first nine months of 2006 consists primarily of $5,500 of bank fees,
$13,400 of legal fees, $4,000 of consulting fees, $2,600 of foreign exchange losses and a $4,300
provision for dispute resolution and environmental remediation costs, partially offset by $(1,200)
of bad debt recovery.
Consolidated Interest Expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
4,716
|
|
|
$
|
5,068
|
|
|
$
|
(352
|
)
|
|
|
(6.9
|
)%
|
Nine months ended
|
|
$
|
14,652
|
|
|
$
|
19,803
|
|
|
$
|
(5,151
|
)
|
|
|
(26.0
|
)%
|
The decrease in interest expense in the nine months ended September 28, 2007, compared to the
corresponding period of 2006, primarily reflects the benefits of our debt reduction initiatives
completed in the second quarter of 2006.
Consolidated Minority Interest in Income of Consolidated Affiliates:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
1,765
|
|
|
$
|
2,255
|
|
|
$
|
(490
|
)
|
|
|
(21.7
|
)%
|
Nine months ended
|
|
$
|
5,038
|
|
|
$
|
3,251
|
|
|
$
|
1,787
|
|
|
|
55.0
|
%
|
Minority interest in income of consolidated affiliates reflects 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 increase in minority interest in income of consolidated
affiliates for the first nine months of 2007 primarily reflects higher plant availability in 2007
at the Martinez facility. This facility was shut down for two repair outages during the first nine
months of 2006.
Consolidated Net Asbestos-Related Gains:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
8,633
|
|
|
$
|
36,074
|
|
|
$
|
(27,441
|
)
|
|
|
(76.1
|
)%
|
Nine months ended
|
|
$
|
8,633
|
|
|
$
|
115,664
|
|
|
$
|
(107,031
|
)
|
|
|
(92.5
|
)%
|
In the third quarter of 2007, our subsidiaries reached agreements to settle their disputed
asbestos-related insurance coverage with two additional insurers. As a result of these
settlements, we recorded a gain of $8,600 in the three and 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.
38
Primarily as a result of our asbestos-related insurance settlements and our successful appeal
of a New York state trial court decision that previously had held that New York, rather than New
Jersey, law applies in the coverage litigation with our subsidiaries insurers, we recorded net
gains of $36,100 and $115,700 in the three and nine months ended September 29, 2006, respectively.
Please refer to Note 12 to the condensed consolidated financial statements in this quarterly report
on Form 10-Q for further information.
Prior Domestic Senior Credit Agreement Fees and Expenses:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
|
|
|
$
|
14,823
|
|
|
$
|
(14,823
|
)
|
|
|
(100.0
|
)%
|
Nine months ended
|
|
$
|
|
|
|
$
|
14,823
|
|
|
$
|
(14,823
|
)
|
|
|
(100.0
|
)%
|
Our prior domestic senior credit agreement fees and expenses resulted from the voluntary
replacement of our prior domestic senior credit agreement with a new domestic senior credit
agreement in October 2006. We were required to pay a prepayment fee of $5,000 as a result of the
early termination of our prior agreement as well as $400 in other termination fees and expenses.
The early termination also resulted in the impairment of $9,400 of unamortized fees and expense
paid in 2005 associated with this agreement. In total, we recorded a charge of $14,800 in the
third quarter of 2006 in connection with the termination of our prior domestic senior credit
agreement.
Consolidated Loss on Debt Reduction Initiatives:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
|
|
|
$
|
|
|
|
$
|
|
|
|
|
0.0
|
%
|
Nine months ended
|
|
$
|
|
|
|
$
|
12,483
|
|
|
$
|
(12,483
|
)
|
|
|
(100.0
|
)%
|
The consolidated loss on debt reduction initiatives for nine months ended September 29, 2006
results primarily from the debt reduction activities completed in the second quarter of 2006. The
charge to income reflects a loss of $8,200 on the 2011 senior notes exchange transaction resulting
primarily from the difference between the fair market value of the common shares issued and the
carrying value of the 2011 senior notes exchanged, a loss of $3,900 on the 2011 senior notes
redemption transaction resulting primarily from a make-whole premium payment, and a loss of $200 on
the trust preferred securities and convertible notes redemptions resulting primarily from the
write-off of deferred charges. The consolidated loss on the debt reduction initiatives for the
nine months ended September 29, 2006 was offset by an improvement in consolidated shareholders
deficit of $58,800, resulting from the issuance of the common shares.
Consolidated Provision for Income Taxes:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
35,439
|
|
|
$
|
6,146
|
|
|
$
|
29,293
|
|
|
|
476.6
|
%
|
Nine months ended
|
|
$
|
102,324
|
|
|
$
|
52,487
|
|
|
$
|
49,837
|
|
|
|
95.0
|
%
|
The consolidated tax provision is calculated by multiplying pre-tax income by the estimated
annual effective tax rate. 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 the fact
that most of our operating units are profitable and are recording a provision for non-U.S.,
national and/or local income taxes, while others are unprofitable and are unable to recognize a tax
benefit for losses. Statement of Financial Accounting Standard, or SFAS, 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.
39
Our effective tax rate is, therefore, dependent on the location and amount of our taxable
earnings and the effects of changes in valuation allowances. Compared to the U.S. statutory rate
of 35%, our effective tax rate for the three and nine months ended September 28, 2007 and for the
three and nine months ended September 29, 2006 were lower because of non-U.S. earnings being taxed
at rates lower than the U.S. statutory rate and because of earnings in jurisdictions where we have
previously recorded a full valuation allowance (primarily the United States). These variances were
partially offset by losses subject to valuation allowance in certain other non-U.S. 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.
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.
As described further under Application of Critical Accounting Estimates within this Item 2,
we adopted the provisions of Financial Accounting Standards Board, or FASB, Interpretation No. 48,
Accounting for Uncertainty in Income Taxesan interpretation of FASB Statement No. 109, Accounting
for Income Taxes, which we refer to as FIN 48, on December 30, 2006, the first day of fiscal year
2007.
Consolidated EBITDA:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
September 29,
|
|
|
|
|
|
|
2007
|
|
2006
|
|
$ Change
|
|
% Change
|
Three months ended
|
|
$
|
178,977
|
|
|
$
|
95,059
|
|
|
$
|
83,918
|
|
|
|
88.3
|
%
|
Nine months ended
|
|
$
|
459,872
|
|
|
$
|
293,450
|
|
|
$
|
166,422
|
|
|
|
56.7
|
%
|
Consolidated EBITDA for the three and nine months ended September 28, 2007 reflects increased
volumes of business, increased margins and the overall strong operating performances in our Global
E&C Group and in our Global Power Group along with $14,400 of income related to the favorable
resolution of project claims and $8,600 of net asbestos-related gains. The increase in
consolidated EBITDA for the nine months ended September 28, 2007 was partially offset by a $30,000
charge recorded in the second quarter of 2007 on a Global Power Group legacy project. Please refer
to the section entitled Business Segments within this Item 2 for further information.
Consolidated EBITDA for the three months ended September 29, 2006 includes $36,100 of net
asbestos-related gains and a $14,800 loss on termination of our prior domestic senior credit
agreement. Consolidated EBITDA for the nine months ended September 29, 2006 includes $115,700 of
net asbestos-related gains, a $14,800 loss on the early termination of our prior domestic senior
credit agreement and a $12,500 loss on debt reduction initiatives.
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 statement 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:
40
|
|
|
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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
C&F
|
|
|
|
Total
|
|
|
E&C Group
|
|
|
Power Group
|
|
|
Group
(1)
|
|
Three Months Ended September 28, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(2)
|
|
$
|
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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 29, 2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(3)
|
|
$
|
95,059
|
|
|
$
|
78,668
|
|
|
$
|
20,371
|
|
|
$
|
(3,980
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(5,068
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(8,018
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
81,973
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(6,146
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
75,827
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 28, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(4)
|
|
$
|
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
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 29, 2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
(5)
|
|
$
|
293,450
|
|
|
$
|
221,027
|
|
|
$
|
56,342
|
|
|
$
|
16,081
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Interest expense
|
|
|
(19,803
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Less: Depreciation and amortization
|
|
|
(22,284
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
251,363
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Provision for income taxes
|
|
|
(52,487
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$
|
198,876
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
|
Includes general corporate income and expense, our captive insurance operation and
eliminations.
|
41
|
|
|
(2)
|
|
Includes in the three months ended September 28, 2007: increased contract profit of $18,000
from the regular re-evaluation of contract profit estimates: $10,800 in our Global E&C Group
and $7,200 in our Global Power Group; and a net gain of $8,600 recorded in our C&F Group on
asbestos-related insurance settlements.
|
|
(3)
|
|
Includes in the three months ended September 29, 2006: increased/(decreased) contract
profit of $(10,300) from the regular re-evaluation of contract profit estimates: $2,900 in
our Global E&C Group and $(13,200) in our Global Power Group; a net gain of $36,100 recorded
in our C&F Group on an asbestos-related insurance settlement; and an aggregate charge of
$(14,800) recorded in our C&F Group in conjunction with the termination of our prior senior
credit agreement.
|
|
(4)
|
|
Includes in the nine months ended September 28, 2007: increased/(decreased) contract profit
of $34,100 from the regular re-evaluation of profit estimates: $50,500 in our Global E&C
Group and $(16,400) in our Global Power Group; and a net gain of $8,600 recorded in our C&F
Group on asbestos-related insurance settlements.
|
|
(5)
|
|
Includes in the nine months ended September 29, 2006: increased/(decreased) contract profit
of $1,000 from the regular re-evaluation of contract profit estimates: $13,800 in our Global
E&C Group and $(12,800) in our Global Power Group; a net gain of $115,700 recorded in our C&F
Group on an asbestos-related insurance settlement; an aggregate charge of $(14,800) recorded
in our C&F Group in conjunction with the termination of our prior senior credit agreement;
and a net charge of $(12,500) recorded in our C&F Group in conjunction with certain debt
reduction initiatives.
|
Business Segments
We use several financial metrics to measure the performance of our business segments. EBITDA,
as discussed and defined above, is the primary earnings measure used by our chief operating
decision makers.
Global E&C Group
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
|
|
|
|
|
|
2007
|
|
|
2006
|
|
|
$ Change
|
|
|
% Change
|
|
|
2007
|
|
|
2006
|
|
|
$ Change
|
|
|
% Change
|
|
Operating revenues
|
|
$
|
951,402
|
|
|
$
|
619,659
|
|
|
$
|
331,743
|
|
|
|
53.5
|
%
|
|
$
|
2,626,816
|
|
|
$
|
1,515,382
|
|
|
$
|
1,111,434
|
|
|
|
73.3
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$
|
129,232
|
|
|
$
|
78,668
|
|
|
$
|
50,564
|
|
|
|
64.3
|
%
|
|
$
|
395,364
|
|
|
$
|
221,027
|
|
|
$
|
174,337
|
|
|
|
78.9
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Results
The increases in operating revenues in the three and nine months ended September 28, 2007,
compared to the corresponding periods of 2006, reflect increased volumes of work at all of our
Global E&C Group operating units. Major projects in the Middle East, Australia, Asia-Pacific and
Europe in the oil and gas, refining and chemical/petrochemical industries led the increase in
activities.
The increases in EBITDA in the three and nine months ended September 28, 2007, compared to the
corresponding periods of 2006, result primarily from the increased volumes of work and improved
margins at all of our Global E&C Group operating units. The markets served by our Global E&C Group
remain strong and we believe there are capacity constraints in the engineering and construction
industry. We increased our direct manpower by 17% in the first nine months of 2007, primarily in
our United Kingdom, Indian, North American and Asian offices, to help capture the market growth.
We plan to continue to expand our operational capacity throughout the remainder of 2007 and into
2008 through the combination of organic growth and selective acquisitions.
Overview of Segment
We expect the strong global economic growth and demand for oil and gas, petrochemicals and
refined products that stimulated investment in new and expanded plants over the last 12 to 24
months to continue throughout the remainder of 2007 and into 2008.
We anticipate that the higher levels of client investment in upstream oil and gas facilities
that we are currently experiencing will continue in most regions, particularly in West Africa, the
Middle East, Russia and the Caspian states. We believe that rising demand for natural gas in
Europe, Asia and the United States, combined with a shortfall in indigenous production, will
continue to act as a stimulant to the LNG business, both for LNG liquefaction plants and receiving
terminals.
42
We believe that the global refining system is currently running at very high utilization
rates, overall global refining margins are strong and expect that global demand for transportation
fuels will continue to increase. Additionally, the price differential between heavier,
higher-sulfur crude oil and lighter, sweeter crudes remains wide relative to the historic average.
These factors are continuing to stimulate refinery investment, particularly to process the heavier,
higher-sulfur crudes.
The crude price differential also creates financial incentives for upgrading lower-value
refinery residue to higher-value transportation fuels, and we expect to see continued substantial
investment in bottom-of-the-barrel upgrading projects in Europe, the Americas, the Middle East and
in Asia. We believe that our clients will make additional investments in upgrading projects during
the remainder of 2007 and into 2008. We have considerable experience and expertise in this area,
including our proprietary delayed coking technology. As of September 28, 2007, we were working on
28 delayed coking projects, which allow refineries to upgrade lower quality crude oil or refinery
residue to high value refined products such as transportation fuels. The projects we are executing
include feasibility studies, front-end engineering and design, or FEED, contracts, delayed coking
technology license agreements, engineering, procurement and construction supervision contracts and
full engineering, procurement and construction contracts. These projects are located in North
America, South America, Europe, the Middle East, Asia and the Indian sub-continent. We believe
that our Global E&C Groups proprietary delayed coking technology, know-how and extensive
experience in designing and constructing delayed cokers place us in a good competitive position to
continue to secure a significant share of this market.
Refinery capacity constraints are generating an interest in additional refinery capacity, both
greenfield and expansions. Major new investments in grassroots refineries have already commenced
and additional investments are planned for the Middle East and Asia. Major expansions are also
planned or underway in Asia and the Americas. We believe that most of the planned investment at
refineries in the United States and Europe to meet the demands of clean fuels legislation is
currently underway. However, refineries in the Middle East, North Africa and Asia are now
embarking on similar programs, both to meet their own domestic environmental programs and to meet
the product quality specifications in their export markets. We are currently working on refining
projects and integrated refining/chemical projects in the Americas, Europe, the Middle East and
Asia.
Investment in petrochemical plants began to rise sharply in 2004 in response to strong growth
in demand. The majority of this investment has been centered in the Middle East and in
Asia-Pacific. We are seeing continued strong demand supporting further new investment in these
regions, which we expect to continue throughout the remainder of 2007 and into 2008. We are also
seeing 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. We continue to
execute several major petrochemical contracts and expect to secure new petrochemicals business in
the remainder of 2007 and into 2008.
While the outlook for oil and gas, refining and petrochemicals in the remainder of 2007 and
into 2008 remains positive, we are seeing that, as the demand and cost for engineering and
construction services, materials and equipment and commodities continues to rise, some companies
are electing to commit to only partial or staged investments, to reduce the scope of their
investments, or to postpone or cancel investments, until the market slows. 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.
Investment in new pharmaceutical production facilities slowed in 2004 and 2005. We believe
this was attributable to a range of factors including industry cost pressure. Investment has been
focused more on plant rationalization, upgrading and improvement projects than on major new
greenfield production facilities. There are now indications of renewed interest in more
significant plant investment, particularly in biotechnology (including vaccine) facilities,
especially in some of the key pharmaceutical investment hubs Singapore, the U.S., Ireland and
Puerto Rico.
43
Global Power Group
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
Nine Months Ended
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
|
|
|
|
|
|
|
September 28,
|
|
|
September 29,
|
|
|
|
|
|
|
|
|
|
2007
|
|
|
2006
|
|
|
$ Change
|
|
|
% Change
|
|
|
2007
|
|
|
2006
|
|
|
$ Change
|
|
|
% Change
|
|
Operating revenues
|
|
$
|
348,470
|
|
|
$
|
290,979
|
|
|
$
|
57,491
|
|
|
|
19.8
|
%
|
|
$
|
1,014,944
|
|
|
$
|
786,347
|
|
|
$
|
228,597
|
|
|
|
29.1
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$
|
58,390
|
|
|
$
|
20,371
|
|
|
$
|
38,019
|
|
|
|
186.6
|
%
|
|
$
|
99,780
|
|
|
$
|
56,342
|
|
|
$
|
43,438
|
|
|
|
77.1
|
%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Results
The increases in operating revenues in the three and nine months ended September 28, 2007, as
compared to the corresponding periods of 2006, result from execution on increased bookings that
occurred largely in the early part of 2006 in our operations in North America, China and Europe.
Our Global Power Group experienced higher levels of EBITDA in the three and nine months ended
September 28, 2007, as compared to the corresponding periods of 2006, as a result of increased
volumes of business and increased margins experienced by our operations in North America, China and
Europe. In addition, EBITDA in the three and nine months ended September 28, 2007 included $14,400
related to the favorable resolution of project claims. The $14,400 impacted contract profit by
$9,600, interest income by $4,000 and reduced other deductions by $800. EBITDA in the nine months
ended September 28, 2007 was also adversely impacted by a $30,000 contingency taken in the second
quarter of 2007 on a legacy engineering, procurement and construction project in Europe. The
$30,000 contingency was in addition to a $25,000 contingency established during the fourth quarter
of 2006 and other write-downs and profit reversals in 2004. This project was bid in 2001 and
awarded in 2002, prior to the implementation of our current system of risk management controls and
our Project Risk Management Group. The two plants involved in this project are completed and have
been operating, but have experienced a series of technical issues, which largely involve corrosion
in the front-end of the plant, which we believe is caused by the clients use of fuel that is not
within the contract specifications, as well as back-end corrosion of subcontractor-provided
emissions control equipment and induction fans. The cause of the back-end corrosion, which we
discovered during the second quarter of 2007 to be more extensive than previously determined, is
under investigation. Working with the client, we have identified potential technical solutions to
ameliorate the corrosive effects of the out-of-specification fuel, and together with the client we
are in the process of evaluating those alternative solutions for the front-end corrosion. We are
currently in dispute with our client and our subcontractor as to who is financially responsible for
the required plant modifications. For further information, please see Note 12 to the condensed
consolidated financial statements in this quarterly report on Form 10-Q.
Overview of Segment
Although the solid fuel-fired boiler market remains highly competitive, we believe that there
are several continuing global market forces that will positively influence our Global Power Group
over the next two to three years. We believe that continued worldwide economic growth is driving
power demand growth in most world regions. In addition, continued tight global natural gas and oil
supplies have driven gas and oil prices upwards to historically high levels. We expect natural gas
fuel price volatility to remain high over the next three to five years due to declining domestic
supplies in Europe and the United States. In addition, we expect continued growth in the sales of
our environmental retrofit products due to further tightening of environmental regulations,
including the development and growing acceptance of global greenhouse gas regulation. We believe
that the combined effect of these factors will have a significant positive influence on the demand
for our products and services, such as new
utility and industrial solid fuel boilers, boiler services, boiler environmental products and
boiler-related construction services.
In North America, we believe the declining generating capacity reserves across the region,
coupled with persistent high oil and natural gas pricing, is spurring market growth for large coal
utility boilers. However, we are also seeing escalating plant costs and the concern for greenhouse
gas emissions having a growing impact on this market.
We believe plant price escalation is driven by the historically high demand for utility steam
power plants globally and is a result of strained supply of some key components needed to build the
new plants, such as steel,
44
cement and labor. As in most markets, we believe price will have a
dampening or smoothing effect to the up and down swings of this market.
To capitalize on this business opportunity, our Global Power Group is actively marketing
large-scale supercritical boiler technology in its key geographic markets as part of our utility
boiler product portfolio. We have been successful in securing two projects based on supercritical
technology: (i) a project in Poland where we will be supplying the worlds first supercritical
circulating fluidized-bed, or CFB, boiler that will utilize Siemens advanced BENSON vertical tube
supercritical steam technology and (ii) a project for the design and supply, or D&S, of a
supercritical once-through pulverized-coal, or PC, steam boiler for a coal-fired generating
facility located in West Virginia. This D&S project will be the first application of Siemens
advanced BENSON vertical tube supercritical steam technology to a PC boiler. We believe that we
can leverage these key project wins to further grow our position in the supercritical utility
boiler market for both PC and CFB boilers.
In anticipation of future greenhouse gas regulation, we are actively involved in developing
oxy-combustion boiler technology designed to provide a practical solution to producing a
concentrated stream of carbon-dioxide, or CO
2
, from a coal power plant. This CO
2
stream could then
be transported to a storage location in the most cost effective manner. To support the development
and commercialization of this new technology, we have entered into two separate alliance
agreements. One is with a large industrial gas company which allows us to co-pursue and develop
specific key demonstration projects. Together we believe that we form a strong technology team for
the successful development of the technology. In addition, we have entered into an alliance
agreement with another organization to support the development of an oxy-combustion pilot testing
facility to be built in Spain.
From the industrial sector, we are seeing growth in the solid fuel industrial boiler market,
driven by high oil and gas pricing. These boilers offer industrial clients an attractive economic
solution to supply their energy needs by utilizing low cost biomass and other solid opportunity
fuels. Many of these fuels also carry governmental tax credits and other financial incentives to
encourage their use as renewable fuels, making them more attractive to both the industrial and
utility power sectors. We believe that our leading CFB technology is well positioned to serve this
market segment due to its ability to burn difficult-to-burn fuels, its outstanding fuel
flexibility and its excellent environmental performance.
The United States Environmental Protection Agencys, or EPAs, Clean Air Interstate Rule,
which became effective during 2005, as well as the continued settlements of earlier New Source
Review lawsuits brought against a number of utilities by the EPA, continue to drive a strong
retrofit pollution control market, including add-on pollution control systems, such as low NOx
combustion systems, selective catalytic reduction systems and flue gas desulphurization systems.
We believe this market trend will benefit sales of our environmental products. We also believe
that, due to reducing capacity margins (which represent the amount of unused available electric
generating capacity as a percentage of total electric capacity), coal
power plants for independent power producers and utilities are
operating at greater capacity to produce more electricity, which, in turn, is spurring maintenance
investment by owners. We also see evidence that owners are making larger capital investments in
these plants to extend their useful lives. We believe these factors are helping to maintain a
strong boiler service market, which should benefit our boiler service business.
We believe that many of the same market forces discussed above are resulting in similar
beneficial market trends for our Global Power Group business in Europe. We believe that declining
power capacity reserves across the region, coupled with persistent high oil and natural gas
pricing, are spurring market growth for large utility coal boilers. Similar to the market in North
America, we are also seeing escalating plant costs and the concern for greenhouse gas emissions
having a growing impact on restraining this market.
45
Due to Europes historical preference for high efficiency coal power plants and active
greenhouse gas regulation for power plants (such as Europes emissions trading scheme, which became
effective in 2005), we believe supercritical boiler technology will continue to be the preference
in the European utility boiler market sector. We believe that, with the supercritical CFB and PC
boiler projects described above, we are well positioned to pursue this market sector by offering
both PC and CFB-type supercritical boilers. Historically, PC boiler technology has been the only
combustion technology choice for the supercritical utility boiler market segment globally.
However, we believe that supercritical CFB boiler technology has the potential to penetrate the
supercritical utility boiler market and to shift a portion of the market away from PC to CFB-type
boilers, especially for non-premium solid fuels such as lignite, brown coals and waste coals.
Since we expect to be the first boiler supplier with an operational supercritical CFB reference
plant (which is expected to be commissioned in 2009), we believe we are well positioned to pursue
this market opportunity.
From the industrial sector, driven by increasing power prices and high oil and gas pricing, we
are seeing growth in the solid fuel industrial power market, which is benefiting sales of our
industrial boilers. The European Union, or EU, has established regulation and incentive programs
to encourage the use of biomass and other waste fuels, which we believe is spurring growth both in
the industrial and utility sectors for our CFB boilers market. The EUs landfill and waste
recycling directives (which became effective in 2004) have opened a new market for our CFB boilers
firing refuse-derived fuels. The EUs Large Combustion Plant Directive, or LCPD (which has
governed the emission regulation of utility boiler power plants in Europe over the last five years
and continues to be revised to enforce even tighter emission standards), is expected to drive
growth in the retrofit pollution control market, which should benefit our environmental products
business. Due to the LCPDs relatively mild first step reduction goals, we do not expect to see
significant growth until after 2008 when the second phase of the program calls for tighter emission
limits. Finally, coal power plants for independent power producers
and utilities in Europe are operating at greater capacity to produce
more electricity spurring maintenance and life extension investment by owners. Similar to the
United States, reduced capacity margins are driving this market, which is having a positive effect
on the volume of our boiler service sales.
In Asia, we believe that high economic growth continues to drive strong power demand growth
and demand for new power capacity. We believe that the regions historically high coal use, now
coupled with high world oil and gas pricing, will likely continue to drive growth for coal-fueled
utility and industrial boilers in the region. The region contains some of the worlds largest
utility and industrial boiler markets, such as China and India, offering opportunities to our
Global Power Group businesses. Historically, it has been difficult for foreign companies to
penetrate these markets due to national trade policies and client preference for local companies.
To maximize our opportunities, we are continuing our licensing strategy, which allows us to gain
access to these closed markets while also expanding our capacity and resources through our
licensees allowing us to expand further in the global market place. Due to the regions growing
environmental awareness, including CO
2
and its link to global warming, we see opportunities for our
entire new boiler line from small industrial boilers to large utility supercritical boilers, as
well as for our environmental retrofit products (such as low NOx combustion systems and coal
pulverizers). Finally, reduced capacity margins are also resulting in coal power plants for independent power producers
and utilities operating at greater capacity to produce more electricity, which in turn spurs maintenance and life
extension investment by owners, offering further opportunity for our boiler services.
46
Liquidity and Capital Resources
Year-to-Date 2007 Activities
As of September 28, 2007, we had cash and cash equivalents on hand, short-term investments and
restricted cash totaling $883,100, compared to $630,000 as of December 29, 2006. The increase
results primarily from cash provided by operations of $238,500, cash provided by financing
activities of $20,600 and favorable exchange rate changes on cash and cash equivalents of $21,200,
partially offset by cash used in investing activities of $30,900. Of the $883,100 total at
September 28, 2007, $692,300 was held by our foreign subsidiaries.
Cash provided by operations in the first nine months of 2007 was $238,500, compared to
$133,600 in the first nine months of 2006. The cash provided by operations in the first nine
months of 2007 is attributable primarily to our strong operating performance, partially offset by
making $35,000 of mandatory and discretionary contributions to our domestic pension plan and
funding $30,500 of asbestos liability indemnity payments and defense costs. The cash provided by
operations in the first nine months of 2006 is attributable primarily to the strong operating
performance of our Global E&C Group, partially offset by funding $30,200 of asbestos liability
indemnity payments and defense costs. 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.
Cash used in investing activities in the first nine months of 2007 was $30,900, compared to
$16,000 in the comparable period of 2006. The cash used in investing activities in the first nine
months of 2007 is attributable primarily to capital expenditures of $33,500 (which includes $10,600
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 cash subject to restrictions of $2,800, the $1,500 purchase
of 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 from 2006, partially offset by a $6,300
distribution from our unconsolidated affiliates and proceeds from the sale of assets of $6,700.
The cash used in investing activities in the first nine months of 2006 is attributable primarily to
capital expenditures of $19,400 and an increase in investments in and advances to unconsolidated
affiliates of $3,400, partially offset by a reduction in cash subject to restrictions of $4,800 and
proceeds from asset sales of $1,500. Other than the construction expenditures related to FW Power
S.r.L., the capital expenditures related primarily to leasehold improvements, information
technology equipment and office equipment at our Global E&C Group offices in the United Kingdom,
India, Continental Europe and Asia-Pacific. These expenditures reflect the increased volumes of
business.
Cash provided by financing activities in the first nine months of 2007 was $20,600, compared
to $7,000 in the comparable period in 2006. The cash provided by financing activities in the first
nine months of 2007 reflects primarily stock option and warrant proceeds, partially offset by the
repayment of our convertible notes, which matured in June 2007, and a scheduled payment on our
limited-recourse project debt. The cash provided by financing activities in the first nine months
of 2006 reflects primarily warrant offer and stock option proceeds, partially offset by the
redemption of our 2011 senior notes and trust preferred securities.
47
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 claims recoveries and proceeds from asset sales, if any. These forecasts
extend over a rolling 12-month period and continue to indicate that our existing cash balances and
forecasted net cash provided from operating activities will be sufficient to fund our operations
throughout the next 12 months. The majority of our cash balances are invested in short-term
interest bearing accounts. As we did in the first quarter of 2007, we are considering investing
some of our cash in longer-term investment opportunities, including the reduction of certain
liabilities such as unfunded pension liabilities and/or the acquisition of other entities or
operations in the engineering and construction industry.
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.
We are required in certain circumstances to provide security to banks and sureties to obtain
new standby letters of credit, bank guarantees and performance bonds. Certain of our foreign
subsidiaries are required to and have cash collateralized $6,600 and $5,300 of their bonding
requirements as of September 28, 2007 and December 29, 2006, respectively.
Our domestic operating entities do not generate sufficient cash flow to fund our obligations
related to corporate overhead expenses and asbestos 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 repatriated $98,900
and $112,400 from our non-U.S. subsidiaries in the first nine months of 2007 and 2006,
respectively. Our current 2007 forecast assumes total cash repatriation from our non-U.S.
subsidiaries of approximately $134,600 from royalties, management fees, intercompany loans, debt
service on intercompany loans and/or dividends.
Our non-U.S. subsidiaries need to keep certain amounts available for working capital purposes,
to pay known liabilities and for other general corporate purposes. In addition, certain of our
non-U.S. subsidiaries are subject to statutory requirements in their jurisdictions of organization
that restrict the amount of funds that such subsidiaries may distribute. These factors limit our
ability to repatriate funds held by certain of our non-U.S. subsidiaries. However, we believe we
could repatriate additional cash from certain other of our foreign subsidiaries should we desire,
and we continue to have access to the revolving credit portion of our domestic senior credit
facility, if needed.
We have funded $30,500 of the asbestos liability indemnity payments and defense costs from our
cash flow in the first nine months of 2007, net of the cash received from insurance settlements.
We expect net positive cash inflows of $1,500 in the fourth quarter of 2007 from our asbestos
management program. The estimated positive fourth quarter of 2007 net cash inflow represents the
excess of our estimated cash receipts from existing insurance settlements over our estimated
indemnity payments and defense costs. For all of 2007, we are estimating a net cash outflow of
$29,000 from our asbestos management program. As we continue to collect cash from insurance
settlements and assuming no increase in our asbestos insurance liability or any future insurance
settlements, the asbestos insurance receivable recorded on our balance sheet will continue to
decrease.
On May 4, 2007, we executed an amendment to our domestic senior credit agreement to increase
the facility by $100,000 to $450,000, to reduce the pricing on a portion of the letters of credit
issued under the facility and to restore an accordion feature, which permits further incremental
increases of up to $100,000 in total availability under the facility. We had $312,400 and $189,000
of letters of credit outstanding under our domestic senior credit agreement as of September 28,
2007 and December 29, 2006, respectively. The letter of credit fees now range from 1.50% to 1.60%.
We do not intend to borrow under our domestic senior revolving credit facility during 2007.
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.
48
We have not declared or paid a common share dividend since July 2001 and we do not have any
plans to declare or pay any common share dividends. Our current credit agreement contains
limitations on dividend payments.
Capital Structure
We have the following common shares and common share equivalents as of October 31, 2007:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common
|
|
|
|
Outstanding
|
|
|
Share
|
|
|
|
Units
|
|
|
Equivalents
|
|
Common shares
|
|
|
71,835,337
|
|
|
|
71,835,337
|
|
Convertible preferred shares
|
|
|
3,063
|
|
|
|
199,595
|
|
Stock options
|
|
|
727,842
|
|
|
|
727,842
|
|
Class A common share purchase warrants
|
|
|
207,608
|
|
|
|
349,633
|
|
Restricted share units
|
|
|
86,926
|
|
|
|
86,926
|
|
|
|
|
|
|
|
|
|
Common shares and common share equivalents outstanding
|
|
|
|
|
|
|
73,199,333
|
|
Common shares available for issuance
|
|
|
|
|
|
|
74,802,996
|
|
|
|
|
|
|
|
|
|
Authorized common shares
|
|
|
|
|
|
|
148,002,329
|
|
|
|
|
|
|
|
|
|
Each convertible preferred share is convertible at the holders option into 65 common shares.
Each Class A warrant entitles its owner to purchase 1.6841 common shares at an exercise price of
$9.378 per common share. The Class A warrants are exercisable on or before September 24, 2009.
The remaining outstanding Class B warrants expired on September 24, 2007.
Off-Balance Sheet Arrangements
We own several non-controlling equity interests in power projects in Chile and Italy. Certain
of the projects have third-party debt that is not consolidated on 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.
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 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 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 mark-up and
corresponds to our services plus fees for reimbursable contracts and total selling price for
lump-sum contracts.
49
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28, 2007
|
|
|
September 29, 2006
|
|
|
|
Global
|
|
|
Global
|
|
|
|
|
|
|
Global
|
|
|
Global
|
|
|
|
|
|
|
E&C
|
|
|
Power
|
|
|
|
|
|
|
E&C
|
|
|
Power
|
|
|
|
|
|
|
Group
|
|
|
Group
|
|
|
Total
|
|
|
Group
|
|
|
Group
|
|
|
Total
|
|
NEW ORDERS BY PROJECT LOCATION (FUTURE REVENUES):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America
|
|
$
|
131,000
|
|
|
$
|
73,100
|
|
|
$
|
204,100
|
|
|
$
|
142,200
|
|
|
$
|
119,600
|
|
|
$
|
261,800
|
|
South America
|
|
|
7,400
|
|
|
|
10,800
|
|
|
|
18,200
|
|
|
|
1,300
|
|
|
|
33,500
|
|
|
|
34,800
|
|
Europe
|
|
|
163,800
|
|
|
|
196,300
|
|
|
|
360,100
|
|
|
|
349,700
|
|
|
|
53,100
|
|
|
|
402,800
|
|
Asia
|
|
|
1,022,100
|
|
|
|
20,000
|
|
|
|
1,042,100
|
|
|
|
1,088,300
|
|
|
|
39,900
|
|
|
|
1,128,200
|
|
Middle East
|
|
|
104,200
|
|
|
|
400
|
|
|
|
104,600
|
|
|
|
99,800
|
|
|
|
|
|
|
|
99,800
|
|
Australasia and other
|
|
|
143,500
|
|
|
|
5,900
|
|
|
|
149,400
|
|
|
|
66,800
|
|
|
|
1,900
|
|
|
|
68,700
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
1,572,000
|
|
|
$
|
306,500
|
|
|
$
|
1,878,500
|
|
|
$
|
1,748,100
|
|
|
$
|
248,000
|
|
|
$
|
1,996,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America
|
|
$
|
214,700
|
|
|
$
|
639,900
|
|
|
$
|
854,600
|
|
|
$
|
279,400
|
|
|
$
|
648,700
|
|
|
$
|
928,100
|
|
South America
|
|
|
13,600
|
|
|
|
79,400
|
|
|
|
93,000
|
|
|
|
11,700
|
|
|
|
80,500
|
|
|
|
92,200
|
|
Europe
|
|
|
567,800
|
|
|
|
531,200
|
|
|
|
1,099,000
|
|
|
|
615,800
|
|
|
|
235,800
|
|
|
|
851,600
|
|
Asia
|
|
|
1,455,300
|
|
|
|
140,200
|
|
|
|
1,595,500
|
|
|
|
1,276,000
|
|
|
|
84,600
|
|
|
|
1,360,600
|
|
Middle East
|
|
|
355,700
|
|
|
|
5,200
|
|
|
|
360,900
|
|
|
|
1,011,600
|
|
|
|
1,300
|
|
|
|
1,012,900
|
|
Australasia and other
|
|
|
268,100
|
|
|
|
7,200
|
|
|
|
275,300
|
|
|
|
275,700
|
|
|
|
2,900
|
|
|
|
278,600
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
2,875,200
|
|
|
$
|
1,403,100
|
|
|
$
|
4,278,300
|
|
|
$
|
3,470,200
|
|
|
$
|
1,053,800
|
|
|
$
|
4,524,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NEW ORDERS BY INDUSTRY (FUTURE REVENUES):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Power generation
|
|
$
|
12,700
|
|
|
$
|
275,300
|
|
|
$
|
288,000
|
|
|
$
|
90,600
|
|
|
$
|
218,300
|
|
|
$
|
308,900
|
|
Oil refining
|
|
|
274,000
|
|
|
|
|
|
|
|
274,000
|
|
|
|
822,100
|
|
|
|
|
|
|
|
822,100
|
|
Pharmaceutical
|
|
|
21,800
|
|
|
|
|
|
|
|
21,800
|
|
|
|
35,800
|
|
|
|
|
|
|
|
35,800
|
|
Oil and gas
|
|
|
176,700
|
|
|
|
|
|
|
|
176,700
|
|
|
|
166,200
|
|
|
|
|
|
|
|
166,200
|
|
Chemical/petrochemical
|
|
|
1,073,200
|
|
|
|
|
|
|
|
1,073,200
|
|
|
|
562,300
|
|
|
|
|
|
|
|
562,300
|
|
Power plant operation and maintenance
|
|
|
|
|
|
|
31,200
|
|
|
|
31,200
|
|
|
|
|
|
|
|
29,700
|
|
|
|
29,700
|
|
Environmental
|
|
|
7,300
|
|
|
|
|
|
|
|
7,300
|
|
|
|
81,500
|
|
|
|
|
|
|
|
81,500
|
|
Other, net of eliminations
|
|
|
6,300
|
|
|
|
|
|
|
|
6,300
|
|
|
|
(10,400
|
)
|
|
|
|
|
|
|
(10,400
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
1,572,000
|
|
|
$
|
306,500
|
|
|
$
|
1,878,500
|
|
|
$
|
1,748,100
|
|
|
$
|
248,000
|
|
|
$
|
1,996,100
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Power generation
|
|
$
|
20,400
|
|
|
$
|
1,313,600
|
|
|
$
|
1,334,000
|
|
|
$
|
93,200
|
|
|
$
|
972,300
|
|
|
$
|
1,065,500
|
|
Oil refining
|
|
|
978,000
|
|
|
|
|
|
|
|
978,000
|
|
|
|
1,294,900
|
|
|
|
|
|
|
|
1,294,900
|
|
Pharmaceutical
|
|
|
80,500
|
|
|
|
|
|
|
|
80,500
|
|
|
|
84,800
|
|
|
|
|
|
|
|
84,800
|
|
Oil and gas
|
|
|
462,500
|
|
|
|
|
|
|
|
462,500
|
|
|
|
425,700
|
|
|
|
|
|
|
|
425,700
|
|
Chemical/petrochemical
|
|
|
1,266,900
|
|
|
|
|
|
|
|
1,266,900
|
|
|
|
1,451,400
|
|
|
|
|
|
|
|
1,451,400
|
|
Power plant operation
and maintenance
|
|
|
|
|
|
|
89,500
|
|
|
|
89,500
|
|
|
|
|
|
|
|
81,500
|
|
|
|
81,500
|
|
Environmental
|
|
|
25,400
|
|
|
|
|
|
|
|
25,400
|
|
|
|
96,200
|
|
|
|
|
|
|
|
96,200
|
|
Other, net of eliminations
|
|
|
41,500
|
|
|
|
|
|
|
|
41,500
|
|
|
|
24,000
|
|
|
|
|
|
|
|
24,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
2,875,200
|
|
|
$
|
1,403,100
|
|
|
$
|
4,278,300
|
|
|
$
|
3,470,200
|
|
|
$
|
1,053,800
|
|
|
$
|
4,524,000
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
50
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 28, 2007
|
|
|
September 29, 2006
|
|
|
|
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
|
|
$
|
116,300
|
|
|
$
|
525,000
|
|
|
$
|
641,300
|
|
|
$
|
246,500
|
|
|
$
|
318,500
|
|
|
$
|
565,000
|
|
Other fixed-price
|
|
|
401,900
|
|
|
|
655,900
|
|
|
|
1,057,800
|
|
|
|
493,000
|
|
|
|
880,200
|
|
|
|
1,373,200
|
|
Reimbursable
|
|
|
4,385,800
|
|
|
|
199,700
|
|
|
|
4,585,500
|
|
|
|
4,107,700
|
|
|
|
47,000
|
|
|
|
4,154,700
|
|
Eliminations
|
|
|
(10,500
|
)
|
|
|
(1,000
|
)
|
|
|
(11,500
|
)
|
|
|
(29,800
|
)
|
|
|
6,300
|
|
|
|
(23,500
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
4,893,500
|
|
|
$
|
1,379,600
|
|
|
$
|
6,273,100
|
|
|
$
|
4,817,400
|
|
|
$
|
1,252,000
|
|
|
$
|
6,069,400
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BACKLOG (FUTURE REVENUES) BY PROJECT LOCATION:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America
|
|
$
|
218,900
|
|
|
$
|
542,200
|
|
|
$
|
761,100
|
|
|
$
|
234,300
|
|
|
$
|
638,600
|
|
|
$
|
872,900
|
|
South America
|
|
|
12,200
|
|
|
|
86,900
|
|
|
|
99,100
|
|
|
|
73,700
|
|
|
|
76,100
|
|
|
|
149,800
|
|
Europe
|
|
|
642,500
|
|
|
|
616,200
|
|
|
|
1,258,700
|
|
|
|
627,200
|
|
|
|
403,700
|
|
|
|
1,030,900
|
|
Asia
|
|
|
2,265,400
|
|
|
|
127,700
|
|
|
|
2,393,100
|
|
|
|
1,305,000
|
|
|
|
130,300
|
|
|
|
1,435,300
|
|
Middle East
|
|
|
1,205,900
|
|
|
|
600
|
|
|
|
1,206,500
|
|
|
|
1,663,400
|
|
|
|
800
|
|
|
|
1,664,200
|
|
Australasia and other
|
|
|
548,600
|
|
|
|
6,000
|
|
|
|
554,600
|
|
|
|
913,800
|
|
|
|
2,500
|
|
|
|
916,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
4,893,500
|
|
|
$
|
1,379,600
|
|
|
$
|
6,273,100
|
|
|
$
|
4,817,400
|
|
|
$
|
1,252,000
|
|
|
$
|
6,069,400
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BACKLOG (FUTURE REVENUES) BY INDUSTRY:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Power generation
|
|
$
|
101,000
|
|
|
$
|
1,263,100
|
|
|
$
|
1,364,100
|
|
|
$
|
154,400
|
|
|
$
|
1,124,000
|
|
|
$
|
1,278,400
|
|
Oil refining
|
|
|
1,761,200
|
|
|
|
|
|
|
|
1,761,200
|
|
|
|
1,737,500
|
|
|
|
|
|
|
|
1,737,500
|
|
Pharmaceutical
|
|
|
58,000
|
|
|
|
|
|
|
|
58,000
|
|
|
|
138,700
|
|
|
|
|
|
|
|
138,700
|
|
Oil and gas
|
|
|
718,700
|
|
|
|
|
|
|
|
718,700
|
|
|
|
1,149,300
|
|
|
|
|
|
|
|
1,149,300
|
|
Chemical/petrochemical
|
|
|
2,186,100
|
|
|
|
|
|
|
|
2,186,100
|
|
|
|
1,539,400
|
|
|
|
|
|
|
|
1,539,400
|
|
Power plant operation and maintenance
|
|
|
|
|
|
|
116,500
|
|
|
|
116,500
|
|
|
|
|
|
|
|
128,000
|
|
|
|
128,000
|
|
Environmental
|
|
|
42,200
|
|
|
|
|
|
|
|
42,200
|
|
|
|
81,400
|
|
|
|
|
|
|
|
81,400
|
|
Other, net of eliminations
|
|
|
26,300
|
|
|
|
|
|
|
|
26,300
|
|
|
|
16,700
|
|
|
|
|
|
|
|
16,700
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$
|
4,893,500
|
|
|
$
|
1,379,600
|
|
|
$
|
6,273,100
|
|
|
$
|
4,817,400
|
|
|
$
|
1,252,000
|
|
|
$
|
6,069,400
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
FOSTER WHEELER SCOPE IN BACKLOG
|
|
$
|
1,672,100
|
|
|
$
|
1,366,500
|
|
|
$
|
3,038,600
|
|
|
$
|
1,759,500
|
|
|
$
|
1,237,700
|
|
|
$
|
2,997,200
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
E&C MAN-HOURS IN BACKLOG (in
thousands)
|
|
|
13,300
|
|
|
|
|
|
|
|
13,300
|
|
|
|
13,300
|
|
|
|
|
|
|
|
13,300
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Inflation
The effect of inflation on our revenues and earnings 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 2006
Form 10-K. The only significant change to our application of critical accounting policies and
estimates is our adoption of FIN 48, as discussed below.
51
Accounting for Uncertainty in Income Taxes
We adopted the provisions of FIN 48 on December 30, 2006, the first day of fiscal year 2007.
In June 2006, the FASB issued FIN 48, which addresses the determination of whether tax benefits
claimed or expected to be claimed on a tax return should be recorded in the financial statements.
Under FIN 48, we recognize the tax benefit from an uncertain tax position only if it is more likely
than not that the tax position will be sustained on examination by the taxing authorities, based on
the technical merits of the position. The tax benefits recognized in the financial statements from such a position are based on the largest benefit that has a greater than fifty
percent likelihood of being realized upon ultimate settlement. FIN 48 also provides guidance on
the derecognition of the benefit of an uncertain tax position, classification of the unrecognized
tax benefits in the balance sheet, accounting for and classification of interest and penalties on
income tax uncertainties, accounting in interim periods and disclosures.
Our subsidiaries file income tax returns in numerous tax jurisdictions, including the United
States, several U.S. states and several non-U.S. jurisdictions, primarily in Europe and Asia. 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 2002.
A number of tax years are under audit by the relevant federal, state, and foreign tax
authorities. We anticipate that several of these audits may be concluded in the foreseeable
future, including in 2007. 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.
As a result of the adoption of FIN 48, we recognized a $4,400 reduction in the opening balance
of our shareholders equity. This resulted from changes in the amount of tax benefits recognized
related to uncertain tax positions and the accrual of interest and penalties.
As of the adoption date, we had $44,800 of unrecognized tax benefits, of which $44,300 would,
if recognized, affect our effective tax rate. There were no material changes in this amount during
the nine months ended September 28, 2007.
In our condensed consolidated statement of operations, we recognize interest accrued on the
unrecognized tax benefits in interest expense and penalties on the unrecognized tax benefits in
other deductions. We recorded $1,100 and $1,900 in interest expense and penalties for the three
and nine months ended September 28, 2007, respectively. We had $24,200 accrued for the payment of
interest and penalties as of September 28, 2007.
Accounting Developments
In September 2006, the 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. SFAS No. 157 is
effective for all financial statements issued for fiscal years beginning after November 15, 2007.
We do not expect our adoption of this new standard to have a material impact on our financial
position, results of operations or cash flows.
In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets
and Financial Liabilities, including an amendment of FASB Statement No. 115. SFAS No. 159 permits
entities to choose to measure many financial instruments and certain other items at fair value that
are not currently required to be measured at fair value. Unrealized gains and losses on items for
which the fair value option has been elected are reported in earnings. SFAS No. 159 does not
affect any existing accounting literature that requires certain assets and liabilities to be
carried at fair value. SFAS No. 159 is effective for fiscal years beginning after November 15,
2007. We are still evaluating whether we want to adopt this new optional standard.
52
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 and the various industries within
which we operate. These include statements regarding our expectation 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 under Part II, Item 1A, Risk Factors and the following, could
cause business conditions and our results to differ materially from what is contained in
forward-looking statements:
|
|
|
changes in the rate of economic growth in the United States and other major
international economies;
|
|
|
|
|
changes in investment by the oil and gas, oil refining, chemical/petrochemical and power
industries;
|
|
|
|
|
changes in the financial condition of our customers;
|
|
|
|
|
changes in regulatory environment;
|
|
|
|
|
changes in project design or schedules;
|
|
|
|
|
contract cancellations;
|
|
|
|
|
changes in our estimates of costs to complete projects;
|
|
|
|
|
changes in trade, monetary and fiscal policies worldwide;
|
|
|
|
|
compliance with laws and regulations relating to our global operations;
|
|
|
|
|
currency fluctuations;
|
|
|
|
|
war and/or terrorist attacks on facilities either owned or where equipment or services
are or may be provided;
|
|
|
|
|
interruptions to shipping lanes or other methods of transit;
|
|
|
|
|
outcomes of pending and future litigation, including litigation regarding our liability
for damages and insurance coverage for asbestos exposure;
|
|
|
|
|
protection and validity of our patents and other intellectual property rights;
|
|
|
|
|
increasing competition by foreign and domestic companies;
|
|
|
|
|
compliance with our debt covenants;
|
|
|
|
|
recoverability of claims against our customers and others by us and claims by third
parties against us; and
|
|
|
|
|
changes in estimates used in our critical accounting policies.
|
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.
53
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.
54
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
There have been no material changes in the market risks as described in our annual report on
Form 10-K for the year ended December 29, 2006.
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 have been no changes in our internal control over financial reporting in the quarter
ended September 28, 2007 that have materially affected, or are reasonably likely to materially
affect, our internal control over financial reporting.
55
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
Our business is subject to a number of risks and uncertainties, including those described
below. If any of these events occur, our business could be harmed and the trading price of our
securities could decline. The following discussion of risks relating to our business should be
read carefully in connection with evaluating our business and the forward-looking statements
contained in this quarterly report on Form 10-Q. For additional information regarding
forward-looking statements, see Part I, Item 2, Managements Discussion and Analysis of Financial
Condition and Results of OperationsSafe Harbor Statement.
Our current and future lump-sum or fixed-price contracts and other shared risk contracts may result
in significant losses if costs are greater than anticipated.
Some of our contracts are fixed price contracts and other shared-risk contracts that are
inherently risky because we agree to the selling price of the project at the time we enter into the
contract. The selling price is based on estimates of the ultimate cost of the contract and we
assume substantially all of the risks associated with completing the project, as well as the
post-completion warranty obligations. Certain of these contracts are lump-sum turnkey projects
where we are responsible for all aspects of the work from engineering through construction, as well
as commissioning, all for a fixed selling price.
We assume the projects technical risk and associated warranty obligations, meaning that we
must tailor products and systems to satisfy the technical requirements of a project even though, at
the time the project is awarded, we may not have previously produced such a product or system. We
also assume the risks related to revenue, cost and gross profit realized on such contracts that can
vary, sometimes substantially, from the original projections due to changes in a variety of other
factors, including but not limited to:
|
|
|
engineering design changes;
|
|
|
|
|
unanticipated technical problems with the equipment being supplied or developed by us,
which may require that we spend our own money to remedy the problem;
|
|
|
|
|
changes in the costs of components, materials or labor;
|
|
|
|
|
difficulties in obtaining required governmental permits or approvals;
|
|
|
|
|
changes in local laws and regulations;
|
|
|
|
|
changes in local labor conditions;
|
|
|
|
|
project modifications creating unanticipated costs;
|
|
|
|
|
delays caused by local weather conditions; and
|
|
|
|
|
our project owners, suppliers or subcontractors failure to perform.
|
These risks may be exacerbated by the length of time between signing a contract and completing
the project because most lump-sum or fixed-price projects are long-term. In addition, we sometimes
bear the risk of delays caused by unexpected conditions or events. Long-term, fixed-price projects
often make us subject to penalties if portions of the project are not completed in accordance with
agreed-upon time limits. Therefore, significant losses can result from performing large, long-term
projects on a lump-sum basis. These losses may be material, including in some cases up to or
slightly exceeding the full contract value in certain events of non-performance, and could
negatively impact our business, financial condition, results of operations and cash flow.
We may increase the size and number of lump-sum turnkey contracts, sometimes in countries
where we have limited previous experience.
56
We may bid for and enter into such contracts through partnerships or joint ventures with
third-parties. This may increase our ability and willingness to bid for increased numbers of
contracts and/or increased size of contracts. Entering into these partnerships or joint ventures
will expose us to credit and performance risks of those third-party partners, which could have a
negative impact on our business and our results of operations if these parties fail to perform
under the arrangements.
Because we recognize operating revenues and costs of operating revenues on a
percentage-of-completion basis, revisions to revenues and estimated costs could result in changes
to previously recorded revenues, costs and profits. For further information on our revenue
recognition methodology, please refer to Note 1, Summary of Significant Accounting
PoliciesRevenue Recognition on Long-Term Contracts, to the condensed consolidated financial
statements in this quarterly report on Form 10-Q.
Failure by us to successfully defend against claims made against us by project owners or by our
project subcontractors, or failure by us to recover adequately on claims made against project
owners, could materially adversely affect our business, financial condition, results of operations
and cash flow.
In the ordinary course of business, claims involving project owners and subcontractors are
brought against us and by us in connection with our project contracts. Claims brought against us
include back charges for alleged defective or incomplete work, breaches of warranty and/or late
completion of the project work and claims for canceled projects. The claims and back charges can
involve actual damages, as well as contractually agreed upon liquidated sums. If we were found to
be liable on any of the project claims against us, we would have to incur a charge against earnings
to the extent a reserve had not been established for the matter in our accounts along with an
associated impact on our cash flow. Claims brought by us against project owners include claims for
additional costs incurred in excess of current contract provisions arising out of project delays
and changes in the previously agreed scope of work. Claims between us and our subcontractors and
vendors include claims like any of those described above. These project claims, if not resolved
through negotiation, are often subject to lengthy and expensive litigation or arbitration
proceedings. Charges associated with claims brought against us and by us could materially
adversely impact our business, financial condition, results of operations and cash flow.
If we have a material weakness in our internal control over financial reporting, our ability to
report our financial results on a timely and accurate basis may be adversely affected.
Although we had no material weaknesses as of December 29, 2006, we have reported material
weaknesses in our internal control over financial reporting in the past. We cannot assure that we
will avoid a material weakness in the future. If we have another material weakness in our internal
control over financial reporting in the future, it could adversely impact our ability to report our
financial results in a timely and accurate manner.
We require cash repatriations from our non-U.S. subsidiaries to meet our domestic cash needs
related to our asbestos-related liabilities and corporate overhead expenses. Our ability to
repatriate funds from our non-U.S. subsidiaries is limited by a number of factors.
As of September 28, 2007, we had cash, cash equivalents, short-term investments and restricted
cash of $883,100, of which $692,300 was held by our non-U.S. subsidiaries. Our fiscal year 2007
forecast assumes total cash repatriation from our non-U.S. subsidiaries of approximately $134,600
from royalties, management fees, intercompany loans, debt service on intercompany loans and/or
dividends. There can be no assurance that the forecasted foreign cash repatriation will occur as
our non-U.S. subsidiaries need to keep certain amounts available for working capital purposes, to
pay known liabilities, to comply with covenants and for other general corporate purposes. The
repatriation of funds may also subject those funds to taxation.
Our international operations involve risks that may limit or disrupt operations, limit repatriation
of cash, increase foreign taxation or otherwise materially adversely affect our business, financial
condition, results of operations and cash flow.
We have substantial international operations that are conducted through foreign and domestic
subsidiaries, as well as through agreements with foreign joint venture partners. Our international
operations accounted for approximately 80% of our operating revenues and substantially all of our
operating cash flow in the first nine months of 2007. We have international operations in Eastern
and Western Europe, Asia, Australia, Africa, the Middle East and South America. Additionally, we
purchase materials and equipment on a worldwide basis. Our foreign operations are subject to risks
that could materially adversely affect our business, financial condition, results of operations and
cash flow, including:
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uncertain political, legal and economic environments;
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potential incompatibility with foreign joint venture partners;
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foreign currency controls and fluctuations;
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energy prices and availability;
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terrorist attacks;
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the imposition of additional governmental controls and regulations;
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war and civil disturbances;
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labor problems; and
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interruption or delays in international shipping and/or increases in the costs of
international shipping.
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Because of these risks, our international operations and our execution of projects may be
limited, or disrupted; we may lose contract rights; our foreign taxation may be increased; or we
may be limited in repatriating earnings. In addition, in some cases, applicable law and joint
venture or other agreements may provide that each joint venture partner is jointly and severally
liable for all liabilities of the venture. These potential events and liabilities could materially
adversely affect our business, financial condition, results of operations and cash flow.
In addition, many of the countries in which we transact business have laws that restrict the
offer or payment of anything of value to government officials or other persons with the intent of
gaining business or favorable government action. We are subject to these laws in addition to being
governed by U.S. Federal laws restricting these types of activities. In addition to prohibiting
certain bribery-related activity with foreign officials and other persons, these laws provide for
recordkeeping and reporting obligations. Any failure to comply with these legal and regulatory
obligations could impact us in a variety of ways that include, but are not limited to, significant
criminal, civil and administrative penalties. The failure to comply with these legal and
regulatory obligations could also result in the disruption of our business activities.
We may invest in longer-term investment opportunities, such as the acquisition of other entities or
operations in the engineering and construction industry. Acquisitions of other entities or
operations have risks that could materially adversely affect our business, financial condition,
results of operations and cash flow.
During the first quarter of 2007, we began exploring strategic acquisitions within the
engineering and construction industry to complement or expand on our technical capabilities. The
acquisition of engineering and construction companies and assets is subject to substantial risks,
including the failure to identify material problems during due diligence, the risk of over-paying
for assets and the inability to arrange financing for an acquisition as may be required or desired.
Further, the integration and consolidation of acquisitions requires substantial human, financial
and other resources and, ultimately, our acquisitions may not be successfully integrated and our
resources may be diverted. There can be no assurances that we will consummate any such
acquisitions, that any future acquisitions will perform as expected or that the returns from such
acquisitions will support the investment required to acquire them or the capital expenditures
needed to develop them.
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Our business may be materially adversely impacted by regional, national and/or global requirements
to significantly limit or reduce greenhouse gas emissions in the future.
Greenhouse gases that result from human activities, including burning of fossil fuels, have
been the focus of increased scientific and political scrutiny and are being subjected to various
legal requirements. International agreements, national laws, state laws and various regulatory
schemes limit or otherwise regulate emissions of greenhouse gases, and additional restrictions are
under consideration by different governmental entities. We derive a significant amount of revenues
and contract profits from engineering and construction services and from the supply of our
manufactured equipment to clients that own and/or operate electric power generating plants.
Additionally, we own or partially own plants that generate electricity from burning natural gas or
various types of solid fuels. These plants emit greenhouse gases as part of the process to
generate electricity. Compliance with the existing greenhouse gas regulation may prove costly or
difficult. It is possible that owners and operators of existing or future electric generating
plants could be subject to new or changed environmental regulations that result in significantly
limiting or reducing the amounts of greenhouse gas emissions, increasing the cost of emitting such
gases or requiring emissions allowances. The costs of controlling such emissions or obtaining
required emissions allowances could be significant. It also is possible that necessary controls or
allowances may not be available. Such regulations could negatively impact client investments in
capital projects, which could negatively impact the market for our manufactured products and
certain of our services, and also could negatively affect the operations and profitability of our
own electric power plants. This could materially adversely affect our business, financial
condition, results of operations and cash flow.
Certain of our various debt agreements impose financial covenants, which may prevent us from
capitalizing on business opportunities, which could materially adversely affect our business,
financial condition, results of operations and cash flow.
Our senior credit agreement imposes financial covenants on us. These covenants limit our
ability to incur indebtedness, pay dividends or make other distributions, make investments and sell
assets. These limitations may restrict our ability to pursue business opportunities, which could
impede our ability to compete and could negatively impact our business. Failure to comply with
these covenants may allow lenders to elect to accelerate the repayment dates of certain of our
existing or future outstanding debt or other obligations. We may not be able to repay such
obligations if accelerated. Our failure to repay such obligations could materially adversely
affect our business, financial condition, results of operations and cash flow.
We face limitations on our ability to obtain new letters of credit and bank guarantees on the same
terms as we have historically. If we were unable to obtain letters of credit and bank guarantees
on reasonable terms, our business, financial condition, results of operations and cash flow could
be materially adversely affected.
It is customary in the industries in which we operate to provide letters of credit and bank
guarantees in favor of clients to secure obligations under contracts. We may not be able to
continue obtaining new letters of credit and bank guarantees in sufficient quantities to match our
business requirements or at favorable rates. If our financial condition deteriorates, we may also
be required to provide cash collateral or other security to maintain existing letters of credit and
bank guarantees. If this occurs, our ability to perform under existing contracts may be adversely
affected and our business, financial condition, results of operations and cash flow could be
materially adversely affected.
We may have high working capital requirements and we may have difficulty obtaining additional
financing, which could negatively impact our business, financial condition, results of operations
and cash flow.
In some cases, we may require significant amounts of working capital to finance the purchase
of materials and performance of engineering, construction and other work on certain of our projects
before we receive payment from our customers. In some cases, we are contractually obligated to our
customers to fund working capital on our projects. Increases in working capital requirements could
materially adversely affect our business, financial condition, results of operations and cash flow.
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Projects included in our backlog may be delayed or cancelled, which could materially adversely
affect our business, financial condition, results of operations and cash flow.
The dollar amount of backlog does not necessarily indicate future earnings related to the
performance of that work. Backlog refers to expected future revenues under signed contracts and
legally binding letters of intent that we have determined are likely to be performed. Backlog
represents only business that is considered firm, although cancellations or scope adjustments may
and do occur. Because of changes in project scope and schedule, we cannot predict with certainty
when or if backlog will be performed. In addition, even where a project proceeds as scheduled, it
is possible that contracted parties may default and fail to pay amounts owed to us. Material
delays, cancellations or payment defaults could materially adversely affect our business, financial
condition, results of operations and cash flow.
The number and cost of our current and future asbestos claims in the United States could be
substantially higher than we have estimated and the timing of payment of claims could be sooner
than we have estimated, which could materially adversely affect our business, financial condition,
results of operations and cash flow.
Some of our subsidiaries are named as defendants in numerous lawsuits and out-of-court
administrative claims pending in the United States in which the plaintiffs claim damages for
alleged bodily injury or death arising from exposure to asbestos in connection with work performed,
or heat exchange devices assembled, installed and/or sold, by our subsidiaries. We expect these
subsidiaries to be named as defendants in similar suits and that claims will be brought in the
future. For purposes of our financial statements, we have estimated the indemnity and defense
costs to be incurred in resolving pending and forecasted domestic claims through year-end 2021.
Although we believe our estimates are reasonable, the actual number of future claims brought
against us and the cost of resolving these claims could be substantially higher than our estimates.
Some of the factors that may result in the costs of asbestos claims being higher than our current
estimates include:
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the rate at which new claims are filed;
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the number of new claimants;
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changes in the mix of diseases alleged to be suffered by the claimants, such as type of
cancer, asbestosis or other illness;
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increases in legal fees or other defense costs associated with asbestos claims;
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increases in indemnity payments;
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decreases in the proportion of claims dismissed with zero indemnity payments;
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indemnity payments being required to be made sooner than expected;
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bankruptcies of other asbestos defendants, causing a reduction in the number of
available solvent defendants and thereby increasing the number of claims and the size of
demands against our subsidiaries;
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adverse jury verdicts requiring us to pay damages in amounts greater than we expect to
pay in settlements;
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changes in legislative or judicial standards that make successful defense of claims
against our subsidiaries more difficult; or
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enactment of legislation requiring us to contribute amounts to a national settlement
trust in excess of our expected net liability, after insurance, in the tort system.
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The total liability recorded on our balance sheet is based on estimated indemnity and defense
costs expected to be incurred through year-end 2021. We believe that it is likely that there will
be new claims filed after 2021, 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 2021. Our forecast contemplates that the number of new claims requiring indemnity
will decline from year to year. If future claims fail to decline as we expect, our aggregate
liability for asbestos claims will be higher than estimated.
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Since year-end 2004, we have worked with Analysis Research Planning Corporation, or ARPC,
nationally recognized consultants in projecting asbestos liabilities, to estimate the amount of
asbestos-related indemnity and defense costs for the following 15-year period. ARPC reviews our
current year-to-date asbestos indemnity payments, defense costs and claims activity and compares
them to our 15-year forecast prepared at the previous year-end. Based on its review, ARPC may
recommend that the assumptions used to estimate our future asbestos liability be updated, as
appropriate.
Our forecast of the number of future claims is based, in part, on a regression model, which
employs the statistical analysis of our historical claims data to generate a trend line for future
claims and, in part, on an analysis of future disease incidence. Although we believe this forecast
method is reasonable, other forecast methods that attempt to estimate the population of living
persons who could claim they were exposed to asbestos at worksites where our subsidiaries performed
work or sold equipment could also be used and might project higher numbers of future claims than
our forecast.
The actual number of future claims, the mix of disease types and the amounts of indemnity and
defense costs may exceed our current estimates. We update at least annually our forecasts to take
into consideration recent claims experience and other developments, such as legislation and
litigation outcomes, that may affect our estimates of future asbestos-related costs. The
announcement of increases to asbestos liabilities as a result of revised forecasts, adverse jury
verdicts or other negative developments involving asbestos litigation or insurance recoveries may
cause the value or trading prices of our securities to decrease significantly. These negative
developments could also negatively impact our liquidity, cause us to default under covenants in our
indebtedness, cause our credit ratings to be downgraded, restrict our access to capital markets or
otherwise materially adversely affect our business, financial condition, results of operations and
cash flow.
The adequacy and timing of insurance recoveries of our asbestos-related costs in the United States
is uncertain. The failure to obtain insurance recoveries could materially adversely affect our
business, financial condition, results of operations and cash flow.
Although we believe that a significant portion of our subsidiaries liability and defense
costs for asbestos claims will be covered by insurance, the adequacy and timing of insurance
recoveries is uncertain. Since 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 claims 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
year-end 2006. We utilized that analysis to determine our estimate of the value of the unsettled
insurance asset.
The asset recorded on our condensed consolidated balance sheet represents our best estimate of
settled and probable future insurance settlements relating to our domestic liability for pending
and estimated future asbestos claims through year-end 2021. The estimate of recoveries from
unsettled insurers in the insurance litigation discussed below is based upon the application of New
Jersey law to certain insurance coverage issues and assumptions relating to cost allocation and
other factors. The insurance asset also includes an estimate of the amount of recoveries under
existing settlements with other insurers. On February 13, 2001, litigation was commenced against
certain of our subsidiaries by certain of our insurers seeking to recover from other insurers
amounts previously paid by them and to adjudicate their rights and responsibilities under our
subsidiaries insurance policies. As of September 28, 2007, we estimated the value of our asbestos
insurance asset contested by our subsidiaries insurers in this litigation at $26,500. While this
litigation has been pending, we have had to cover a substantial portion of our settlement payments
and defense costs out of our cash flow.
Certain of our subsidiaries have entered into settlement agreements calling for certain
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 that we previously have incurred. We entered into two additional
settlements in 2007 and 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 the
remaining unsettled insurance asset at amounts significantly in excess of our current estimates, it
is likely that the amount of our insurance settlements will not cover all future asbestos-related
costs and we will continue to fund a portion of such future costs, which will reduce our cash flow
and our working capital. Additionally, certain of the settlements with insurance companies during
the past several years were for fixed dollar amounts that do not change as the liability changes.
Accordingly, increases in the asbestos liability will not result in an equal increase in the
insurance asset.
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An adverse outcome in the pending insurance litigation described above could limit our
remaining insurance recoveries. However, a favorable outcome in all or part of the litigation
could increase remaining insurance recoveries above our current estimate.
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 also may fail to reimburse amounts owed to us on a timely basis. If we fail to realize
expected insurance recoveries, or experience delays in receiving material amounts from our
insurers, our business, financial condition, results of operations and cash flow could be
materially adversely affected.
The U.S. Congress could pass federal legislation addressing asbestos-related claims, which could
require us to pay amounts in excess of current estimates of our net asbestos liability and which
could adversely affect our business, financial condition, results of operations and long-term cash
flow.
From time to time various bills have been introduced in the U.S. Congress seeking to deal with
asbestos litigation, including asbestos trust fund legislation that was considered in the U.S.
Senate in 2006. Although such legislation has not been reintroduced in the current Congress, if it
were reintroduced and enacted into law in substantially similar form, it could require us to
contribute amounts into a national trust fund in excess of our forecasted asbestos liability, net
of expected insurance recoveries.
A number of asbestos-related claims have been received by our subsidiaries in the United Kingdom.
To date, these claims have been covered by insurance policies and proceeds from the policies have
been paid directly to the plaintiffs. The timing and amount of asbestos claims that may be made in
the future, the financial solvency of the insurers and the amount that may be paid to resolve the
claims, are uncertain. The insurance carriers failure to make payments due under the policies
could materially adversely affect our business, financial condition, results of operations and cash
flow.
Some of our subsidiaries in the United Kingdom have received claims alleging personal injury
arising from exposure to asbestos in connection with work performed, or heat exchange devices
assembled, installed and/or sold, by our subsidiaries. We expect these subsidiaries to be named as
defendants in additional suits and claims brought in the future. To date, insurance policies have
provided coverage for substantially all of the costs incurred in connection with resolving asbestos
claims in the United Kingdom. In our condensed consolidated balance sheet, we have recorded U.K.
asbestos-related insurance recoveries equal to the U.K. asbestos-related liabilities, which are
comprised of an estimated liability relating to open (outstanding) claims and an estimated
liability relating to future unasserted claims through year-end 2021. Our ability to continue to
recover under these insurance policies is dependent upon, among other things, the timing and amount
of asbestos claims that may be made in the future, the financial solvency of our insurers and the
amount that may be paid to resolve the claims. These factors could significantly limit our
insurance recoveries, which could materially adversely affect our business, financial condition,
results of operations and cash flow.
Because our operations are concentrated in four particular industries, we may be adversely impacted
by economic or other developments in these industries.
We derive a significant amount of revenues from services provided to clients that are
concentrated in four industries: oil and gas, oil refining, chemical/petrochemical and power.
Unfavorable economic or other developments in one or more of these industries could adversely
affect our clients and could materially adversely affect our business, financial condition, results
of operations and cash flow.
We may lose business to competitors.
We are engaged in highly competitive businesses in which customer contracts are often awarded
through bidding processes based on price and the acceptance of certain risks. We compete with
other general and specialty contractors, both foreign and domestic, including large international
contractors and small local contractors. The strong competition in our markets requires
maintaining skilled personnel, investing in technology and also puts pressure on profit margins.
Because of this, we could be prevented from obtaining contracts for which we have bid due to price,
greater perceived financial strength and resources of our competitors and/or perceived technology
advantages.
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A failure by us to attract and retain qualified personnel, joint venture partners, advisors and
subcontractors could materially adversely affect our business, financial condition, results of
operations and cash flow.
Our ability to attract and retain qualified engineers and other professional personnel, as
well as joint venture partners, advisors and subcontractors, will be an important factor in
determining our future success. The market for these professionals is competitive and we may not
be successful in efforts to attract and retain these professionals. Failure to attract or retain
these professionals, joint venture partners, advisors and subcontractors could materially adversely
affect our business, financial condition, results of operations and cash flow.
We are subject to various environmental laws and regulations in the countries in which we operate.
If we fail to comply with these laws and regulations, we may incur significant costs and penalties
that could materially adversely affect our business, financial condition, results of operations and
cash flow.
Our operations are subject to U.S., European and other laws and regulations governing the
generation, management and use of regulated materials, the discharge of materials into the
environment, the remediation of environmental contamination, or otherwise relating to environmental
protection. Both our Global E&C Group and our Global Power Group make use of and produce as wastes
or byproducts substances that are considered to be hazardous under these environmental laws and
regulations. We may be subject to liabilities for environmental contamination as an owner or
operator of a facility or as a generator of hazardous substances without regard to negligence or
fault, and we are subject to additional liabilities if we do not comply with applicable laws
regulating such hazardous substances, and, in either case, such liabilities can be substantial.
These laws and regulations could expose us to liability arising out of the conduct of current
and past operations or conditions, including those associated with formerly owned or operated
properties caused by us or others, or for acts by us or others which were in compliance with all
applicable laws at the time the acts were performed. In some cases, we have assumed contractual
indemnification obligations for environmental liabilities associated with some formerly owned
properties. Additionally, we may be subject to claims alleging personal injury, property damage or
natural resource damages as a result of alleged exposure to or contamination by hazardous
substances. The ongoing costs of complying with existing environmental laws and regulations can be
substantial. Changes in the environmental laws and regulations, remediation obligations,
enforcement actions or claims for damages to persons, property, natural resources or the
environment could result in material costs and liabilities.
We rely on our information systems in our operations. Failure to protect these systems against
security breaches could adversely affect our business and results of operations. Additionally, if
these systems fail or become unavailable for any significant period of time, our business could be
harmed.
The efficient operation of our business is dependent on computer hardware and software
systems. Information systems are vulnerable to security breaches by computer hackers and cyber
terrorists. We rely on industry accepted security measures and technology to securely maintain
confidential and proprietary information maintained on our information systems. However, these
measures and technology may not always be adequate to properly prevent security breaches. In
addition, the unavailability of the information systems or the failure of these systems to perform
as anticipated for any reason could disrupt our business and could result in decreased performance
and increased overhead costs, causing our business and results of operations to suffer. Any
significant interruption or failure of our information systems or any significant breach of
security could adversely affect our business and results of operations.
We may lose market share to our competitors and be unable to operate our business profitably if our
patents and other intellectual property rights do not adequately protect our proprietary products.
Our success depends significantly on our ability to protect our intellectual property rights
to the technologies and know-how used in our proprietary products. We rely on patent protection,
as well as a combination of trade secret, unfair competition and similar laws and nondisclosure,
confidentiality and other contractual restrictions to protect our proprietary technology. However,
these legal means afford only limited protection and may not adequately protect our rights or
permit us to gain or keep any competitive advantage. We also rely on unpatented proprietary
technology. We cannot provide assurance that we can meaningfully protect all our rights in our
unpatented proprietary technology or that others will not independently develop substantially
equivalent proprietary products or processes or otherwise gain access to our unpatented proprietary
technology. We also hold licenses from third-parties that are necessary to utilize certain
technologies used in the design and manufacturing of some of our products. The loss of such
licenses would prevent us from manufacturing and selling these products, which could harm our
business.
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We have anti-takeover provisions in our bye-laws that may discourage a change of control.
Our bye-laws contain provisions that could make it more difficult for a third-party to acquire
us without the consent of our board of directors. These provisions provide for:
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The board of directors to be divided into three classes serving staggered three-year
terms. Directors can be removed from office only for cause, by the affirmative vote of the
holders of two-thirds of the issued shares generally entitled to vote. The board of
directors does not have the power to remove directors. Vacancies on the board of directors
may only be filled by the remaining directors. Each of these provisions can delay a
shareholder from obtaining majority representation on the board of directors.
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Any amendment to the bye-law limiting the removal of directors to be approved by the
board of directors and the affirmative vote of the holders of three-quarters of the issued shares entitled to vote at general meetings.
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The board of directors to consist of not less than three nor more than 20 persons, the
exact number to be set from time to time by a majority of the whole board of directors.
Accordingly, the board of directors, and not the shareholders, has the authority to
determine the number of directors and could delay any shareholder from obtaining majority
representation on the board of directors by enlarging the board of directors and filling
the new vacancies with its own nominees until a general meeting at which directors are to
be appointed.
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Restrictions on the time period in which directors may be nominated. A shareholder
notice to nominate an individual for election as a director must be received no less than
120 calendar days prior to the anniversary of the date on which we first mailed our proxy
materials for the preceding years annual meeting.
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Restrictions on the time period in which shareholder proposals may be submitted. To be
timely for inclusion in our proxy statement, a shareholders notice for a shareholder
proposal must be received not less than 120 days prior to the anniversary of the date on
which we first mailed our proxy materials for the preceding years annual general meeting.
To be timely for consideration at the annual meeting of shareholders, a shareholders
notice must be received no less than 45 days prior to the anniversary of the date on which
we first mailed our proxy materials for the preceding years annual meeting.
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The board of directors to determine the powers, preferences and rights of preference shares and to issue preference shares without shareholder approval. The board of directors
could authorize the issuance of preference shares with terms and conditions that could discourage a takeover or other transaction that holders of some or a majority of the common shares might believe to be in their best interests or in which holders might receive a
premium for their shares over the then market price of the shares.
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A general prohibition on business combinations between Foster Wheeler Ltd. and an
interested member. Specifically, business combinations between an interested member
and Foster Wheeler Ltd. are prohibited for a period of five years after the time the
interested member acquires 20% or more of our outstanding voting shares, unless the
business combination or the transaction resulting in the person becoming an interested
member is approved by the board of directors prior to the date the interested member
acquires 20% or more of the outstanding voting shares.
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Business combinations is defined broadly to include amalgamations or consolidations with
Foster Wheeler Ltd. or our subsidiaries, sales or other dispositions of assets having an
aggregate value of 10% or more of the aggregate market value of the consolidated assets,
aggregate market value of all outstanding shares, consolidated earning power or consolidated
net income of Foster Wheeler Ltd., adoption of a plan or proposal for liquidation and most
transactions that would increase the interested members proportionate share ownership in
Foster Wheeler Ltd.
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Interested member is defined as a person who, together with any affiliates and/or
associates of that person, beneficially owns, directly or indirectly, 20% or more of the
issued voting shares of Foster Wheeler Ltd.
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Any matter submitted to the shareholders at a meeting called on the requisition of
shareholders holding not less than one-tenth of our paid-up voting shares to be approved by
the affirmative vote of all of the shares eligible to vote at such meeting.
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These provisions could make it more difficult for a third-party to acquire us, even if the
third-partys offer may be considered beneficial by many shareholders. As a result, shareholders
may be limited in their ability to obtain a premium for their shares.
We are a Bermuda company and it may be difficult to enforce judgments against us or our directors
and executive officers.
We are a Bermuda exempted company. As a result, the rights of our shareholders will be
governed by Bermuda law and by our memorandum of association and bye-laws. The rights of
shareholders under Bermuda law may differ from the rights of shareholders of companies incorporated
in other jurisdictions. A substantial portion of our assets are located outside the United States.
It may be difficult for investors to enforce in the United States judgments obtained in U.S.
courts against us or our directors based on the civil liability provisions of the U.S. securities
laws. Uncertainty exists as to whether courts in Bermuda will enforce judgments obtained in other
jurisdictions, including the United States, under the securities laws of those jurisdictions or
entertain actions in Bermuda under the securities laws of other jurisdictions.
Our bye-laws restrict shareholders from bringing legal action against our officers and directors.
Our bye-laws contain a broad waiver by our shareholders of any claim or right of action, both
individually and on our behalf, against any of our officers or directors. The waiver applies to
any action taken by an officer or director, or the failure of an officer or director to take any
action, in the performance of his or her duties, except with respect to any matter involving any
fraud or dishonesty on the part of the officer or director. This waiver limits the right of
shareholders to assert claims against our officers and directors unless the act or failure to act
involves fraud or dishonesty.
65
ITEM 6. EXHIBITS
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Exhibit No.
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Description
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3.1
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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.)
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3.2
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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.)
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3.3
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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.)
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3.4
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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.)
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10.1
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Consulting Agreement, dated September 1, 2007, between John T. La Duc and Foster Wheeler
Inc.
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31.1
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Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 of Raymond J.
Milchovich
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31.2
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Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 of Franco Baseotto
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32.1
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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
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32.2
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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
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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 7, 2007
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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 7, 2007
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/s/
Franco Baseotto
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Franco Baseotto
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Executive Vice President and
Chief Financial Officer
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67
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